Solar Now

The Ministry of New and Renewable Energy (MNRE) has issued the ninth revision of the Approved List of Models and Manufacturers (ALMM) List-II for solar PV cells, effective August 21, 2026. The revision updates the efficiency ranges of four existing manufacturers and adds new models from three additional producers.
Efficiency revisions
TP Solar Ltd., based in Tirunelveli, Tamil Nadu, has received revised efficiency ranges for both PERC and TOPCon technologies. Its PERC efficiency range now stands at 20.5%-23.7%, while its TOPCon listing covers 20.5%-25.5%. The company has an enlisted capacity of 4,480 MW.
Renewsys India Pvt. Ltd., Ranga Reddy, Telangana, has a revised TOPCon efficiency range of 20.5%-25.6%, with an enlisted capacity of 452 MW. Premier Energies Photovoltaic Private Limited, also based in Ranga Reddy, has a revised TOPCon efficiency range of 22.5%-26.0% and an enlisted capacity of 1,358 MW. Reliance Industries Limited, Jamnagar, Gujarat, has received a revised HJT efficiency range of 23.8%-26.0%, with an enlisted capacity of 1,238 MW.
New models
The revision also adds models from Waaree Energies Limited, EMMVEE Energy Pvt. Ltd. and Avaada Electro Private Limited.
Waaree Energies, based in Navsari, Gujarat, has added a TOPCon model under its enlisted capacity of 4,021 MW per year. The company also has 1,328 MW of enlisted Mono-PERC capacity. EMMVEE Energy, Bangalore Rural, Karnataka, has added a TOPCon model under its enlisted capacity of 2,153 MW per year. Avaada Electro Private Limited has received model additions under its enlisted capacity of 3,621 MW per year.
The ALMM List-II was first issued on July 31, 2025, as the regulatory framework for solar PV cell manufacturers seeking enlistment for use in domestic projects. The ninth revision reflects changes in listed manufacturing capacities, technology specifications and model portfolios as domestic solar cell manufacturing expands.
The featured photograph is for representation only.
CleanMax has secured Rs 400 crore in pre-IPO funding from 360 One Asset Management. The capital will support promoter stake consolidation ahead of the company’s planned public listing. The stake was acquired from Augment Infrastructure and the Danish Investment Fund. The funding is structured as a three-year instrument at 13 per cent interest, with repayment…
Read More CleanMax raises Rs 400 crore in pre-IPO round
The Central Electricity Regulatory Commission (CERC) has issued the draft Deviation Settlement Mechanism and Related Matters (Second Amendment) Regulations, 2025, proposing limited payments for infirm power injected by thermal generating stations before trial runs. Currently, under the DSM Regulations, 2024, no payments are made for infirm power unless scheduled after a successful trial run. Thermal…
Read More CERC proposes payment for infirm power from thermal plants before trial run
AESL Projects Limited has taken over all responsibilities for the Rajasthan Part I Power Transmission Limited HVDC project through a novation agreement signed on November 14, 2025. The move places the entire set of rights and obligations with the Adani Energy Solutions subsidiary for the link that will move renewable energy from Rajasthan and Uttar…
Read More Adani unit takes charge of Rajasthan Part I HVDC project
Saatvik Green Energy Private Limited has signed an agreement for the supply of solar photovoltaic (PV) modules to support 1,200 MW solar power projects in India. Key details include: A contract to supply N-type TopCon PV modules worth Rs 15 billion for 1,000 MW utility-scale solar projects. An agreement with Enrich Energy Private Limited for…
Read More Saatvik Green Energy wins contract for 1,200 MW solar projects
China is facing unprecedented electricity demand as a severe heatwave grips large parts of the country. The National Energy Administration reported that the national power load crossed 1.5 billion kW for the third time in July 2025, marking a new peak in consumption. Reuters noted that temperatures have surged across cities including Chongqing, Chengdu, and…
Read More China sees record power load as heatwave grips southern provinces
Atlanta Electricals Limited has received a debarment order from South Bihar Power Distribution Company Limited (SBPDCL), restricting the company from participating in its tenders for a period of two years, according to a stock exchange filing. The order relates to a purchase order executed during FY2023-24 for the supply of four units of 10 MVA,…
Read More Atlanta Electricals debarred by Bihar utility; disputes test findings
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Floating solar: Can it be India’s next renewable energy success story?  The Indian Express
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In some cases, installers start work and never finish it.
Photo Credit: iStock
A knock at the door can make rooftop solar sound like an easy win. You might hear “free panels,” or be told of endless government support, and electric bills that vanish.
However, the Better Business Bureau says those promises can also be an early warning sign of an expensive scam.
In its report, KYMA said the BBB is warning homeowners to scrutinize unexpected solar offers, particularly when salespeople tout federal tax breaks, advertise “free solar panels,” or suggest monthly electric bills will fall to nothing. 
KYMA added that many of the federal incentives once available to solar buyers are no longer in place after they were retired under direction from the Trump administration, so exaggerated credit claims deserve extra skepticism.
Want to go solar but not sure who to trust? EnergySage has your back with free and transparent quotes from fully vetted providers in your area.
To get started, just answer a few questions about your home — no phone number required. Within a day or two, EnergySage will email you the best options for your needs, and their expert advisers can help you compare quotes and pick a winner.
One customer highlighted in BBB Scam Tracker said he paid $52,000 for panels and a battery and later found the system repeatedly shutting down after the installer went out of business, per KYMA. 
In a separate account, a buyer said he was assured the system would generate enough electricity to erase his power bill, yet he still had to cover those charges plus a $128 monthly lease payment.
The BBB has also stressed that many solar owners are happy they made the switch. Experts quoted by KYMA did say, however, that most households should not expect solar to fully eliminate their electricity costs, even if they are substantially reduced and save enormous amounts of money in the long run.
Rooftop solar can make everyday life more affordable when it is installed and financed properly, lowering household energy costs while also cutting pollution tied to fossil-fueled electricity. But solar contracts can be complicated, and differences in incentives, system design, and company stability can create openings for bad actors to take advantage of confused buyers.
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Want to go solar but not sure who to trust? EnergySage has your back with free and transparent quotes from fully vetted providers that can help you save as much as $10k on installation.
To get started, just answer a few questions about your home — no phone number required. Within a day or two, EnergySage will email you the best local options for your needs, and their expert advisers can help you compare quotes and pick a winner.
The BBB said scams can take several forms, from collecting personal banking information “to see if you qualify” to demanding upfront payments tied to fake reimbursement programs. In some cases, installers start work and never finish it, or they install panels so poorly that the system never performs as promised.
BBB now advises homeowners to check complaints, use BBB.org to verify accredited solar businesses, seek at least three written estimates, and avoid signing under pressure. Buyers should also ask who is responsible for maintenance and repairs if an installer goes out of business. 
If you want solar panel estimates from vetted installers, check out EnergySage. EnergySage’s free services can also help homeowners avoid the high-pressure sales tactics that often come with doorstep pitches. 
The average person who uses EnergySage’s quote comparison tools can save up to $10,000 on solar purchases and installations. That kind of side-by-side comparison can make unrealistic promises easier to spot before a contract is signed.
💡Go deep on the latest news and trends shaping the residential solar landscape
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An “inspection log” from a smart drone  Khmer Times
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By: Luis Reyes
Published: Aug 23, at 11:00am ET
Ten percent is the number direct solar hydrogen has been chasing since before most people had heard of green hydrogen. Hit 10% solar-to-hydrogen efficiency in a panel you can actually manufacture, and the cost models start producing a number that competes with buying solar panels and an electrolyzer separately. Miss it, and you have a very expensive science fair project.
SunHydrogen said on August 11 that its modules cleared the line in an Australian partner’s lab, and that both companies are moving to pilot testing in South Australia.
The claim is real and both sides call it preliminary. What nobody put in the headline is the part where the efficiency went down the last time these panels got bigger.
Here is the track record, which matters more than any single lab result.
In October 2024, SunHydrogen reported that its 100-square-centimeter modules, built with German manufacturer CTF Solar, reached 10.8% solar-to-hydrogen efficiency in testing at Honda R&D in Japan. Solid number. Small panel, roughly the size of a drink coaster.
Then the company scaled up. It built a 1-square-meter array and had 1,200-square-centimeter modules tested at Professor Kazunari Domen’s lab at the University of Tokyo, which is about as authoritative an address as this field has.
Those modules came in at 9% active-area efficiency. SunHydrogen called it the highest reported figure for a module that size, which may well be true. It is also 1.8 points below what the coaster-sized version managed.
That is the whole problem with this technology in one comparison. Efficiency at bench scale does not survive the trip to panel scale intact, and panel scale does not survive the trip outdoors intact either.
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Every efficiency figure SunHydrogen has published came from SunHydrogen or a company it pays or partners with. This one came from Sparc Hydrogen, which had no obligation to say anything flattering.
Sparc’s testing put the modules above 10% and found they produced more hydrogen as the light was concentrated, which is the behavior its reactor is built around. SunHydrogen CEO Tim Young called it “exactly the kind of outside validation our shareholders want to see.”
That framing is worth sitting with for a second. SunHydrogen is a nine-person company in Coralville, Iowa, with no revenue, roughly 5.3 billion shares outstanding and a stock trading around two cents. It was incorporated in 2009 as HyperSolar and renamed in 2020. Seventeen years of announcements, no product.
None of which makes the science wrong. It does mean the company has strong reasons to publicize a lab number, and readers should weight it accordingly.
Sparc Hydrogen is a joint venture between Sparc Technologies, the University of Adelaide and Fortescue, through a wholly owned subsidiary. Its reactor uses photocatalytic water splitting, invented by University of Adelaide chemistry professor Greg Metha, which produces hydrogen from concentrated sunlight and water with no electrolyzer and no grid connection at all.
Andrew Forrest’s Fortescue Future Industries first took a stake in 2022 and moved to an equal top ownership position in January 2025. Michael Dolan, Fortescue’s head of R&D, sits on the board.
The timing tells you what this is. Fortescue gutted its own green hydrogen program in 2024, scrapping a target of 15 million tons a year by 2030 and cutting 700 jobs, because electrolysis powered by renewables cost too much at that scale. Then it doubled down on a technology that skips electrolysis entirely.
That is a hedge, and a rational one. It is also not a vote of confidence in green hydrogen broadly.
The local backdrop is worse. South Australia canceled a $600 million hydrogen hub planned for Whyalla, which would have included the world’s largest electrolyzer, and moved the money to rescuing the Whyalla steelworks instead.
The Sparc Hydrogen Advanced Research Pilot sits at the University of Adelaide’s Roseworthy campus north of the city. It came online in June 2025, and Sparc believes it is the only facility anywhere purpose-built to test photocatalytic water splitting under concentrated solar conditions.
Stage one prototype testing happened back in late 2023 at CSIRO’s Energy Centre in Newcastle, using 451 heliostats aimed at a 100-foot solar tower.
In December 2025, Sparc announced sustained hydrogen generation at Roseworthy, completing commissioning. The plant currently runs on photocatalyst powders from Shinshu University in Japan.
SunHydrogen’s modules would go into the same reactor as a different chemistry. That is the actual experiment: does a photoelectrochemical panel work inside a rig designed for powders?
Most coverage of this deal has called it a partnership with off-ramps. The actual terms are more specific than that.
Sparc gets rights to apply SunHydrogen’s technology in concentrated-light applications above an agreed threshold. SunHydrogen keeps everything in decentralized production under natural, unconcentrated sunlight. That is a field-of-use split, not a shared bet.
If the collaboration finishes successfully, Sparc holds an 18-month option to negotiate a long-term supply agreement or a manufacturing license, plus a right of first offer against competing arrangements in concentrated light. Each side keeps its own IP and its own improvements. The whole thing runs 24 months with independent review points and go or no-go decisions between phases.
And Sparc Technologies told the Australian Securities Exchange the agreement is expected to have limited near-term financial impact. When the listed partner tells its own shareholders not to get excited, that is the most honest sentence in the announcement.
SunHydrogen’s other program is at the Hydrogen ProtoHub at the University of Texas at Austin, and it has not been smooth.
Earlier prototype modules suffered a voltage drop in the solar substrates and coating failures that let moisture reach the semiconductor layer. Those were fixed at lab scale with help from CTF Solar, and the pilot restarted with upgraded modules.
Worth remembering when reading efficiency numbers. Moisture reaching a semiconductor stack is exactly the failure mode you would expect from a device whose entire operating principle involves sitting in water, and concentrated sunlight makes thermal stress worse rather than better. Panels lose performance as they heat up, which is why desert solar installations fight temperature so hard.
SunHydrogen also has a roughly $2.3 million order with CTF Solar for 1,000 modules of nearly 2 square meters each, plus new offices in Japan and Austria. As of this spring the company reported about $33 million in cash and no debt, which buys time but not a product.
Two things have to land.
The modules need to hold above 10% bolted into the SHARP reactor at Roseworthy, outdoors, for months rather than hours. Given that the 1,200-square-centimeter version already gave up almost two points indoors, that is not a formality.
Then the jointly funded techno-economic assessment has to produce a levelized cost of hydrogen that beats solar plus an electrolyzer in a sunny place. That is the deliverable both companies named, and it is the only number that decides anything. Efficiency is a talking point. Dollars per kilogram at the fence line is a business.
The useful thing about a 24-month agreement with review gates is that it produces an answer either way. Either the panels make hydrogen under an Australian sun at a price that works, or Sparc walks at a gate and keeps its powders. Hydrogen programs rarely fail loudly. They go quiet, and the next press release is about something else.
What do you think?
Luis Reyes · Aug 15, 2026
Luis Reyes · Aug 21, 2026
Luis Reyes · Aug 5, 2026
Luis Reyes · Aug 3, 2026
Luis Reyes · Aug 16, 2026
Luis Reyes · Aug 11, 2026
Luis Reyes · Aug 23, 2026
Luis Reyes · Aug 23, 2026
Luis Reyes · Aug 23, 2026
Luis Reyes · Aug 23, 2026
Luis Reyes · Aug 23, 2026
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Energies Media
ative bees working soybean flowers beside a solar farm fence
There is a fence, and there is a soybean field on the other side of it.
Inside the fence, rows of dark panels stand over waist high prairie in flower.
Outside, an ordinary crop, planted by somebody who had no say in any of it.
The bees do not know about the fence.
Counting them turned out to be the interesting part, because they were not staying put, and the farmer was getting something for nothing.
Where did they all come from?
A raised solar array changes two things about the dirt underneath it, and both of them favor prairie.
The first is heat. Panels take the hardest midday sun off the soil, and the plants below get a cooler, damper root zone than open ground offers in a Midwest August.
The second is water. Rain does not land evenly any more. It runs off the panel surface and arrives in a concentrated line along the drip edge, which leaves the ground under an array patchy by design, wet in strips and dry between them.
That patchiness is a problem for a crop, which needs every row alike.
For a prairie mix it is closer to home conditions. These are plants shaped by uneven ground, and dozens of species sorting themselves into the wet lines and the dry ones is exactly what a seeded prairie is supposed to do.
The two sites sit on retired farmland in southern Minnesota. Before the first summer of operation, the soil under and around the arrays was seeded with dozens of species of native grasses and wildflowers rather than the usual gravel or mown turf.
Then almost nothing happened.
Prairie is slow. Seeded plants spend their early years putting roots down rather than flowers up, and the first counts under those panels found sparse bloom and very few insects.
The change arrived on the plants’ schedule, not the operator’s. By the third growing season the flowering had thickened enough that the insect numbers stopped wobbling and started climbing, and they kept climbing until the counting stopped.
Four fifths of all the native bees seen across the whole project were seen after year two.
The work was deliberately unglamorous. Walk the same transects, four times each summer through the peak flowering weeks, and write down every flowering plant and every insect that lands. 358 surveys in all, from the first August to the last.
The totals came out lopsided in an interesting way.
Total insect abundance roughly tripled. The number of distinct insect groups rose by about 150 percent. Flowering plant species richness went up sevenfold.
And native bees, counted on their own, multiplied by a factor of 20.
That gap is the finding. A tripling of insects overall alongside a twentyfold rise in one group means the habitat was not simply getting busier, it was selecting for the animals that work flowers.
None of that would matter much to a farmer if it stayed on the site.
So the team counted bees on the soybean flowers next door as well, and found twice as many visiting the rows closest to the solar fence as the rows farther away. Visitation beside the arrays came out on par with soybean grown beside conservation grassland, the land a federal program pays farmers to keep out of production.
Which is the quiet economic point. One neighbor is being paid to maintain that habitat, the other built it as ground cover under a power plant, and the crop next door cannot tell the difference.
It also lands differently than most arguments about panels on farmland, where the usual frame is land taken out of production rather than a service handed over the fence for free.
It is two sites in one state, in a region where prairie grows anyway. Nobody has shown the same thing in the desert Southwest, and the researchers do not claim it.
Site preparation decides a great deal of it. An array built on a scraped and leveled pad starts from bare subsoil, and a seed mix put down there is beginning a much longer job than one sown into soil left in place.
The economics still push the other way. Pollinator seed costs more than turf and needs different mowing, and developers who might do it want to know they will break even.
There is a counterweight worth keeping in view too. Panels reflect polarized light in a way that can read as water to some insects, which is a real effect and not one this study measured.
A senior director at a clean energy policy center said that making solar farms support native pollinators is an obvious solution. On this evidence it is obvious, cheap and slow, and the slow part is the reason it keeps losing arguments to gravel.
Hugo is an engineer with strong technical expertise and deep knowledge of the space industry. Multilingual from an early age, his writing combines technical clarity with a strong interest in science and energy.
Hugo is an engineer with strong technical expertise and deep knowledge of the space industry. Multilingual from an early age, his writing combines technical clarity with a strong interest in science and energy.
Hugo is an engineer with strong technical expertise and deep knowledge of the space industry. Multilingual from an early age, his writing combines technical clarity with a strong interest in science and energy.

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The company’s pilots reflect a broader shift in how utilities are thinking about clean energy land.
Photo Credit: iStock
Solar farms in Florida are starting to look less like fenced-off power sites and more like working landscapes, as Florida Power & Light uses land around solar panels for honeybees, grazing animals, and crop research — an approach that could help clean energy projects do more for nearby communities by supporting food production, pollinators, and lower-maintenance green space.
A new milestone for Florida Power & Light’s pilot work is that more than 40 honeybee projects are in place at the company’s solar energy centers across the state, WUSF reported.
Those hives are being added through partnerships with beekeepers in 18 counties, using the green space available at the solar locations.
One of those beekeepers, Mark McCoy of McCoy’s Sunny South Apiaries in Loxahatchee, said, “It’s been great keeping bees with FPL on their solar sites because it allows us to have access to remote areas and different locations that we never had access to before, finding more natural resources for the bees.”
FPL says the impact of those pollinators could extend beyond the solar sites, helping local ecosystems while also potentially increasing nearby farm yields and supporting food production.
The company is also trying other agricultural uses on solar properties, including cattle at a DeSoto County location and sheep at sites in Northwest Florida.
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This type of shared land use is often referred to as agrivoltaics, which pairs solar infrastructure with agriculture rather than treating the two as competing demands for land.
Using the same acreage for renewable energy and agricultural activity can reduce pressure to set aside separate land for separate purposes.
Sheep and cattle can also take on some of the vegetation control that would otherwise be handled through mowing.
Better pollination can support farm output, while more efficient land use can help communities expand renewable power without losing agricultural opportunities.
At its Miami-Dade Solar Energy Center, FPL is working with UF/IFAS to evaluate how efficiently crops can be grown on solar sites, which could help identify the kinds of farming that work best alongside panels in Florida conditions.
The company’s pilots reflect a broader shift in how utilities are thinking about clean energy land.
Instead of reserving solar properties only for electricity generation, FPL is testing whether those same areas can also host beekeeping, livestock grazing, and crop research.
If the model proves successful, it could open new opportunities for beekeepers and ranchers while helping solar developers get more value from land they already manage.
