Solar Now

Hydro-Québec has introduced a grant offering up to CAD 1,000 ($718.40) per kilowatt installed, covering up to 40% of eligible costs to accelerate rooftop solar adoption and reduce payback periods for residential and business customers in the Canadian province of Québec.
Image: Hydro Québec
Provincial utility Hydro-Québec has launched a new grant program aimed at residential and commercial customers installing PV systems, as part of its broader strategy to expand solar generation in Québec, Canada.
The program provides CAD 1,000/kW of installed capacity and can cover up to 40% of eligible project costs. According to the utility, typical residential systems range between CAD 5,000 and CAD 6,000 in total costs, while business installations average around CAD 45,000.
Hydro-Québec said the initiative is designed to shorten payback periods for customers who choose to become self-generators. It expects typical payback times to fall from between 25 and 30 years to around 10 to 12 years under the new program.
Residential customers can apply through the LogiVert Efficient Homes Program, provided installations were completed on or after June 30, 2025, and meet program eligibility requirements. Business customers must apply via the OSE calculation tool under the Efficient Solutions Program, with projects required to meet technical and administrative criteria and be purchased after March 31, 2026.
The utility also allows participants to enroll in a net metering option, enabling them to export surplus electricity to the grid in exchange for kilowatt-hour credits. Hydro-Québec has increased the maximum self-generation capacity under this option from 50 kW to 1 MW over the past months.
To qualify for the grant, all installations must secure authorization for grid connection from Hydro-Québec and comply with the technical standards set out under the relevant residential and commercial program frameworks.
Canada’s installed PV capacity stood at around 5.4 GW at the end of 2025, with Québec contributing just 17 MW of the cumulative total. The new grant program is part of Hydro-Québec’s broader push to close that gap, alongside a 300 MW utility-scale solar tender launched last year and a long-term target of integrating 3 GW of solar into the provincial grid by 2035, driven by rising electricity demand.
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 Brian Publicover
Please be mindful of our community standards.
Your email address will not be published. Required fields are marked *
Comment *
Name *
Email *
Website
Save my name, email, and website in this browser for the next time I comment.


Δ
By submitting this form you agree to pv magazine using your data for the purposes of publishing your comment.
Your personal data will only be disclosed or otherwise transmitted to third parties for the purposes of spam filtering or if this is necessary for technical maintenance of the website. Any other transfer to third parties will not take place unless this is justified on the basis of applicable data protection regulations or if pv magazine is legally obliged to do so.
You may revoke this consent at any time with effect for the future, in which case your personal data will be deleted immediately. Otherwise, your data will be deleted if pv magazine has processed your request or the purpose of data storage is fulfilled.
Further information on data privacy can be found in our Data Protection Policy.
Legal Notice Terms and Conditions Data Privacy © pv magazine 2026
Δ
This website uses cookies to anonymously count visitor numbers. View our privacy policy. ×
The cookie settings on this website are set to “allow cookies” to give you the best browsing experience possible. If you continue to use this website without changing your cookie settings or you click “Accept” below then you are consenting to this.
Close

source

Adani Green Energy Limited (AGEL) added over 5 GW (5,051 MW) of renewable energy in the financial year 2025-26. It claims this is the highest annual greenfield expansion by any company globally outside China. The new capacity includes 3.4 GW of solar, 0.7 GW of wind, and 1 GW of hybrid projects, expected to offset around 10 million tonnes of carbon emissions each year. Most of the new capacity was installed at AGEL’s Khavda, Gujarat site, the world’s largest renewable energy project, which now has 9.4 GW of cumulative capacity. Spread across 538 km² – 5 times the size of Paris – the project is planned to reach 30 GW by 2029. AGEL also commissioned 1,376 MWh of battery storage in Khavda, helping stabilize the grid and integrate renewable power. With a total operational portfolio of 19.3 GW, the company says it is reinforcing India’s position as a global leader in renewable energy. “Our addition of over 5 GW is a major milestone for India’s clean energy sector and moves us closer to our target of 50 GW by 2030,” said Sagar Adani, Executive Director, AGEL. 
Macquarie Asset Management-backed Blueleaf Energy has commissioned its 300 MW Pachora Hybrid Power Project in Madhya Pradesh. Valued at around INR 1,900 crore, the utility-scale project combines wind and solar generation across 40 sites spanning 347 ha. The project is designed to produce nearly 600 million units of electricity annually, enough to power over 550,000 households. Blueleaf says it will sell the energy on the Indian power market through a 15-year power purchase agreement (PPA) with a major Indian trader. Additionally, it will provide international Renewable Energy Credits (I-RECs) under a separate 15-year contract to a large international technology company. The project features 35 wind turbines, a multi-site solar farm, and a dedicated substation. It stressed that delivering consistent power day and night improves system efficiency and reduces the need for grid expansion. The company is also progressing with solar developments in Rajasthan, with full delivery expected later this year. 
Serentica Renewables India Pvt. Ltd has partnered with Cairn Oil & Gas and Sanathan Polycot Private Limited to deliver hybrid renewable energy solutions across industrial sectors. Under a 25 MW agreement with Cairn, 20% of power demand at India’s largest onshore oil-producing asset, the Mangala facility in Barmer, Rajasthan, will be met through solar and wind energy from Serentica’s Gadag facility in Karnataka. The project is expected to reduce Cairn’s operational carbon emissions by around 115 kilotonnes of CO₂e annually and deliver approximately 153 million units of renewable energy each year.   
Separately, Serentica has signed a long-term PPA with Sanathan Polycot, forming a special purpose vehicle (SPV) to supply 32 MW of round-the-clock renewable power to its manufacturing facility in Punjab. Sanathan holds a 26% stake in the SPV, ensuring reliable and cost-efficient green energy to support its sustainability goals.  
Indian solar EPC Rays Power Infra Limited has secured a 200 MW round-the-clock (RTC) renewable energy supply order from the Indian Railways. Secured through its subsidiary Bhalki Solar Power, the project will supply clean energy to Railways Energy Management Company Limited (REMCL). The company said that the project will integrate more than 700 MW of solar and capacity, supported by over 1,000 MWh of battery energy storage system (BESS). The project is scheduled to come online by June 2028. It will deploy modules produced by its subsidiary, Rays Green Energy, at its upcoming facility in Madhya Pradesh.  
Jindal Renewables India has announced a 150 MW RTC power purchase agreement with Northern Railways. The deal guarantees at least 50% supply of the contracted capacity every 15-minute time block, supported by a combination of solar, wind, and storage. It is the company’s maiden non-captive offtake agreement. Jindal says it complements its 3 GW of captive power currently under advanced construction. 
Inox Clean Energy Limited has completed its acquisition of Macquarie-backed Vibrant Energy, with its total portfolio of 1.34 GW, valuing it at approximately $550 million. An independent power producer (IPP), Vibrant Energy operates commercial and industrial (C&I) projects that are spread across multiple Indian states, including Madhya Pradesh, Maharashtra, Karnataka, Telangana, and Andhra Pradesh. Inox Clean had reached an agreement to acquire Vibrant Energy in December 2025 (see India Solar PV News Snippets).  
NewEnergie Renewables Limited, an ISO-certified solar tracker manufacturer from Navi Mumbai, has announced it has reached the milestone of more than 500 MW of solar tracker installations. It claims the company’s advanced tracking systems – single-axis, tilted module, and dual-axis (patent pending) – offer up to 30% higher energy generation while enhancing land-use efficiency and reducing costs. NewEnergie says its trackers are designed for durability and optimized for BESS with improved project economics. It operates a 2 GW manufacturing facility in India. 
TaiyangNews 2024

source

Published 1:30 am Wednesday, March 18, 2026
By Pat Call For The Beachcomber
Workers install a new solar photovoltaic system at Vashon Center for the Arts’ Kay White Hall. (Kevin Jones Photo)
With support anticipated through a planned gift, Vashon Center for the Arts expects Kay White Hall to have a new look by the end of February. A 100-kilowatt solar photovoltaic (PV) system is planned for the south and west roofs. This project reflects the donor’s wish to make a positive impact in the community, and VCA will plan a ceremony in the near future to recognize the donor and formally unveil the installation.
The system will be comprised of 210 individual panels and is projected to offset over 60% of the annual energy usage for the building. VCA, having committed to the project in December 2025 before the expiration of the federal tax credits for renewable energy, will get a 40% rebate on the cost of the installation.
Over the estimated twenty-year lifetime, the average cost of PV power will be about nine cents per kWh (PSE, the local utility, currently charges about 16 cents per kWh). Initial savings of over $16,000 per year will only go up as electricity costs climb in future years. The money saved will be reinvested into VCA’s programs and operations.
Beyond the financial savings, this installation represents a significant step toward long-term community resilience. As the Kay White Hall serves as a vital cooling and warming center for islanders during extreme weather, reducing reliance on the external grid during peak demand ensures a sustainable haven remains for years to come. This PV system lays the groundwork for future energy independence and reinforces VCA’s role in supporting the island community.
Executive Director, Allison Reid said, “VCA is proud to join a growing network of island businesses that prioritize energy independence. A key priority in the original design of the Kay was to be a leader in energy efficiency, and we received a Leed Silver award in recognition of this hard effort. The solar panels are fulfilling even more of that original mission and promise to our Island.”
The system size was determined by the “net metering” limit imposed by PSE. 100kW is the largest system size that is allowed to participate in that program. “Net metering” means that when there is more solar power being generated than consumed in the building the residual goes back into the grid and currently is compensated at the retail price of electricity. PSE has announced plans to modify that formula to a less favorable rate. Getting grandfathered into the current “net metering” program was another factor in the decision to install solar now.
According to the China Photovoltaic Industry Association, China is producing more than 200 gigawatts (a billion watts) of PV capacity per year. To put that number in perspective the entire United States electric generation capacity is about 1,300 gigawatts. So, China is currently producing photovoltaic capacity at an annual rate that is comparable to about one-sixth of the total current US electricity generating capacity. And to connect back to the local community it would take China about 17 seconds to produce the panels for the VCA installation.
In the second year of the Carter administration (1977) the government created the Solar Energy Research Institute which set goals for the cost effectiveness of photovoltaic systems.
The interim milestone was for a price under $25 per watt by 1985. So, the unsubsidized cost of the VCA system at about $3/watt shows how much the scaleup in production has caused the price to drop. At current costs this renewable energy source makes economic sense even in the relatively high latitude and rainy Northwest. To further punctuate that fact, in addition to the 100kW system at VCA a 40kW PV array is currently being installed at IGA.
In jest Board President Bruce Morser said, “we are thrilled to be adding solar to the Kay. Of course it wasn’t our first choice. In keeping with the current administration’s energy policies, we first looked into a small fluid-bed coal fired plant but sadly with the intermittent ferry service there was no way to reliably get the coal onto the island.”
Pat Call is a contributing writer for the Beachcomber, is on the Board at VCA and was employee number seven at the Solar Energy Research Institute.

source

An official website of the United States government
Here’s how you know
Official websites use .gov
A .gov website belongs to an official government organization in the United States.
Secure .gov websites use HTTPS
A lock ( ) or https:// means you’ve safely connected to the .gov website. Share sensitive information only on official, secure websites.
To mark Earth Day 2019, Federal Energy Management Program (FEMP) Director Rob Ivester and ESPC ENABLE Program Manager Ira Birnbaum joined officials from the U.S. Department of Commerce, National Institute of Standards and Technology (NIST), the energy service company (ESCO) and financier team of Legatus6 and Constellation New Energy, and Congressman Dave Trone at a ribbon-cutting ceremony for the NIST solar photovoltaic (PV) project.
The project, implemented using FEMP’s Energy Savings Performance Contract (ESPC) ENABLE program, is a 5 MW DC, 4 MW AC ground-mounted PV system using an energy sales agreement (ESA)—the second under ENABLE. It is the largest PV system installed at a civilian government agency that uses all of the produced electricity on-site, according to the National Renewable Energy Laboratory (NREL). 
The project was awarded to Legatus6, a service disabled veteran-owned small business solar developer and ESCO, with financing provided by Constellation New Energy. It was the sixteenth project awarded under ESPC ENABLE (the current number of ESPC ENABLE projects awarded now stands at 19).
The Earth Day 2019 showcase project provided an outstanding example of one of the U.S. Department of Energy’s Office of Energy Efficiency and Renewable Energy’s key objectives: energy affordability. The project represents an economical clean-energy solution that reduces government energy costs. The project generates significant infrastructure development and a boost to manufacturing, as well as excellent construction and other trades-related jobs—and all this at a cost savings to the U.S. government.
NIST installed a 5 MW DC, 4 MW AC ground-mounted PV system using an ESPC ESA.
The total contract amount is $10,225,198, making it the largest ESPC ENABLE project to date. Total guaranteed cost savings are $11,720,431. NIST currently purchases electricity from non-renewable sources at $0.1017/kWh. The proposed price for electricity produced by the solar PV system is $0.0709805 per kWh in operational year one, for a net savings of $0.0307195 per kWh. Over the 20-year contract period during which the ESCO will own, operate, maintain, repair and replace the system, NIST will gain the following benefits:
After NIST purchases the system at the end of the contract, savings are anticipated for an additional 10 years of solar generation, during which NIST is expected to save an additional $8,297,618, bringing the total net electric bill savings to almost $12 million.
After contract award, the project was acquired by Constellation New Energy, which assume its role as the owner of the solar PV system for the next 20 years. The solar PV system will be owned and operated by the ESCO for the 20-year contract period. As per ESPC ESA requirements, at the end of the contract, NIST will purchase the system at its fair market value.
FEMP provided support in terms of the ESPC ENABLE process, including advice on structuring and rating proposals, contracting, project facilitation, and technical support from NREL entailing support throughout the investment grade audit, including reviewing the final version and final proposal, and on structuring the ESPC ESA. FEMP and NREL support was provided throughout the procurement process.
A unique aspect of the project is that it was originally bid under a standard government-owned scenario before the IRS issued its ESA revenue procedure clarifying how developers could utilize renewable energy investment tax benefits in conjunction with a federal project. As a single energy conservation measure project, NIST took FEMP’s advice to bid the project on the basis of the offerors’ installed cost-per-KWh. After ranking all proposals on this basis under a government-owned scenario, the IRS revenue procedure was issued, and the offerors were asked to submit proposals under a private-ownership ESPC ESA scenario. The result was that cost to the government was significantly lower—about 25%. This dual-track bidding, while unplanned, provided a perfect case study of the benefits of using an ESPC ESA to reduce project costs and provide best value to the government.
A broadly applicable lesson the project shows is that due to improved economics of PV systems from falling technology costs in combination with using the ESPC ESA structure, there are ample opportunities to add PV at facilities even where ESPC projects were previously implemented (NIST did an earlier ESPC project at the same facility but PV was not economical at that time).
For additional project information, contact John Bollinger at NIST.
For information on ESPC ENABLE, see the information on the FEMP website under Energy and Project Procurement Development Services, or contact Ira Birnbaum at FEMP.
Committed to Restoring America’s Energy Dominance.
Follow Us

source

Sukošan Solar Power Plant Set For 45 MW Grid Connection And New 110/33 kV Substation Construction  SolarQuarter
source

The Taduff Solar Farm in South Roscommon could net the council approximately €500,000 to €600,000 in commercial rates per year, a meeting heard last week. 
The Taduff Solar Farm in South Roscommon could net the council approximately €500,000 to €600,000 in commercial rates per year. 
The farm, which extends over 130 hectares, is scheduled to be fully operational by 2028, and its rates’ income will be linked with the amount of energy produced, a meeting of the Athlone Municipal District heard lst week.
A community benefit fund of approximately €180,000, which will be established once the project is operational, will be used to support local positive initiatives, and will run for 15 years.
While some initial works have been carried out, construction on the massive solar farm is scheduled to commence at the end of this month, on the site’s entrance, infrastructure and internal access tracks. The solar panels themselves are due to be installed in September of this year.
At a recent meeting of the Athlone Municipal District, a presentation on the Taduff Solar Park by EDF Power Solutions was given to councillors by James McDermot and David Clancy.
The presentation estimated that the local authority received €1.75 million from renewable energy sources, with the solar farm expected to contribute hundreds of thousands of additional euro a year.
The operational lifespan of the project is 30 years but the developers have land rights in place with the owners for 40 years. There are currently no plans to expand the farm.
Cllr Laurence Fallon asked whether the rates would remain the same every year, or were linked to energy production.  He was informed that the rates would be linked to energy production, but the developers said they would revert to the councillors on how the rates would be calculated with regards to energy yield. There would be a baseline for the rates, he was told.
* Published as part of the Local Democracy Reporting Scheme.
More in this section




Subscribe to the Roscommon Herald digital edition today from just €1.50 per week
Sign up to our newsletter for updates on Roscommon news, sport, community notes and more






© roscommonherald.ie

source

WATCH: 'Reform Councillor Ingrid Sheard fears Lincolnshire solar farm becoming a 'solar panel graveyard'
GB NEWS
By James Saunders, 
Published: 06/04/2026
A council is backing farmers in a battle with Ed Miliband's Department for Energy over the 'land grab'
Farmers in Staffordshire fear their land is being "stolen" for massive solar developments – and are being urged to back a major campaign to stop it.
Staffordshire County Council's Stop the Solar Land Grab campaign has warned that the county's rural communities are "under attack" from huge international developers who want to carpet the countryside with solar panels.