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California Senate bill would allow “balcony” solar panels  KTVU
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India has invested heavily in building a domestic solar manufacturing ecosystem. Over ₹1 lakh crore has been committed to establish solar cell manufacturing capacity and develop an integrated value chain spanning cells, wafers, ingots and polysilicon. Yet, in FY 2025-26, India imported more than $3 billion worth of solar photovoltaic (PV) cells, with the overwhelming majority sourced from one nation.
At prevailing global prices, these imports are equivalent to approximately 70-80 GW of solar cells, enough to meet nearly two years of India’s annual demand. For a country pursuing self-reliance in clean energy manufacturing, this level of import dependence warrants serious attention.
The import trend is equally revealing. Solar cell imports stood at $1.85 billion in FY 2023-24, declined marginally to $1.64 billion in FY 2024-25, and then surged by 86 per cent to $3.06 billion in FY 2025-26.
The acceleration has been even sharper in recent months. Between January and April 2026 alone, India imported $1.37 billion worth of solar cells, compared to $702 million during the same period in 2025 and $528 million in 2024. Imports during the January to April period have nearly tripled in just two years.
The January to April period is particularly significant because solar cells generally have a usable shelf life of five to six months before module manufacturers prefer to process them into modules.
These imports are therefore not inventory being accumulated for future use. They are cells entering production during the current manufacturing cycle. Every imported cell assembled into a module represents demand that could have been met by an Indian cell manufacturer. Once that module is produced, the opportunity for domestic value addition has already been lost.
The implications extend beyond today’s cell manufacturers. Solar cells account for nearly half the value of a finished module and represent the technology-intensive core of the manufacturing process.
Weak utilisation of domestic cell capacity also weakens the commercial case for investments in wafers, ingots and polysilicon, precisely the upstream segments that India seeks to develop. Every imported cell shifts value addition, skilled employment, manufacturing know-how and future investment outside the country.
The concentration of imports adds another dimension. Nearly two-thirds of India’s solar cell imports over the past three years have originated from one nation.
Such dependence on a single source for a strategically important component exposes the industry to supply chain disruptions, pricing pressures and geopolitical risks.
As solar power becomes central to India’s energy security, resilience in the manufacturing supply chain becomes just as important as the pace of renewable energy deployment.
This is not an argument against international trade or healthy competition. Indian manufacturers recognise that global competition drives efficiency and innovation.
However, every successful manufacturing economy has provided policy stability while strategic industries mature.
Consistent implementation of ALMM List II for solar cells, faithful enforcement of Domestic Content Requirement provisions and a predictable procurement pipeline would provide the confidence required for manufacturers to continue investing across the upstream value chain.
The $3 billion spent on imported solar cells in FY 2025-26 is more than a trade statistic.
It represents demand that could have strengthened domestic manufacturing, accelerated technology adoption, created skilled employment and supported the next generation of investments in India’s solar ecosystem.
Building factories is only the first step. Ensuring that they remain competitive, fully utilised and integrated into India’s energy transition is the real test of a successful industrial policy.
The writer is Secretary General, Indian Solar Manufacturers Association (ISMA)
Published on August 23, 2026
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It can offer lower energy bills, less exposure to electricity price swings.
Photo Credit: iStock
For many households, the ability to save money with solar has long depended on owning a home and having the right roof. 
Now, Iowa lawmakers can consider a change that could expand those savings to renters and apartment residents through community solar, a shared model that allows people to buy into (and benefit from) an off-site solar project.
If the legislation advances in Iowa, community solar could reach more residents. As Axios reported, the Iowa Business for Clean Energy recently released a report that argues that residents across Iowa could financially benefit from community solar, all without impacting non-participants’ bills.
The latter piece of that argument matters because utility companies and energy corporations have long argued against the cost-saving solar projects due to their potential to impact other customers who do not participate.
If Iowa ends up adopting community solar legislation, instead of putting panels on a house they own, participants would join a shared installation and receive credits on their electricity bills. Nearly half of states across the country (24) allow community solar, with many specifically designed to help low- and moderate-income families save money on energy, per Axios.
Most people cannot easily use or afford rooftop solar, whether they rent, live in multifamily buildings, or cannot manage the upfront expense of a private system. This makes community solar projects helpful for far more people to access the savings associated with cleaner energy without requiring any work on their own homes.
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Utility companies continue to push back on its legalization.
Community solar has become an increasingly popular option in places where homeownership rates, housing density, or building design make rooftop installations more difficult. It can offer lower energy bills, less exposure to electricity price swings, and access to a technology that might otherwise be limited to single-family homeowners.
A household that cannot install panels because of a landlord, too much shade, or poor roof conditions could still benefit from solar energy generated elsewhere. For apartment residents in particular, shared projects can provide monthly savings.
Expanding solar can also reduce demand for electricity generated by polluting fuel sources, which may help improve air quality over time and support healthier communities. 
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Lincoln Electric System and Google have entered into an agreement that could bring up to 202 megawatts of solar energy into the Southwest Power Pool to help support the tech giant’s data center north of Lincoln.
Solar panels are seen near Hallam on Friday. Google wants to tap into energy genered from the Panama Energy Center solar farm near the village.
Lincoln High school players run through drills at Beechner Athletic Complex on Monday, Aug. 17, 2026, in Lincoln.
Window washer Rogelio Perez repels from the roof of the Scott Engineering Center ahead of classes at the University of Nebraska-Lincoln on Monday, Aug. 17, 2026, in Lincoln.
Nebraska Wesleyan University baseball player Jaxson Volmer loads an incoming University of Nebraska-Lincoln freshman’s bags on Monday on the UNL campus. “It is a lot easier with volunteers helping,” NWU baseball player Drake Venema said. “I know as a freshman, I was scared and flustered by the experience. So this definitely would have helped me.” Athletes from Wesleyan were earning money for travel and equipment for their team’s programs by helping with move-in.
A long-exposure-pan photograph of a cyclist on Tuesday, Aug. 11, 2026, as they ride the Billy Wolff Trail at Holmes Lake Park in Lincoln.
Lead teacher Alex Deaney (left) watches as 1-year-old Daniel Obe (right) plays with a bubble machine on Friday, Aug. 14, 2026, in a classroom located at the Bansal Family Home for Head Start in Lincoln.
Pius X head coach Michael Grindey greets players during warmups as the Thunderbolts hold football practice on Thursday, Aug. 13, 2026, at Lincoln Pius X High School in Lincoln.
Andrew La Grone, representing the Nebraska Republican Party, presents his case during a hearing at the Lancaster County Courthouse on on Wednesday, Aug. 12, 2026, in Lincoln.
Jennifer Kramer hugs her son, Christian, as she drops him off for his first day of kindergarten at Humann Elementary School on Wednesday, Aug. 12, 2026, in Lincoln.
Jasper Gonzalez plays in the water from a sprinkler during the city’s first-ever hydrant party at Densmore Park on Monday. The city is hosting four hydrant parties this month. The next three are Friday at UPCO Park; Monday at Arnold Heights Park; and Aug. 21 at the Roberts Park. All parties are 4:30-6 p.m.
Seen through the digital viewfinder of a Journal Star video camera Nebraska head coach Matt Rhule speaks on Saturday, Aug. 8, 2026 during a press conference at the Hawks Championship Center in Lincoln.
Nebraska quarterback Anthony Colandrea hands back a signed ball to 4-year-old Lily Decker, from Lincoln, on Saturday during Nebraska football’s fan day at the Hawks Championship Center.
Seen from the interior of a car, raindrops on the front windshield reflect the Nebraska State Capitol on Wednesday, Aug. 5, 2026, in downtown Lincoln. The city experienced its 10th wettest July on record, with 6.78 inches of rain, surpassing the normal by 3.53 inches
Lorenzo and Desarie Ball, co-owners of Capitol View Winery and Vineyards, stand in their vineyard Tuesday in Roca. The couple gave up their work in the corporate world to take over the winery south of Lincoln. 
Independent Senate candidate Dan Osborn waves to supporters as he is introduced during a campaign rally at Bourbon Theater on Monday in Lincoln.
Law enforcement officers on motorcycles lead a funeral procession for Crete Police Chief Gary Young as they arrive outside of Lincoln Memorial Cemetery on Monday.
Carpet Land, including Fisher Irons (5), dogpiles with Bradyn Erickson (2, catcher) after defeating Creighton Prep to win the American Legion Class A state tournament Saturday at Den Hartog Field.
Carpet Land head coach Mychal Lanik celebrates with his 8-year-old son, Gehrig Lanik, after Carpet Land (Lincoln East) defeated Five Points Bank (Creighton Prep) 7-2 on Saturday at Den Hartog Field in Lincoln to win the American Legion baseball championship. Carpet Land swept the best-of-three series 2-0.
A sixth-grade Sixers’ player attempts a block as a T-Wolves player shoots inside the paint during the annual Railyard Rims 3-on-3 basketball tournament sponsored by YMCA of Lincoln, Downtown Lincoln Association and Scheels on Saturday, Aug. 1, 2026, at The Railyard in Lincoln.
Elsie Maranville ducks underneath her horse Katniss while her friend Saylor Bontrager, right, works to secure her saddle on Wednesday, July 29, 2026, at the Sandhills Global Event Center.
Contact the writer at tronen@journalstar.com or 402-473-7391. On X @tronen22

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“This follows a significant first half of the year for renewable energy, with a number of other notable milestones.”
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Ireland’s power mix reached a notable milestone in July, with solar delivering its strongest monthly showing yet, helping renewable sources supply more than 30% of the country’s electricity. This also signals a broader shift toward cleaner power that could reduce reliance on fossil fuels tied to price swings and pollution.
After rising from 7.8% in May to 8.2% in June, solar’s share of Ireland’s electricity mix climbed to nearly 10% in July, its strongest monthly performance on record, according to the Irish Examiner.
Electricity demand totaled 2,744 GWh in July, which was 68 GWh higher than in June. Wind supplied 22% of that power, equal to 614 gigawatt-hours. Meanwhile, gas remained the largest single source of power at 43%, while imports through interconnectors (via undersea cables connected to the U.K.) accounted for 24%.
EirGrid director of system operation Diarmaid Gillespie said the July result was part of a broader stretch of strong renewable performance.
“This follows a significant first half of the year for renewable energy, with a number of other notable milestones including a new record for wind generation in February and grid-scale solar power reaching a peak of more than 1GW of electricity for the first time in April,” Gillespie said.
As renewable output grows, EirGrid said it’s upgrading the electricity system to handle higher levels of clean power while maintaining safe operation. The grid operator reports that it’s now able to safely handle up to 75% of electricity coming from variable renewable sources (like wind and solar) at a time. And the organization is aiming to increase this percentage to 95%.
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The Irish Examiner reported that five new wind energy projects won approval in the second quarter of 2026, the highest total since the first quarter of 2025, and only one project was denied planning permission.
According to Wind Energy Ireland, the approved projects will add a “combined generation capacity of 311MW, enough to power just over 180,000 homes each year.” The group also noted that “concerns are growing about the large backlog of wind farm planning decisions.”
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On the morning of July 13, smoke rose from a field on Bracken Road in Schaghticoke, New York.
Firefighters arrived expecting almost anything, and what they found was blackened dry grass smoldering beneath a row of solar panels, the panels themselves untouched, and a single piece of electrical equipment at the center of it all.
The question the investigation had to answer was how a device meant to manage electricity had turned a summer field into a fire scene.
Solar panels generate direct current electricity, a flow that cannot be fed into a home or a grid without first being converted into the alternating current that standard wiring carries. That conversion happens inside a box mounted near the panel array, working continuously whenever the sun is shining and carrying significant electrical load on hot midsummer days.
When a converter develops an internal fault, the direct current flowing through it does not simply stop the way household alternating current does when a circuit breaker trips. Direct current arcs persist because the voltage does not pass through zero, which means a failing component can sustain a spark far longer than a comparable fault on the alternating current side.
That sustained arc generates intense, localized heat. On a July afternoon in upstate New York, the grass around the array base was dry, and the sequence was straightforward: a component fault, a persistent arc, and heat transfer to vegetation below.
Crews responded to the Herrington Community Solar Farm on Bracken Road, with the local fire department confirming the incident. Fire Chief George Conover said authorities received a call for a smoke investigation, and when crews arrived they contacted the operator of the site and did not enter until they verified the power was shut off. That decision reflects standing guidance on solar site response: energized panels continue to produce voltage even when disconnected from the grid.
Once the system was de-energized, crews deployed on ATVs with a water wagon and extinguished the ground fire. The site’s footprint kept the blaze from reaching the road or neighboring parcels, and there was no damage to panels, electrical components or other equipment.
An investigation determined there was an AC/DC converter that failed, sparked and then caught the grass on fire. The power system tripped the breaker and operated as it was supposed to. That automatic disconnection almost certainly limited how far the grass fire spread.
DC arc faults are among the more serious hidden risks in solar installations. Modern inverter and converter units at utility and community scale sites are required in the United States to carry arc fault circuit interrupters on the DC side, devices designed to detect the irregular current signature of a sustained arc and open the circuit before ignition can follow. Yet many solar fire incidents begin with small faults that stay unnoticed too long: loose connectors, overheating inverters or damaged cables that slowly become serious risks.
Fire Chief Conover met with the solar farm’s operators and the town code inspector, and they agreed that prior to restarting the system the operator would need to provide a letter confirming the system meets all codes. That requirement put the burden of proof on the operator before a single panel could generate power again, which is the standard posture a municipality takes after any electrical incident that produces a fire.
The Herrington site is a shared subscription model, meaning households in the surrounding area draw credits from its output rather than owning panels outright. A restart hold therefore reaches beyond the site fence and affects subscribers waiting on their next billing cycle. That exposure is the quiet cost of a single component failure at a community installation. For context on how these sites interact with their surroundings, Minnesota solar farms show how vegetation decisions on the ground shape a community installation in ways equipment specs never anticipate.
The Schaghticoke event was small by most measures: no injuries, no panel damage, no structural loss. Yet it illustrates the physical chain investigators trace in almost every solar farm grass fire: a component fails, direct current sustains an arc, localized heat reaches dry vegetation, and the outcome depends on how quickly the protection circuit and the fire department both respond.
The Herrington site had a native habitat program running beneath its panels, including wildflower seeding and sheep grazing, which is part of why vegetation management in the array corridor matters beyond aesthetics. A maintained, short grass buffer between converter housings and the surrounding meadow may be the simplest mitigation available, and it costs almost nothing.
For a look at how ground conditions beneath floating solar arrays present their own unresolved questions, the pattern is consistent: the panels themselves rarely cause the problem, but everything around them still can. A town’s solar subscribers waited on their operator to produce a compliance letter, and small fires, it turns out, have long administrative tails.
Hugo is an engineer with strong technical expertise and deep knowledge of the space industry. Multilingual from an early age, his writing combines technical clarity with a strong interest in science and energy.
Hugo is an engineer with strong technical expertise and deep knowledge of the space industry. Multilingual from an early age, his writing combines technical clarity with a strong interest in science and energy.
Hugo is an engineer with strong technical expertise and deep knowledge of the space industry. Multilingual from an early age, his writing combines technical clarity with a strong interest in science and energy.

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The proposed solar project in Oakland would be 35 acres on Kornstedt Farms west of Hope Lake Road.
The proposed solar project in Oakland would be 35 acres on Kornstedt Farms west of Hope Lake Road.
OAKLAND — The Oakland Town Board reviewed the language in the road agreement for the 35-acre solar farm planned off Hope Lake Road on Tuesday.
The board approved in July the conditions and stormwater agreement for the solar farm at Kornstedt Farms.
Oakland Town Board Chair Laura Payne said the town has no control over whether the solar farm goes in, so the road agreement protects the town in the case of potential road use and damage.
The road agreement included guidelines on what roads construction workers could drive on, in this case only County Highway A and Hope Lake Road.
Payne also said the solar company must be done with construction by the time the town starts its project on Hope Lake Road, which is March 1, 2028.
The solar company will also need to repair any roads if they were damaged during construction and will do an inspection ahead of starting construction to see the state of the roads beforehand.
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Scientific Reports volume 16, Article number: 16671 (2026) Cite this article
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Maximum Power Point Tracking (MPPT) algorithms, which are employed to extract the maximum power from photovoltaic (PV) systems, exhibit different performance characteristics under uniform irradiance and partial shading conditions (PSC) arising from nonuniform solar irradiance distribution on PV panels. Under PSC, the performance of conventional MPPT algorithms becomes inadequate, leading to increased interest in optimization-based approaches. In this study, the Grey Wolf Optimization (GWO) algorithm, commonly used in MPPT applications, was modified, and an Improved Grey Wolf Optimization (IGWO) algorithm was proposed. A PV system model consisting of four series-connected PV panels and a boost converter was developed in the MATLAB/Simulink environment to evaluate the performance of the proposed algorithm. The effectiveness of the algorithm was tested under nine distinct and complex PSC scenarios. The results obtained under these nine PSC cases were analyzed through comparisons of the proposed IGWO algorithm with GWO, the Cuckoo Search Algorithm (CSA), and the Flower Pollination Algorithm (FPA). The results demonstrate that the IGWO algorithm achieves the highest mean maximum power and exhibits superior MPPT performance compared to the other algorithms, with a mean tracking efficiency of 98.34%.
Global warming, environmental pollution, the depletion of carbon-based fuel reserves, and the steadily increasing energy demand have significantly increased interest in renewable energy sources. Among renewable energy sources, solar energy stands out due to its sustainability and wide applicability. Photovoltaic (PV) panels generate different power levels depending on variable atmospheric conditions such as irradiance and temperature. The relatively low efficiency of PV panels and the requirement to operate at maximum power under varying operating conditions necessitate the use of effective control and tracking methods. Accordingly, Maximum Power Point Tracking (MPPT) algorithms have been developed to maximize the power extracted from PV systems^1,2.
In PV systems, PV panels are connected in series and parallel configurations to achieve the desired power and voltage levels. When all panels in a PV system are subjected to identical temperature and irradiance conditions, the system is considered to operate under uniform irradiance, whereas exposure of panels to different irradiance levels is referred to as partial shading conditions (PSC). Under uniform irradiance conditions, conventional MPPT algorithms such as Perturb and Observe (P&O), Incremental Conductance (InC), and the 0.8 V_oc method provide effective and reliable performance³. However, MPPT algorithms are expected to rapidly reach the maximum power point during transient conditions while minimizing power oscillations under steady-state operation. To satisfy these requirements, advanced MPPT approaches have been proposed in the literature, including Fuzzy Logic^4,5, Artificial Neural Networks (ANNs)^6,7, modified P&O^8,9, and modified InC^10,11.
Achieving maximum power in PV systems operating under PSC constitutes a significant challenge. The primary reason for this difficulty is that, under PSC, multiple maximum power points can occur at different voltage levels depending on the number of PV panels. Among these points, only one corresponds to the highest power, known as the Global Maximum Power Point (GMPP), and operating the PV system at this point is critical for maximizing power generation. The remaining maximum power points are defined as Local Maximum Power Points (LMPPs), and operation at these points results in undesirable power losses. To achieve maximum power under PSC, modified conventional MPPT algorithms have been proposed in the literature^12,13. In addition, scanning-based MPPT algorithms, similar in principle to conventional MPPT approaches, have also been reported in recent studies. MPPT algorithms based on voltage scanning and voltage transient behavior stand out due to their high tracking speed and efficiency^14,15. While scanning-based algorithms offer the advantage of being independent of PV system parameters, high-speed and high-efficiency methods such as voltage segmentation and the modified 0.8 V_oc are known to operate in a parameter-dependent manner with respect to PV panel characteristics^16,17.
Interest in optimization-based MPPT algorithms has increased in recent years, primarily because these algorithms offer a significant advantage over conventional methods by largely eliminating power oscillations under steady-state conditions. Moreover, these approaches are capable of achieving high performance under both uniform irradiance and partial shading conditions (PSC), thereby reducing the need for separate PSC detection mechanisms. It has been demonstrated in the literature that Particle Swarm Optimization (PSO)-based MPPT algorithms provide superior performance under both uniform and PSC conditions compared to conventional hill-climbing methods, while significantly reducing steady-state power fluctuations¹⁸. The Cuckoo Search Algorithm (CSA) is another optimization algorithm widely used in MPPT applications, its effectiveness has been validated in numerous studies. CSA can be applied independently or in combination with the Golden Section Search (GSS) algorithm to achieve faster maximum power point tracking^19,20. Unlike swarm-based algorithms, the Flower Pollination Algorithm (FPA) is inspired by the natural pollination mechanism of flowers and has been extensively employed in the literature to extract maximum power from PV systems^21,22.
In recent years, a wide range of optimization-based approaches has been proposed for MPPT applications, including the honey badger algorithm²³, seagull optimization algorithm²⁴, coot optimization algorithm²⁵, dung beetle optimization algorithm²⁶, zebra optimization algorithm²⁷, search and rescue optimization algorithm²⁸, horse herd optimization algorithm²⁹, salp swarm optimization algorithm³⁰, roach infestation optimization algorithm³¹, falcon optimization algorithm³², arithmetic optimization algorithm³³, and musical chairs algorithm³⁴. The primary objective of these algorithms is to reach the maximum power point with high efficiency and short tracking time under complex PSC scenarios. However, in practical applications, low computational burden is of critical importance for microcontroller-based systems. Reducing the computational complexity of MPPT algorithms enables cost reduction through the use of simpler hardware.
The Grey Wolf Optimization (GWO) algorithm is one of the early optimization-based methods developed for MPPT applications and has become an important benchmark approach frequently used to compare the performance of newly developed algorithms in the literature. GWO models the leadership hierarchy and hunting behavior of grey wolves in nature³⁵. Although the GWO algorithm has demonstrated successful results in identifying the maximum power point in PV systems, further studies have been required to improve its tracking speed. In this context, a modified GWO algorithm in which the convergence factor a was adjusted achieved an approximately 45% improvement in tracking time³⁶. Similarly, enhanced GWO algorithms, in which the convergence factor a was restructured using trigonometric expressions, were comparatively evaluated in combination with the Salp Swarm Optimization algorithm^37,38. The results indicate that the improved GWO algorithms provide significant advantages, particularly for PV systems operating under PSC.
In another study, a newly designed two-stage MPPT algorithm combined the GWO and P&O algorithms, resulting in a substantial improvement in tracking time³⁹. Furthermore, MPPT approaches that hybridize GWO and the Whale Optimization Algorithm (WOA) with the P&O method were proposed, and their performance was compared through simulations conducted under uniform irradiance conditions and using real field data⁴⁰. A high-efficiency hybrid MPPT algorithm, developed by integrating GWO with the Equilibrium Optimizer algorithm, was experimentally compared with Particle Swarm Optimization (PSO), WOA, and FPA methods⁴¹. Similarly, high-efficiency hybrid MPPT algorithms based on CSA-GWO and PSO-GWO combinations were developed, and their effectiveness was validated under different PSC scenarios^42,43. Finally, in a recently developed GWO-based MPPT algorithm, tracking efficiency was further improved, and the experimentally obtained results were presented graphically⁴⁴.
In this study, a novel MPPT algorithm based on Improved Grey Wolf Optimization (IGWO) is proposed by redefining the operating boundaries of the conventional GWO algorithm. The proposed IGWO algorithm is designed to operate over a total of 20 iterations. In the GWO algorithm, if the targeted maximum power is reached within the first 10 iterations, the process is terminated; otherwise, when the desired power variation is not achieved, the duty cycle corresponding to the highest power obtained at the end of the 10th iteration is used as the initial reference, and the algorithm is restarted. With this approach, the search space of the GWO algorithm is constrained, aiming to reach the maximum power point more rapidly within a narrower operating range.
A PV cell can be represented by an equivalent circuit model consisting of a diode, two resistors, and a current source, as shown in Fig. 1^45,46. By connecting PV cells in series and parallel, PV panels are formed, and multiple panels combined together constitute PV arrays. In this study, a PV system model is developed in the MATLAB/Simulink environment by connecting four SunPower SPR-X19-240 PV panels in series.
Single PV cell modelling.
Each PV panel produces approximately 240 W of power at the maximum power point under nominal test conditions (1000 W/m², 25 °C), resulting in a total nominal power of 960 W for the four-panel system. A boost converter is connected to the output of the PV system to supply the load and enable the implementation of MPPT algorithms. To operate the optimization-based MPPT algorithms, the current and voltage values of the PV system are measured. The parameters of the PV panels and the boost converter are presented in Table 1.
In the PV system simulation, the sampling time is set to 1 µs, while the switching frequency of the boost converter is 40 kHz. The MATLAB/Simulink blocks of the PV system simulation are shown in Fig. 2.
MATLAB blocks of the PV system.
When all PV panels in a PV system are subjected to the same irradiance level, the operating condition is referred to as uniform irradiance. The effectiveness of conventional and modified MPPT algorithms under uniform irradiance conditions has been well established. When PV panels are exposed to irradiance levels of varying magnitudes, partial shading conditions (PSC) occur⁴⁷. The P–V curves obtained under uniform irradiance and PSC conditions are shown in Fig. 3.
P–V curves of the PV system under uniform irradiance and PSC.
As shown in Fig. 3, multiple maximum power points occur under PSC. Among these points, only one corresponds to the GMPP, while the others are LMPPs. Conventional MPPT algorithms may converge to LMPPs, which leads to unsuccessful operation under PSC. Consequently, the need to develop new and advanced MPPT algorithms has emerged. Another important aspect to consider is that the number of potential maximum power points formed in different voltage regions increases with the number of series-connected PV panels.
The GWO algorithm, proposed by Mirjalili et al.⁴⁸, mathematically models the hierarchical social structure and hunting strategies of grey wolves. In nature, grey wolves are apex predators that live and hunt in packs. To emulate this leadership hierarchy, four types of wolves are defined in the GWO algorithm: alpha (α), beta (β), delta (δ), and omega (ω). In a grey wolf pack, the alpha leads the group by directing activities such as hunting and migration. If the alpha becomes ineffective, leadership is assumed by the beta. The delta supports both the alpha and beta, while the omega represents the remaining members of the pack. The GWO algorithm is structured according to this hierarchical order. Accordingly, the alpha (α) symbolizes the optimal solution, reflecting the wolves’ leadership hierarchy. The beta (β) and delta (δ) represent the second and third best solutions, respectively, while the omega (ω) denotes all other candidate solutions. During hunting, grey wolves exhibit encircling behavior around their prey. The iterative process begins at the onset of hunting; therefore, the α, β, and δ wolves guide the remaining wolves (search agents) to surround the prey. This encircling behavior is mathematically expressed in Eq. (1).
Here (vec{X}) represents the position of the search agents, (vec{X}_{p}) denotes the prey position, and (vec{A}) is the coefficient vector at the (left( {t + 1} right){text{th}}) iteration. The coefficient (vec{D}) is defined in Eq. (2).
Here, the parameter vectors (vec{A}) and (vec{C}) are obtained using the randomly generated vectors (vec{r}_{1}) and (overrightarrow { r}_{2}) whose elements are randomly selected within the interval [0, 1], as shown in Eqs. (3) and (4).
Here, the components of (vec{a}) decrease linearly from 2 to 0 over the iterations.
During the hunting process, grey wolves update their positions by considering the location of the prey. The α, β, and δ wolves guide the ω wolves toward potential prey locations, thereby coordinating their movements to maximize hunting efficiency. The following equations describe the position-update mechanism through which the pack collectively tracks the prey and maximizes hunting success.
The position vector is modified by (vec{a}) at each iteration to guide the omega-type wolves either toward or away from the prey. The vector (vec{a}) decreases from 2 to 0 after each iteration, as expressed in Eq. (8).
Here, t represents the current iteration number, while N denotes the total number of iterations.
In the IGWO method, upon reaching a certain iteration, the initial conditions or boundaries of the search space are redefined, and the GWO algorithm is restarted to improve hunting performance. Initially, the GWO algorithm is run for 10 iterations. If, at the end of the 10th iteration, the change in power is very small ((Delta P_{pv} < 5)), it is considered that the maximum power has been approached, and the algorithm is terminated. Otherwise, the position corresponding to the closest approach to the prey is determined, and the GWO algorithm is restarted. In the second step, the position obtained in the first step ((D_{new})) is used to define the initial conditions, as shown in Eq. (9). By narrowing the search area in this second step, the success rate of locating the maximum power point is increased.
Here, (D_{1} , D_{2} , D_{3} ,) and (D_{4}) represent the initital duty cycles determined during the first execution of the GWO algorithm and are set to 0.05, 0.3, 0.5, and 0.7, respectively. The flowchart of the IGWO algorithm is shown in Fig. 4.
Flowchart of IGWO algorithm.
In GWO algorithm, if convergence toward the maximum power cannot be achieved within a specified number of iterations under steady-state conditions according to the expression given in Eq. (10) the algorithm is terminated, and the best position attained up to that point is accepted as the optimization result. In this study, after the 10th iteration, the search space was narrowed to achieve faster convergence and higher efficiency. The 10th iteration threshold was determined through extensive trial-and-error analyses. Restarting the algorithm before the 10th iteration led to unfavorable results in certain scenarios. This is because, during the initial startup phase, the assigned duty cycles operate temporarily under transient conditions, which may mislead the algorithm. To mitigate the influence of transient states during initial operation and under dynamic atmospheric conditions, the number of iterations was selected such that each duty cycle (D1–D2–D3–D4) was applied at least twice.
After the 10th iteration, redefining the initial duty cycles using a simple computational technique such that they oscillate around the newly assigned starting value facilitates convergence toward the maximum power point and enhances the algorithm’s efficiency without increasing the number of iterations. In the proposed method, the values added to and subtracted from the new initial value are obtained using 20% of the sum of the first assigned maximum and minimum duty cycles, 20% of the sum of the second and last duty cycles, and the first duty cycle. In the second stage, the newly generated initial duty cycles were associated with the initial state, and the reuse of identical values was prevented. Consequently, after the 10th iteration, the power values oscillate around the newly assigned initial point, and the subsequent position is determined based on the power levels obtained from the preceding and succeeding duty cycles.
If, after the second stage and up to the 10th iteration, the convergence criterion toward the maximum power specified in Eq. (10) is not satisfied, the algorithm is terminated, and the highest power value obtained in the second stage is accepted as the optimization result. Even in cases where convergence to the maximum power is not fully achieved, the IGWO algorithm continues the search process around the maximum power region, as it utilizes the duty cycle transferred from the first stage in the second stage. Consequently, the probability of accurately identifying the maximum power point is increased.
MPPT algorithms are expected to reach the maximum power rapidly and operate at high efficiency under PSC in PV systems. Therefore, the proposed algorithm is tested under nine different PSC scenarios, as illustrated in Fig. 5. The irradiation levels applied to each PV panel for generating the P–V curves illustrated in Fig. 5 are presented in Table 2. All partial shading condition (PSC) scenarios were established at a constant temperature of 25 °C.
Nine different PSCs used to test proposed algorithm.
A detailed examination of Fig. 5 reveals PSCs in which maximum power points of different magnitudes occur across four distinct voltage regions. Moreover, as observed in PSC2b and PSC3, there are challenging scenarios in which multiple power points within the same PSC scenario produce very similar power levels in different voltage regions. Similarly, the maximum power points in PSC1a and PSC3a occur at different voltage regions but have approximately the same power values. In PSC2, PSC2a, and PSC2b, two of the maximum power points are close to each other, while the third is lower, with all occurring within the same voltage region. The PSCs include P–V curves with two, three, or four distinct maximum power values. To evaluate the performance of the proposed algorithm, challenging PSC scenarios were created, and the proposed IGWO method was compared with the GWO, FPA, and CSA algorithms. All methods were tested under identical conditions, with the GWO and IGWO algorithms completing the same number of iterations. Each iteration was applied at equal time intervals. Simulation time and sampling time were taken as equal for all methods. Optimization stopping criteria were limited by Eq. 10 and the maximum number of iterations for GWO and IGWO, while they were limited by Eq. 10 for FPA and CSA. Important parameters of the optimization algorithms are given in Table 3.
As shown in Fig. 6, under PSC1, the PV system achieves a maximum power of 625.24 W using the FPA method. The IGWO algorithm produces a power of 623.01 W, which is very close to the FPA result. Although the GWO algorithm is faster, it achieves only 584.1 W, demonstrating lower performance. While the FPA algorithm generates slightly higher power than IGWO, its tracking speed of 0.245 s is considerably slower.
Power, current, voltage, and duty cycles obtained using GWO, FPA, CSA, and IGWO algorithms for PV system under PSC1 conditions.
As observed in Fig. 7, the IGWO algorithm achieves the highest power of 306 W while reaching the maximum power in approximately the same time as the GWO algorithm. Although the GWO algorithm has a high tracking speed, it delivers the lowest output power of 220.1 W from the system. The FPA algorithm closely approaches the maximum power but demonstrates a very low tracking speed of approximately 0.5 s. The CSA algorithm shows poor performance in both tracking speed and maximum power output. When examining the maximum power obtained under PSC1 and PSC1a conditions, both IGWO and FPA achieve the highest efficiency at the GMPP voltage region; however, the tracking time of FPA is significantly longer than that of IGWO.
Power, current, voltage, and duty cycles obtained using GWO, FPA, CSA, and IGWO algorithms for PV system under PSC1a conditions.
In Fig. 8, the algorithms were executed for the GMPP occurring in another voltage region. Except for the GWO algorithm, all other methods produced approximately the same power. Specifically, FPA, CSA, and IGWO achieved powers of 465.1 W, 465.1 W, and 464 W, respectively, while GWO delivered 461.8 W. The IGWO algorithm reached the maximum power faster than CSA and FPA, with a tracking speed of 0.11 s.
Power, current, voltage, and duty cycles obtained using GWO, FPA, CSA, and IGWO algorithms for PV system under PSC2 conditions.
As shown in Fig. 9, the performance of the algorithms under PSC2 is similar, except for GWO. The GWO algorithm delivers a significantly lower power of 392 W from the PV system. Both FPA and CSA achieve a power of 528.74 W with a tracking time of 0.23 s, showing similar performance. The IGWO algorithm reaches 528.26 W in only 0.11 s, achieving nearly the same efficiency but with a much higher tracking speed.
Power, current, voltage, and duty cycles obtained using GWO, FPA, CSA, and IGWO algorithms for PV system under PSC2a conditions.
As shown in Fig. 10, under PSC2b, the highest powers are obtained using FPA and IGWO, with values of 314.7 W and 314.5 W, respectively. In terms of tracking speed, IGWO reaches the maximum power in 0.115 s, whereas FPA requires 0.35 s, clearly demonstrating the speed advantage of IGWO. For the voltage regions corresponding to the maximum power obtained under PSC2, PSC2a, and PSC2b conditions, FPA produces slightly higher power than IGWO; however, both algorithms achieve approximately the same maximum power. On the other hand, IGWO stands out due to its superior tracking speed.
Power, current, voltage, and duty cycles obtained using GWO, FPA, CSA, and IGWO algorithms for PV system under PSC2b conditions.
Figure 11 shows the power, voltage, current, and duty cycles obtained from the PV system operating under PSC3. Compared to other voltage regions, the FPA algorithm delivers a lower power of 436.8 W, indicating reduced performance. The IGWO algorithm achieves 461.8 W, operating at slightly lower efficiency than FPA and CSA in this scenario. In terms of tracking speed, both GWO and IGWO reach the maximum power in 0.11 s, performing significantly better than the other two algorithms.
Power, current, voltage, and duty cycles obtained using GWO, FPA, CSA, and IGWO algorithms for PV system under PSC3 conditions.
Figure 12 presents the power, voltage, current, and duty cycles obtained from the PV system operating under PSC3a conditions using the different algorithms. While GWO, FPA, and CSA achieve approximately the same power from the PV system, IGWO delivers a lower power of 301.5 W. In this voltage region, the GWO algorithm demonstrates superior performance in terms of both efficiency and tracking speed.
Power, current, voltage, and duty cycles obtained using GWO, FPA, CSA, and IGWO algorithms for PV system under PSC3a conditions.
As observed in Fig. 13, all algorithms achieve the same power from the PV system operating under PSC4. Both GWO and IGWO algorithms demonstrate successful performance with a tracking speed of 0.1 s.
Power, current, voltage, and duty cycles obtained using GWO, FPA, CSA, and IGWO algorithms for PV system under PSC4 conditions.
As shown in Fig. 14, the lowest maximum power generated in the lowest voltage region is obtained using the GWO algorithm. FPA, CSA, and IGWO produce approximately the same power, while the IGWO algorithm stands out due to its superior tracking speed.
Power, current, voltage, and duty cycles obtained using GWO, FPA, CSA, and IGWO algorithms for PV system under PSC4a conditions.
The powers, efficiencies, and tracking speeds obtained under all atmospheric conditions are presented in Table 4. The efficiency of the PV system is calculated as seen in Eq. (11).
where, (P_{pv}) represents the power obtained from the PV system and is calculated as (V_{pv} times I_{pv}). (P_{GMPP}) represents the maximum power that can be obtained in the PSC scenario and is determined using P–V curves as shown in Fig. 5. Tracking speeds of the MPPT algorithms is calculated as in shown Eq. (12). Each iteration occurred at 5 ms intervals. The sampling time of the duty period is 25 µs and is compatible with the switching frequency of the boost converter.
Examining Table 4, the average power obtained across all scenarios is highest with the IGWO algorithm, reaching 367.45 W. The FPA algorithm achieves 365.26 W, coming very close to the IGWO result. This trend is also reflected in the average efficiencies, with FPA and IGWO achieving 97.88% and 98.34%, respectively, which are very similar. A notable difference is observed in tracking speeds: the average tracking time of IGWO is 0.11 s, whereas FPA requires 0.33 s. Thus, in addition to the small advantage in efficiency, IGWO reaches the maximum power approximately three times faster than FPA. The challenging selection of atmospheric conditions and the wide duty cycle range over which power is obtained further demonstrate the robustness and effectiveness of the proposed algorithm.
To evaluate the performance of the proposed algorithm under rapidly varying atmospheric conditions, four different scenarios were designed, as illustrated in Fig. 15. In each scenario, five distinct PSCs states were applied to the PV system at 0.2 s intervals using different combinations. The steady-state power values and the corresponding efficiencies obtained for each PSC state are presented in the figure. Accordingly, it was observed that high-efficiency operation was achieved in nearly all cases. In conclusion, the superior performance of the proposed MPPT algorithm under dynamic atmospheric conditions has been demonstrated.
Power obtained from a PV system operating under four different dynamic atmospheric conditions using the IGWO method.
In Scenario 1, considering the steady-state algorithm efficiencies of five different PSC conditions, a very good average efficiency of 99.6% was obtained. In Scenario 2, the average efficiency of 5 different PSCs applied sequentially was obtained as 98.64%. However, only PSC4 showed low efficiency. Currently, the efficiency of all algorithms under PSC4 is very low. In other cases, the efficiency is quite high. In Scenario 3, the average efficiency was very high at 99.89%. In Scenario 4, the average efficiency was very high at 98.12%. However, the efficiency is again reduced by the operation under PSC4. Very high efficiency was achieved under other atmospheric conditions.
Figure 15 shows that the proposed algorithm is as successful as other methods when the simulations are repeated. When the system is first energized, the voltage rise times can change in transient situations due to the system’s behavior. The duty cycles recorded in the first study can sometimes give misleading results. As seen in Fig. 15, higher power was obtained in PSC3a in Scenario 1 and Scenario 2. Overall, the superiority of the method is clearly seen in the average power obtained from nine different scenarios.