The Amington Moors solar farm sparked fresh debate at a recent council meeting (file photo)

| PA

Farmers and the council are 'battling' Ed Miliband's Department for Energy, Andrew Mynors said

| GETTY

The council itself has confirmed 5,000 acres across the county have been ring-fenced for solar farm development, and has warned that pannelling the fields would force the county to choose between food and energy security.
Councillor Andrew Mynors said last year farmers are being repeatedly pressured by companies to sell their land for renewable energy schemes.
Then, this January, the council wrote to MPs – with discussions with the Department for Energy now underway.
The campaign says that districts and borough councils can approve planning applications for solar farms "without looking at the bigger picture across the county, and the Government is not developing the national picture fast enough".
One of those, a 55-hectare solar farm approved for land near Tamworth more than two years ago, sparked fresh debate at a recent council meeting.
Councillor Tracey Dougherty raised concerns on behalf of local residents over the development at Amington Moors.
The Amington Moors solar farm sparked fresh debate at a recent council meeting (file photo)
She asked what councillors were doing to address fears over fires, "particularly given public concerns about lithium-ion storage, emergency access, and environmental risk".
In response, Mr Mynors said: "We engaged with Tamworth Borough Council Planning, Staffordshire County Council Planning, National Grid, and the developer's UK representatives to seek clarification on matters including fire safety, emergency access and lines of accountability.
"We were advised that no battery storage is proposed for this site."
Their enquiries prompted Tamworth Borough Council to open discussions with the fire service, which had not been consulted during the original planning submission.
"However," he added, "residents have continued to express concerns about the choice of location, particularly the use of productive agricultural land, and have asked why alternative options, such as brownfield sites or rooftop installations, were not utilised in preference to this highly valued area."
Mr Mynors highlighted that farmers across Staffordshire have faced significant pressure from multinational corporations seeking to acquire their land.
He said: "A lot of discussion has been on farms and the farming community.
"We rely on farming in Staffordshire and all of the farmers we have spoken to have felt a great duress of the pressure they are having from multinational companies coming to Staffordshire and we're saying they're stealing our land."
Mr Mynors then described the situation as "a battle that Staffordshire and rural communities are taking to the Department for Energy Security and Net Zero".
Farmers and the council are 'battling' Ed Miliband's Department for Energy, Andrew Mynors said
The local authority has contacted the Government requesting improved national and regional coordination for renewable energy projects and battery storage systems.
"We are concerned about the growing number of solar farms and battery storage in rural Staffordshire," the campaign's website says.
"Currently there is no coordination on solar and alternative energy nationally or locally… Something must be done."
In response to the campaign, Energy Minister Michael Shanks said the Government "recognises the importance of good planning, local engagement, and appropriate regulation".
"We will continue to work with local authorities and stakeholders to ensure that renewable energy deployment is managed in a balanced and coordinated way," he added.

Our Standards: The GB News Editorial Charter

source

People walk across state Route 9 in downtown Springdale, Utah, July 15, 2025.
A pilot program is addressing parking issues for town visitors, Springdale, Utah, Aug. 22, 2023.
This file photo shows the Springdale Town Hall, Springdale, Utah, Dec. 6, 2021.
The sun rises over wind and solar farms in Southern Utah, location and date not specified.
Solar panels installed behind the Good Shepherd Presbyterian Church are a part of a small solar farm behind the church, St. George, Utah, Aug. 15, 2024.
Stock image of a wind farm, location and date not specified.
Visitors to Zion National Park walk past the line of cars waiting to enter, Springdale, Utah, May 26, 2025.

Reporter
People walk across state Route 9 in downtown Springdale, Utah, July 15, 2025.
People walk across state Route 9 in downtown Springdale, Utah, July 15, 2025.
A pilot program is addressing parking issues for town visitors, Springdale, Utah, Aug. 22, 2023.
Stock image of a wind farm, location and date not specified.
Visitors to Zion National Park walk past the line of cars waiting to enter, Springdale, Utah, May 26, 2025.
Springdale residents will have the option to choose clean, renewable energy beginning in early 2027.
The Public Service Commission approved the Community Clean Energy Program in March, and 19 Utah communities have opted to participate, including Springdale.
“Our general plan directs us to look for ways to become more resilient and sustainable and also protect our natural resources, particularly our air quality,” Springdale Director of Community Development Tom Dansie told St. George News. “So for all those reasons, a project that allows us to get our utilities as renewable resources fits in really well with the goals and objectives of our general plan.”
The program, spearheaded by the Utah Renewable Communities initiative, has been in the works since 2019, when then-Gov. Gary Herbert signed Utah HB 411, dubbed the Community Renewable Energy Act, into law. The act directs the Public Service Commission to implement a 100% renewables plan in communities across the state in collaboration with Rocky Mountain Power. 
This file photo shows the Springdale Town Hall, Springdale, Utah, Dec. 6, 2021.
“All 19 communities in our coalition are served by Rocky Mountain Power. That’s part of the statute that underlies the program,” said Glade Sowards, the Senior Energy and Climate program manager in Salt Lake City. “It’s giving those Rocky Mountain Power customers and those communities the choice to continue participating, which will happen once the ordinance is adopted, or to opt out.”
What that means for Springdale is that, in late 2026, residents will receive notices about the Community Clean Energy Program, which will reportedly include details on an additional $4-per-month charge and instructions on how to opt out if they so choose. Businesses or commercial customers will pay based on usage.
Then, in early 2027, customers who do not opt out will begin receiving services from the program, which will include a new line item on their Rocky Mountain Power bill listed as “Schedule 100,” according to Utah Renewable Communities. 
Customers who prefer to opt out will have 60 days to do so without being charged a termination fee, according to Utah Renewable Communities. If residents choose to leave the program after that 60-day window, a $30 fee will be imposed for non-commercial customers. For businesses, the cost will vary. Whether customers remain enrolled or opt out, their utility provider will remain listed as Rocky Mountain Power. 
The sun rises over wind and solar farms in Southern Utah, location and date not specified.
“Rocky Mountain Power cooperated with communities, Utah legislators and the PSC to advise about changes to state energy policy changes and program design so participating communities could achieve their renewable energy goals,” Tim Solomon, director of community relations, Rocky Mountain Power, said in a press release provided to St. George News. “We’ll continue to assist communities as they make further efforts to move the program forward.”
Each month, a portion of the money collected from the additional $4 residential charge will be allocated to a low-income assistance fund to provide bill credits for qualifying customers. Another portion, Sowards said, will be used to fund the acquisition of renewable resources at scale. Utah Renewable Communities undertook a separate process with the Service Commission last year to obtain approval to issue a call for renewable energy proposals to be acquired for the program. 
“We received 14 qualifying bids, and we’ve been narrowing that down to a list of what we call our final short list of top candidate projects,” Sowards said. “Then we will forward as an agency in conjunction with Rocky Mountain Power to do a purchase agreement with one of those projects initially.”
Although the bids are still under negotiation, which prevents Sowards from sharing specific details, he said that examples of viable projects could include solar, wind, geothermal and hydroelectric proposals.
“A common example might be a solar farm,” he added.
Solar panels installed behind the Good Shepherd Presbyterian Church are a part of a small solar farm behind the church, St. George, Utah, Aug. 15, 2024.
Regardless of which projects are chosen by the agency, Springdale residents will have the opportunity to utilize renewable energy resources as soon as the power begins to flow in early 2027. 
“The Utah Renewable Communities program creates a new pathway for residents and businesses to support clean energy in our own communities,” said Springdale Town Council Member Randy Aton in a press release provided to St. George News. “It balances Springdale’s sustainability goals with long-term energy needs while making clean energy accessible to more Utahns.”
Reporter
{{description}}
Email notifications are only sent once a day, and only if there are new matching items.
Success! An email has been sent to with a link to confirm list signup.
Error! There was an error processing your request.
Each day’s obituaries, delivered to your inbox.
Get the latest headlines on local sports!
Get our expert short-term forecast, summary of the weather details and news of any severe weather.
We’ll send breaking news and news alerts to you as they happen!
We’ll send News at 8pm to your inbox!
We’ll send News at Noon to your inbox!
Receive Sunday Local Offers Coupons from St. George News.
Best trending stories from the week.
Receive Weekly News, Breaking News, Local Savings and/or a Birthday text with a gift. Sign up for one or all 4 of the text groups.
Your browser is out of date and potentially vulnerable to security risks.
We recommend switching to one of the following browsers:
Sorry, an error occurred.

Already Subscribed!

Cancel anytime
Account processing issue – the email address may already exist
Each day’s obituaries, delivered to your inbox.
Get the latest headlines on local sports!
Get our expert short-term forecast, summary of the weather details and news of any severe weather.
We’ll send breaking news and news alerts to you as they happen!
We’ll send News at 8pm to your inbox!
We’ll send News at Noon to your inbox!
Receive Sunday Local Offers Coupons from St. George News.
Best trending stories from the week.

Thank you .
Your account has been registered, and you are now logged in.
Check your email for details.
Invalid password or account does not exist
Submitting this form below will send a message to your email with a link to change your password.
An email message containing instructions on how to reset your password has been sent to the email address listed on your account.
No promotional rates found.

Secure & Encrypted
Secure transaction. Secure transaction. Cancel anytime.

Thank you.
Your gift purchase was successful! Your purchase was successful, and you are now logged in.
A receipt was sent to your email.

source

Rooftop solar generating capacity in Puerto Rico totaled 1,456 megawatts (MW) at the end of 2025, 20% of the overall capacity mix. Rooftop solar capacity has increased faster than other sources over the past decade. Between 2016 and 2025 rooftop solar installations accounted for 81% of the new generating capacity in Puerto Rico, according to data from our Electric Power Monthly and Puerto Rico Energy Bureau’s (PREB) Quarterly Report on System Data. In 2025, rooftop solar became the second-largest capacity source, after petroleum liquids capacity (3,671 MW), and surpassed natural gas capacity (1,391 MW).
Distributed generation resources, particularly rooftop solar coupled with battery systems, have grown as Puerto Rico has grappled with electricity reliability and frequent power outages. On average, 3,850 rooftop solar panel systems were installed in homes and businesses per month in 2025, with a cumulative 191,929 systems in place at the end of the year.
In addition to rooftop solar capacity, distributed battery storage has also increased in Puerto Rico. According to data from PREB, 171,372 households and businesses had a distributed battery storage system at the end of 2025, with a total energy capacity of 2,864 megawatt-hours.
Puerto Rico established net metering policies in August 2007 allowing rooftop solar owners to sell excess electricity to the grid. Last summer, Puerto Rico’s grid operator, LUMA, expanded the Customer Battery Energy Sharing program, allowing power stored in distributed battery storage units to supply power to the grid when the operator forecasts electricity supply shortages. Thousands of these batteries form systems known as virtual power plants (VPP). VPPs are an aggregation of geographically dispersed distributed energy resources, like batteries that can dispatch power to the grid as one singular power plant. Companies like Sunrun, Tesla, and others work with LUMA and manage these VPPs. Participating battery owners are financially compensated for exporting excess electricity to the grid.
Article from Today in Energy. Principal contributor: Lindsay Aramayo
CleanTechnica’s Comment Policy
The EIA collects, analyzes, and disseminates independent and impartial energy information to promote sound policymaking, efficient markets, and public understanding of energy and its interaction with the economy and the environment.
US Energy Information Administration has 330 posts and counting. See all posts by US Energy Information Administration