The high speed and efficiency of the IGWO method have been demonstrated through simulation studies. On the other hand, a significant advantage of the IGWO algorithm over other modified GWO and hybrid GWO algorithms is its simple structure. In the proposed approach, if steady-state operation cannot be achieved within the first 10 iterations, the initial conditions are adjusted using a simple procedure and the GWO is restarted. In³⁶, the convergence speed was improved by deriving the convergence factor through an alternative formulation; however, the use of complex mathematical operations increased the overall complexity of the optimization method. In³⁷, a nonlinear convergence factor calculation method was proposed, and the newly introduced approach involving trigonometric expressions further increased the computational burden. In^{38,39,40,41,42,43}, new hybrid optimization algorithms were developed by combining two different optimization techniques. The computational complexity of such hybrid algorithms is inevitably high. A review of the literature indicates that the IGWO method stands out due to its high efficiency, rapid convergence, and low computational complexity.
Tracking the global maximum power point rapidly and with high efficiency remains a major challenge for MPPT algorithms in PV systems operating under partial shading conditions (PSC). Therefore, the development of new MPPT algorithms that simultaneously improve tracking speed and ensure high steady-state efficiency is of great importance. In this study, a PV system consisting of four series-connected PV panels and a boost converter was modeled in the MATLAB/Simulink environment, and nine different PSC scenarios were constructed to evaluate the performance of MPPT algorithms. The widely used GWO algorithm was improved by redefining its operating boundaries, resulting in a novel Improved Grey Wolf Optimization (IGWO)-based MPPT algorithm that offers both high tracking speed and high efficiency. The performance of the proposed algorithm was comparatively analyzed against well-established algorithms in the literature, namely the Flower Pollination Algorithm (FPA) and the Cuckoo Search Algorithm (CSA). The IGWO algorithm was obtained through a simple yet effective modification of the conventional GWO approach. By restricting the search space and restarting the algorithm after a predefined number of iterations, the hunting (search) capability was enhanced, enabling faster convergence toward the maximum power point. To ensure a fair comparison, both the conventional GWO and the proposed IGWO algorithms were executed using the same number of iterations. The results demonstrate that the IGWO algorithm provides a significantly higher average tracking efficiency compared to the conventional GWO. Across the nine PSC scenarios, the IGWO algorithm achieved an average power of 367.45 W, while the FPA algorithm yielded a closely comparable average power of 365.26 W. In terms of average tracking efficiency, IGWO and FPA achieved 98.34% and 97.88%, respectively. However, a notable distinction was observed in tracking speed: the IGWO algorithm reached the maximum power point with an average tracking time of 0.11 s, whereas the FPA algorithm required 0.33 s. These findings indicate that, in addition to delivering high efficiency, the IGWO algorithm offers approximately three times faster tracking performance.
In conclusion, this study introduces a new IGWO-based MPPT algorithm capable of rapidly and efficiently extracting maximum power from PV systems operating under partial shading conditions. Simulation results obtained under challenging PSC scenarios clearly confirm the effectiveness and reliability of the proposed method. Future work will focus on supporting the IGWO algorithm with hybrid structures and further improving its average tracking efficiency, aiming to develop next-generation MPPT algorithms that simultaneously provide very high speed and ultra-high efficiency.
The datasets used and/or analysed during the current study available from the corresponding author on reasonable request.
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The authors received no funding for this work.
Department of Mechatronics Engineering, Firat University, 23200, Elazig, Turkey
Resat Celikel & Omur Aydogmus
Department of Electrical and Electronics Engineering, Batman University, 72100, Batman, Turkey
Musa Yilmaz
Center for Environmental Research and Technology, Bourns College of Engineering, University of California at Riverside, Riverside, CA, 92521, USA
Musa Yilmaz
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R.C. Writing—review & editing, original draft, software, methodology, investigation, formal analysis. O.A. Writing—review & editing, formal analysis, investigation, visualization. M.Y. Review, original draft, validation, visualization.
Correspondence to Musa Yilmaz.
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Celikel, R., Aydogmus, O. & Yilmaz, M. An improved grey wolf optimization-based MPPT algorithm for photovoltaic systems under partial shading conditions. Sci Rep 16, 16671 (2026). https://doi.org/10.1038/s41598-026-45860-z
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Scientific Reports volume 16, Article number: 21979 (2026) Cite this article
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This study investigates the bearing behavior of a pile-bucket composite foundation in marine soft clay under combined vertical, horizontal, and moment (V-H-M) loading, with direct application to offshore photovoltaic systems deployed in shallow-water regions. Centrifuge tests and validated 3D finite element analyses employing the Nanshui constitutive model were conducted. The results indicate that the pile-bucket foundation exhibits a hybrid deformation mode, effectively integrating the deep rotational restraint of the pile with the shallow translational constraint of the bucket. Under combined V-H-M loading, the composite foundation demonstrates a significantly expanded failure envelope. Notably, the vertical load enhances the lateral capacity to a greater extent in the composite system compared to monopile or suction caisson foundations. Plastic strain analysis reveals a synergistic interaction, where the pile extends the plastic zone deeper while the bucket mobilizes a broader near-surface soil mass, leading to a more distributed and efficient load-transfer mechanism. The findings provide critical insights for the optimized design of innovative pile-bucket hybrid foundations in soft clay for offshore photovoltaic arrays.
With the global expansion of renewable energy development^1,2,3,4,5,6, offshore photovoltaic projects are progressively advancing into shallow-water regions underlain by extensive soft soil deposits (Fig. 1). The presence of soft seabeds, combined with wave, current, and operational loads, imposes significant challenges on conventional foundation systems^7,8,9,10. The pile-bucket composite foundation, which integrates a shallow bucket with an embedded pile, offers a promising solution by enhancing load distribution and adapting to soft soil conditions^11,12. Nevertheless, its bearing mechanism under combined vertical, horizontal, and moment (V-H-M) loading remains insufficiently understood, particularly in soft clay, limiting its optimized design for offshore PV applications.
Field implementation of offshore photovoltaic projects in China. (a) Installation process of photovoltaic panels, (b) soft foundation in coastal tidal flat areas.
The bearing capacity of foundations has long been a critical research topic in geotechnical and offshore engineering^{13,14,15,16,17}. For bucket foundations, Fan et al.¹⁸ employed advanced constitutive models to investigate failure envelopes. For monopiles, studies have focused on lateral response under combined loading. However, single pile or single bucket systems often suffer from either insufficient shallow restraint or limited deep rotational capacity. Recently, hybrid foundation systems have attracted increasing attention^{19,20,21,22,23}. Li et al.²⁴ experimentally and numerically studied hybrid pile-bucket foundations under lateral loading, finding that such foundations improve load distribution, reduce the accumulation of permanent plastic strain and soil stiffness degradation, and enhance overturning stability compared to monopiles, providing valuable insights for the design of offshore wind turbine foundations in soft soils. Yang et al.²⁵ conducted centrifuge tests to study the influence of pile spacing on the seismic response of piled raft foundations in soft clay, highlighting the importance of boundary effects and soil–structure interaction. Liu et al.²⁶ systematically investigated the bearing capacity of a novel pile-bucket composite jacket foundation through 1 g model tests and 3D finite element analysis. Their findings indicate that increasing pile diameter and length can significantly enhance the horizontal and bending moment capacities, while the composite structure effectively reduces plastic deformation within the bucket, shifts the rotation center downward, and expands the failure envelope under combined loading. These findings collectively emphasize the critical importance of enhancing and optimizing traditional pile or bucket foundations, particularly in scenarios where shallow soil layers are insufficient and the underlying strata consist of bedrock, stiff layers, or other difficult-to-penetrate soil types. While recent studies have highlighted the superior performance of hybrid foundation systems, systematic investigations focusing on the synergistic interaction between the pile and bucket components under realistic in-situ stress conditions are still limited. Specifically, the failure envelope under combined loading, the evolution of soil–structure interaction mechanisms, and the comparative performance against conventional single-pile or single-bucket systems in soft clays have not been thoroughly characterized through centrifuge modeling coupled with advanced constitutive numerical simulations.
To address these research gaps, this study conducts the centrifuge model test on a pile–bucket composite foundation embedded in marine soft clay. A corresponding three-dimensional finite element model is developed and validated against experimental results, employing an advanced double-yield-surface elastoplastic constitutive model to accurately capture the nonlinear soil behavior. The findings of this study are expected to provide theoretical insights and practical guidelines for the optimized design and application of pile–bucket composite foundations in offshore renewable energy infrastructure. It is important to clarify that the present investigation focuses on the ultimate bearing behavior under monotonic combined loading, which serves as the fundamental basis for understanding foundation capacity under extreme environmental events such as storm surges.
The stress state induced by soil self-weight is fundamental in geotechnical engineering, as soil mechanical properties are inherently stress-dependent. Small-scale physical model tests conducted under normal gravitational conditions often fail to satisfy stress similitude, resulting in poor representation of prototype behavior. The geotechnical centrifuge addresses this limitation by generating an enhanced gravitational field through centrifugal acceleration^27,28. This method effectively scales up soil stresses in a reduced-scale model, ensuring that stress levels correspond to those in the prototype^{29,30,31,32,33}. Consequently, the centrifuge enables accurate simulation of prototype mechanical response and failure mechanisms under representative in-situ stress conditions.
Experimental equipment in this study. (a) Geotechnical centrifuge, (b) consolidation instrument.
The centrifuge modelling tests in this study were conducted using the large-scale geotechnical centrifuge facility at the Nanjing Hydraulic Research Institute (NHRI). As illustrated in Fig. 2, the centrifuge is characterized by a maximum radius of 5.5 m and is capable of achieving a centrifugal acceleration of up to 200 g. At this acceleration level, the platform can carry a maximum payload of 2000 kg. The geometric scaling between the prototype and the model is characterized by the scale factor, defined as the ratio of the prototype dimension to the corresponding model dimension. The scale factors are presented in Table 1. In this study, a scaling factor of 80 was adopted. The model container used in the tests features a transparent acrylic side panel for visual observation, while the remaining sides, base, and cover are constructed from high-strength aluminium alloy to ensure structural integrity under elevated 80 g-levels. The internal dimensions of the model container are 700 mm (length) × 350 mm (width) × 450 mm (height).
The foundation soil was reconstituted using material analogous to that of the prototype site to preserve realistic strength characteristics. For modeling purposes, soil layers exhibiting comparable geotechnical properties were homogenized through weighted averaging of their shear strength and thickness, a validated approach routinely employed in centrifugal modeling of port and offshore engineering problems. The cohesive soil was prepared by air-drying, pulverizing, and subsequently remixing with controlled water content to achieve the target consistency. The soil was placed and compacted in successive lifts from the bottom of the model container upward. Consolidation of the soil model was conducted in consolidation instrument (Fig. 2b). The evolution of undrained shear strength during consolidation was monitored using a pocket penetrometer until the design strength—14 kPa in this case—was attained uniformly throughout the soil profile. It should be noted that natural soft clay deposits are often stratified. The homogenization approach, while necessary for centrifuge repeatability, may smooth out weak interlayers or drainage interfaces that could act as preferential failure planes (Table 2).
The pile-bucket foundation model in this study was fabricated from aluminum alloy. Since the structure is predominantly subjected to flexural loading under lateral forces, the model design follows the principle of equivalent bending stiffness. The scaling of bending stiffness follows the centrifuge similitude law. This ensures that the flexural deformation characteristics of the model under lateral loading faithfully represent those of the prototype, even under ultimate loading conditions where significant bending occurs. The wall thickness of the model components was determined using the following expression¹⁸:
where d_m and d_p represent the wall thicknesses of the model and prototype, respectively, E_m and E_p represent their modulus of elasticity, and N is the scale factor.
Following this conversion, the pile model has a diameter of 12.5 mm, a height of 100 mm, and bucket model has a diameter of 75 mm, a height of 50 mm, a wall thickness of 0.46 mm, as shown in Table 3.
The embedded lengths of the pile and the bucket foundation below the mudline are 8 m and 4 m, respectively, in prototype scale. The centrifuge model test adopted a displacement-controlled loading scheme, with the loading point positioned 6 m above the mudline. This height represents the approximate resultant elevation of wind and wave loads on the PV support structure in shallow water. Horizontal displacement at the loading point and vertical displacement on the surface of the bucket foundation were monitored using reflective laser displacement sensors, as shown in Fig. 3. The sensors feature a measurement resolution of less than 0.01 mm, which satisfies the precision requirements of the experimental program.
Schematic of the centrifuge model cross-section and experimental setup photograph.
Figure 4 illustrates the horizontal load–displacement and horizontal load–rotation responses of the pile-bucket foundation. Both the horizontal displacement and the rotation of the foundation exhibit a positive correlation with the applied horizontal load. During the initial loading phase, the load–displacement and load–rotation relationships are approximately linear under relatively low load levels, indicating that the soil remains within the elastic deformation range. As the horizontal load exceeds 100 kN, the displacement and rotation increase nonlinearly with further loading. The slope of the curves gradually decreases in this regime, reflecting the progressive development of plastic deformation in the soil. The ultimate lateral capacity for foundation e is defined as the load at which the load-displacement curve reaches a horizontal asymptote, i.e. further displacement occurs without a significant increase in load, indicating fully developed plastic failure (as observed in the centrifuge test when the load reached 470 kN). In addition, the failure mode of the surrounding soil was also shown in Fig. 4, at the ultimate state, obvious soil heave occurred in front of the foundation, accompanied by a distinct gap forming behind the bucket.
Centrifugal test results of horizontal displacement and structural rotation angle.
A three-dimensional finite-element model was developed to simulate the lateral response of the pile–bucket composite foundation under monotonic horizontal loading, maintaining strict consistency with the geometric and material properties of the centrifuge test prototype. The three‑dimensional finite element analyses were performed using Abaqus³². The model consisted of two main components: the composite foundation structure (pile and bucket) and the surrounding saturated soft clay deposit, as shown in Fig. 5. To ensure that boundary effects did not artificially constrain the development of failure mechanisms, the soil domain was extended laterally to five times the diameter of the bucket and vertically to three times its embedded depth. Both structural and soil domains were discretized predominantly with eight‑node reduced‑integration hexahedral elements (C3D8R). A graded mesh was implemented to enhance computational efficiency and accuracy: the region surrounding the foundation and the near‑field soil were finely meshed to capture localized plasticity and interface behavior, while a gradually coarser mesh was used toward the far‑field boundaries. A mesh convergence study was conducted with three mesh densities. The difference in ultimate lateral capacity between the medium and fine meshes was less than 3%, while the coarse mesh showed a larger deviation. The medium mesh was therefore selected as providing a satisfactory balance between accuracy and computational cost.
Schematic diagram of the finite element model.
This paper employs the Mohr-Coulomb frictional contact model to simulate the interaction between the pile-bucket foundation and the soil. In mechanical analysis, face-to-face contact is commonly used, with the surface having a higher modulus of elasticity defined as the master face. Therefore, the pile-bucket foundation is set as the master face, and the soil is set as the slave face. The contact pair includes a normal behavior model and a tangential behavior model. The normal behavior uses a penalty function, while the divergent behavior adopts hard contact, allowing the pile-bucket foundation and soil to separate after contact, making the numerical model more realistic. The friction coefficient µ = 0.2 was selected based on interface shear tests on steel-soft clay interfaces reported in the literature³³. Geometric nonlinearity was activated throughout the analysis to account for finite rotations and displacements under progressively applied lateral loads.
This paper adopts the Nanshui constitutive model, an advanced double‑yield‑surface elastoplastic formulation grounded in generalized plasticity theory. Unlike single‑yield‑surface models (e.g., Modified Cam‑Clay), the Nanshui model separately describes volumetric hardening and shear hardening through two independent yield surfaces, making it particularly suitable for soft clays under combined loading.
The yield surface equation is as follows:
Here, p denotes the spherical stress, q is the deviatoric stress, and s and r are parameters that define the shape and size of the yield surface.
The elastoplastic stress–strain relationship of the soil can be expressed as follows:
where A₁ and A₂ are the plastic multipliers corresponding to the yield surfaces f₁ and f₂, respectively, and [D] is the elastic stiffness matrix.
Under triaxial test conditions:
Substituting these expressions into the above equation:
According to the Duncan–Chang formulation of the elastic modulus, the tangent modulus and tangent bulk modulus are defined as follows:
Substituting these relationships into the above expression:
where G is the shear modulus, B is the bulk modulus, and η denotes the stress ratio.
The tangent modulus E_t is defined according to the Duncan–Chang model as follows:
where R_f denotes the failure ratio; K is a dimensionless coefficient; n is a dimensionless exponent; p_a denotes the standard atmospheric pressure; c is the cohesion; and φ is the internal friction angle.
The tangent bulk modulus can be expressed as follows:
where R_s denotes the stress level; R_d represents the ratio of the deviatoric stress (σ₁−σ₃)_d at the point of maximum volumetric contraction to the ultimate deviatoric stress (σ₁−σ₃)_ult; d is a dimensionless exponent; and c_d is the maximum contractive volumetric strain corresponding to a confining pressure of the standard atmospheric pressure.
The Nanshui model was implemented in Abaqus via a user‑defined material (UMAT) subroutine¹⁸. The calibrated parameters of the Nanshui model for the soft clay foundation are summarized in Table 4, which were calibrated against a series of triaxial compression tests. As shown in Fig. 6, the Nanshui model predictions agree well with the measured stress–strain responses under different confining pressures, confirming the validity of the calibrated parameters. The pile-bucket foundation was simulated as a linear-elastic material with an elastic modulus of 210 GPa, a density of 7850 kg/m³, and a Poisson’s ratio of 0.3.
Validation of the Nanshui constitutive model. (a) Indoor test results, (b) prediction of constitutive model.
Figure 7(a) compares the horizontal load–displacement responses of the pile-bucket foundation obtained from centrifuge model testing and numerical simulation. As shown in the figure, the two load–displacement curves exhibit consistent trends and demonstrate close agreement, with a difference of only 2.6% in the ultimate lateral load, thereby validating the accuracy of the numerical model. In addition to horizontal displacement, the foundation rotation at the loading point was also compared⁴. As shown in Fig. 7(b), the numerical model accurately reproduces the rotation–load relationship observed in the centrifuge test, with a difference of less than 5% at the ultimate state. This additional metric further strengthens the validation basis. The observed agreement between the experimental and simulated results confirms the reliability of the modeling methodology, including the constitutive models, contact formulations, and boundary conditions employed. Moreover, this consistency supports the use of the calibrated numerical model for subsequent parametric analyses under more complex loading scenarios that are challenging to replicate in physical testing.
Comparison of response of the foundation between centrifuge test and numerical simulation. (a) load–displacement response, (b) load–rotation response.
To systematically evaluate the bearing mechanism of the pile-bucket composite foundation, two reference models—a single pile foundation and a single suction caisson foundation—were established for comparative analysis. Figure 8 illustrates the three-dimensional finite element models of the single pile and the single caisson used in this study. The single pile model and bucket model retains the geometric and material properties of the pile component and bucket component from the composite system, respectively. The soil domain, constitutive model (Nanshui model), boundary conditions, and interface properties are identical to those used in the pile-bucket composite foundation simulation, ensuring a consistent basis for comparison. It should be specifically noted that, to ensure consistency in the comparative testing conditions, the loading point for all control models (single pile and single bucket) was set at the same elevation as that of the pile-bucket foundation, i.e., 6 m above the mudline.
Numerical simulation model of comparative models. (a) Pile foundation, (b) bucket foundation.
To elucidate the mechanical advantages of the pile-bucket composite foundation under lateral loading, this section presents a systematic comparison of its behavior against that of single pile and single caisson foundations subjected to pure horizontal force. The evaluation encompasses both global load-displacement responses and detailed displacement field characteristics. As illustrated in Fig. 9, all three foundations exhibit hyperbolic load–displacement curves under lateral loading, with distinct differences in stiffness and ultimate capacity. The pile-bucket composite foundation demonstrates the highest lateral capacity, approximately 490 kN, along with the greatest initial stiffness. The bucket foundation follows, with an ultimate lateral capacity of about 300 kN and intermediate stiffness, while the single pile foundation shows the lowest capacity, around 175 kN, and the smallest stiffness. These results clearly highlight the superior load–bearing and deformation‑resisting performance of the pile–bucket composite system under lateral loading.