source

We use cookies to improve your experience and for marketing. Read our cookie policy or manage cookies.
Search across reports, market insights, and blog stories.
Tell us where to send the sample and whether you want this report customized.
Thanks. Our team will review your request and get back to you at your business email.
Your request will be reviewed by our team and routed to support@indexbox.io.
According to the latest IndexBox report on the global Glass Cutting Machine market, the market enters 2026 with broader demand fundamentals, more disciplined procurement behavior, and a more regionally diversified supply architecture.
The global glass cutting machine market is poised for a significant transformation over the 2026-2035 forecast horizon, transitioning from a tool-based industry to a solutions-oriented sector centered on precision, automation, and material efficiency. This evolution is underpinned by the dual forces of industrial modernization and the global push for sustainable infrastructure. Demand is bifurcating: high-volume, standardized cutting lines for commoditized applications like basic architectural glass, and highly sophisticated, integrated systems capable of processing complex, value-added glass for automotive, display, and renewable energy sectors. The latter segment, driven by technological innovation in laser and waterjet cutting, CNC accuracy, and in-line quality control, is expected to capture disproportionate value growth. Market expansion will be supported by capital investment in new flat glass production capacity, particularly in Asia-Pacific, and the retrofitting of existing lines with more efficient, digitalized equipment in mature economies. However, the market faces headwinds from cyclical downturns in construction, supply chain vulnerabilities for critical components like precision guides and CNC controllers, and intense price competition in entry-level machine segments. This analysis provides a detailed forecast, segment breakdown, and examination of the commercial and technological dynamics shaping the next decade of glass processing equipment.
The baseline scenario for the glass cutting machine market from 2026 to 2035 projects steady expansion, anchored in the fundamental growth of its core end-use industries rather than speculative new applications. The market’s trajectory is intrinsically linked to global capital expenditure in construction, automotive production, and renewable energy infrastructure. In this scenario, architectural glass remains the volume anchor, with demand for machines tracking the construction of commercial buildings and high-rise residential projects, particularly in urbanizing emerging economies. Automotive glass demand follows vehicle production cycles and the trend toward larger, more complex panoramic sunroofs and lightweight glazing, requiring advanced contour cutting systems. The solar panel glass segment is forecast to be the highest-growth driver, necessitating high-throughput, precision scribing and cutting machines as global solar capacity targets escalate. The market will see a continued shift from manual and semi-automatic tables toward fully automated, CNC-controlled lines and non-contact laser/waterjet systems, driven by the need for higher yield, reduced labor costs, and the ability to process newer, thinner, and coated glass variants. Competitive intensity will remain high, with established European and Japanese manufacturers defending premium positions through innovation, while Chinese and other Asian producers expand share in volume segments via cost-competitive offerings. The overall market growth will be modulated by raw material (flat glass) price volatility, interest rate-sensitive investment cycles, and the pace of automation adoption in small and medium-sized glass processors.
This segment constitutes the largest volume demand for glass cutting machines, primarily for processing flat glass into panels for windows, facades, and interior applications. Current demand is driven by global construction activity, with a focus on energy-efficient building envelopes requiring coated and laminated glass. Through 2035, the trend will shift from simple rectangular cuts to more complex shapes for bespoke architectural designs, necessitating greater CNC flexibility. Demand will also be fueled by the retrofit market for building renovation. Key demand-side indicators are global construction spending, commercial building starts, and regulatory standards for energy efficiency (e.g., LEED, BREEAM). The mechanism is direct: new building projects and facade renovations specify glass, which requires cutting, driving orders for both new machines and replacement/upgrades in glass processing plants. The push for larger, jumbo-sized glass panels is particularly demanding, requiring machines with bigger beds and higher precision to minimize material waste. Current trend: Stable growth with premiumization toward larger formats and smart glass..
Major trends: Adoption of jumbo glass processing lines for oversized facade panels, Integration of automated loading/unloading and sorting systems to streamline high-volume production, Growing demand for machines capable of cutting laminated and coated glass without edge delamination or coating damage, and Increased use of waterjet cutting for complex architectural shapes and decorative openings.
Representative participants: Guardian Glass, Saint-Gobain, AGC Inc, Vitro, and Central Glass.
Automotive glass cutting is a high-precision segment requiring machines to handle curved, tempered, and laminated glass for windshields, side windows, and increasingly, large panoramic roofs. The current phase is characterized by the transition to more complex 3D shapes and the integration of sensors (for ADAS) into the glass. Through 2035, demand will be accelerated by electric vehicle (EV) production, which often features larger glass surfaces for aesthetic and aerodynamic purposes, and the trend toward lightweighting. The critical demand indicator is global automotive production, with a specific focus on EV output and premium vehicle segments. The mechanism is technology-pull: automotive OEMs and tier-1 glass suppliers (like AGC, Fuyao) invest in advanced cutting and preliminary shaping equipment to meet stringent OEM specifications for fit, safety, and optical quality. This segment demands the highest level of automation, traceability, and integration with downstream tempering and bending processes. Current trend: Strong growth driven by complex glazing and electric vehicle adoption..
Major trends: Rising demand for CNC and waterjet systems to cut complex 3D contours for panoramic roofs and wrap-around windows, Integration of machine vision for 100% defect inspection inline with the cutting process, Machines adapted for processing thinner, lightweight glass to improve vehicle efficiency, and Growing need for flexible cells that can handle multiple glass variants for mixed-model production.
Representative participants: Fuyao Glass, AGC Automotive, Saint-Gobain Sekurit, Vitro Automotive, and Xinyi Glass.
This is the fastest-growing end-use segment, involving the cutting and often edge deletion of low-iron, tempered glass used as covers for photovoltaic (PV) modules. Current demand is surging due to global policy support for renewable energy, leading to massive investments in new PV gigafactories. The process requires high-throughput, high-precision cutting (often laser scribing and mechanical breaking) to maximize yield from large glass sheets. Through 2035, demand will be sustained by the continued global rollout of solar farms and distributed rooftop PV. Key indicators are annual PV capacity additions, government renewable energy targets, and capital expenditure announcements by PV panel manufacturers. The mechanism is capacity-driven: each new GW of panel manufacturing capacity requires a corresponding investment in glass processing lines. Efficiency gains in cutting technology, which reduce glass waste (kerf loss), are a major purchasing driver as manufacturers seek to lower module production costs. Current trend: Rapid expansion as global solar capacity targets drive manufacturing investment..
Major trends: Dominance of laser scribing and breaking systems for clean, high-speed processing of tempered solar glass, Machines designed for larger glass format sizes (e.g., for 210mm+ wafers) to improve panel power output, Integration of automated handling to manage thin, fragile glass sheets with minimal breakage, and Demand for systems that can process anti-reflective coated glass without damaging the coating.
Representative participants: LONGi Green Energy, Jinko Solar, Trina Solar, Canadian Solar, and First Solar.
This segment encompasses the cutting of glass for tables, shelves, shower enclosures, partitions, and decorative elements. Demand is currently linked to residential and hospitality construction and renovation cycles. The segment is highly fragmented, serving both large furniture manufacturers and small artisanal workshops. Through 2035, growth will be supported by interior design trends favoring glass for its modern aesthetic and perceived spaciousness. Demand indicators include furniture production indices, retail sales of home improvement products, and hospitality sector investment. The mechanism is demand for customization: unlike high-volume sectors, this segment often requires machines that are flexible, easy to program for one-off designs, and capable of producing decorative edges (bevels, grooves). This drives demand for versatile CNC machines and waterjet cutters that can handle intricate patterns. The trend toward online customization of furniture is also creating a need for digital file-to-cut automation in smaller shops. Current trend: Moderate growth with emphasis on customization and decorative processing..
Major trends: Popularity of waterjet cutting for intricate decorative patterns and shapes in interior glass, Growth of compact, affordable CNC machines for small batch and custom work in job shops, Increased processing of safety glass (tempered, laminated) for furniture and partitions, and Demand for machines that combine cutting with basic edge finishing in a single setup.
Representative participants: IKEA, Hafele, Glassolutions, and Regional fabricators and processors.
This segment involves cutting glass for home appliance panels (ovens, refrigerators), touchscreen displays, and cover glass for consumer electronics. It is characterized by extremely high precision requirements and the handling of thin, often chemically strengthened glass. Current demand is driven by consumer electronics refresh cycles and smart appliance adoption. Through 2035, growth will be fueled by the proliferation of touch interfaces in appliances, automotive displays, and new consumer devices. Key demand indicators are global smartphone, TV, and appliance shipment volumes. The mechanism is precision-driven: manufacturers of displays and appliances require cutting systems with micron-level accuracy, ultra-fine cutting heads (for lasers), and pristine environments to avoid micro-cracks. The shift to flexible and ultra-thin glass for foldable devices presents a new frontier for cutting technology. This segment is less volume-driven than architectural glass but commands a premium for technology and is a key R&D focus for machine builders. Current trend: Technology-driven demand for precision in thin and specialty glass..
Major trends: Laser cutting as the dominant technology for thin, brittle display glass due to its non-contact, crack-free advantages, Machines integrated into cleanroom-compatible environments for high-end display manufacturing, Growing need for systems to cut curved glass for appliance control panels and automotive displays, and Development of ultrafast lasers for processing next-generation glass-ceramics and strengthened glass.
Representative participants: Corning Incorporated, Schott AG, Nippon Electric Glass, LG Hausys, and Asahi Glass.
Interactive table based on the Store Companies dataset for this report.
Asia-Pacific is the undisputed engine of the global market, accounting for over half of demand. This dominance is fueled by massive investments in solar panel manufacturing in China and Southeast Asia, a robust automotive production base in China, Japan, and India, and sustained construction activity. China is both the largest consumer and a leading producer of glass cutting machines, with local manufacturers competitive in mid-range segments. The region will see the highest volume growth, though price competition remains intense. Direction: Dominant and growing.
Europe represents a mature, high-value market characterized by demand for advanced, automated systems. Growth is driven by the region’s leadership in automotive premium segments (requiring complex glazing), stringent building energy regulations pushing high-performance architectural glass, and a strong solar panel manufacturing base. European machine manufacturers (e.g., Bystronic, Lisec) are global technology leaders, particularly in automated lines and software integration. Demand is for retrofitting and upgrading existing facilities for higher efficiency. Direction: Mature with premium focus.
The North American market exhibits steady growth, supported by reshoring trends in some manufacturing sectors, healthy non-residential construction, and investments in solar energy under supportive policies like the Inflation Reduction Act. The automotive sector is a key consumer, especially for trucks and SUVs featuring large glass areas. The market is technologically advanced, with strong adoption of automation and a preference for integrated solutions from established global and regional suppliers. Direction: Steady growth.
Latin America is an emerging market with growth potential tied to economic stability and infrastructure development. Brazil and Mexico are the primary markets, driven by automotive production (serving domestic and export markets) and construction activity. Demand is primarily for cost-effective, reliable machines, with growing interest in automation as labor costs rise. The market is price-sensitive, offering opportunities for competitive Asian manufacturers. Direction: Emerging potential.
This region presents niche growth opportunities, largely concentrated in the Gulf Cooperation Council (GCC) countries. Demand is propelled by mega construction projects requiring vast quantities of architectural glass and, increasingly, investments in solar power generation (e.g., Saudi Arabia’s Vision 2030). The market is characterized by high-value projects but is volatile and dependent on oil prices and government spending. Import dependency for high-end machinery remains high. Direction: Niche growth.
In the baseline scenario, IndexBox estimates a 4.8% compound annual growth rate for the global glass cutting machine market over 2026-2035, bringing the market index to roughly 162 by 2035 (2025=100).
Note: indexed curves are used to compare medium-term scenario trajectories when full absolute volumes are not publicly disclosed.
For full methodological details and benchmark tables, see the latest IndexBox Glass Cutting Machine market report.
This report provides an in-depth analysis of the Glass Cutting Machine market in the World, including market size, structure, key trends, and forecast. The study highlights demand drivers, supply constraints, and competitive dynamics across the value chain.
The analysis is designed for manufacturers, distributors, investors, and advisors who require a consistent, data-driven view of market dynamics and a transparent analytical definition of the product scope.
This report covers the global market for machinery and equipment specifically designed for cutting, scoring, and separating glass. The analysis encompasses a range of technologies used to process flat glass, including automated systems for high-volume production and specialized machines for precision work in various industrial and artisanal applications.
The market is segmented and analyzed by product type (e.g., CNC, laser, waterjet, manual), application (architectural, automotive, solar, furniture, etc.), and value chain position. This provides a detailed view of demand drivers, technological adoption, and supply dynamics across different machine categories and end-user industries.
World
The analysis is built on a multi-source framework that combines official statistics, trade records, company disclosures, and expert validation. Data are standardized, reconciled, and cross-checked to ensure consistency across time series.
All data are normalized to a common product definition and mapped to a consistent set of codes. This ensures that comparisons across time are aligned and actionable.
Making Data-Driven Decisions to Grow Your Business
A Quick Overview of Market Performance
Understanding the Current State of The Market and its Prospects
What Is Included and How the Market Is Defined
How the Market Is Split into Comparable Segments
Upstream Inputs, Manufacturing Landscape and Go-to-Market
End-Use Drivers and Adoption Requirements
Finding New Products to Diversify Your Business
Choosing the Best Countries to Establish Your Sustainable Supply Chain
Choosing the Best Countries to Boost Your Export
The Latest Trends and Insights into The Industry
The Largest Import Supplying Countries
The Largest Destinations for Exports
The Key Company Types and Market Structure
The Largest Markets And Their Profiles
Part of Conzzeta, strong in flat glass
Major supplier for architectural & automotive glass
Integrated cutting, washing, insulating systems
Wide range for flat & shaped glass
Part of the Swiss Glaston group
Part of the Biesse Group
Part of the Glaston group
Strong in architectural glass machinery
Specialist in finishing machinery
Part of the AGC group
Exports globally
Wide product portfolio
Cutting, tempering, coating lines
Specialist in cutting tools/accessories
Manufacturer and exporter
Specialist for shaped cutting
Precision machinery
Known for automated sorting & cutting
Exports to over 80 countries
Subsidiary of Shenyang North Glass
Serves domestic and export markets
Manufacturer of POLNA brand machines
Includes cutting in integrated lines
Growing exporter
Wide range of affordable machines
Instant access. No credit card needed.
Online access to 2M+ reports, dashboards, and tables. Trusted by Fortune 500 teams.
IndexBox, Inc.
2093 Philadelphia Pike #1441
Claymont, DE 19703, USA
Contact us
© 2026 IndexBox, Inc
Instant access. No credit card needed.
Online access to 2M+ reports, dashboards, and tables. Trusted by Fortune 500 teams.

source

+ 787.30
+ 255.15
 -69.00
+ 380.00
+ 1,569.00
+ 787.30
+ 255.15
+ 255.15
 -69.00
 -69.00
+ 380.00
Kotak Institutional Equities
Target: ₹250
CMP: ₹223.80
We initiate coverage on Emmvee Photovoltaic with an Add rating and a DCFbased Fair Value of ₹250 (13.0X March 2028E EPS).
Our FV implies Emmvee capacity to see 10/15 per cent CAGR for module and cell capacities, respectively, 20/30 per cent volume CAGR for Emmvee’s module and cell volumes until FY2035, driven by capacity addition and utilisation levels of about 60 per cent for modules and 80 per cent for cells, a contraction of EBITDA margins from 34 per cent in FY2025 to 14 per cent in FY2035, factoring in heightened competitive intensity, a cost of equity of 14.5 per cent and WACC of 11.6 per cent and terminal value of 1.5X FY2035 book value (in line with Chinese solar companies’ valuations).
Emmvee is currently setting up a 6 GW integrated cell and module manufacturing unit, which will take its total capacity to 16.3 GW and 8.9 GW module and cell, respectively, making it the fourth largest player in India.
Given the implementation of ALMM list II from June 1, 2026, this will enable Emmvee to benefit from superior profitability relative to peers in the medium term.
Key risks: Lack of diversification away from the solar PV module value chain, increasing margin risks, changes in the domestic policy environment, delay in getting cell capacity on stream, slower-than-expected growth in renewable capacity addition and faster-than-expected ramp-up of competitors’ cell capacities.
Published on April 6, 2026
Copyright© 2026, THG PUBLISHING PVT LTD. or its affiliated companies. All rights reserved.
BACK TO TOP
Comments have to be in English, and in full sentences. They cannot be abusive or personal. Please abide by our community guidelines for posting your comments.
We have migrated to a new commenting platform. If you are already a registered user of TheHindu Businessline and logged in, you may continue to engage with our articles. If you do not have an account please register and login to post comments. Users can access their older comments by logging into their accounts on Vuukle.
Terms & conditions  |  Institutional Subscriber

source

Photo: PPC Group
Published
April 6, 2026
Country
Greece
Author
Igor Todorović
Comments
0
Print
Share
Published:
April 6, 2026
Country:
Greece
Author
Igor Todorović
Comments:
0
Print
Share
Construction works for PPC Group’s photovoltaic plants in Amyntaio and Ptolemaida in northern Greece have been completed. The state-controlled power utility utilizes former lignite mine areas as it is phasing out the solid fossil fuel. The coal exit is scheduled for this year.
Total capacity of the new complex is 2.13 GW, capable of generating 3.15 GWh per annum. It corresponds to nearly 6% of the country’s annual electricity consumption and the needs of 750,000 households. The operation of the photovoltaic stations will prevent more than 1.5 million tons of emissions annually, the company calculated.
“In a volatile geopolitical, economic, and energy environment, renewable energy sources constitute a high-value domestic asset that ensures the country’s energy independence. Greece represents a true success case study, as from 2019 to today, in less than seven years, the share of thermal generation has decreased from 67% to 50%, with PPC Group playing a crucial role in this achievement,” said the group’s Deputy Chief Executive Officer Konstantinos Mavros, responsible for renewables.
In his words, the Western Macedonia region in northern Greece is becoming the country’s new green energy hub, hosting the largest photovoltaic cluster in Europe, alongside storage units.
All the major facilities are in Western Macedonia. Phoebe, of 550 MW in peak capacity, is the second-biggest photovoltaic plant in the EU. The location is near the Agios Dimitrios coal power plant and the village of Pontokomi, between Ptolemaida and Kozani.
Estimated annual production, 880 GWh, corresponds to 1.8% of Greece’s interconnected system production, data shows.
The Amyntaio photovoltaic complex, 940 MW in peak capacity, has surpassed the 850 MW cluster of 17 units in Spain, called Escatrón-Chiprana-Samper Solar Farm, which was considered to be the largest in Europe.
The Amyntaio solar power cluster is the largest in Europe
PPC Group developed and built it in cooperation with RWE. The cluster near Florina spans Rodonas, Filotas, Lakkia and Perdikkas. Amyntaio generates an estimated 1.5 TWh per year.
Helios Velos 1 is a new PV park in the vicinity of the city of Ptolemaida. At 200 MW in peak capacity, its yearly output amounts to 320 GWh, the utility calculated.
Solar power plants Exochi 7 and Akrini both have 80 MW in peak terms, each generating an estimated 122 GWh per year. PPC Group said ten more smaller photovoltaic stations are in former lignite areas.
Of note, joint venture Ameresco Sunel Energy is building a PV plant of 560 MW in peak capacity for Lightsource bp. The area is in the central part of Greece.
PPC Renewables, a wholly-owned subsidiary of PPC Group, has completed an electrochemical energy storage station in Ptolemaida, near the Kardia coal power plant, and Meliti, near an eponymous coal plant, with a total capability of 98 MW and storage capacity of 196 MWh. They are waiting for permits to start storing and releasing electricity.
Near the Amyntaio coal power plant, construction works are underway for a battery energy storage system (BESS) of 50 MW, with 200 MWh in capacity. It means it can supply electricity to the grid for up to four hours at maximum power.

At the same time, two major pumped storage hydropower projects are maturing in former mining areas of PPC Group, having already secured the necessary regulatory approvals.
The first site is at the Kardia mine. It will have a generation capacity of 320 MW, for eight hours, which translates to 2.56 GW, the company added. The former mine would be the lower reservoir.
In the South Field mine, the group is planning a pumped storage facility of 240 MW for 12 hours. The investment cost is EUR 310 million.
The South Field pumped storage hydropower project is worth EUR 310 million
Pumped hydro mitigates the intermittency of renewable energy sources and contributes to grid stability. A typical facility includes two water reservoirs at different elevations. During low demand, excess electricity drives pumps that move water from the lower reservoir to the upper one, storing it as potential energy. When demand increases, water is released back down through turbines, generating electricity.
Engaging local communities in Kozani and Florina, PPC Group launched a bond on March 13, amounting to EUR 5 million. It gives the holders, residents, the opportunity to participate in the company’s investments in the area.
In November, the utility completed a wind farm of 36 MW in Fokida in central Greece. The seven Siemens Gamesa SG145 wind turbines are on Karkaros mountain, spanning the territories of municipal units Antikyra and Desfina. Expected output is 82.5 GWh per year.
As for the activities in surrounding countries, also five months ago, PPC commissioned a 130 MW solar farm in Călugăreni in Romania. The site south of Bucharest, in Giurgiu county, features 227,240 bifacial panels. The company expressed expectations that annual production would exceed 193 GWh.
PPC Renewables Romania intends to add a 13.5 MW / 27 MWh battery system to its Topolog (Gebeleisis) wind farm, Financial Intelligence reported last month. The project is worth RON 29.85 million (EUR 5.86 million). Up to 16.6% would be a grant via the EU’s Modernisation Fund.
The wind park, of 27 MW, consists of 11 turbines.
Be the first one to comment on this article.
Stay informed. In your Inbox once a week.
Montenegro
06 April 2026 – Representatives of the Ministry of Energy and Mining and state-owned power utility Elektroprivreda Crne Gore held talks with EDF’s delegation
Region/EU
06 April 2026 – The European Union’s grids lack the capacity to connect new renewables and meet additional electricity demand
Greece
06 April 2026 – Public Power Corp. said its new PV cluster is the biggest in Europe. It includes Phoebe, the second-largest solar park in the European Union.
Montenegro, Region/EU
03 April 2026 – The Ministry of Energy and Mining of Montenegro and Balkan Green Energy News signed a memorandum of understanding
Email: office@balkangreenenergynews.com
Phone: +381 65 88 50 557
© CENTER FOR PROMOTION OF SUSTAINABLE DEVELOPMENT 2008-2020.
website developed by ogitive

source

A study funded by NextEra Energy projects that Louisiana’s annual solar deployment will decline from 2028 through 2030 due to expiring tax credits and then rise steadily through 2035, with associated employment impacts and tax revenues for local communities.
The projected shape of Louisiana’s utility-scale solar deployment in a base case and a high-growth case.
Image: Kathleen Babineaux Blanco Public Policy Center at the University of Louisiana at Lafayette
A study by researchers at the University of Louisiana at Lafayette has projected that Louisiana’s utility–scale solar deployment will reach 12.1 GW by 2035, generating electricity equal to 27% of current generation or 17% of the generation projected in 2035.
The study assesses the effects of solar development on employment, tax revenues, land use, and rural communities. NextEra Energy provided research funding.
The researchers assumed that a “large percentage” of the 38 solar projects in Louisiana that have secured interconnection approval from grid operator MISO, totaling 5.6 GW of capacity, will be built before the OBBBA “tax credit cliff” arrives. To receive federal tax credits, projects must begin construction by July 4 or enter service by year-end 2027.
For projects still awaiting interconnection, the researchers generally assumed that 25% of those projects approval will be built, but assumed a lower completion rate for 2028 and 2029. Overall, they projected that annual deployment will decline from 2028 through 2030, and then rise from 2031 through 2035 as electricity demand increases and solar costs continue to decline.
Noting that the Louisiana Energy Users Group, whose members sought to buy clean power, successfully lobbied the Louisiana Public Service Commission to enable “sleeved” power purchase agreements, the researchers also analyzed a high growth case that could result if Louisiana industries further prioritized renewable power, or if there were a return to a favorable policy environment. The high growth case is illustrated in the featured image above.
Louisiana’s direct employment in the utility-scale solar industry is projected to rise from 4,000 jobs in 2025 to 8,000 jobs this year and next, and then decline to an average of 4,600 jobs from 2028 to 2035.
The projected increase in land requirements to build 12.1 GW of solar equals just 1.1% of Louisiana’s agricultural land area, based on a requirement of seven acres per MW.
Local government property tax revenues for a utility-scale solar development would be about 60 times greater than for a comparable agricultural property, the researchers said. That estimate is based on agricultural land property tax rates and a calculation of solar tax revenues by a representative of the Morehouse Parish Economic Development Corporation, who said that a 200 MW solar development in the parish would yield up to $180 million in property tax revenue over the project lifetime.
The researchers said that tax revenue will make “a major impact” on funding for local schools, fire and police departments, and road improvements.
The study also considers the potential for Louisiana to capitalize on supply chain opportunities to support solar projects in Louisiana and beyond.
The study, from researchers at the Kathleen Babineaux Blanco Public Policy Center at the University of Louisiana at Lafayette, is titled “The impact of utility-scale solar power in Louisiana.”
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 William Driscoll
Please be mindful of our community standards.
Your email address will not be published. Required fields are marked *
Comment *
Name *
Email *
Website
Save my name, email, and website in this browser for the next time I comment.


Δ
By submitting this form you agree to pv magazine using your data for the purposes of publishing your comment.
Your personal data will only be disclosed or otherwise transmitted to third parties for the purposes of spam filtering or if this is necessary for technical maintenance of the website. Any other transfer to third parties will not take place unless this is justified on the basis of applicable data protection regulations or if pv magazine is legally obliged to do so.
You may revoke this consent at any time with effect for the future, in which case your personal data will be deleted immediately. Otherwise, your data will be deleted if pv magazine has processed your request or the purpose of data storage is fulfilled.
Further information on data privacy can be found in our Data Protection Policy.
pv magazine USA offers daily updates of the latest photovoltaics news. We also offer comprehensive global coverage of the most important solar markets worldwide. Select one or more editions for targeted, up to date information delivered straight to your inbox.
Δ
Legal Notice Terms and Conditions Privacy Policy © pv magazine 2026
Δ
Welcome to pv magazine USA. This site uses cookies. Read our policy. ×
The cookie settings on this website are set to “allow cookies” to give you the best browsing experience possible. If you continue to use this website without changing your cookie settings or you click “Accept” below then you are consenting to this.
Close

source

11,000+ projects in Latin America.
24,000+ global companies doing business in the region.
83,000+ key contacts related to companies and projects
Analysis, reports, news and interviews about your industry in English, Spanish and Portuguese.

source

source

Roofsol Energy Signs 2 MWp OPEX Solar PPA with Whirlpool India  SolarQuarter
source

TCL Zhonghuan has agreed to take majority control of Chinese solar manufacturer DAS Solar, a producer of advanced n-type modules based on tunnel oxide passivated contact (TOPCon) and back-contact (BC) technologies.
Image: DAS Solar
TCL Zhonghuan has signed a definitive agreement to acquire control of DAS Solar through a combination of share transfers, capital injection, and voting rights delegation, in one of the most closely watched solar sector consolidation deals of 2026.
The Shenzhen-listed company, a unit of TCL Technology, said on March 30 that it had finalized transaction documents after securing a 90-day exclusive negotiation window under a framework agreement signed Jan. 16.
Under the terms of the deal, TCL Zhonghuan will pay CNY 1.258 billion ($182.7 million) in cash. This includes CNY 258 million to acquire 8.06% of DAS Solar’s pre-money equity from 50 existing shareholders, and CNY 1 billion in new capital, giving it 55.56% of post-money equity. The transaction implies a pre-investment valuation of CNY 800 million, roughly 10% of the company’s peak valuation. TCL Zhonghuan will also receive voting rights over an additional 7.20% of shares from founder Liu Yong and affiliated partnerships.
Following completion, TCL Zhonghuan will hold 59.14% of DAS Solar and control 66.34% of voting rights. DAS Solar will become a consolidated subsidiary.
The deal has been approved by TCL Zhonghuan’s board and does not require shareholder approval, according to the company. Remaining steps include state asset approvals, antitrust filing, and final closing.
Founded in 2018, DAS Solar has built significant capacity in n-type technologies. By the end of 2025, it had more than 50 GW of cell capacity and more than 70 GW of module capacity, with a strong presence in n-type TOPCon and BC module bidding in recent years.
However, the company faces financial pressure. As of the end of 2025, DAS Solar reported liabilities of CNY 14.189 billion and negative net assets of CNY 1.292 billion.
The acquisition would extend TCL Zhonghuan downstream from wafers into cells and modules, strengthening vertical integration. The company, via subsidiary Maxeon, holds BC-related intellectual property, while DAS Solar contributes manufacturing capacity. The combination could accelerate BC commercialization, according to the announcement.
Industry views are mixed. Supporters see a low-cost acquisition of a strategic asset at a depressed valuation and a signal of broader industry consolidation. Risks include near-term earnings pressure from DAS Solar’s losses, potential goodwill impairment, and integration challenges across operations, talent, and customers.
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 Vincent Shaw
Please be mindful of our community standards.
Your email address will not be published. Required fields are marked *
Comment *
Name *
Email *
Website
Save my name, email, and website in this browser for the next time I comment.


Δ
By submitting this form you agree to pv magazine using your data for the purposes of publishing your comment.
Your personal data will only be disclosed or otherwise transmitted to third parties for the purposes of spam filtering or if this is necessary for technical maintenance of the website. Any other transfer to third parties will not take place unless this is justified on the basis of applicable data protection regulations or if pv magazine is legally obliged to do so.
You may revoke this consent at any time with effect for the future, in which case your personal data will be deleted immediately. Otherwise, your data will be deleted if pv magazine has processed your request or the purpose of data storage is fulfilled.
Further information on data privacy can be found in our Data Protection Policy.
Legal Notice Terms and Conditions Data Privacy © pv magazine 2026
Δ
This website uses cookies to anonymously count visitor numbers. View our privacy policy. ×
The cookie settings on this website are set to “allow cookies” to give you the best browsing experience possible. If you continue to use this website without changing your cookie settings or you click “Accept” below then you are consenting to this.
Close

source

The Government of the Republic of Zambia, in partnership with the Kingdom of Norway, has launched a call for proposals under a new Carbon Feed In Premium programme aimed at accelerating investment in solar PV with storage.
The initiative follows a bilateral agreement signed on 16 November 2024 to develop mitigation activities and enable the transfer of internationally transferred mitigation outcomes under Article 6 of the Paris Agreement. Under this framework, Zambia will host projects that generate carbon credits for transfer to Norway, unlocking results based climate finance to support clean energy deployment.
Related news: JA Solar DeepBlue 5.0 preferred as developers seek bankable solar performance
The programme is backed by the Norwegian Article 6 Climate Action Fund, established in 2024 and managed by the Global Green Growth Institute as trustee. Through this mechanism, a fixed carbon price will be paid for verified emission reductions over a minimum period of 10 years, creating a predictable additional revenue stream for project developers.
The Carbon Feed In Premium is designed to complement existing power purchase agreement revenues rather than replace them. By topping up electricity tariffs with carbon payments, the scheme aims to close financing gaps and enable projects that would otherwise struggle to reach financial close.
The first application window focuses exclusively on grid connected solar PV projects with a combined capacity of up to 300 MW. Eligible projects must include battery energy storage systems with a minimum duration of 30 minutes to support grid stability and reduce reliance on coal based generation.
Project developers have a two month window to submit proposals, with a deadline set for 31 May 2026. Submissions will be assessed against strict eligibility criteria, including financial additionality, contribution to Zambia’s nationally determined contribution, and alignment with sustainable development goals.
Only projects demonstrating a clear financing gap will qualify. Developers must provide detailed financial models showing that the project internal rate of return falls below the benchmark commercial lending rate of 12.5% per year without the carbon premium. The programme will then bridge this gap through carbon payments linked to verified emission reductions.
In addition to financial viability, projects must demonstrate measurable development impacts, including emissions reductions, electricity generation, and job creation. Compliance with international environmental and social safeguards, including Gold Standard and Global Green Growth Institute requirements, is also mandatory.
Shortlisted projects will undergo due diligence between July and August 2026, covering technical, financial, and environmental aspects. Successful developers will enter into a standardised contract with ZANACO, acting as fund manager, which will define carbon payment terms and require the transfer of all emission reduction rights to the programme.
The scheme also introduces competitive bidding for carbon premiums by technology, marking a shift towards market-based mechanisms to allocate climate finance efficiently. Importantly, the bidding process applies only to the carbon component, while electricity tariffs remain governed by existing power purchase agreements, primarily with ZESCO.
Projects must be at an advanced stage of development but not yet under construction. Requirements include completed feasibility studies, secured land, environmental approvals, and evidence of investor interest.
By integrating carbon finance with energy infrastructure development, Zambia is positioning itself to leverage international carbon markets to scale up renewable energy capacity, improve energy security, and advance its decarbonisation objectives.
Link to the call for proposals document HERE
Author: Bryan Groenendaal
For enquiries on the African continent, email: africa@jasolar.com

 






Δ

February 26, 2026
March 18, 2026
March 16, 2026
February 25, 2026
March 16, 2026
March 23, 2026
Disclaimer | Privacy Policy | Terms & Conditions | Returns Policy | Intellectual Property | Cookie Policy
© 2019 – 2026 GBA Digital Media Group. All Rights Reserved | Site Credit
Copyright Green Building Africa 2024.