Comparison of load displacement relationship curves.
Figure 10 illustrates the displacement contours of the three foundation types at comparable load levels. The single pile foundation undergoes a characteristic deep-seated flexural deformation. Displacement is concentrated primarily at the pile head, with progressively smaller displacements along the embedded shaft, indicating a rotational mechanism constrained by the deeper soil. The single bucket, in contrast, exhibits a more rigid-body translational mechanism, characterized by nearly uniform lateral displacement along its embedded depth and a distinct separation gap forming behind the foundation at the mudline.
Comparison of displacement fields (Units: m). (a) Pile foundation, (b) bucket foundation, (c) pile-bucket composite foundation.
The pile-bucket composite foundation demonstrates a fundamentally different displacement pattern. The bucket component restricts shallow translation and rotation, while the embedded pile provides deep rotational restraint. This interaction results in a more uniform displacement field with reduced lateral movement at the mudline and enhanced deformation control throughout the soil profile. The combined system effectively transforms the failure mechanism from a localized deep rotation (pile) or shallow translation (bucket) into a composite mode that engages both shallow and deep soil layers simultaneously.
In the context of offshore renewable energy infrastructure, such as photovoltaic arrays or wind turbines, foundations are subjected to complex environmental loads that are fundamentally multi-directional and dynamic. These include persistent vertical dead loads from the superstructure, horizontal forces induced by waves and currents, and significant overturning moments generated by wind and eccentric loading. This combined vertical (V), horizontal (H), and moment (M) loading regime critically governs the stability, serviceability, and long-term performance of the support structure. Understanding the bearing behavior under such multi‑component loading is essential for the safe and economical design of foundations, as the interaction between different load components can significantly influence the overall bearing capacity and failure mechanism.
Figure 11 presents the bearing capacity envelopes of the single pile, single bucket, and pile-bucket composite foundations in the V-H, H-M, and V-M loading planes, respectively. Herein, V_ult, H_ult, and M_ult represent the ultimate bearing capacities of the foundation under pure vertical, pure horizontal, and pure moment loading, respectively.
Comparison of V-H-M bearing capacity. (a) H-V load plane, (b) H-M load plane, (c) M-V load plane.
As can be seen from the figure, despite the differences in geometric configuration and load transfer mechanisms among the single pile, single bucket, and pile-bucket composite foundations, their normalized bearing capacity envelopes in the V-H, H-M, and V-M combined loading spaces exhibit remarkably similar patterns. Specifically, In the V-H and V-M planes, the influence of vertical load on horizontal and moment capacities demonstrates a clear nonlinear coupling characteristic: at low vertical load levels, an increase in vertical load significantly enhances the system’s lateral and moment capacities by improving the lateral confinement of the foundation soil and increasing base friction. However, when the vertical load continues to increase beyond a critical threshold, the resulting excessive vertical stress induces punching shear or deep-seated yielding in the soil, thereby degrading the system’s lateral and flexural performance. This leads to the typical “rise-then-fall” shape of the envelope. This coupling behavior is consistent with classical V‑H interaction theories for undrained clay³⁴ where the failure envelope expands under moderate vertical load and contracts as the vertical load approaches the pure vertical capacity due to soil punching. In the H-M plane, the capacity envelopes of all three foundations can be approximated as straight lines passing through the origin, with their slopes representing a stable proportionality between the system’s flexural and lateral resistances. This phenomenon indicates that, although the overall stiffness and embedment depth vary among different foundations, their internal force distribution and failure mechanisms under combined horizontal force and moment share an inherent consistency. In other words, horizontal load and moment exhibit a similar driving effect on the bearing behavior of these foundation types.
The similarity in normalized envelope shapes can be explained by the normalization procedure itself. The ultimate capacities V_ult, H_ult, and M_ult inherently incorporate geometric information such as foundation width, embedment depth, and contact area. Normalizing by these values removes geometry-dependent scaling, yielding dimensionless coordinates that represent the intrinsic failure envelope of the soil-foundation system. Classical plasticity solutions for undrained clay^18,35 demonstrate that demonstrate that for various foundation types, the normalized failure envelope in V-H space follows a consistent shape. Once geometric effects are normalized, the dimensionless collapse mechanism converges to a similar form. This theoretical expectation is confirmed by the present numerical results: despite distinct deformation modes (deep rotation for the pile, shallow translation for the bucket, and hybrid for the composite foundation), their normalized V-H-M envelopes collapse onto a nearly unique surface, indicating that the envelope is a fundamental property of the clay–foundation interface under combined loading.
Meanwhile, differences in the responses of different foundations under combined loading are also evident, particularly in the enhancing effect of vertical load on lateral capacity and its optimal coupling ratio. As noted previously, the presence of moderate vertical load mobilizes additional lateral soil resistance through increased confining pressure and interface friction. The data further reveal that the effectiveness of this coupling is foundation-dependent. Specifically, the single pile, single bucket, and pile-bucket composite foundations reach their peak lateral capacities when the vertical load reaches 0.35, 0.50, and 0.55 times their respective ultimate vertical capacities (V_ult), with the corresponding peak values being 1.18, 1.59, and 1.84 times their ultimate horizontal capacities (H_ult), respectively. This gradation suggests that the composite foundation benefits from a more extended and efficient load-transfer mechanism: the bucket engages shallow soil to provide initial confinement, while the pile distributes vertical load to deeper strata, thereby delaying the onset of soil yield and allowing a higher vertical load to be applied before the coupling benefit diminishes. Consequently, the pile-bucket composite foundation not only achieves the highest absolute lateral capacity but also exhibits the most significant synergistic enhancement under its optimal vertical load, underscoring its superior performance in combined loading scenarios.
Figure 12 presents a comparative visualization of the plastic strain contours developed in the soil surrounding the single pile, single caisson, and pile-bucket composite foundation under identical monotonic loading. The distribution and extent of the plastic zones reveal fundamental differences in their failure mechanisms and load-transfer efficiency.
In the single pile foundation, the plastic zone is primarily localized around the pile shaft at a certain depth, forming an asymmetric bulb-shaped region that indicates a deep-seated rotational failure mechanism. The soil near the mudline remains largely elastic, underscoring the pile’s reliance on deeper soil resistance for moment capacity. For the single caisson foundation, significant plastic strains develop along the outer skirt and beneath the caisson base. The failure mechanism is dominated by a shallower translational movement, with pronounced soil yielding near the leading edge and a distinct gap forming on the trailing side. The plastic zone spreads laterally rather than extending deeply into the soil profile.
In contrast, the pile-bucket composite foundation exhibits a synergistic and integrated plastic zone that encompasses both the embedded pile and the periphery of the bucket. The pile extends plastic deformation deeper into the soil, while the bucket engages a broader volume of near-surface soil and enhances lateral confinement. This results in a composite failure mechanism that is more spatially distributed, effectively mobilizing a larger soil mass and providing a more efficient load-transfer path than either system acting independently.
Comparison of plastic zones. (a) Pile foundation, (b) bucket foundation, (c) pile-bucket composite foundation.
The overlapping and interacting plastic regions demonstrate a clear mechanical interaction between the pile and bucket components. This integrated failure mechanism corresponds directly to the expanded VHM failure envelope observed earlier, confirming that the enhanced bearing capacity of the composite foundation stems from a fundamentally optimized soil-structure interaction.
This paper conducted a centrifuge model test and advanced numerical simulations to investigate the bearing characteristics and synergistic mechanisms of a pile–bucket composite foundation in marine soft clay under complex loading conditions. The primary conclusions are as follows:
The centrifuge tests and validated FE model demonstrate that the pile–bucket composite foundation effectively combines the mechanical advantages of both components. Under lateral loading, it exhibits a hybrid deformation mode, restraining shallow translation through the bucket and providing deep rotational restraint via the pile, resulting in a more uniform displacement field and enhanced deformation control compared to single-pile or single-bucket foundations.
Under combined V–H–M loading, all three foundation types exhibit similar normalized envelope shapes, characterized by a “rise-then-fall” response in the V–H and V–M planes and a linear relationship in the H–M plane. However, the composite foundation achieves the most significant expansion of the failure envelope, indicating superior load-carrying integration.
The composite foundation benefits the most from vertical load coupling. It reaches its peak lateral capacity (1.84 H_ult) at a higher vertical load ratio (0.55 V_ult) than the single pile (1.18 H_ult at 0.35 V_ult) and single bucket (1.59 H_ult at 0.50 V_ult). This is attributed to its more efficient load-transfer mechanism, where the bucket mobilizes shallow confinement and the pile distributes load to deeper strata, delaying soil yield.
Analysis of plastic strain contours confirms a synergistic soil–structure interaction. The composite system develops an integrated plastic zone that engages both shallow and deep soil masses simultaneously, leading to a more spatially distributed failure mechanism and a more efficient load-transfer path than either component acting alone.
This study provides a technical foundation for the design of pile-bucket composite foundations in soft clay for offshore photovoltaic applications. It should be acknowledged that offshore foundations are subjected to long-term cyclic loads, whereas the present study is limited to monotonic loading. Under cyclic conditions, accumulated rotation, stiffness degradation, and soil remoulding may reduce the effective bearing capacity compared to the monotonic envelope. Nevertheless, the monotonic failure envelope established herein provides an essential upper-bound reference and a basis for subsequent cyclic analyses. Future research will include centrifuge cyclic loading tests and advanced numerical simulations to quantify the effects of cyclic loading on the pile-bucket composite foundation.
The original contributions presented in this study are included in the article. Further inquiries can be directed to the corresponding authors.
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This study was funded by the National Natural Science Foundation of China (52501347 and 52401336) and Basic Research Program of Jiangsu (BK20250285) and China Postdoctoral Science Foundation (2025M773225) and Central Public-Interest Scientific Institution Basal Research Fund (Yj326005).
Department of Geotechnical Engineering, Nanjing Hydraulic Research Institute, Nanjing, 210024, China
Guanghui Yu, Kaifang Fan, Changsheng Gao & Xun Zhu
East China Branch Construction Department, China Resources Power Investment Co., Ltd, Nanjing, 210024, China
Guanghui Yu
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Conceptualization, G.Y. and K.F.; Methodology, G.Y. and K.F.; Software, G.Y., K.F. and C.Gao; Validation, G.Y. and X.Z.; Formal analysis, X.Z.; Investigation, X.Z.; Resources, C.Gao.; Data curation, G.Y., K.F. and C.Gao.; Writing—original draft, G.Y.; Writing—review & editing, K.F., C.Gao. and X.Z.; Visualization, C.Gao. and X.Z.; Supervision, K.F.; Project administration, K.F.; Funding acquisition, K.F. and X.Z. All authors have read and agreed to the published version of the manuscript.
Correspondence to Kaifang Fan.
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Yu, G., Fan, K., Gao, C. et al. Bearing mechanism of innovative pile-bucket foundations for offshore photovoltaic systems in soft clay under combined loading. Sci Rep 16, 21979 (2026). https://doi.org/10.1038/s41598-026-53057-7
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DOI: https://doi.org/10.1038/s41598-026-53057-7
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In a bid to strengthen South Sudan’s health security, diagnostic capacity, and waste management, the Ministry of Health and the UNDP inaugurated and handed over the Aweil Regional Reference Laboratory, equipped with a new 150 kWp solar power system and a modern incinerator at Aweil State Hospital.
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Dignitaries and High-Level Ceremony
The laboratory is equipped with advanced testing machinery, and complete workstations.
The commissioning event brought together key national, state, humanitarian and community leaders. They include; Hon. Luke Thompson Thoan Teny (Minister of Health), H.E Dr. Tong Lual Ayat, (Deputy Governor of Northern Bahr El Ghazal State), Hon. Dr. Oromo Francis Seriano, (Undersecretary, Ministry of Health) and Mrs. Sheila Ngatia, (UNDP Deputy Resident Representative – Programmes.) Others were; Hon. Dr. Riiny Riny Lual, State Minister of Health, Northern Bahr El Ghazal State, Dr. Gregory Wani, (Director General of Laboratory and Diagnostic services), Dr. Nguach Aguot Aguot, (Medical Director, Aweil State Hospital) and Deng Angok Apin, (Sultan, Aweil town.)
Strategic Partnership Insights
Government, UNDP and community leaders during the inauguration ceremony.
Today, we celebrate more than the opening of a new building. We celebrate a strategic investment in South Sudan’s health security, resilience, emergency preparedness and sustainable development, said Mrs. Sheila Ngatia, UNDP Deputy Resident Representative – Programmes. 
Mrs. Ngatia also thanked the Global Fund for the financial support and reiterated UNDP’s commitment to supporting the Government in building resilient health systems that can respond to both routine health needs and public health emergencies.
The modern laboratory equipment will improve diagnostic capacity and inform treatment options and outcomes.
On his part, Hon. Luke Thompson Teny Thoan, National Minister of Health said, “This milestone reflects the stability and peace we continue to foster in Northern Bahr El Ghazal—a peace that influenced our decision to locate these critical investments here in Aweil. UNDP has honored its responsibility, delivering this facility to 100 percent of what was expected.” He called for proper stewardship and maintenance of the investments, “Now, the fundamental responsibility shifts to us. As the Ministry of Health, our duty is to sustain this facility, while the ultimate stewardship rests with the local government and leadership of Mading Aweil,” the Minister said.
Big smiles for big progress! Government and UNDP officials and healthcare leaders during the grand opening of the Aweil Regional Reference Laboratory—a momentous step forward in strengthening regional diagnostic capabilities.
Hon. Dr. Francis Oromo Seriano, Undersecretary, Ministry of Health said that the lab is larger in scale than the National Public Health Laboratory in Juba noting that the investments are a game-changer in Aweil given its strategic location along the country’s northern corridor,
“Because this facility sits along an active corridor with high population movement, it will serve as an essential defense shield. Beyond immediate diagnostics, this laboratory will serve Universities and regional research institutions—we may very well discover new medical breakthroughs or identify emerging diseases right here.”
Safe waste management in action! The newly installed medical incinerator ensures proper waste management and protects community health.
He also called for the proper maintenance of the investments for posterity, “UNDP and the Global Fund have delivered the infrastructure; now, the local community and leadership must protect and maintain this asset.” Dr. Oromo added that the construction is part of a broader effort to decentralize health services, adding that UNDP is currently building a similar facility in Yambio, also funded by the Global Fund.
The commissioning of the new facilities marked a vital step forward in healthcare diagnostic services and public safety.
Similarly, Hon. Dr. Riiny Riiny Lual, State Minister of Health, Northern Bahr El Ghazal State said that the investments will minimize clinical disruptions and guarantee 24-hour delivery of essential health services at Aweil State Hospital.
“We are equally grateful for the prioritization of Aweil State Hospital for the installation of the specialized medical incinerator. Safe, systematic disposal of healthcare waste is essential for infection prevention and control, environmental protection, and elevating the overall quality of care for our people.”
United Nations
Development Programme
© United Nations Development Programme

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Near West Side nonprofit offers job training and lessons that are ‘bigger than solar panels’  Chicago Sun-Times
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Workers carry out offshore operations at the CNNC Tianwan tidal flat photovoltaic (PV) demonstration project in Lianyungang, East China’s Jiangsu Province, on August 23, 2026. Jiangsu became the first province to exceed 100 million kilowatts of solar power installations, with PV overtaking coal, gas and wind to become the province’s largest power source. Photo: VCG
Workers operate alongside intelligent equipment at a chemical fiber company in Suqian, East China’s Jiangsu Province, on August …
Workers erect a transmission tower at height at the site of the ±500 kV Longzheng Line elevation and …
Workers install solar panels at a “fishing-solar hybrid” photovoltaic power station in Shuangtan Lake in East China’s Anhui …

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I just did a full solar install instead of waiting for plug-in solar in the UK — here’s why  TechRadar
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Australia’s ‘sun tax’ warning for Britain’s solar panel owners  AOL.com
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Sunscreen-like coating could help solar panels deliver 4.8% more power  Yahoo Tech
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amNewYork, in conjunction with the MTA, present “Ask the MTA,” a column where MTA officials answer your questions about transit service in New York City. If you have a question for the MTA about subways, buses, commuter rails and more, email askthemta@amny.com.
A: Yes, we are planning to increase service before gates open and after matches end each day for fans attending the U.S. Open. The 7 line will be operating local and express service, with seven extra trains nightly after matches. There will also be additional service during concurrent Mets home games. 
The LIRR will have direct service via the Port Washington branch. The trip to Flushing Meadows from Penn Station and Grand Central takes 19 minutes and costs just $5.25 during off-peak hours. Customers traveling from other locations can transfer at Woodside. We’ll be adding a Mets-Willets Point stop to four morning and four afternoon peak trains. All Port Washington trains for the rest of the day already make that stop, as well as all weekend trains. 
Buses and paratransit are also great travel options. The Q90 bus stops at Seaver Way and Roosevelt Ave, not far from the USTA Billie Jean King National Tennis Center. Full schedules are available in the MTA and Train Time apps. – Shanifah Rieara, MTA Chief Customer Officer 
A: The MTA is exploring installing solar panels on elevated station canopies, as well as buildings at maintenance facilities.  A recent example is the installation of solar panels on the roof of the new Maintenance building at Metro North’s Croton Harmon Yard.  Design and construction of the solar photovoltaic system was included as part of new building construction and came online at the end of 2023.  
The MTA is looking at similar opportunities across all its facilities – identifying projects such as roof replacements, building upgrades and new construction as opportunities to deploy renewable energy like solar panels.  – Dana Mecomber, Director, Climate Sustainability Planning, MTA Construction & Development 
A: The MTA offers many learning opportunities for young people interested in transit, including the Summer Youth Employment Program (SYEP), the nation’s largest youth employment program. 
SYEP provides high school and college students (ages 16-21) with career exploration opportunities and paid work experience every summer. It’s too late to participate this year, but applications will open again for the 2027 season in the new year. Candidates must live in the five boroughs and be legally authorized to work in the City. 
During the school year, students 16 and older can also participate in the Industry Schols Program and the Global Kids Program. You can learn more about MTA’s youth programming on our website. – Diana Arciniegas, Senior Director, Emerging Talent
All comments are subject to our Community Guidelines. Schneps Media does not endorse the views shared by readers in our comment sections.
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Illinois disability provider taps community solar to cut power bills by up to 20%  Yahoo
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Lithuania breakthrough could bring durable solar panels to windows, facades, and more  Yahoo Tech
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Solar panels and heat pumps can work together to cut energy bills – here’s how  AOL.com
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Homeowner’s 1960s bungalow slashes energy bills with solar, battery, and heat pump  Yahoo
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“They were ripped away too quickly and with too little warning.”
Photo Credit: iStock
The United States residential solar business is heading into a sharper-than-expected reset. A major federal incentive that helped many families afford rooftop panels has disappeared, and solar installers are now being forced to show whether they can survive without it.
For homeowners, that raises a practical concern alongside the political one: Is it still safe to move forward with a solar company if the rules can change this quickly?
In an essay for Fast Company, Chris Hopper, co-founder of Aurora Solar, described a jarring shift in federal policy. The piece says the One Big Beautiful Bill Act (OBBBA) ended the 30% tax credit for homeowners installing residential solar on January 1, 2026, with no gradual phase-down beforehand.
The credit had long reduced the upfront cost of installing solar panels. 
Hopper acknowledged that incentives played a major role in helping the market grow, writing, “Government incentives played an important role in helping solar reach more homeowners. They accelerated adoption, created jobs, and helped prove residential solar could scale.”
Instead of a short-term setback, installers may be facing a more fundamental test of staying power — one in which pricing, efficiency, trust, and customer value matter more than the expectation of sustained policy support.