Subscribe to our weekly Top 5 Stories
"*" indicates required fields
Δ

source

India has done an incredible job driving domestic manufacturing through the Production Linked Incentive (PLI) scheme, which has successfully operationalised tens of gigawatts of solar module and cell production. But true energy sovereignty means looking beyond the glass and silicon.
April 06, 2026. By News Bureau

Icon Solar Modules Are Engineered for India’s Harsh Conditions, Says Rajat Shrivastava

Mobile Charging and Energy Storage Will Drive India’s EV Adoption: Mobec’s Harry Bajaj

10th Edition of RenewX Expo Set to Showcase a Decade of Clean Energy Progress

Trontek’s Samrath Kochar Explains How Rooftop Solar Adoption is Boosting Battery Storage Demand

Waterless Robotics Can Recover Up to 12% Lost Solar Generation, Says TAYPRO’s Yogesh Kudale

source

An official website of the United States government
Here’s how you know
Official websites use .gov
A .gov website belongs to an official government organization in the United States.
Secure .gov websites use HTTPS
A lock ( ) or https:// means you’ve safely connected to the .gov website. Share sensitive information only on official, secure websites.
The U.S. Department of Energy (DOE) Solar Energy Technologies Office (SETO) has issued a request for information (RFI) to better understand the market barriers and technical challenges for photovoltaic-thermal (PVT) systems.  
PVT systems combine standard photovoltaic (PV) panels with waste heat recovery systems and can be coupled with thermal energy storage. Heat from PV panels that is normally lost to the environment can be transferred to a thermal collector at the back of a PV panel to produce domestic hot water, heated ventilation air, or usable thermal energy that is stored for future application. 
SETO seeks feedback from industry, academia, research laboratories, state and local government agencies, and other stakeholders on four topic areas:  
DOWNLOAD THE RFI. 
Responses to this RFI must be submitted electronically to ​PVT-RFI@ee.doe.gov​ no later than 5 p.m. ET on ​December 31, 2024​. Responses must be provided as attachments to an email. It is recommended that attachments with file sizes exceeding 25MB be compressed (i.e., zipped) to ensure message delivery. Responses must be provided as a Microsoft Word (.docx) attachment to the email, and no more than ​5​ pages in length, 12-point font, and 1-inch margins. Only electronic responses will be accepted. 
Please identify your answers by responding to a specific question or topic if applicable.  
The DOE Office of Energy Efficiency and Renewable Energy will not respond to individual submissions or publish publicly a compendium of responses. A response to this RFI will not be viewed as a binding commitment to develop or pursue the project or ideas discussed. 
Please provide the following information at the start of your response to this RFI: 
See all open funding opportunities from SETO and sign up for our newsletter to stay current with the latest SETO news. 
Committed to Restoring America’s Energy Dominance.
Follow Us

source

Solar power in Africa is heating up — thanks in part to chili peppers  cbc.ca
source

Power-starved Cuba deepens reliance on Chinese solar tech  Financial Times
source

Crews knockdown ‘suspicious’ solar panel fire in Fallbrook  fox5sandiego.com
source

New research from the University of New South Wales shows that PV module degradation varies widely with system design and location, driven by UV exposure, temperature, humidity, and atmospheric conditions. Tropical and desert regions face the highest stress, highlighting the need for climate-specific testing and system design.
Image: pv magazine/AI generated

Utraviolet (UV) radiation has been long recognized as a key driver of PV module degradation. This factor, however, is significantly underestimated in current testing standards, particularly for modern system designs and high-irradiance regions.
With this in mind, a group of researchers at the University of New South Wales (UNSW) in Australia has developed a high-precision global UV irradiance model on tilted surfaces, capturing the impact of system design, climate, and atmospheric conditions.
“Our new model demonstrates that identical module technologies degrade differently depending on deployment location, highlighting the need for climate-specific reliability assessment,” corresponding author Bram Hoex told pv magazine. “It also offers a pathway to move beyond generic accelerated testing toward regionally relevant degradation modeling and qualification protocols.”
The researchers highlighted that global UV irradiance can range from below 30 W/m² in high-latitude regions to over 80 W/m² in deserts and dry climates. In some locations, the UV dose specified in the IEC 61215 standard, which is just 15 kWh/m², can be reached in less than two months. By contrast, real-world exposure over a module’s lifetime is orders of magnitude higher.
“Current testing thresholds are simply too low to replicate long-term field conditions,” the authors noted, adding that even enhanced protocols fall short of simulating 25–30 years of operation.
One of the most striking findings of the study relates to system design. The researchers compared fixed-tilt installations with single-axis tracking (SAT) systems and found that trackers receive significantly more UV radiation due to their orientation toward the sun throughout the day.

In high-irradiance regions, such as deserts, single-axis tracking (SAT) systems can be exposed to up to 1.5 times more UV radiation than fixed-tilt systems, leading to degradation rates that are nearly twice as high. This results in annual UV-driven degradation rates of up to 0.35% per year for SAT systems, compared with approximately 0.25% per year for fixed-tilt installations.
Over the course of a typical project lifetime, this difference can accumulate to several percentage points of additional power loss, directly impacting the economics and long-term performance of the PV system.
The study also showed that identical PV modules can degrade at markedly different rates depending on their installation location. The key factors driving this variability include UV irradiance, temperature, humidity, and atmospheric conditions such as ozone levels, aerosols, and cloud cover. Among the most challenging environments are tropical and desert regions, where high UV exposure combines with intense thermal and environmental stress, accelerating module degradation.
“Current standards significantly underestimate real-world UV exposure, in some cases by orders of magnitude relative to lifetime conditions,” Hoex stressed. “UV exposure varies significantly with location and system configuration, with tracking systems experiencing up to around two times higher degradation rates in high-irradiance regions. In arid and tropical climates, UV-induced degradation can reach about 0.25–0.35%/year, contributing substantially to long-term performance loss.”
The novel high-precision model to estimate UV radiation in PV systems was presented in the paper “Closing the UV-Induced Photodegradation Gap Through Global Scale Modeling of Fixed Tilt and Tracking Photovoltaic Systems,” pubished in the IEEE Journal of Photovoltaics.
“This work forms part of our group’s broader effort to connect fundamental degradation mechanisms with system-level impacts in the field, combining targeted accelerated testing—such as UV, damp heat, and contamination—with physics-based and data-driven modeling at the system scale to quantify how both established and emerging failure modes translate into real-world energy yield losses across diverse climates and system designs,” Hoex concluded.
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 *
Comment *
Name *
Email *
Website


Δ
By submitting this form you agree to pv magazine using your data for the purposes of publishing your comment.
Your personal data will only be disclosed or otherwise transmitted to third parties for the purposes of spam filtering or if this is necessary for technical maintenance of the website. Any other transfer to third parties will not take place unless this is justified on the basis of applicable data protection regulations or if pv magazine is legally obliged to do so.
You may revoke this consent at any time with effect for the future, in which case your personal data will be deleted immediately. Otherwise, your data will be deleted if pv magazine has processed your request or the purpose of data storage is fulfilled.
Further information on data privacy can be found in our Data Protection Policy.
By subscribing to our newsletter you’ll be eligible for a 10% discount on magazine subscriptions!
Δ
Legal Notice Terms and Conditions Privacy Policy © pv magazine 2026
Δ
This website uses cookies to anonymously count visitor numbers. To find out more, please see our Data Protection Policy. ×
The cookie settings on this website are set to “allow cookies” to give you the best browsing experience possible. If you continue to use this website without changing your cookie settings or you click “Accept” below then you are consenting to this.
Close

source

0
By clicking the button, I accept the Terms of Use of the service and its Privacy Policy, as well as consent to the processing of personal data.
Don’t have an account? Signup
Powered by :
Deye’s Residential ESS Secures Dual ECHONET Lite Certification Photograph: (Archive)
Deye has secured dual certification for ECHONET Lite and ECHONET Lite AIF for its residential energy storage system (ESS), enabling integration with Japan’s home energy management systems (HEMS) and broader smart home ecosystem.
The certification allows Deye’s systems to connect with household devices such as air conditioners, lighting, photovoltaic systems and storage units through a unified interface, addressing interoperability challenges in Japan’s fragmented smart home market.
The development comes as Japan accelerates adoption of smart and energy-efficient housing. Under the updated 2025 GX ZEH framework, battery storage and HEMS are increasingly becoming standard installations, reflecting a shift toward structurally embedded energy management systems.
At the same time, the emergence of virtual power plants (VPPs) and rising demand for real-time energy monitoring are driving the need for integrated, app-based control of residential energy systems.
ECHONET Lite, a widely adopted communication protocol in Japan, enables interoperability across devices from multiple manufacturers, positioning residential storage systems as central energy management hubs rather than standalone backup units.
Deye said its ESS leverages integration with smart meters and HEMS to optimise energy usage using weather forecasts, time-of-use tariffs and consumption patterns. The system dynamically adjusts charging and discharging cycles to improve self-consumption and reduce electricity costs.
The system also enhances backup capabilities by automatically switching to off-grid mode during outages, ensuring power supply to critical loads while allowing users to manage stored energy through centralised controls.
Introduced in 2012 and backed by Japan’s Ministry of Economy, Trade and Industry, ECHONET Lite has evolved into a core standard for smart energy integration across residential and commercial applications.
Deye said the dual certification aligns its products with Japan’s technical standards while supporting localisation requirements in one of the world’s most advanced smart energy markets.
We are India’s leading B2B media house, reporting full-time on solar energy, wind, battery storage, solar inverters, and electric vehicle (EV)
Quick Links
© 2025 Saur Energy. All Rights Reserved.

source

Lawmakers enact controversial bill in attempt to suppress revenue-generating agrivoltaics on farms  Yahoo
source

Indian economy size is likely to surpass $5 trillion by 2030, driven by manufacturing expansion, infrastructure development, and strong economic reforms. However, sustaining that growth requires not just clean energy but also one that is predictable, uninterrupted and dispatchable.
Basant Jain, Joint Managing Director & CEO, Bhilwara Energy Limited
Bhilwara Energy Limited
India’s clean energy story is no longer about how much we can build but whether what we build will work when it matters most. To be sure, the country’s clean energy ambitions are among the most ambitious anywhere — 500 GW of non-fossil fuel capacity by 2030, net zero by 2070, and a rapidly growing manufacturing ecosystem in solar, batteries, and green hydrogen. The targets are bold, the investment is flowing, and the political commitment is visible. Yet beneath the optimism lies an uncomfortable truth that will determine whether the transition succeeds or stalls. It’s the question of reliability.
As things stand, Indian economy size is likely to surpass $5 trillion by 2030, driven by manufacturing expansion, infrastructure development, and strong economic reforms. However, sustaining that growth requires not just clean energy but also one that is predictable, uninterrupted and dispatchable. A steel mill in Odisha, a graphite processing plant in Madhya Pradesh, a semiconductor fab in Karnataka, or a data centre in Hyderabad cannot function on power that arrives only when the sun shines or the wind blows. They need electrons on demand, 24 hours a day, every day of the year. The moment clean energy fails to deliver that reliability, the transition loses the constituency that matters most — the industrial consumer who actually pays cost-reflective tariffs and cross-subsidises the rest of the system.
Solar and wind are valuable resources, and India is blessed with both. But the sun sets, the wind stills, and the grid does not pause to accommodate either. Meanwhile, India’s current storage capacity stands at a fraction of what its renewable ambitions demand. Peak solar generation is often concentrated in the afternoon and floods the grid precisely when industrial demand is low, while the evening demand triggers expensive, carbon-intensive energy. This problem demands a structural solution.
States with high renewable penetration are managing increasingly complex balancing acts, and distribution companies are discovering that cheap solar PPAs signed a decade ago did not account for the integration costs that arrive when variable generation reaches 20-30% of the energy mix.
The consequences of ignoring existing situation of intermittency of renewable energy generation, can hurt Indian economy by increasing input costs for manufacturers, stifling foreign direct investment, and forcing businesses into expensive solutions like deploying diesel generators, captive coal, and load curtailment.
According to estimates from the India Energy Storage Alliance (IESA), inadequate storage infrastructure could cost India billions of dollars in stranded renewable assets and foregone industrial output over the next decade.
The missing piece is not more solar panels or wind capacity. India can install those in several GW over many years. The missing piece is the infrastructure of reliability — storage at scale, flexible generation that can ramp in minutes, transmission corridors that move renewable energy from where it is generated to where it is consumed, and forecasting and scheduling systems that manage variability in real time rather than after the fact.
A shift from capacity to reliability
What India’s energy transition needs now is a rethinking of how generation, storage, and grid intelligence work together rather than in isolation.
Hybrid energy systems are emerging as one of the most compelling responses to this challenge. By co-locating solar and wind assets with battery storage, and increasingly with pumped hydro, these systems smooth out the challenges that make standalone renewables unpredictable. A well-designed hybrid plant does not only generate power but also manages it while delivering clean energy on demand.
Storage, in particular, is the foundation that transforms intermittent generation into firm power. While battery energy storage systems are becoming cost-competitive faster than most analysts’ predictions. But it is not technology alone that determines success but how storage is integrated across the energy stack.
Grid modernization is another critical leg of this stool. Smart grid technologies like real-time demand forecasting, automated switching, and advanced metering allow operators to anticipate and respond to fluctuations before they turn into outages. Without this intelligence layer, even the best generation and storage assets underperform.
The policy architecture must evolve accordingly. Today, India’s renewable energy policy is overwhelmingly oriented toward capacity addition — megawatts installed, auctions conducted, record-low tariffs achieved. These are necessary metrics, but they are insufficient. The next phase of policy must reward reliability contribution — the ability of a generator, storage system, or demand-response provider to deliver firm, dispatchable power when the grid needs it, not merely when nature provides it.
The states and institutions that solve reliability first will attract the energy-intensive industries that define economic competitiveness — advanced manufacturing, data infrastructure, mineral processing, and green hydrogen production. Those that treat reliability as an afterthought will find their clean energy capacity underutilised, their industrial consumers migrating to captive generation, and their transition ambitions stranded alongside their thermal assets.
The competitive advantage
For sure, India’s energy transition will not be won by any single technology. It will perhaps be won by the organizations and platforms that can integrate across solar, hydro, and storage.
This is where cross-sectoral experience becomes decisive. For instance, while deploying solar power at scale is a discipline, designing a hybrid system incorporating a hydro balancing and intelligent storage dispatch is a different ball game entirely. The latter requires not just engineering capability, but also deep operational insight across the full energy value chain.
At its core, India’s clean energy story is a developmental story. Reliable, affordable, and clean power will electrify the next tier of manufacturing clusters and power hospitals and schools, apart from supporting digital infrastructure that will define the country’s next phase of growth.
The question for the next decade is not whether India can build enough renewable capacity but whether that capacity will be reliable enough to carry the weight of a $5 trillion economy in the making. Meanwhile, a new class of energy platforms are being designed not just to build assets but also to orchestrate them into reliable, dispatchable power.
 