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For many households, rooftop panels can also mean lower utility bills, more predictable energy costs, and a measure of resilience as electricity prices continue to fluctuate.
Fewer installations mean fewer homes producing pollution-free electricity and fewer families gaining access to the savings that helped make solar more attractive in the first place.
However, the credit was never something the industry could rely on forever. As Hopper wrote, “They were ripped away too quickly and with too little warning, but let’s be clear: They always had an expiration date.”
Homeowners who are considering solar can vet installers by asking how long a company has been in business, whether it handles installations directly or uses subcontractors, what warranties are included, and how service would be handled if business conditions worsen.
Even with major federal support, running the numbers can help show whether a system still makes sense based on projected utility savings, roof condition, financing terms, and local incentives.
For solar companies, survival may depend on building a business that can deliver value even in an unfavorable policy environment. That could mean improving installation efficiency, reducing soft costs, and focusing more on customer experience rather than relying on subsidies to close deals.
The broader challenge for the industry will be keeping solar accessible even as Washington pulls back. 
“Markets change. Policies evolve. Customer expectations shift,” Hopper said. “Companies that can create value even when the tides change dramatically are the ones who will survive these moments.”
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“We can point people in the right direction and give them the right questions to ask.”
Photo Credit: iStock
After seven contractors pushed DC-area homeowner Bob Soule toward gas appliances instead of an electric heat pump, he found himself with no one he could trust for guidance.
So, Soule cofounded a free coaching effort, according to Washingtonian.
Among the seven proposals he collected for an electric heat pump, four contractors told him his home could not be electrified and would need gas instead. Another said the system would stop working in below-freezing weather.
Soule chose to investigate those claims on his own and later helped launch Go Electric DMV, a free volunteer program that helps people in the Washington area navigate electrification decisions involving solar panels, heat pumps, induction cooktops, and electric vehicles.
Want to go solar but not sure who to trust? EnergySage has your back with free and transparent quotes from fully vetted providers in your area.
To get started, just answer a few questions about your home — no phone number required. Within a day or two, EnergySage will email you the best options for your needs, and their expert advisers can help you compare quotes and pick a winner.
That approach stands out because homeowners often have to sort through advice from companies that are also trying to make a sale. The program connects people with neighbors who have already been through the process and have no financial stake in the sale.
For many households, the challenge is not just deciding what to buy but figuring out which claims are accurate, which incentives apply, and which upgrades make the most sense to prioritize.
For homeowners considering rooftop panels, going solar is one of the best ways to save money on home energy. EnergySage can help you get free solar installation estimates and compare quotes before signing anything.
Many homeowners run into the same problem when they try to electrify: conflicting information that makes even straightforward upgrades feel hard to evaluate. Soule’s experience also shows how easily cleaner technology can be dismissed when contractors disagree or fall back on familiar systems.
FROM OUR PARTNER
Want to go solar but not sure who to trust? EnergySage has your back with free and transparent quotes from fully vetted providers that can help you save as much as $10k on installation.
To get started, just answer a few questions about your home — no phone number required. Within a day or two, EnergySage will email you the best local options for your needs, and their expert advisers can help you compare quotes and pick a winner.
In the end, Soule installed the electric heat pump, put solar panels across his roof, and now powers almost all of his home with electricity, as reported by Washingtonian. He said he now gets through winter “quite comfortably.”
That kind of firsthand guidance can be especially valuable for families trying to lower utility bills, reduce indoor air pollution from gas appliances, or make their homes less dependent on carbon-heavy energy sources. It can also save people time and stress when comparing bids, timelines, and product claims.
In a market crowded with sales pressure, programs like this can make clean-energy upgrades feel less overwhelming and more within reach.
A volunteer coach, a local community group, or even a well-informed neighbor can help people ask better questions before committing to a major home upgrade.
💡Go deep on the latest news and trends shaping the residential solar landscape
Readers can also use EnergySage’s solar map. Together, those resources can help readers get the best price for rooftop solar panels and access available incentives.
Adding battery storage to a solar setup is one of the best ways to protect your home during outages, save money on energy, and go off grid. Homeowners who want to pair solar with backup power can explore EnergySage for information about home battery storage options.
And for anyone who wants to support the kind of grassroots work that helps more households make these changes, it may also be worth learning more about donating money to climate causes.
For Soule, the program’s value comes down to practical experience: “We’re not professionals, but we have a lot of experience with these systems, and we can point people in the right direction and give them the right questions to ask.”
Get TCD’s free newsletters for easy tips, smart advice, and a chance to earn $5,000 toward home upgrades. To see more stories like this one, change your Google preferences here.
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Ground-mounted bifacial solar panels are hitting performance targets that exceed initial expectations in California, driven by the reflective properties of the ground surface beneath them. Unlike traditional monofacial panels that capture sunlight only on their front side, bifacial panels generate electricity from both faces, with the rear side drawing on light reflected from the ground and surrounding surfaces.
The key to this performance boost is the albedo effect — the measure of how much light a surface reflects. According to research, when ground reflectivity is optimized, bifacial solar panels can increase their total energy output by up to 10 to 30 percent compared to their rated specifications. This additional gain comes entirely from the rear side of the panel, which captures light bouncing up from the ground below.
Ground albedo values vary significantly based on surface material. A typical grass-covered area reflects about 20 percent of sunlight, while high-reflectance materials — such as white membranes or specially treated surfaces — can reach 60 to 70 percent reflectivity. According to research published in 2025, utilizing actual albedo values in calculations can increase photovoltaic output by up to 37 percent compared to using a constant 0.2 albedo assumption. This means that ground preparation directly affects bifacial panel performance more than it does with standard panels.
California’s solar boom has created ideal conditions for this technology to flourish. The state produced over half its electricity from solar in May 2026, a world record, and had approximately 23,400 megawatts of utility-scale solar capacity installed as of mid-2026. That capacity makes California second only to Texas in the nation. As developers continue building large-scale solar farms, bifacial panels mounted on optimized ground surfaces have become an increasingly attractive option for maximizing energy yield from existing land.
The performance gains from bifacial panels depend heavily on mounting height and ground conditions. Research from 2026 indicates that bifacial panels perform best when elevated above ground, as increased mounting height improves the rear-side view factor and allows greater access to reflected light. However, even at lower heights, properly designed ground-mounted systems can capture significant reflected radiation.
For utility-scale projects, the economic case is compelling. By capturing additional power from the same footprint of land, developers can reduce the cost per megawatt of installed capacity. This is particularly valuable in California, where land availability and permitting costs are significant factors in project economics. As bifacial panel costs continue to decline and the technology matures, ground-mounted bifacial installations are becoming standard practice for new solar developments across the state.
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Chris Martin is a US economics and current affairs journalist covering the intersection of policy, markets, and everyday financial life. With a background in financial reporting and a sharp eye for the stories behind the numbers, Chris brings clarity to some of the most complex issues shaping the American economy today. At ECIKS.org, Chris covers breaking developments across domestic economic policy, business strategy, Wall Street movements, and political decisions that ripple through financial markets. His reporting blends rigorous data analysis with accessible storytelling making critical information useful for investors, entrepreneurs, and engaged citizens alike.
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Keep Cool Anywhere With Walmart’s $65 High-Velocity Fan That Includes a Super Convenient Solar Panel  Autoblog
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This coverage is made possible through a partnership between WABE and Grist, a nonprofit environmental media organization.
Inside the vast QCells factory in Cartersville, Ga, workers — and a bevy of robots — move ultra-thin slices of polysilicon through a lengthy series of machines and chemical baths to transform them into what are known as cells.
In June, the plant, about an hour northwest of Atlanta, expanded beyond assembling the major components of solar panels. By the end of October, the company plans to have the whole production process under one roof. 
“The $2.5 billion, the 3.5 million gallons of water, the 90 megawatts of power, the 60 tons of chemicals on site, and all of the football fields worth of infrastructure you’ve seen is to arrive at this,” said Scott Bell, vice president of external affairs at QCells, holding up one of the paper-thin blue cells.
It’s the basic building block of a solar panel.
QCells’ expansion here is a major milestone for the U.S. solar industry. China has dominated solar panel manufacturing since the 2010s, flooding the global market with far cheaper panels than anyone else could make. For varying reasons — national security, labor practices, job creation, boosting the clean energy industry in the face of climate change — both the Trump and the Biden administrations have tried to bring back domestic production. 
“Having the full supply chain is critical,” said solar manufacturing expert Ben Damiani, chief technology officer at Atlanta-based solar developer Cherry Street Energy. But moving that supply chain to the U.S., he said, hasn’t been a smooth road. “Probably the biggest hindrance has been the constant change of our own policies.”
In the latest move, the Trump administration plans to levy new tariffs and impose minimum import prices on polysilicon, the key ingredient for solar cells. The new measures go into effect in December. 
The Biden administration had taken a carrot approach to attracting solar panel makers: the 2022 Inflation Reduction Act included tax credit bonuses for solar projects that used U.S.-made panels. QCells, a South Korean firm that already had a gigantic solar panel factory in Dalton, Ga., has said those incentives were a major reason they built their Cartersville plant. 
The Trump administration, by contrast, is taking a stick approach. While last year’s One Big Beautiful Bill Act revoked most of the tax credits, it also made solar equipment from certain countries — including China — ineligible for the few tax credits that remain. That, along with the new tariffs, may help a U.S. manufacturer like QCells compete with Chinese imports, which are now more expensive.
The two policy approaches have the same ultimate goal, according to researcher Coco Zhang of the banking and investment firm ING. But it’s been whiplash for companies.
Following Trump’s latest executive actions, QCells is still likely able to find a way to be successful, Zhang said. But other manufacturers may have a tougher time. QCells had already made a multibillion-dollar investment in its brand new facility. And that plant took more than three years to come online. For companies with less capital and poorer timing, the supply-side incentives for domestic production may not be enough — especially when the policies could completely change again.
“For any business, including the clean energy industry, they like consistency, they like predictability,” Zhang said. 
In the long run, Zhang is optimistic that the U.S. solar panel industry can complete its shift to domestic production. But rules under the Trump administration cutting deeper into the supply chain, as well as the policy back-and-forth, could make things harder to navigate in the short-term, she said.
The short-term outlook is complicated for those buying solar panels, too. The phaseout of federal clean energy tax credits removed a major incentive to develop new solar projects, and the Trump administration has taken steps to cancel federal funding for clean energy projects and add new hurdles for solar and wind installations on federal land. The courts have blocked or reversed some of those actions, but the delays add costs and uncertainties even for projects that do ultimately move forward. 
In the first quarter of this year, clean energy advocacy group E2 tracked nearly $13 billion in abandoned investments in solar, wind, and battery projects. But some $18 billion in new projects were announced as companies scrambled to meet the deadline of the expiring tax credits. While the new tariffs and price controls on polysilicon could help U.S. manufacturers compete to supply the solar developments that remain, they could also drive up costs for developers, Zhang said, and “limited U.S. supply means many will still depend on imports and face higher costs.”
But industry experts maintain that solar isn’t going anywhere. It’s still one of the cheapest sources of electricity at a time when energy demand is growing fast. Solar panels are also readily available, while gas turbines are backordered for years. Solar and storage made up 90 percent of new power added to the U.S. grid in the first quarter of the year, according to the Solar Energy Industries Association.
“We absolutely should make solar, right? Like it is the fastest deployed, lowest cost,” said Damiani. “Solar will be, for the next hundred years, a good portion of our energy.”
The questions, experts agreed, aren’t whether solar development will continue, but how quickly it’ll happen, how much it will cost, who will make the solar panels — and where that manufacturing will happen.

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The equipment may not be failing outright so much as suffering from a bad installation from the beginning.
Photo Credit: Reddit
After water appeared near a bathroom vent and caused ceiling paint to bubble, one homeowner found themselves facing a confusing series of HVAC recommendations: a $17,500 full replacement, a repair attempt that failed, and then a new $3,900 estimate.
The catch may have been a missing layer of protection that should have been there from the start.
In a post on Reddit‘s r/hvacadvice, the homeowner explained that the problem started with a leak near the bathroom return vent that eventually made the ceiling paint blister. The first HVAC technician who inspected it said the primary condensate drain connection was broken at the pan. His proposed solutions were costly: about $17,500 for a full system replacement or roughly $10,000 for a new coil and condenser while leaving the current heater in place.
The homeowner’s reaction: “If the pipe is broken, is there a less drastic way to address this before replacing thousands of dollars worth of equipment?”
Rather than jump straight to replacement, a second technician tried repairing the broken drain connection by bonding it and adding another drip pan. After letting that repair cure for two days, he ran the system for around 30 to 45 minutes, but the leak came back. He later concluded that water was also escaping from behind the unit and quoted $3,900 for a new ductboard plenum and coil, a condensate P-trap, and drainage corrections.
If you do end up needing a new system, upgrading your heating and cooling system is one of the best ways to save money on your utility bills and protect yourself against rising energy prices. Palmetto’s Comfort Plan network can help you find efficient heating and cooling solutions for your home and connect you with vetted installers, including high-efficiency HVACs and heat pumps that can slash energy bills.
A lot of the discussion in the comments centered on possible installation flaws, not only the broken drain connection. 
One user asked, “Where in the heck is your secondary drain pan??? Also my guess would be the evap pan is cracked or the system is leaning away from the drain.”
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Want to go solar but not sure who to trust? EnergySage has your back with free and transparent quotes from fully vetted providers in your area.
To get started, just answer a few questions about your home — no phone number required. Within a day or two, EnergySage will email you the best options for your needs, and their expert advisers can help you compare quotes and pick a winner.
Solar panels can save you more than $50k over their 25-year lifespan, and EnergySage can help you save as much as $10k on installation. Which begs the question — isn’t that worth an email or two?
Condensate problems can escalate fast. A cracked evaporator pan, improper slope, missing secondary protection, or a faulty drainage setup can let water escape into ceilings and walls, turning a relatively modest repair into a much larger problem involving mold, drywall, and insulation.
Some commenters also suggested the builder could bear part of the responsibility if the home is fairly new and required drainage safeguards were never installed. That could be the difference between a $3,900 repair and a $17,500 replacement quote: the equipment may not be failing outright so much as suffering from a bad installation from the beginning.
The homeowner’s next move was to get a third opinion. It may help to ask that technician to check for cracks in the evaporator pan, make sure the unit slopes properly toward the drain, confirm that the P-trap and drain lines are working as they should, and clarify whether code requires a full secondary pan.
It can also help to request photos showing exactly where the leak is happening and a written itemization of each quote. That makes it easier to compare a true repair, a partial replacement, and a full system replacement.
If the verdict does point to replacement, Palmetto‘s Comfort Plan may be worth considering. If you’re not ready to spend up front, the Comfort Plan includes $0-down options that can lower your heating and cooling costs by up to 50%, and Palmetto Comfort Plans include 12 years of free maintenance.
You can also pair solar panels with electric appliances, including efficient HVACs, to drive your utility costs even lower. EnergySage makes it easy to find the best solar system and installer for your home and budget, saving you up to $10,000 on installations.
Get TCD’s free newsletters for easy tips, smart advice, and a chance to earn $5,000 toward home upgrades. To see more stories like this one, change your Google preferences here.
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The Ring
The Ring is Euronews’ weekly political showdown, where Europe’s toughest debates meet their boldest voices. In each episode, two political heavyweights from across the EU face off to propose a diversity of opinions and spark conversations around the most important issues of EU affairs and the wider European political life.
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Dare to imagine the future with business and tech visionaries
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The Food Detectives
Europe's best food experts are joining forces to crack down on fraud. Euronews is following them in this special series: The Food Detectives
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The EU’s largest solar farm has taken one step closer to becoming a reality, and could soon deliver enough power for almost one million people.
According to local news, the Romanian Energy Regulatory Authority (ANRE) has issued an establishment authorisation. This happens when developers can prove they have the necessary financing needed for large infrastructure projects.
The Dama Solar farm, spearheaded by Rezolv Energy, will be located in north-west Arad County, Romania, near the Hungarian border.
With aims to enter commercial operation by 2030, the project will dethrone the Witznitz Solar Park near Leipzig, Germany, which is currently the EU’s largest operational solar farm.
It could also help Romania transition away from fossil fuels, as it begins to lag behind.
According to data compiled by energy think-tank Ember, Romania only generated 9.78 per cent of its electricity from solar last year – compared to the EU average of 13.1 per cent.
It also lagged behind the EU average for wind power (12 per cent compared to 17 per cent), as well as bioenergy and nuclear.
While the majority of Romania’s electricity generation in 2025 came from hydropower (24.3 per cent), it heavily relied on gas (16.9 per cent) and coal (15.2 per cent), which is often referred to as the most polluting source of energy.
Both of these are above the EU average (16.8 per cent and 9.18 per cent).
According to Rezolv Energy, the solar farm will have an installed capacity of 1.24 GW when operational. It could in theory produce a maximum of 10.86 TWh of electricity per year (more than double Romania’s current solar production).
However, solar farms do not run at maximum capacity all year due to relying on specific weather conditions (clear skies and sunlight). However, even if the farm runs at an average of 15 per cent capacity in one year, which is a conservative estimate given its location, it could still produce 1.63 TWh of electricity.
The developers predict that the annual estimated energy production of the plant will be able to cover the consumption of more than 280,000 households, or close to one million people. It will also create more than 500 new jobs over the next three years.
Resolv Energy says the solar farm will make a “remarkable contribution” to Romania’s 2030 renewable energy targets, and that it is evaluating the future addition of “substantial energy storage”. This will help minimise wasting excess solar energy that is produced when electricity consumption is low.
“Much of the low-quality agricultural land will be returned to pasture, with sheep managing the vegetation through grazing,” the organisation adds.
“The project will also incorporate an 82-hectare nature reserve – one of the largest private-led nature restoration initiatives associated with a solar project in Southeastern Europe.”


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The Vatican plans to build an 80–90 MW agrivoltaic plant for €100 million. Surplus electricity will be supplied to Italy.
The Vatican plans to build a power plant costing around €100 million, which is intended to provide electricity to the Holy See and contribute to the state’s energy independence, Reuters reports, writes UNN.
The project envisions combining solar generation with agriculture. The future plant’s capacity is estimated at 80–90 MW, which could make it one of the largest agrivoltaic installations in Italy.
The solar panels will be installed several meters above the ground so that agricultural crops can be grown beneath them. The shade from the panels is also expected to reduce water evaporation and protect plants from extreme weather conditions.
The Pope called for an end to attacks on civilians in Ukraine and Russia10.08.26, 04:57 • 16647 views
The project will be implemented on the grounds of the approximately 450-hectare Santa Maria di Galeria estate on the northwestern outskirts of Rome. Since the 1950s, it has housed transmission facilities of Vatican Radio.
An Italian-Vatican joint commission held a meeting at the beginning of August to launch the project. This became possible after Italy ratified a bilateral agreement in 2025 allowing the site to be developed.
According to Reuters sources, construction of the plant could take 18 to 24 months, taking into account permitting and administrative procedures. Contracts for the work are expected to be put out to tender in the coming weeks.
In the Russian edition of the Pope’s autobiography, passages about LGBT people were censored16.08.26, 18:07 • 5977 views
Solar panels could cover around 200 hectares of the site, or nearly half of the estate’s area. The electricity is planned to be used to operate Vatican Radio’s transmission station and other facilities associated with the Holy See. These could include the Bambino Gesù hospital in Rome.
The surplus electricity generated is planned to be supplied to Italy. At the same time, the Vatican will not use the financial incentives available to Italian households and businesses that install solar power plants.
The project was one of the priorities of the late Pope Francis and received the approval of Pope Leo XIV. The bilateral agreement between Italy and the Vatican also extended to the agrivoltaic plant the special status already held by Vatican Radio facilities, including exemption from Italian taxes and state fees.
At the same time, the Italian law ratifying the agreement stipulates that its implementation must not create a new or additional burden on public finances.
Vatican and China agree on new bishop after 20-year vacancy24.07.26, 17:34 • 5599 views
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The EU’s largest solar farm has taken one step closer to becoming a reality, and could soon deliver enough power for almost one million people.
According to local news, the Romanian Energy Regulatory Authority (ANRE) has issued an establishment authorisation. This happens when developers can prove they have the necessary financing needed for large infrastructure projects.
The Dama Solar farm, spearheaded by Rezolv Energy, will be located in north-west Arad County, Romania, near the Hungarian border.
With aims to enter commercial operation by 2030, the project will dethrone the Witznitz Solar Park near Leipzig, Germany, which is currently the EU’s largest operational solar farm.
It could also help Romania transition away from fossil fuels, as it begins to lag behind.
According to data compiled by energy think-tank Ember, Romania only generated 9.78 per cent of its electricity from solar last year – compared to the EU average of 13.1 per cent.
It also lagged behind the EU average for wind power (12 per cent compared to 17 per cent), as well as bioenergy and nuclear.
While the majority of Romania’s electricity generation in 2025 came from hydropower (24.3 per cent), it heavily relied on gas (16.9 per cent) and coal (15.2 per cent), which is often referred to as the most polluting source of energy.
Both of these are above the EU average (16.8 per cent and 9.18 per cent).
According to Rezolv Energy, the solar farm will have an installed capacity of 1.24 GW when operational. It could in theory produce a maximum of 10.86 TWh of electricity per year (more than double Romania’s current solar production).
However, solar farms do not run at maximum capacity all year due to relying on specific weather conditions (clear skies and sunlight). However, even if the farm runs at an average of 15 per cent capacity in one year, which is a conservative estimate given its location, it could still produce 1.63 TWh of electricity.
The developers predict that the annual estimated energy production of the plant will be able to cover the consumption of more than 280,000 households, or close to one million people. It will also create more than 500 new jobs over the next three years.
Resolv Energy says the solar farm will make a “remarkable contribution” to Romania’s 2030 renewable energy targets, and that it is evaluating the future addition of “substantial energy storage”. This will help minimise wasting excess solar energy that is produced when electricity consumption is low.
“Much of the low-quality agricultural land will be returned to pasture, with sheep managing the vegetation through grazing,” the organisation adds.
“The project will also incorporate an 82-hectare nature reserve – one of the largest private-led nature restoration initiatives associated with a solar project in Southeastern Europe.”


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Solar panel prices are falling faster than distributors can adjust, and for FosRich Company Limited, the result is a business that moves more product but collects less money for it.
The challenge is compounded by an unregulated local market where a growing number of importers compete on price with few barriers to entry.
“Our turnover numbers continue to be affected by the substantial fall in solar panel cost on the world markets, which affects our business,” Managing Director Cecil Foster said in the company’s quarterly report. He added that uncertainty in the United States had prompted some global suppliers to offer more favourable credit terms to non-US distributors such as FosRich, providing “measurable benefits”.
Despite the revenue decline, FosRich’s gross profit margin edged higher to 39 per cent year to date from 36 per cent a year earlier – a sign that the company is maintaining its markup even as the dollar value of each sale shrinks. Solar products remained one of the group’s key revenue generators alongside hardware, LED products, PVC items, and wiring devices.
The Junior Market-listed electrical and solar energy distributor reported a net loss of $265.2 million for the three months ended June 30, more than double the $121 million loss recorded a year earlier. Quarterly revenue fell 46 per cent to $397.2 million from $734.4 million.
For the six-month period, revenue slumped to $812.3 million from $1.59 billion a year earlier. Losses widened to $444 million from $189.6 million, and loss per share deteriorated to nine cents from four cents.
Global solar module prices have fallen by more than half since early 2023, driven by Chinese overcapacity that has pushed manufacturing capacity to more than double annual demand, according to the International Energy Agency. Oilprice.com reported on Thursday that panel prices have dropped 90 per cent over the past 15 years.
For manufacturers, falling input costs can be absorbed. For distributors like FosRich, the dynamics work in reverse. The company purchases and ships panels at prevailing prices, but by the time inventory clears Customs and reaches a Jamaican warehouse, the global market may have moved lower – eroding the resale price, particularly amid heightened competition.
Any business can import and resell panels, and as global prices have collapsed, the number of players entering the space has grown – compressing margins for established distributors such as FosRich that carry higher fixed costs.
The damage came not from margins but from the mismatch between falling revenue and fixed overheads. Administrative costs for the first half totalled $680.3 million, broadly flat against $677.8 million in the prior year.
FosRich has endured three consecutive years of declining earnings, with net profit sliding from $325 million in 2022 to $235 million in 2023 and $34.5 million in 2024, according to the audited results. The downward trajectory culminated in a net loss of $506 million for the 2025 financial year.
To stem the losses, Foster said management is pursuing a recovery plan. One measure includes opening its Molynes Road superstore by September.
“We anticipate commencing activities at our new superstore by the end of the third quarter, which will contribute significantly to our top line and cash flows,” Foster said.
Inventory rationalisation is another priority. FosRich’s inventory stands at $2 billion – roughly equivalent to a year of sales at the current rate, tying up capital the company needs elsewhere. Management is also tightening administrative spending and pursuing partnerships with property developers to drive demand for its electrical, lighting, and solar products. The company is planning a sale-and-leaseback of its real estate assets aimed at retiring loans and freeing cash to support inventory purchases. Management said the combined initiatives are expected to generate an “increase in sales”.
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By: Luis Reyes
Published: Aug 22, at 9:30am ET
The pronghorn tops out around 60 mph, which makes it the fastest land animal in North America and the second-fastest on Earth behind the cheetah. It is built for exactly one job: spotting trouble across miles of open country and simply leaving. Huge eyes, oversized windpipe, a heart that would look ambitious on an animal twice its size.
What it never learned to do is jump. Pronghorn evolved on plains with nothing vertical on them, and High Country News notes they have trouble clearing fences and other barriers. A six-foot barrier that a whitetail deer hops without breaking stride functions, for a pronghorn, like a wall.
So when a utility-scale solar farm went up across 1,100 acres of grassland in northwestern New Mexico, wrapped in the tall fencing the law requires for sites like it, the reasonable bet was that the local herd had lost that ground for good. Seventy-five GPS collars are now saying something more interesting. The animals are not going around the farm. They are walking through it, threading the gaps between the fenced panel blocks like they have read the site plan.
The San Juan Solar and Storage Project is a 200-megawatt solar facility with a 100-megawatt battery near Farmington, in New Mexico’s Four Corners. It occupies 1,100 acres a few miles from the San Juan Generating Station, the coal plant that shut down in 2022 and lost its four 400-foot smokestacks to demolition crews in 2024.
That location is not sentimental. Developer D. E. Shaw Renewable Investments built the project as capacity replacement for the retired coal units, feeding the grid through the dead plant’s existing interconnection under a 20-year power purchase agreement with Public Service Company of New Mexico. Construction wrapped in the fall of 2024.
Here is the detail that turned an ordinary solar build into a wildlife experiment. The land under it came with public roads, a crowd of private landowners, and deep dry washes called arroyos cutting through it. Rather than fight all that, the builders carved the site into nine individually fenced arrays plus a battery yard, with open passages running between the blocks.
Those passages exist because of property lines and drainage. Wildlife was not the reason. It just turned out to be the beneficiary.
Wildlands Network, a conservation nonprofit, saw the construction coming and launched one of the first studies of its kind at an active American solar facility: it wired up the herd while the panels were still going in. Backed by a $1.7 million award from the Department of Energy’s Solar Energy Technologies Office, the group’s biologists fitted GPS collars on 75 female pronghorn across two study areas, one around the San Juan site and a second on the Navajo Nation in eastern Arizona.
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Since March 2024, every collar has reported its position once an hour, around the clock. By this spring the project had banked over 1 million GPS locations and more than 5 million trail camera photos, which is a staggering amount of homework about one animal and one fence line.
The early returns cut against the doomsday scenario. Of the 30 collared females living near San Juan Solar, 18 have come within 328 feet of the fencing. The researchers went looking for a buffer zone, some distance at which pronghorn refuse to approach, and so far they cannot find one.
And the passages are getting used. Every single gap between the nine arrays has recorded pronghorn traffic to some degree, according to the project’s May 2026 update. The fastest land animal in the Americas is treating a 1,100-acre industrial site less like a wall and more like a maze it has already solved.
Because the gaps came from surveyors and arroyos instead of biologists, they vary wildly. Some passages are wide and short, others long and pinched, and they sit next to everything from flat grass to cliff-edged washes and county roads. That messiness is exactly what makes San Juan useful as an experiment. It is nine different corridor designs tested on the same herd at the same time.
The collar data published by Wildlands Network shows the animals are picky in ways a siting map would never predict. The biggest, most open passages get the heaviest traffic, and the longest, narrowest ones get almost none. Then the pronghorn broke their own rule and used the narrowest passage on site, which also happens to be the shortest, when food and water sat on the other side.
Terrain matters just as much as geometry. The largest passage has a deep arroyo running through it with cliffs the animals cannot cross, and on its western edge the fence was built only about 100 feet from that arroyo. The collars show pronghorn mostly refusing to squeeze through that pinch point, even inside a passage they otherwise like.
In short, the animals are not reading the corridor. They are reading what the corridor gets them to. A gap that leads to water earns traffic. A gap that leads to a cliff and a fence does not, no matter how generous it looks on a map.
The reason biologists expected the worst in New Mexico is that the only comparable American study found it. The 80-megawatt Sweetwater facility, Wyoming’s first utility-scale solar plant, went up in 2018 with a single continuous fence around the whole thing, and researchers had pronghorn collared there before construction started.
The results were rough. A follow-up study in Ecological Solutions and Evidence tracked the herd for five years after the build and found the avoidance never faded: fewer encounters near the site, more time spent away from it, and behavioral changes reaching almost a mile beyond the fence. The habitat loss extended far past the acreage the panels actually occupied.
One farm sealed with a single fence, one farm broken into nine blocks with gaps. One herd retreated, the other moved in. The New Mexico team is careful not to declare the passages the proven cause, and the two sites differ in plenty of other ways. But the design contrast is the obvious suspect, and it is the exact question their next paper is built to answer.
It fits a pattern this industry keeps bumping into. Oregon just permitted 406,000 panels on the condition the developer leave a 600-foot gap so deer and elk can still reach their water, a corridor nobody has built or tested yet. In California, an endangered kit fox moved into two solar farms and raised pups inside the fence.
And in Oregon again, a half-pound ground squirrel holds legal veto power over a 380-megawatt plant’s construction schedule. San Juan is the first case where the animal in question runs 60 mph and has a million data points backing up its opinion.
Before anyone declares solar and pronghorn best friends, the people running the study are loudly hedging their own results. The observations cover one landscape, one facility, and a couple of years. What happens in a New Mexico valley with nine arrays says nothing automatic about a Wyoming migration route with one.
The formal science is only now arriving. The first paper, written with Conservation Science Partners from the initial year and a half of data, has been submitted to the journal Ecosphere and is under peer review. The second, focused specifically on which passage sizes and shapes pronghorn will actually use, is being drafted for submission later in 2026. Until those clear review, everything above carries an asterisk the researchers themselves put there.
And there is a harder truth sitting under the good news. Animals walking near panels does not mean the panels cost them nothing. Aaron Facka, the Wildlands Network senior wildlife biologist running the project, put it plainly: the ground under San Juan Solar was, and remains, “among the best habitat our animals have available – they just have less of it now.”
Pronghorn numbers are already declining across New Mexico, and drought keeps tightening the squeeze. A herd threading the aisles of a solar farm is a herd making do, not a herd that got its valley back.
Still, the practical takeaway is hard to ignore. The gaps at San Juan were an accident of roads, deeds, and drainage, and they may end up defining how solar gets built across pronghorn country. If the second paper confirms which passages work, the cheapest wildlife mitigation in the solar business will turn out to be the fence a contractor never got around to closing.
Don’t bite your tongue. Speak up.
Luis Reyes · Jul 29, 2026
Luis Reyes · Aug 10, 2026
Luis Reyes · Aug 13, 2026
Olivia Richman · Jul 25, 2026
Luis Reyes · Aug 6, 2026
Luis Reyes · Aug 13, 2026
Luis Reyes · Aug 22, 2026
Olivia Richman · Aug 21, 2026
Luis Reyes · Aug 21, 2026
Luis Reyes · Aug 21, 2026
Luis Reyes · Aug 21, 2026
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By island, O’ahu led with 2,505 new systems, followed by Hawai’i Island at 490 and Maui County at 434.
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The expiration of a major federal solar subsidy has not brought Hawaiʻi’s rooftop market to a halt, suggesting continued homeowner interest in lower electricity bills and emergency backup. Over the first six months of 2026, Hawaiian Electric customers installed thousands of new home solar systems, a sign that demand is holding up even under less favorable policy conditions.
Even though the federal clean energy tax credit ended on Jan. 1, 2026, Hawaiian Electric reported 3,429 new grid-connected rooftop systems between January and June. Combined, those installations added 36 megawatts of capacity, according to Maui Now.
Battery adoption was also significant during that stretch, with customers adding 55 megawatts of storage — a clue that solar buyers are often seeking backup power too. By island, Oʻahu led with 2,505 new systems, followed by Hawaiʻi Island at 490 and Maui County at 434.
If you’re looking to reduce energy costs and considering installing a system of your own, it can help to explore EnergySage to get free solar installation estimates and compare quotes from installers.
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More than two decades after starting its first customer solar program, Hawaiian Electric now operates in one of the country’s most established rooftop solar environments. The utility says it has also emerged as a national leader in managing the grid complexities associated with large amounts of intermittent solar generation, Maui Now reported.
Those efforts coincide with exceptionally strong solar uptake. Rooftop systems are installed at about 27% of the utility’s residential accounts and 45% of its single-family-home customers, and on Oʻahu the single-family figure reaches 50%.
Rooftop solar can help households lower monthly electricity costs, while battery storage can provide added reliability during outages or periods of heavy demand. It also means more homes are producing cleaner electricity on-site, which can reduce pollution associated with conventional power generation and support healthier communities.
According to Hawaiian Electric, its customer energy resource programs continue to provide benefits despite the disappearance of the federal tax break. Programs including Smart Renewable Energy Export and other grid-services offerings can help customers receive bill credits or otherwise increase the value of their distributed energy resources.
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EnergySage’s free services can also make the buying process less overwhelming for households deciding whether to go solar. With EnergySage’s help, the average person can save up to $10,000 on solar purchases and installations. You can also use EnergySage’s solar map, which shows the average cost of a home solar panel system on a state-by-state level as well as details on solar panel incentives for each state. Together, those resources can help you get the best price for rooftop solar panels and access available incentives.
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A flash of light lasting less than a millisecond can heat a semiconductor coating to nearly 2,000°C while the glass beneath it stays cool enough to touch. Researchers at the Hebrew University of Jerusalem used this technique, called flash photonic heating, to rearrange atoms inside bismuth oxide thin films, producing a crystal phase that generates up to 50 times more electrical current from light than the conventional form. The method works on the same transparent conducting glass used in solar cells and touchscreens, opening a path to higher-performance solar energy materials without the damage that traditional furnaces would cause.
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Solar cells and touchscreens rely on transparent conducting glass, typically coated with fluorine-doped tin oxide (FTO) or indium tin oxide (ITO). To maximize the performance of semiconductor thin films deposited on this glass, high-temperature processing is essential. Heating a semiconductor to 800°C or above improves its crystallinity, reducing defects that trap electrical charges and lower efficiency.
There is a fundamental contradiction, however. FTO glass and its conductive layer begin to degrade above 500–600°C. Place the entire stack in a conventional furnace, and the substrate fails before the semiconductor film ever reaches its target temperature. Stop at a temperature the substrate can survive, and the film remains riddled with crystal defects, unable to efficiently convert light into electricity.
This constraint becomes even more limiting when polymorphism enters the picture. Many semiconductor materials can exist in multiple crystal structures, or phases, with dramatically different properties. The phase with the most desirable characteristics is often only stable at high temperatures. Cool it slowly, and it reverts to the ordinary, less useful phase. Conventional furnaces, which heat and cool gradually, have no way to trap these high-performance metastable structures at room temperature.
Flash photonic heating (FPH) is a technique that uses extremely short, intense pulses of white light to heat a thin semiconductor coating almost instantaneously. The concept is similar to a photographic flash, but far more powerful and precisely controlled.
In experiments published in Small Structures on July 28, 2026, a team led by Shahar Artzi and Dr. Ronen Gottesman deposited thin films of bismuth oxide (Bi2O3) on FTO conducting glass and exposed them to powerful pulses of white light. Each pulse lasted from about one-tenth of a millisecond to a few milliseconds.
The semiconductor film absorbs the light directly and heats up almost instantaneously. Because the energy is delivered so quickly, cooling finishes before the glass substrate beneath it has any time to catch up thermally. The film reached roughly 2,000°C, while the FTO glass underneath stayed below 100°C, a temperature gap that is impossible to achieve with a conventional furnace.
The heating rates achieved by flash photonic heating are staggering: up to 10 million degrees Celsius per second. For comparison, a typical laboratory furnace heats at around 10°C per minute, which is roughly six orders of magnitude slower.
The key to this extreme speed is the direct absorption of light energy by the thin film. When a pulse of white light strikes the bismuth oxide coating, the material absorbs the photons and converts their energy into heat within microseconds. The heat does not have time to conduct into the glass substrate before the pulse ends, creating a brief window in which the film exists at extreme temperatures while the substrate remains nearly at room temperature.
This thermal decoupling between the film and the substrate is what makes FPH possible.
The researchers compared the process to a blacksmith quenching hot steel: cool it fast enough, and the atoms do not have time to settle back into their preferred arrangement. In this case, the team accomplishes the transformation with light, on a millisecond timescale, on the exact same kind of transparent conductive glass found behind a smartphone touchscreen.
Bismuth oxide can form multiple crystal structures, or polymorphs, with significantly different optical and electrical properties. The stable alpha phase (α-Bi2O3) has a monoclinic crystal structure with a bandgap of about 2.8 eV. It appears pale gray and is the form that conventional heating produces.
The beta phase (β-Bi2O3) has a tetragonal crystal structure with a narrower bandgap of about 2.5 eV. This narrower bandgap means it absorbs a broader range of visible light wavelengths, capturing light that the alpha phase simply lets pass through. The beta phase is bright yellow and has been known since at least 2010 to show higher photocatalytic activity.
The problem has always been that the beta phase is metastable: it only exists at high temperatures and reverts to the alpha phase when cooled slowly.
Flash photonic heating solves this problem through kinetic control. By heating and cooling the material extremely rapidly, the researchers trap the beta phase at room temperature before the atoms have time to rearrange back into the stable alpha configuration. The result is a metastable crystal structure that would normally disappear, preserved on a conducting glass substrate ready for use in real devices.
The improvement in photocurrent was dramatic. Depending on how the films were prepared, the beta phase generated between 10 and 50 times more electrical current from light than the alpha phase. The researchers attributed this improvement partly to more effective movement of electrical charges through the altered crystal structure.
One of the most striking findings from the study is that the speed at which energy is delivered can be more important than the total energy supplied. Even when the total energy delivered by a pulse was held constant, simply changing the delivery speed, the combination of pulse width and intensity, switched which crystal phase formed.
Longer pulses produced the stable alpha phase. Shorter, more intense pulses locked in the metastable beta phase at room temperature. This is not thermodynamic equilibrium at work. It is kinetic control: the cooling completes before the atoms have a chance to revert to their preferred arrangement.
As Dr. Gottesman explained in a press release: “The idea is to heat and cool the material so quickly that we can trap it in a crystal structure that would normally disappear. It gives us access to useful properties that are hard to preserve with conventional heating methods.”