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 *
Comment *
Name *
Email *
Website


Δ
By submitting this form you agree to pv magazine using your data for the purposes of publishing your comment.
Your personal data will only be disclosed or otherwise transmitted to third parties for the purposes of spam filtering or if this is necessary for technical maintenance of the website. Any other transfer to third parties will not take place unless this is justified on the basis of applicable data protection regulations or if pv magazine is legally obliged to do so.
You may revoke this consent at any time with effect for the future, in which case your personal data will be deleted immediately. Otherwise, your data will be deleted if pv magazine has processed your request or the purpose of data storage is fulfilled.
Further information on data privacy can be found in our Data Protection Policy.
By subscribing to our newsletter you’ll be eligible for a 10% discount on magazine subscriptions!
Δ
Legal Notice Terms and Conditions Privacy Policy © pv magazine 2026
Δ
This website uses cookies to anonymously count visitor numbers. To find out more, please see our Data Protection Policy. ×
The cookie settings on this website are set to “allow cookies” to give you the best browsing experience possible. If you continue to use this website without changing your cookie settings or you click “Accept” below then you are consenting to this.
Close

source

China’s perovskite solar cell hits 27.98% efficiency, setting new world record  dailynews.lk
source

Citicore expands Philippine solar park to 94 MWp  Renewables Now
source

New research from the University of New South Wales shows that PV module degradation varies widely with system design and location, driven by UV exposure, temperature, humidity, and atmospheric conditions. Tropical and desert regions face the highest stress, highlighting the need for climate-specific testing and system design.
Image: pv magazine/AI generated
From pv magazine Global
Utraviolet (UV) radiation has been long recognized as a key driver of PV module degradation. This factor, however, is significantly underestimated in current testing standards, particularly for modern system designs and high-irradiance regions.
With this in mind, a group of researchers at the University of New South Wales (UNSW) in Australia has developed a high-precision global UV irradiance model on tilted surfaces, capturing the impact of system design, climate, and atmospheric conditions.
“Our new model demonstrates that identical module technologies degrade differently depending on deployment location, highlighting the need for climate-specific reliability assessment,” corresponding author Bram Hoex told pv magazine. “It also offers a pathway to move beyond generic accelerated testing toward regionally relevant degradation modeling and qualification protocols.”
The researchers highlighted that global UV irradiance can range from below 30 W/m² in high-latitude regions to over 80 W/m² in deserts and dry climates. In some locations, the UV dose specified in the IEC 61215 standard, which is just 15 kWh/m², can be reached in less than two months. By contrast, real-world exposure over a module’s lifetime is orders of magnitude higher.
“Current testing thresholds are simply too low to replicate long-term field conditions,” the authors noted, adding that even enhanced protocols fall short of simulating 25–30 years of operation.
One of the most striking findings of the study relates to system design. The researchers compared fixed-tilt installations with single-axis tracking (SAT) systems and found that trackers receive significantly more UV radiation due to their orientation toward the sun throughout the day.

In high-irradiance regions, such as deserts, single-axis tracking (SAT) systems can be exposed to up to 1.5 times more UV radiation than fixed-tilt systems, leading to degradation rates that are nearly twice as high. This results in annual UV-driven degradation rates of up to 0.35% per year for SAT systems, compared with approximately 0.25% per year for fixed-tilt installations.
Over the course of a typical project lifetime, this difference can accumulate to several percentage points of additional power loss, directly impacting the economics and long-term performance of the PV system.
The study also showed that identical PV modules can degrade at markedly different rates depending on their installation location. The key factors driving this variability include UV irradiance, temperature, humidity, and atmospheric conditions such as ozone levels, aerosols, and cloud cover. Among the most challenging environments are tropical and desert regions, where high UV exposure combines with intense thermal and environmental stress, accelerating module degradation.
“Current standards significantly underestimate real-world UV exposure, in some cases by orders of magnitude relative to lifetime conditions,” Hoex stressed. “UV exposure varies significantly with location and system configuration, with tracking systems experiencing up to around two times higher degradation rates in high-irradiance regions. In arid and tropical climates, UV-induced degradation can reach about 0.25–0.35%/year, contributing substantially to long-term performance loss.”
The novel high-precision model to estimate UV radiation in PV systems was presented in the paper “Closing the UV-Induced Photodegradation Gap Through Global Scale Modeling of Fixed Tilt and Tracking Photovoltaic Systems,” pubished in the IEEE Journal of Photovoltaics.
“This work forms part of our group’s broader effort to connect fundamental degradation mechanisms with system-level impacts in the field, combining targeted accelerated testing—such as UV, damp heat, and contamination—with physics-based and data-driven modeling at the system scale to quantify how both established and emerging failure modes translate into real-world energy yield losses across diverse climates and system designs,” Hoex concluded.
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 *
Comment *
Name *
Email *
Website
Save my name, email, and website in this browser for the next time I comment.


Δ
By submitting this form you agree to pv magazine using your data for the purposes of publishing your comment.
Your personal data will only be disclosed or otherwise transmitted to third parties for the purposes of spam filtering or if this is necessary for technical maintenance of the website. Any other transfer to third parties will not take place unless this is justified on the basis of applicable data protection regulations or if pv magazine is legally obliged to do so.
You may revoke this consent at any time with effect for the future, in which case your personal data will be deleted immediately. Otherwise, your data will be deleted if pv magazine has processed your request or the purpose of data storage is fulfilled.
Further information on data privacy can be found in our Data Protection Policy.
pv magazine USA offers daily updates of the latest photovoltaics news. We also offer comprehensive global coverage of the most important solar markets worldwide. Select one or more editions for targeted, up to date information delivered straight to your inbox.
Δ
Legal Notice Terms and Conditions Privacy Policy © pv magazine 2026
Δ
Welcome to pv magazine USA. This site uses cookies. Read our policy. ×
The cookie settings on this website are set to “allow cookies” to give you the best browsing experience possible. If you continue to use this website without changing your cookie settings or you click “Accept” below then you are consenting to this.
Close

source

Sundaram Multi Pap Limited has announced the successful installation of solar roof panels at its Palghar manufacturing facility, marking a significant step in its sustainability journey and commitment to reducing environmental impact. Spread across a four-acre site, the Palghar plant now incorporates solar infrastructure designed to generate clean and renewable energy. The initiative is expected to significantly reduce dependence on conventional power sources while lowering the company’s overall carbon footprint.
The transition to solar energy is projected to deliver multiple benefits, including reduced greenhouse gas emissions and long-term cost efficiencies. The environmental impact is comparable to planting hundreds of trees, reflecting the company’s focus on responsible manufacturing practices.
Chief Executive Officer Hardik Shah described the project as a meaningful step toward building a more sustainable future. He emphasised that the initiative represents both an environmental responsibility and a strategic investment in cleaner energy solutions.
The solar panels were installed during the facility’s latest upgrade phase and are currently operating at optimal efficiency. The project was executed in collaboration with Polaris Renewable Solutions Pvt. Ltd., whose expertise ensured seamless integration with existing operations while minimising disruption.
In addition to environmental benefits, the installation is expected to reduce energy costs and provide greater resilience against fluctuations in power prices. The savings generated will support further investments in innovation, operational improvements, and community initiatives.
Founded in 1995, Sundaram Multi Pap Limited is a well-established stationery brand with a strong presence across India, particularly in western markets. The company offers a wide range of products, including notebooks, drawing books, scrapbooks, and office supplies, known for quality, durability, and design.
The adoption of renewable energy aligns with Sundaram’s broader sustainability goals and reflects its commitment to responsible growth. By integrating clean energy into its manufacturing processes, the company continues to strengthen its position as an environmentally conscious player in the stationery industry. This initiative underscores Sundaram’s ongoing efforts to combine operational efficiency with environmental stewardship, contributing to a more sustainable industrial ecosystem.
The story of ‘MAKE IN INDIA’ has reached far and wide. But who are makers of ‘MAKE IN INDIA’? What is their story? ‘Machine Maker’ is a dedicated magazine that seeks to bring the incredible stories… Read more
B-201, SPIREA, Wakad, Pune – 411057
[email protected]
+91-703-093-2700
Contact Us
Subscribe
India’s Top

source

An IEA-PVPS report finds that solar power above 60° North is not only viable but rapidly expanding, driven by cold-climate performance gains, bifacial technologies, and rising energy security needs. While challenges like extreme seasonality, snow, permafrost, and scarce data remain, Arctic PV is emerging as a critical—and technically distinct—frontier for global solar deployment.
A snow-covered pv system
Image: Firat University, Case Studies in Thermal Engineering, CC BY 4.0

For decades, the Arctic has been dismissed as a solar dead zone. Long winters, heavy snow loads, and extreme cold seemed to rule out photovoltaics as a serious energy option for communities above the 60th parallel. A new report from the IEA Photovoltaic Power Systems Programme (Task 13) challenges that assumption, arguing that solar PV is not just viable in the Arctic, but increasingly essential to the region’s energy security.
The 77-page report, titled “Photovoltaics and Energy Security in the Greater Arctic Region“ and authored by researchers across the US, Canada, Sweden, Norway, Denmark, and Finland, arrives at a moment when Arctic PV capacity is growing at rates of 46 to 145% per year in some regions. Total installed capacity above 60°N now stands at roughly 1,400 MWp as of 2023 — still a tiny fraction of global capacity, but the trajectory is unmistakable.
First and foremost, when planning a PV project at higher latitudes, the starting point must be considering seasonality: near the summer solstice in June, high-latitude regions receive large amounts of solar radiation. In contrast, near the winter solstice in December high-latitude regions receive little solar radiation (or not at all above the Arctic Circle at 66.56°N).
Bridging the gap between the intensity of summer and the scarcity of winter is the defining integration challenge for Arctic PV systems, and one that is addressed at length throughout the report.
The report’s central argument rests on a counterintuitive insight: cold is not the enemy of solar panels. It’s often an advantage.
Silicon PV cells produce more power at lower temperatures because the semiconductor bandgap widens, boosting voltage. The report cites data from a south-facing system in Alaska, where the median module temperature during daylight hours was just 15°C, which is far below the 25°C standard test condition at which panels are rated. In cold climates, modules may also degrade more slowly, with a median performance loss rate of just -0.37%/year measured across 16 systems above 59°N, compared to -0.75%/year for systems across the continental United States.
Snow, meanwhile, is a double-edged factor. It can block panels and stress racking systems, but it also dramatically raises ground albedo, potentially boosting the rear-side gain of bifacial modules to levels unseen in lower latitudes. The report notes that bifacial gain increases with latitude precisely because of long-lasting snow cover, increased diffuse light, and low solar elevation angles. The recommendation is clear: bifacial modules should be the default technology choice for Arctic deployments.
One of the report’s more striking practical findings concerns system orientation. East-west facing vertical bifacial arrays show particular promise above 60°N. Their near-90° tilt sheds snow naturally, avoiding the extended zero-production periods that plague tilted fixed-tilt systems in winter. They also produce power earlier and later in the day, better matching electricity demand curves and reducing the “cannibalization effect” that depresses midday wholesale prices.
Field data from a vertically-mounted agrivoltaic system in Sweden (59.55°N) illustrates the point. In December 2023, the vertical system outperformed its south-facing fixed-tilt neighbor on 28 out of 31 days, averaging 6.1 kWh/kW/month versus just 1.32 kWh/kW for the tilted array. On 14 of those days, the tilted system produced nothing at all due to snow coverage.
However, there is one section of the report that deserves special attention from developers: the discussion of frost heave and permafrost. Two detailed case studies — a 699 kW system in Luleå, Sweden, and a 563 kW array in Fairbanks, Alaska — document costly structural failures caused by ground freezing that installers failed to adequately anticipate.
In Luleå, perforated C-profile piles allowed the clay substrate to grip the racking, causing visible deformation within the first winter. The entire racking system had to be replaced with deeper, non-perforated piles. In Fairbanks, helical piles in a historically filled slough zone were jacked out of the ground and sank, breaking modules and requiring partial disassembly and reinstallation at 5.5 m depth.
The lesson from both cases: standard geotechnical surveys designed for construction and road work are not adequate for PV racking in frost-prone soils. Developers must commission surveys with PV-specific methodology, and should factor in the less obvious effect of the array itself.
In permafrost regions, the problem compounds further. Monitoring data from an array in Kotzebue, Alaska, shows that snow drifts accumulating behind solar rows are warming the permafrost, potentially destabilizing foundations over time. According to the report, solar arrays in these environments can act as snow fences, and the long-term structural consequences remain poorly understood.
For developers seeking to bankroll Arctic projects, the report identifies a persistent obstacle: the almost total absence of high-quality irradiance data above 60°N. Geostationary satellites degrade in accuracy beyond 65° latitude. Polar-orbiting satellites struggle to distinguish snow from cloud cover. Ground-based measurement networks are sparse, and those that exist face unique maintenance challenges, such as rime ice forming on radiometer domes, malfunctioning tracker mechanisms, and limited site access in winter.
As a result, energy yield assessments for Arctic projects carry substantially higher uncertainty than those at lower latitudes, which leads to complicated financing. The authors call for investment in heated, ventilated measurement instruments, rigorous maintenance protocols, and expanded ground-station networks across high-latitude regions.
The country-level data in the report paints a picture of a region moving fast despite the obstacles. Norway’s PV capacity above 60°N reached 173 MW in 2023, growing at 145% annually, with the country targeting 8 TWh of solar generation by 2030. Finland crossed 1 GW nationally and projects up to 9.1 GW by 2030. Arctic Sweden’s installed base hit 350 MW with a five-year mean growth rate of 58%/year, and utility-scale ground-mounted parks are now entering the permitting pipeline at gigawatt scale.
In North America, the story is different but equally dynamic. Alaska’s total PV capacity reached roughly 30 MW at end-2023, with the largest single facility at 8.5 MW and a 45 MW project announced for the Railbelt grid. More than 150 isolated diesel-dependent rural microgrids are receiving funding for solar-plus-storage systems, with some already capable of 100% renewable operation during favorable conditions.
The overarching message of this report is that the Arctic solar market is real, it is growing, and it has specific technical requirements that the global PV industry has not yet fully addressed. Bifacial vertical arrays, PV-specific geotechnical standards, Arctic-grade snow loss modeling, and expanded irradiance datasets are not nice-to-haves, but rather the foundations on which a credible high-latitude solar industry must be built.
Author: Ignacio Landivar
To access the full “Photovoltaics and Energy Security in the Greater Arctic Region,” you can download it here.
IEA PVPS Task 13 focuses on international collaboration to improve the reliability of photovoltaic systems and subsystems. This is achieved by collecting, analyzing, and disseminating information about their technical performance and durability. This creates a basis for their technical evaluation and develops practical recommendations to increase their electrical and economic efficiency in various climate regions.
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 *
Comment *
Name *
Email *
Website


Δ
By submitting this form you agree to pv magazine using your data for the purposes of publishing your comment.
Your personal data will only be disclosed or otherwise transmitted to third parties for the purposes of spam filtering or if this is necessary for technical maintenance of the website. Any other transfer to third parties will not take place unless this is justified on the basis of applicable data protection regulations or if pv magazine is legally obliged to do so.
You may revoke this consent at any time with effect for the future, in which case your personal data will be deleted immediately. Otherwise, your data will be deleted if pv magazine has processed your request or the purpose of data storage is fulfilled.
Further information on data privacy can be found in our Data Protection Policy.
By subscribing to our newsletter you’ll be eligible for a 10% discount on magazine subscriptions!
Δ
Legal Notice Terms and Conditions Privacy Policy © pv magazine 2026
Δ
This website uses cookies to anonymously count visitor numbers. To find out more, please see our Data Protection Policy. ×
The cookie settings on this website are set to “allow cookies” to give you the best browsing experience possible. If you continue to use this website without changing your cookie settings or you click “Accept” below then you are consenting to this.
Close

source

  Search 
This brief summarizes the findings of the Responsible Agri-PV Baseline Assessment conducted by The Energy and Resources Institute (TERI) under the Responsible Energy Initiative (REI) India. The study examines an institutional agrivoltaics (Agri-PV) pilot implemented by Renkube Pvt. Ltd. in collaboration with Professor Jayashankar Telangana State Agricultural University (PJTSAU).
The primary focus of this assessment is to evaluate the feasibility of co-locating solar power generation with active agriculture in the semi-arid, water-stressed conditions typical of Telangana.
The pilot features a 10.8 kWp elevated Agri-PV system installed at PJTSAU’s experimental farm in Hyderabad.
The results demonstrate that an “agriculture-first” design can achieve high performance across both energy and food outputs.
The Renkube-PJTSAU pilot provides compelling evidence that Agri-PV can enhance land productivity and water security while supporting Telangana’s renewable energy transition. However, to transition from pilot to widespread adoption, the following “enablers” are required:
The Energy and Resources Institute (TERI)      
Darbari Seth Block, Core 6C,      
India Habitat Centre, Lodhi Road,      
New Delhi – 110 003, India
mailbox@teri.res.in
(+91 11) 2468 2100, 7110 2100
© 2026 | All rights reserved | Privacy Policy | Contact Us

source

New Time has outlined a four-year roadmap to industrialize perovskite solar cells in Italy, with pilot production planned within three years and full-scale output to follow.
Image: New Time
From pv magazine Italia
New Time has outlined plans to industrialize perovskite PV production in Italy, following a two-day strategic meeting in Forlì to advance the project in the Emilia-Romagna region.
The company said the roadmap to commercialization is structured in four phases. The first year will focus on optimizing the perovskite formulation and identifying stabilizing materials. In the second year, the company plans to begin small-scale production for certification purposes.
The third phase will center on developing an industrial solution for large-scale manufacturing, followed by the start of full-scale production in the fourth year. New Time said pilot-scale production with stabilized processes is expected within three years, with large-scale output targeted within four years.
To support the rollout, the company plans to allocate existing industrial facilities to the project, backed by dedicated internal investment. It said funding is already underway and is being sourced through reinvestment of company profits into innovation and research and development.
New Time said current pricing for perovskite PV modules remains influenced by the lack of optimized production processes and ongoing material selection. The project aims to improve cost competitiveness with existing PV technologies while maintaining strong potential for gains in performance and efficiency.
The Forlì meeting, held over two days starting March 31, focused on defining the operational phases of the project and establishing how expertise and technologies will be shared. Participants included researchers from Italy and the Netherlands, including representatives from the Italian National Research Council (CNR), the University of Bari Aldo Moro, and Delft University of Technology.
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 Sergio Matalucci
Please be mindful of our community standards.
Your email address will not be published. Required fields are marked *
Comment *
Name *
Email *
Website
Save my name, email, and website in this browser for the next time I comment.


Δ
By submitting this form you agree to pv magazine using your data for the purposes of publishing your comment.
Your personal data will only be disclosed or otherwise transmitted to third parties for the purposes of spam filtering or if this is necessary for technical maintenance of the website. Any other transfer to third parties will not take place unless this is justified on the basis of applicable data protection regulations or if pv magazine is legally obliged to do so.
You may revoke this consent at any time with effect for the future, in which case your personal data will be deleted immediately. Otherwise, your data will be deleted if pv magazine has processed your request or the purpose of data storage is fulfilled.
Further information on data privacy can be found in our Data Protection Policy.
Legal Notice Terms and Conditions Data Privacy © pv magazine 2026
Δ
This website uses cookies to anonymously count visitor numbers. View our privacy policy. ×
The cookie settings on this website are set to “allow cookies” to give you the best browsing experience possible. If you continue to use this website without changing your cookie settings or you click “Accept” below then you are consenting to this.
Close

source

Diana Sahu is an Assistant Editor with the Times of India. With a professional career spanning nearly two decades, she has been writing extensively on education, livelihood, child rights, gender, heritage & culture, tourism and disability rights. She is also known for her data-driven investigative reports and compelling human interest stories. Her in-depth story on 'Women in Higher Education' had won her the Best Feature Award at the Laadli Media Awards and a Laadli National Fellowship on 'Gender and Disability'. She had also received WNCB Fellowship on Child Rights. Apart from her core reporting interests, she loves documenting the many aspects of Odisha's culture and heritage. She tweets at @DiannaSahu.Read More

source

Markets & Policy
Tenders & Auctions
Solar Projects
Large-Scale Projects
Rooftop
C&I
Manufacturing
Modules
Inverters & BOS
Technology
Finance and M&A
Markets & Policy
T&D
Utilities
Smart Grid
Microgrid
Events
Webinars
Interviews
India’s solar module manufacturing capacity rose to 119 GW
April 6, 2026
Follow Mercom India on WhatsApp for exclusive updates on clean energy news and insights
India added nearly 119 GW of solar modules and over 9 GW of solar cell capacity in 2025, according to Mercom India’s State of Solar PV Manufacturing in India 2026 report. The manufacturing expansion was driven by demand from India’s large utility-scale solar project pipeline, residential rooftop targets, the PM Surya Ghar program, and the Approved List of Models and Manufacturers List-II domestic cell mandate.
India added nearly 547 MWh of battery energy storage capacity in 2025, around 26% year-over-year (YoY) increase from over 433 MWh, according to the newly released 2H & Annual 2025 India’s Energy Storage Landscape Report by Mercom India Research. India’s cumulative installed battery energy storage capacity reached almost 1,082 MWh as of December 2025.
Savings for commercial and industrial (C&I)  consumers under solar open access narrowed across most states in the fourth quarter (Q4) of 2025 as rising power purchase agreement tariffs and charges drove up landed procurement costs, according to Mercom India’s Q4 and Annual 2025 Solar Open Access Market Report.
India imported solar cells and modules worth over $1.12 billion (~₹100.2 billion) in Q4 2025, a 55.6% YoY increase from $723.4 million (~₹61.1 billion), according to data from the Department of Commerce. In a quarter-over-quarter comparison, module and cell imports together increased by 34.4%, totaling over $837 million (~₹73 billion). Solar module imports rose 51.7%, while cell imports grew 30.5% from Q3 2025.
India added 7.8 GW of solar open access capacity in 2025, the highest addition recorded in any calendar year, according to the Q4 and Annual 2025 Mercom India Solar Open Access Market report. Solar open access installations remained steady in 2025, supported by sustained C&I demand for long-term renewable power procurement. Corporates are increasingly opting for green power procurement to reduce electricity costs and meet sustainability commitments.
India’s battery energy storage sector is expanding rapidly, but a less visible challenge is emerging as projects move from planning to operation: the impact of real-world cycling on battery degradation and long-term economics. Early discussions around battery energy storage systems have focused on installed capacity, tariffs, and capital costs.
India’s battery energy storage market is entering a new phase of growth, but developers are increasingly facing a constraint that traditional project models have not fully captured: heat. In key renewable hubs such as Rajasthan and Gujarat, summer temperatures often exceed 40°C, reaching 48°C during peak periods. In some procurement frameworks, systems are now expected to perform at ambient conditions approaching 50°C.
The Ministry of Power’s (MoP) relaxations, allowing group captive projects to meet the 51% consumption requirement collectively rather than based on the individual proportionality requirement, have raised hopes of increased open access adoption by C&I consumers
The U.S.-Iran war triggered ripple effects on the Indian economy, raising fears of supply chain, shipping, and logistics disruptions across sectors. India’s energy security has been imperiled by the closure of the Strait of Hormuz, through which a quarter of global oil passes. Crude prices had risen above $100 a barrel before settling lower on March 12.
The Office of the United States Trade Representative initiated a Section 301 investigation into structural excess capacity and production in manufacturing, with India among the economies under review. The investigation will examine whether policies or practices in these economies are contributing to structural overcapacity in manufacturing sectors that could distort global markets and harm U.S. commerce.
Trade bodies have sharply criticized the Karnataka Electricity Regulatory Commission’s decision to revise electricity tariffs for FY 2025-26, raising charges for C&I consumers to help bridge a subsidy gap arising from free power for farmers. The decision has revived the long-standing debate over cross-subsidies in India’s electricity sector, where C&I consumers effectively pay higher tariffs to offset subsidies for other categories, such as agriculture and low-income households.
The recent imposition of steep countervailing duties by the U.S. on Indian solar imports is not causing much concern among solar manufacturers, given lower export volumes and their focus on the domestic market.
The U.S. Department of Commerce announced its preliminary determination of countervailing duties of up to 125.87% on crystalline silicon solar cells, whether or not assembled into modules, imported from India.
The government has begun invoking emergency powers under Section 11 of the Electricity Act to direct coal-based thermal power plants to increase generation, given the prevailing demand-supply situation and the expected rise in power demand in the coming months. Earlier this month, the MoP directed Coastal Power Gujarat, a Tata Power-owned company, to generate power at full capacity from April 1 to June 30, 2026.
India aims to cut its emissions intensity by 47% from 2005 levels by 2035, reach 60% of its total installed power capacity from non-fossil fuel sources by 2035, and establish a carbon sink of 3.5 to 4 billion tons of CO₂ equivalent through forest cover by 2035, according to the new Nationally Determined Contribution (NDC) for 2031-2035. The Union Cabinet recently approved the NDC.
The Ministry of New and Renewable Energy (MNRE) extended timelines for financial closure and commissioning of certain projects under the Pradhan Mantri Kisan Urja Suraksha evam Utthaan Mahabhiyan program, providing relief to stakeholders grappling with financing constraints.
The Central Electricity Regulatory Commission brought integrated energy storage systems co-located with coal-, lignite-, or gas-based thermal generating stations and inter-state transmission systems under the tariff framework, creating a clear regulatory path for their approval, cost recovery, operation, and billing.
The MNRE asked the Maharashtra government to withdraw its recent move to restrict the capacity of rooftop solar systems installed by consumers under the PM Surya Ghar: Muft Bijli Yojana. In a departure from the earlier policy, the Maharashtra State Electricity Distribution Company began processing rooftop solar proposals from February 12, 2026, based on average electricity consumption over the past 12 months rather than the approved load/contract demand.
The MNRE called for strengthening its role, considering the rapidly expanding scale and strategic importance of renewables, to give greater institutional clarity for effective administration. The Ministry told a parliamentary standing committee that enacting a separate Renewable Energy Act may not be necessary, as electricity generated from renewables is integrated into the grid and governed by the Electricity Act, 2003.
Melvin Mathew
RELATED POSTS
© 2026 by Mercom Capital Group, LLC. All Rights Reserved.

source

Central Mine Planning and Design Institute has issued a tender for a 25 MW (AC)/35 MWp (DC) solar PV project at Bharat Coking Coal’s Dugdha Coal Washery in Dhanbad, Jharkhand. Bid submission ends on April 29, 2026.
April 06, 2026. By Mrinmoy Dey

Icon Solar Modules Are Engineered for India’s Harsh Conditions, Says Rajat Shrivastava

Mobile Charging and Energy Storage Will Drive India’s EV Adoption: Mobec’s Harry Bajaj

10th Edition of RenewX Expo Set to Showcase a Decade of Clean Energy Progress

Trontek’s Samrath Kochar Explains How Rooftop Solar Adoption is Boosting Battery Storage Demand

Waterless Robotics Can Recover Up to 12% Lost Solar Generation, Says TAYPRO’s Yogesh Kudale

source

This website is using a security service to protect itself from online attacks. We are checking your browser to establish a secure connection and keep you safe.

Please enable JavaScript to continue.

Please enable JavaScript to continue.
Performance & security by bunny.net

source

Waterproof Solar Panel Carrying Bag – Compatible With Jackery SolarSaga 100W/200W, Padded Case With Shoulder Strap  ruhrkanal.news
source

Premier Energies Limited has been recognized as one of the top 15 global photovoltaic (PV) manufacturers in the inaugural Terawatt PV 100 ranking released by Terawatt PV Research. The ranking evaluates companies based on production scale, financial strength, and corporate transparency, highlighting the most influential players in the global solar ecosystem.
Premier Energies also emerged as the second-highest ranked Indian company in the list, contributing to India’s growing presence in global solar manufacturing. A total of 21 India-headquartered firms were featured in the top 100, reflecting the country’s rapid advancement as a key hub for renewable energy production.
The company’s strong performance is driven by its strategic “Mission 2028” roadmap, which targets the development of more than 10 GW of integrated manufacturing capacity. A central component of this strategy is backward integration into upstream processes such as ingot and wafer production, enabling greater cost efficiency, supply chain resilience, and operational control.
On the technology front, Premier Energies is advancing next-generation solar solutions, including N-type TOPCon cells and Zero Busbar (0BB) modules. These innovations are designed to deliver higher power output, reduce material usage, and improve long-term durability. The company recently commissioned its Seetharampur facility, adding 5.6 GW of automated module capacity supported by AI-driven quality control systems and traceable manufacturing processes.
Leadership at Premier Energies Limited emphasized that the recognition reflects a disciplined approach to growth, technology adoption, and value chain integration. The company continues to strengthen governance practices and enhance transparency following its public listing, reinforcing investor confidence and global credibility.
With over three decades of industry experience, Premier Energies is investing approximately ₹12,500 crore to expand its manufacturing footprint and diversify into adjacent segments such as inverters, transformers, and battery systems. Its consistent focus on innovation, sustainability, and workforce development has earned it multiple recognitions, including repeated certification as a Great Place to Work. This global ranking underscores Premier Energies’ rising influence in the renewable energy sector and highlights India’s expanding role in shaping the future of solar power worldwide.

The story of ‘MAKE IN INDIA’ has reached far and wide. But who are makers of ‘MAKE IN INDIA’? What is their story? ‘Machine Maker’ is a dedicated magazine that seeks to bring the incredible stories… Read more
B-201, SPIREA, Wakad, Pune – 411057
[email protected]
+91-703-093-2700
Contact Us
Subscribe
India’s Top

source

A UNSW-led team found that annealing conditions significantly affect stress, strain, and microstructure in copper-plated heterojunction solar cell contacts, with fast annealing increasing microstrain in both copper and indium tin oxide.
A solar cell fabricated at UNSW in Australia
Image: University of New South Wales
A team of scientists led by Australia’s University of New South Wales (UNSW) has studied how stress and strain evolve in copper (Cu)-plated contacts on heterojunction (HJT) solar cells under various annealing conditions. Their work specifically examined how annealing affects the material properties of Cu, indium tin oxide (ITO), and silicon (Si).
“We applied multiple characterization methods to understand how annealing conditions influence stress and strain in Cu-plated HJT cells,” co-author Pei-Chieh Hsiao told pv magazine. “Our results show that Cu contacts on HJT cells need careful assessment to balance adhesion with mechanical integrity.”
Hsiao highlighted the importance of controlling the microscopic structure of copper contacts to limit mechanical stress in HJT solar cells. “Ideally, plated Cu with a low defect density and (100) crystal texture is preferred,” he explained. “This reduces stress in Si after annealing because of a lower Young’s modulus. The preferred texture can be achieved by adjusting the electrolyte or plating parameters, and annealing can then be optimized to minimize thermal strain while preserving the (100) orientation.”
The team began with silicon heterojunction G12 half-cut n-type precursors measuring 210 mm × 105 mm. The cells were coated with a resin-based mask to restrict copper plating, with selective openings created via a collimated light source. Copper was then plated onto the exposed ITO surface using an acid-based electroplating solution at a current density of 42 mA/cm².
The team compared three annealing methods. In self-annealing, samples were stored at room temperature in a low-humidity environment. Fast annealing (same day) was carried out in compressed dry air at 205 ± 5 C for 45 seconds under approximately 15 suns of illumination. Fast annealing (next day) used the same conditions but was performed roughly 24 hours after plating.
Image: University of New South Wales, Sydney, Solar Energy Materials and Solar Cells, CC BY 4.0
“Due to the limitation of low temperature processing of HJT cells, fast annealing was performed at 200 C, which is lower than the grain growth stage at over 250 C,” Hsiao said. “It means that annealing of plated Cu contacts on HJT cells would perform distinctly from that on PERC or TOPCon cells, where higher annealing temperatures are permitted and improved contact adhesion has been demonstrated.”
The team then examined the samples in a series of tests. First, nanoindentation was used to measure the mechanical strength and stiffness of the plated copper. Second, X-ray diffraction (XRD) was used to examine the crystal structure of the copper and the underlying ITO layer. Finally, Raman spectroscopy was used to map the mechanical stress induced by the copper contacts in the silicon, especially near the contact edges.
The analysis showed that no significant differences were found in yield strength or plastic response of plated Cu, which was consistent with the comparable Cu grain size. Moreover, XRD patterns showed fast annealing reduced the Cu lattice parameter and promoted grain growth in the Cu (200) crystallographic orientation, while simultaneously increasing the ITO lattice parameter and full width at half maximum (FWHM).
As a result, microstrains in both Cu and ITO rose under rapid annealing, with the scientists noting that Raman spectroscopy revealed approximately 2 μm-wide regions of high local stress in the silicon along the plated Cu fingers, with stress being lower in self-annealed Cu and higher in fast-annealed Cu.
These results indicate that minimizing defects and promoting a preferential (100) texture in plated Cu can reduce stress transfer to Si and ITO. Maintaining uniform plating conditions and careful surface preparation are also essential for achieving optimal texture and adhesion. Overall, self-annealing is preferred when comparable contact adhesion can be achieved, as it preserves the (100) orientation and minimizes thermal strain.
The research work was described in “Stress and strain analysis of Cu plated contacts on HJT cells under different annealing conditions,” published in Solar Energy Materials and Solar Cells. Scientists from Australia’s University of New South Wales and technology company SunDrive Solar have contributed to the research.
In early January, a research team from UNSW and Chinese-Canadian solar module maker Canadian Solar investigated how HJT solar cells are hit by sodium (Na) and moisture degradation under accelerated damp-heat testing and has found that most degradation modes predominantly affect the cells themselves, making cell-level testing the preferred approach.
A month later, another UNSW team assessed the impact of soldering flux on HJT solar cells and found that the composition of this component is key to prevent major cracks and significant peeling.
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 Lior Kahana
Please be mindful of our community standards.
Your email address will not be published. Required fields are marked *
Comment *
Name *
Email *
Website
Save my name, email, and website in this browser for the next time I comment.


Δ
By submitting this form you agree to pv magazine using your data for the purposes of publishing your comment.
Your personal data will only be disclosed or otherwise transmitted to third parties for the purposes of spam filtering or if this is necessary for technical maintenance of the website. Any other transfer to third parties will not take place unless this is justified on the basis of applicable data protection regulations or if pv magazine is legally obliged to do so.
You may revoke this consent at any time with effect for the future, in which case your personal data will be deleted immediately. Otherwise, your data will be deleted if pv magazine has processed your request or the purpose of data storage is fulfilled.
Further information on data privacy can be found in our Data Protection Policy.
Legal Notice Terms and Conditions Data Privacy © pv magazine 2026
Δ
This website uses cookies to anonymously count visitor numbers. View our privacy policy. ×
The cookie settings on this website are set to “allow cookies” to give you the best browsing experience possible. If you continue to use this website without changing your cookie settings or you click “Accept” below then you are consenting to this.
Close

source

Median solar module pricing in the United States reached $0.28 per watt as the market adjusted to intensified trade enforcement and new Foreign Entity of Concern compliance requirements, according to the Q1 2026 Quarterly Pricing & Domestic Content Report from Anza.
Image: First Solar
From pv magazine USA
The US solar market entered 2026 navigating a landscape defined by regulatory shifts and the persistent threat of supply chain disruptions. Following a year of volatility where median pricing rose by as much as 14% between January and November 2025, the first quarter of 2026 has seen prices hold at an elevated baseline.
The current stabilization at $0.28/W represents a shift from the $0.25/W levels seen in early 2025, driven by the convergence of Anti-Dumping and Countervailing Duty determinations and the tightening of domestic content eligibility.
Higher prices are driven in part by stricter Foreign Entity of Concern (FEOC) rules. Under the US Department of the Treasury’s updated guidance, projects seeking to qualify for the full 10% Domestic Content Bonus under the Inflation Reduction Act must navigate requirements regarding prohibited foreign entity material assistance. For projects beginning construction in 2026, the applicable threshold percentage for non-PFE produced property stands at 40% for solar facilities and 55% for Energy Storage Technologies. These thresholds are scheduled to escalate by 5% annually, creating urgency among developers to secure compliant hardware before the 2027 step-ups. 
Anza’s data, which aggregates median pricing from more than 40 suppliers representing over 95% of the US module supply, highlights a growing price delta between compliant and non-compliant hardware. FEOC-compliant modules have seen a steady price increase of approximately 4.9% as supply chains reorganize to exclude components from restricted entities. In contrast, modules that do not meet FEOC standards saw a more aggressive price spike of 9.2% during the previous safe harbor rush.
Anza noted a convergence in the pricing of mainstream cell architectures. Mono PERC saw its historic price advantage over newer technologies nearly disappear. Median pricing for Mono PERC modules stood at approximately $0.275 per watt in Q1. This represents a 4.2% increase from late 2025 levels, as buyers favored the mature supply chain of PERC to mitigate risks associated with newer technologies.
Tunnel Oxide Passivated Contact (TOPCon) technology is currently priced at a median of $0.285 per watt. While TOPCon previously commanded a more significant premium, patent litigation among Tier-1 suppliers has introduced a layer of caution for some buyers. Despite these intellectual property concerns, the efficiency gains of TOPCon continue to drive high demand in the utility-scale segment. Heterojunction (HJT) modules remain the most expensive mainstream option, holding at $0.39 per watt. The HJT market is characterized by limited U.S. availability, with pricing driven more by specific cell origin and tariff status than by broader market commoditization. 
The domestic manufacturing landscape is also showing signs of bifurcated pricing. Modules utilizing U.S.-made cells command the highest premium in the market, with prices at $0.46 per watt. The price reflects a 5.7% increase, as developers compete for a limited pool of domestically produced cells required to maximize tax credit value.
Conversely, U.S.-assembled modules that utilize imported cells have seen more volatility. Pricing for these hybrid domestic products rose to $0.36 per watt, a nearly 6% increase from the previous quarter. Many buyers are blending domestic modules with imported units or high-value domestic balance of system components like racking and inverters to hit the 40% domestic content threshold while managing overall capital expenditure, said the report.
Imported module pricing has remained relatively flat at $0.265 per watt for products not subject to the most severe trade penalties. However, the shadow of the Section 232 investigation looms over these figures. The investigation, which aims to determine if imported solar components pose a national security threat, could lead to new universal tariffs or quotas.
Furthermore, the anticipated AD/CVD determinations on imports from India, Indonesia, and Laos have begun to influence procurement strategies. Modules from Southeast Asian countries already affected by trade policy saw a 7.7% price increase late last year, and while they have eased slightly, they remain higher than pre-litigation levels. 
In the Energy Storage System sector, the pricing trajectory has diverged from that of solar modules. Battery storage pricing has continued to decline, providing a counterbalance to rising module costs for integrated solar-plus-storage projects.
For a 10 MW 4-hour distributed generation system, the AC Wrap median CAPEX price fell to $212 per kWh, representing a 6.8% decrease. Self-integrated battery systems in the same segment dropped to $173 per kWh. Utility-scale storage followed a similar downward trend, with AC Wrap pricing reaching $194 per kWh and self-integrated pricing falling to $158 per kWh, a 10.6% decline from the peak levels seen in mid-2025. This downward pressure is attributed to falling lithium carbonate costs and an expansion of battery manufacturing capacity outside of China, though Section 301 tariffs on Chinese imports scheduled to hit 25% this year remain a variable. 
Looking forward to the remainder of 2026, Anza warns that the status quo of $0.28 per watt module pricing may be short-lived. The potential for Section 232 tariffs on polysilicon and its derivatives could create a new wave of upward pressure, particularly for domestic manufacturers who still rely on imported raw materials.
Additionally, the Treasury’s Cost Percentage Safe Harbor tables, which allow taxpayers to use assigned cost percentages for domestic content calculations, will be a critical tool for developers navigating 2026 construction starts. As the industry moves toward the 40% domestic content requirement, the premium for US-made cells is expected to remain high, further widening the gap between low-cost imported hardware and tax-advantaged domestic products. 
The report concludes that procurement strategies in 2026 must be increasingly granular. Buyers can no longer focus solely on the cents per watt sticker price but must instead account for the impact of tariffs, the value of the 10% domestic content bonus, and the long-term risk of supply chain audits under the Uyghur Forced Labor Prevention Act (UFLPA) and FEOC rules.
As the market absorbs these regulatory costs, the baseline for US solar pricing appears to have shifted higher, ending the era of sub-twenty-cent utility-scale modules in the American market.
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 pv magazine
Please be mindful of our community standards.
Your email address will not be published. Required fields are marked *
Comment *
Name *
Email *
Website
Save my name, email, and website in this browser for the next time I comment.


Δ
By submitting this form you agree to pv magazine using your data for the purposes of publishing your comment.
Your personal data will only be disclosed or otherwise transmitted to third parties for the purposes of spam filtering or if this is necessary for technical maintenance of the website. Any other transfer to third parties will not take place unless this is justified on the basis of applicable data protection regulations or if pv magazine is legally obliged to do so.
You may revoke this consent at any time with effect for the future, in which case your personal data will be deleted immediately. Otherwise, your data will be deleted if pv magazine has processed your request or the purpose of data storage is fulfilled.
Further information on data privacy can be found in our Data Protection Policy.
Legal Notice Terms and Conditions Data Privacy © pv magazine 2026
Δ
This website uses cookies to anonymously count visitor numbers. View our privacy policy. ×
The cookie settings on this website are set to “allow cookies” to give you the best browsing experience possible. If you continue to use this website without changing your cookie settings or you click “Accept” below then you are consenting to this.
Close

source

India has done an incredible job driving domestic manufacturing through the Production Linked Incentive (PLI) scheme, which has successfully operationalised tens of gigawatts of solar module and cell production. But true energy sovereignty means looking beyond the glass and silicon.
April 06, 2026. By News Bureau

Icon Solar Modules Are Engineered for India’s Harsh Conditions, Says Rajat Shrivastava

Mobile Charging and Energy Storage Will Drive India’s EV Adoption: Mobec’s Harry Bajaj

10th Edition of RenewX Expo Set to Showcase a Decade of Clean Energy Progress

Trontek’s Samrath Kochar Explains How Rooftop Solar Adoption is Boosting Battery Storage Demand

Waterless Robotics Can Recover Up to 12% Lost Solar Generation, Says TAYPRO’s Yogesh Kudale

source

What’s ‘plug-in solar?’ And could it catch on in Georgia?  AJC.com
source

Solar Panel Crimping Tool – Crimper For 2.5/4/6mm PV Cable & Connectors  ruhrkanal.news
source

Dreld Waterproof Cable Entry Gland – IP68 ABS Connector For Solar Panels, RV, Boats (2–6mm² Cables)  ruhrkanal.news
source

This website is using a security service to protect itself from online attacks. We are checking your browser to establish a secure connection and keep you safe.

Please enable JavaScript to continue.

Please enable JavaScript to continue.
Performance & security by bunny.net

source

Kurnool already hosts the state’s largest solar installation, the 1 GW Kurnool solar park in Orvakal
The Andhra Pradesh government has approved land allocation for two large-scale solar parks with a combined capacity of 2 GW, further strengthening the state’s renewable energy push.
The projects will be developed in the Kadapa and Kurnool districts, with each site planned to generate 1 GW of solar power. The land will be transferred to Andhra Pradesh Solar Power Corporation Private Limited (APSPCL), which will lease it to private developers under a 33-year agreement.
According to reports, the Kadapa site will span approximately 466.5 acres, while the Kurnool project—located in Orvakal mandal—will cover around 737.7 acres.
Kurnool already hosts the state’s largest solar installation, the 1 GW Kurnool solar park in Orvakal, which has been operational since 2017, making it a key hub for solar energy development in Andhra Pradesh.

source

Xinhua | October 23, 2025

A flock of sheep graze between solar panels at a solar photovoltaic power plant in Gonghe County, Hainan Tibetan Autonomous Prefecture in northwest China's Qinghai Province, April 15, 2024. (Xinhua/Zhang Long)
For generations, the Talatan Gobi Desert in northwest China's Qinghai Province has endured severe sandstorms, persistent droughts and sparse vegetation, making life for local herders a constant struggle against a harsh natural environment.
Today, Talatan, located in Gonghe County in the Hainan Tibetan Autonomous Prefecture, is undergoing a remarkable transformation. Expansive arrays of deep blue solar panels now stretch across the plateau, harnessing abundant sunlight to generate clean energy. Beneath their shade, pasture grass flourishes, and sheep graze and play freely in what is emerging as a vibrant new savanna.
Yehdor, a local 49-year-old herder, has witnessed this change firsthand. He now tends his flock while riding a motorcycle.
"Our village depends mainly on animal husbandry, and many families raise sheep. In the past, the grassland wasn't productive enough, so herders had to take their sheep far away to find grazing land," Yehdor recalled.
Decades of drought and overgrazing had turned Talatan into a near-endless desert. The turnaround began in 2012. Leveraging the region's strong solar resources and vast flat terrain, the local government promoted the construction of a solar energy base. Today, a sprawling photovoltaic park covers more than 300 square kilometers and is operated by over 60 solar companies, making it one of China's major gigawatt-level solar hubs.
Unexpectedly, the dense solar arrays also act as barriers against wind and sand. Their shade creates a cooler microclimate and reduces evaporation, while periodic cleaning by maintenance crews allows runoff water to seep into the soil, further nourishing the land below. This environment has proven ideal for grass growth. As vegetation returns, soil moisture has improved to the point where grass sometimes grows so tall that it almost seems to reclaim the desert.
"In some areas, the grass grew over a meter high, even blocking the solar panels and reducing power efficiency," said Cao Jun, a staff member with the project department of the local industrial park.
Faced with this challenge, the solar companies turned to local herders. An agreement was reached allowing herders to graze their sheep beneath the panels, providing a natural solution that avoided costly manual or chemical methods. In harder-to-reach areas, herders also harvest grass to use as winter fodder.
"It is a win-win solution. Herders earn extra income while companies save on weeding costs," Cao said.
Technicians also adjusted the panel layout, widening the spacing between arrays from three to five meters and raising the mounting height from 50 centimeters to between 1.5 and 1.8 meters, allowing sheep to move freely beneath them.
Once all projects in Hainan prefecture's 609-square-kilometer photovoltaic park are completed, the grass-planted area is expected to reach 450 square kilometers, yielding around 110,000 tonnes of grass annually. The energy base also provides employment opportunities for local residents.
Technology is enhancing both pasture and livestock management. Some photovoltaic stations employ infrared drones and monitoring systems to track herds across the vast area. In addition, certain pastures equip sheep with digital ID cards in the form of QR code ear tags, storing information such as age, vaccination history and owner details for traceable management.
Each year from June to October, herders can graze sheep in the photovoltaic park free of charge. Under these agreements, nearly 100,000 mu, or roughly 66 square kilometers, of company-owned pastureland is now accessible to local herders.
The prefecture has established 32 photovoltaic eco-pastures and 56 centralized grazing sites within the solar park, supporting 18 surrounding villages that raise more than 20,000 sheep each year. As sheep raised under the solar panels gain recognition, locals have developed a brand for "photovoltaic sheep" and now sell mutton nationwide through e-commerce platforms.
"Our family earns nearly 100,000 yuan (about 14,000 U.S. dollars) a year from raising sheep," Yehdor said. "My flock has grown from 200 to over 300, and our sheep are healthy and strong. Life is much better."
The model combining photovoltaic power generation and animal husbandry, pioneered in Talatan, offers a new approach to desertification control and clean energy development.
In Xinjiang Uygur Autonomous Region and Gansu Province, similar initiatives harness solar power to improve the microclimate, supporting agriculture while combating desertification in arid regions. In Yunnan Province and Inner Mongolia Autonomous Region, high-value traditional Chinese medicinal herbs such as licorice and astragalus are planted beneath solar panels, providing an additional source of income for local farmers.
As China advances green energy, an increasing number of industries and applications are being creatively integrated with it, enabling more efficient use of resources and generating greater overall benefits, while transforming once-barren lands into greener, more prosperous landscapes. 

source

Citicore Energizes 69 MWp Solar Power Plant in Negros Occidental to Support Visayas Grid  SolarQuarter
source