This insight has implications beyond bismuth oxide. Any material system where a high-temperature phase has desirable properties but cannot survive slow cooling could potentially benefit from flash photonic heating. The technique adds a new degree of freedom to materials processing: controlling crystal structure through the speed of energy delivery rather than through temperature alone.
The team also demonstrated something that had not been previously achieved on conductive glass: reversible switching between the alpha and beta phases. By simply changing the pulse conditions, the same film could be flipped back and forth between gray and yellow, over and over.
This capability could be significant for electronic and photoactive devices.
It suggests that material properties can potentially be tuned in place, without replacing the underlying component. A solar cell or photocatalytic device could, in principle, be reconfigured on the fly by adjusting the light pulses used to process it.
Flash lamp annealing itself is not new. The technique has been used in semiconductor manufacturing since the 1970s for dopant activation after ion implantation. More recently, it has found applications in perovskite solar cells and flexible electronics. However, most existing applications aim at crystallization or sintering. This study is the first to demonstrate selective, reversible control over crystal polymorphism on a conductive substrate.
The immediate application for flash photonic heating is solar energy conversion. Transparent conducting glass is a fundamental component of modern solar cells, and the ability to process semiconductor films at extreme temperatures without damaging the substrate could unlock new material phases and higher efficiencies.
The technique could also extend to other fields, as recent advances in novel semiconductor compounds have shown:
The broader context is encouraging. Researchers worldwide are pursuing multiple strategies to improve solar cell materials, from advanced thermal management to new compound semiconductors. Flash photonic heating adds a powerful tool to this toolkit, one that sidesteps the traditional trade-off between processing temperature and substrate survival.
Several important questions remain unresolved:
Flash photonic heating is a technique that uses extremely short, intense pulses of white light to heat a thin semiconductor coating to extreme temperatures (up to 2,000°C) in milliseconds, while the substrate underneath remains cool. It was developed by researchers at the Hebrew University of Jerusalem.
A conventional furnace heats both the material and the substrate together, slowly and uniformly. Flash photonic heating delivers energy directly into the thin film so quickly that the substrate does not have time to heat up. This allows temperatures that would destroy the substrate to be reached within the film itself.
The beta phase has a narrower bandgap (about 2.5 eV vs. 2.8 eV for the alpha phase), which means it absorbs a broader range of visible light wavelengths. This results in 10 to 50 times more photocurrent, the electrical current generated by light, compared to the stable alpha phase.
The researchers are currently investigating whether the technique can be adapted to plastic and flexible surfaces. If successful, this could enable new lightweight and flexible solar and electronic devices.
When trapped by flash photonic heating, the beta phase persists at room temperature. However, being metastable, it thermodynamically prefers to revert to the alpha phase. Long-term stability under real-world operating conditions is still being studied.
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Saffron solar panels are proving to be an unexpected combination. The world’s most expensive spice just became a compelling candidate for rooftop solar farms. A five-year experiment at Colorado State University found that saffron planted beneath semi-transparent solar panels produced roughly twice as many flowers and dried stigmas as unshaded plots, generating an estimated $60,000 in net returns alongside electricity production. The findings, published in Living Architecture Monitor, suggest that pairing high-value crops with carefully selected solar panels could transform urban rooftops into dual-income assets.
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Saffron (Crocus sativus) is not a sun-loving crop in the way most agricultural staples are. Native to the arid mountainous regions of Iran, India, Greece, Morocco, and Spain, which collectively produce 98% of the global supply, the plant has evolved to flourish under specific light conditions that many growers misunderstand.
A 2022 study from eastern Morocco quantified this preference for the first time. Researchers grew saffron for 24 months under full sun and at 30%, 50%, and 70% shade levels. The results were clear: plants exposed to 30% shade produced the highest stigma yield at 0.61 grams per square meter and the greatest number of leaves per tuft. At 70% shade, the plants redirected energy underground, producing heavier daughter corms, the underground bulbs that propagate the crop, but at the cost of reduced spice production.
This shade tolerance makes saffron an unusually good fit for agrivoltaics, the practice of co-locating solar panels and agriculture. Most food crops struggle under panels that block too much light. Saffron, by contrast, actively benefits from moderated sunlight, which reduces evapotranspiration and temperature extremes during its autumn flowering period.
At Colorado State University’s Spur campus in Denver, associate professor of horticulture Jennifer Bousselot has studied rooftop plantings under solar panels since 2007. Her master’s student, Reece Bailey, focused his thesis specifically on saffron cultivation in rooftop agrivoltaics, a combination that, to their knowledge, had never been tested before.
The CSU Spur facility houses a 46-kilowatt solar array with 4,356 square feet of cultivable growing space beneath the panels. The semi-transparent modules used in the experiment transmitted approximately 40% of incoming sunlight, a critical specification. Conventional opaque commercial panels, which dominate the U.S. market, typically allow only about 10% of light to reach plants underneath.
The difference was dramatic. Saffron grown under the 40% transparency panels produced flower counts and dried stigma yields that were double those of comparable unshaded control plots. This was not a marginal improvement over a low baseline. The shaded plots outperformed the full-sun plots by a factor of two.
The key finding from the CSU research is not just that saffron tolerates shade, but that the type of solar panel matters enormously. Standard opaque panels create near-total shade, transmitting only about 10% of available light. That level is too dark for saffron to produce optimally. Full sun, on the other hand, exposes the crop to stress that also suppresses yields.
The sweet spot, according to both the Colorado and Moroccan research, lies between 30% and 40% light transmission. The CSU team recommended designing rooftop agrivoltaic systems for saffron with semi-transparent panels mounted six to eight feet above the growing surface. This height allows air circulation and worker access while maintaining the optimal light environment.
Semi-transparent solar modules remain uncommon in the United States, but the CSU results suggest they could unlock significant revenue from rooftop spaces that would otherwise produce only electricity. The technology exists; what has been missing is a compelling crop to justify the investment.
To evaluate the business case, the CSU researchers built a five-year enterprise budget model based on their existing rooftop installation. The analysis assumed dried saffron priced at $35 per gram and included revenue from both stigma sales and the periodic sale of daughter corms, the propagation bulbs that growers harvest and sell to other producers.
The solar array’s electricity output carried an annual value of approximately $2,694, totaling $13,470 over five years. On the crop side, the model projected more than $60,000 in net returns over the same period. The first year runs at a loss because corms must be purchased before the crop establishes itself, but every subsequent year shows a profit.
The researchers stressed several caveats. The budget is a forecasting tool, not a guarantee. The doubled harvest figures came from shade test plots, not the full rooftop array. And saffron remains a labor-intensive crop: University of Vermont trials counted between 159 and 179 blossoms to produce a single gram of dried saffron, which is why the spice commands prices of $5,000 to $9,000 per pound.
The CSU findings build on nearly a decade of saffron agrivoltaics research in the United States. At the University of Vermont, researcher Margaret Skinner and her colleagues at the North American Center for Saffron Research and Development began studying saffron cultivation within solar arrays in 2018, in partnership with the solar installer iSun.
Their three-year trial at a conventional tilted solar array in Burlington produced striking results. In the second year, some plots yielded 17 pounds of saffron per acre, equivalent to $192,775 at $25 per gram. The crop grew well in the aisles between panels and around the array perimeter, though yields dropped by about 30% directly under the opaque panels. Over the full study period, net returns ranged from $7,500 to approximately $130,000 per acre, depending on whether daughter corms were sold alongside the dried stigmas.
In Kentucky, researchers at the University of Kentucky confirmed that saffron thrives in green roof conditions, with both stigma yield and daughter corm production increasing compared to field or high tunnel cultivation. These findings, published in 2023 and 2025, reinforced the CSU conclusion that rooftop environments are surprisingly well-suited to the crop.
The critical difference between the Vermont and Colorado approaches is the panel technology. Vermont used conventional opaque panels, which created too much shade directly underneath. Colorado used semi-transparent panels calibrated to transmit the 30% to 40% of light that saffron actually prefers. That distinction produced the doubled yields that make the economics work.
Agrivoltaics has expanded rapidly in recent years, with projects testing everything from leafy greens to sheep grazing under solar panels. The saffron research adds a high-value specialty crop to the portfolio, one that could make rooftop installations financially viable in urban settings where land costs are high and space is limited.
Colorado has been proactive in supporting this research. In 2023, the state established a dedicated agrivoltaics funding stream through Senate Bill 23-092. The Colorado Department of Agriculture has distributed $1 million across 13 projects in its first two rounds, including:
The broader implication is that panel selection should be crop-driven, not one-size-fits-all. Key considerations for designing a saffron-optimized rooftop system include:
A rooftop designed for saffron production would specify different glass than one designed for tomatoes or lettuce. As semi-transparent solar panel technology matures and costs decline, the ability to tune light transmission to specific crops could make dual-use rooftops a standard feature of urban infrastructure.
One practical challenge remains: there is no domestic corm supply at scale in the United States. American growers currently import corms, and the University of Vermont’s cost analysis put the corm investment at roughly $100,000 per acre before a single flower opens. Developing a domestic corm supply chain would significantly improve the economics and reduce startup barriers for new growers.
In CSU’s Denver experiment, saffron grown under semi-transparent panels transmitting 40% of light produced double the flower count and dried stigma yield of unshaded plots. University of Vermont trials in conventional solar arrays achieved up to 17 pounds per acre in peak year, though yields vary significantly by location, soil, and panel type.
Saffron evolved in the mountainous regions of Iran and the Mediterranean, where it experiences natural light moderation. Research from Morocco found that 30% shade optimizes stigma yield by reducing water stress and temperature extremes. Too much shade (above 50%) redirects the plant’s energy toward underground corm growth at the expense of flower production.
Semi-transparent panels that transmit 30% to 40% of incoming sunlight, mounted six to eight feet above the growing surface, produce the best results. Standard opaque panels transmit only about 10% of light, which is too little for optimal saffron production. The CSU team specifically designed their system around these parameters.
The CSU five-year model projects over $60,000 in net returns from saffron cultivation on a 4,356-square-foot rooftop, in addition to $13,470 from electricity sales. However, the first year runs at a loss due to corm purchase costs, and the model assumes favorable growing conditions and stable saffron prices at $35 per gram.
Saffron must be harvested by hand. Each crocus flower produces only three crimson stigmas, which are carefully removed and dried. University of Vermont researchers counted 159 to 179 flowers to produce a single gram of dried saffron. The harvest occurs in October and November, during the fall blooming season, which complements the seasonal labor patterns of green roof workers.
The convergence of saffron research and solar panel technology points toward a model where urban rooftops generate both clean energy and high-value agricultural products.
The CSU study demonstrates that with the right panel selection, a rooftop can produce electricity worth $2,694 annually while growing one of the world’s most valuable spices underneath.
For building owners, the appeal is straightforward: two revenue streams from the same footprint, with the crop requiring labor primarily in the fall and winter months when other rooftop farming activities are dormant. This approach aligns with the growing trend of urban rooftop farming that cities worldwide are embracing. For the agrivoltaics field, the saffron findings validate the principle that crop-specific panel design, rather than generic installations, can unlock the full potential of dual-use systems.
As semi-transparent panel technology becomes more accessible and domestic corm supplies develop, rooftop saffron agrivoltaics could move from research curiosity to commercial reality. The $60,000 five-year projection is a starting point, not a ceiling.
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An older system may be costing more than necessary.
Photo Credit: iStock
Air-conditioning systems are being pushed harder than usual as temperatures around the country continue to rise. 
For families that depend on AC for comfort and safety, a handful of routine upkeep steps can lower the odds of a summer breakdown and help keep power costs from rising further.
According to The Boca Raton Tribune, citing data from Cinch Home Services, U.S. Google searches for “air conditioning” were 202% above the long-term average, reaching a record high across more than 20 years of data. 
The increase comes as more homes require AC units amid rising global temperatures. It’s more important than ever to regularly maintain your HVAC system to ensure you’re operating it as efficiently as possible. 
Luckily, The Boca Raton Tribune offered five helpful maintenance tips from the home warranty experts at Cinch Home Services to help your HVAC last as long as possible while keeping your utility bills low. 
Cinch’s advice centers on five basics: keep filters clean, replace them on time, verify that the filter is the right size and type, watch for signs of declining performance, and schedule a professional inspection at least once each year.
For homeowners considering more than routine maintenance, Palmetto’s Comfort Plan network can help you find efficient heating and cooling solutions for your home and connect you with vetted installers. For many households, upgrading a heating and cooling system can be one of the strongest ways to lower utility bills and guard against rising energy costs.
Dirty filters are one of the most common AC problems, the outlet reported. As dust, pollen, and pet hair build up, those particles can circulate through the home, worsening indoor air quality, making breathing harder for people with allergies or asthma, and forcing the system to use more energy.
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To get started, just answer a few questions about your home — no phone number required. Within a day or two, EnergySage will email you the best options for your needs, and their expert advisers can help you compare quotes and pick a winner.
Solar panels can save you more than $50k over their 25-year lifespan, and EnergySage can help you save as much as $10k on installation. Which begs the question — isn’t that worth an email or two?
Cinch says, as The Boca Raton Tribune reported, replacing filters every three months is a reasonable general guideline, though pet owners may need to change them every 30 to 60 days and households dealing with severe allergies may need monthly replacements. The wrong filter size or type can also lead to gaps, rattling, and reduced airflow, which can weaken cooling and drive up electric bills.
The outlet noted homeowners should also be alert to warning signs such as slower cooling, utility bills that rise without a clear explanation, and unusual sounds or moisture problems, including leaks or ice buildup on the unit. If those issues are ignored, they may indicate larger mechanical problems.
A yearly inspection can spot wear and tear before it becomes a costly breakdown during the hottest time of year, when repair appointments can be more difficult to book and keeping a home comfortable is toughest.
Begin with the filter. If it looks dusty, clean or replace it based on the manufacturer’s instructions, and make sure it is completely dry before reinstalling it, Cinch Home Services advised. If you notice musty odors, mildew, or mold, stop using the unit until the issue is resolved.
An older system may be costing more than necessary. A newer efficient HVAC unit or heat pump can reduce waste, improve comfort, and lower monthly bills as energy prices continue to climb.
If you want a more efficient HVAC system but aren’t ready to pay everything upfront, Palmetto’s Comfort Plan offers $0-down options that can reduce heating and cooling costs by up to 50% and includes 12 years of free maintenance.
Homeowners may be able to lower costs even more by pairing solar panels with electric appliances such as efficient HVAC systems. EnergySage makes it easy to find the best solar system and installer for your home and budget, with potential savings of up to $10,000 on installations.
Get TCD’s free newsletters for easy tips, smart advice, and a chance to earn $5,000 toward home upgrades. To see more stories like this one, change your Google preferences here.
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Home – Energy – A Bavarian farmer mounted solar panels 23 feet above the poles holding up his hops, and the harvest made more electricity but fewer cones
Could the beer you enjoy during a football game at the pub play a part in generating renewable energy? Bavarian hop farmer Josef Wimmer set out to see if his crop could do exactly that. While contemplating the 23-ft. trellis system across his field, he got the idea to install solar panels on top, and completed the project in 2023.
It generated electricity for about 200 homes, but the shadow cast on the plants limited the growth of hop cones, the thing that brewers actually buy. 
That setback did not end the experiment. A second prototype installed in 2025 tilted the modules from 20° to 45°, giving the plants more light, spreading generation into the morning and late afternoon, and catching more low winter sun. The lesson is simple but useful, since agrivoltaics works only when the panel geometry suits the crop, not just the grid.
The official HoPVen research site covers over 3 acres and combines Hallertauer Tradition and Herkules hops with a 977-kilowatt solar array. Its modules sit 23 ft. above the ground on sturdy steel masts that also serve as hop poles, allowing farming to continue below the glass.
On the first version, the panels were set at 20°, close enough to horizontal to collect strong midday sun. The same layout cast too much shade at the top of the trellis. When the vines reached the roof, they pushed out bushy growth instead of enough cones, reducing both the harvest and the extract that brewers value.
Engineer Bernhard Gruber spent two years reworking the design. The 2025 prototype uses steeper panels that reduce the strong noon shadow and let the hops devote more energy to cone production. It also spreads electricity generation across more valuable hours, rather than concentrating output around midday when Germany’s grid may already be flooded with cheap solar power.
The economics is still a balancing act. Researchers measured hop losses of 10% to 20%, while Wimmer said the farm can still make the numbers work if losses settle between 10% and 15% because electricity revenue fills the gap. “It pays off, it pays off,” he said, while Gruber estimated a roughly 14-year payback for equipment expected to last at least 30 years.
HoPVen runs from November 2023 through October 2026, with Fraunhofer ISE, Weihenstephan-Triesdorf University of Applied Sciences, and Bavarian agricultural researchers comparing the covered field with an uncovered control plot. Sensors track soil moisture, air temperature, humidity, light, wind, and leaf wetness at different heights and depths.
Early results from the first prototype suggest that extra shade improved soil conditions and helped retain moisture, a practical benefit during the hot, dry weeks of June, July, and August. The second prototype is still being tested, and researchers are also studying an unusually messy problem. Crop sprays can land on the underside of the modules, potentially increasing dirt, corrosion, and efficiency losses.
Germany had 904 hop farms in 2026, including 722 in Hallertau. The number of growers has fallen by more than 40% since 2006 even as the national hop area increased by about 4%, a sign that fewer families are managing larger operations. Germany harvested about 95 million lbs. of hops in 2025, down roughly 7% from the previous year.
Climate pressure adds another layer. A 2023 Nature Communications study found that average Hallertau hop yields after 1995 were 13.7% lower than in the earlier comparison period, while average alpha-acid content fell 15.6%. Its models projected yield declines of 4% to 18% and alpha-content declines of 20% to 31% by 2050, which matters to brewers because alpha acids are a major source of beer’s bitterness and a key measure of hop value.
The United States is moving through a different market cycle, but the pressure is familiar. USDA forecast 41,642 acres of hops strung for harvest in 2026, with Washington accounting for 30,301 acres, down 3% from the previous season. The Brewers Association says planted acreage is nearly 31% below its 2021 peak as the industry adjusts to slower beer sales and high inventories.
Washington researchers have already mapped roughly 87,000 acres of farmland that could plausibly support agrivoltaics near electrical substations, though the state still lacks a large-scale example. Hop fields may offer a useful test because they already depend on tall trellises, but Bavaria shows why this is not a plug-and-play upgrade.
The pilot suggests that panel angle, shade timing, crop quality, grid access, permitting, and maintenance all have to work together.
Wimmer is already planning to expand the covered area from about 12 acres to roughly 49 acres, with a target of 8 megawatts of solar capacity and a 1-megawatt battery. That confidence matters, but it is not the same as a final scientific verdict. The second prototype remains under evaluation, and the project still represents one farm, two hop varieties, and a very specific local climate.
Still, the most valuable result may be the design rule it uncovered, because more shade is not automatically better and maximum noon output is not necessarily the most profitable outcome. The winning system is the one that protects the crop, preserves the cones, and produces power when the market values it. 
The official HoPVen project overview was published by Fraunhofer ISE.

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While solar farms must stay weed-free to function, the animals that do that job matter enormously—and sheep have won out over goats, cattle, and every other contender.
By Brendan Brown
Published August 23, 2026 · How we edit
Drive through Milam County, Texas, past the endless glinting rows of one of the biggest solar projects in America, and look under the panels. Down in the shade, working steadily through the grass, are sheep. Thousands of them.
They are not decoration. They are the maintenance crew, and across Texas they have become a booming industry of their own, built on a simple piece of livestock arithmetic: of all the animals a rancher might turn loose on a solar farm, exactly one of them doesn’t wreck the place.
A solar farm is, underneath everything, a field, and fields grow. Let the grass rise too tall and it starts shading the bottom edge of the panels, cutting the electricity the site was built to make. Let it dry out and it becomes a fire hazard threading between millions of dollars of equipment.
The traditional answer was mowing, which on a several-thousand-acre site means crews, diesel, noise, and machines squeezing endlessly through narrow rows and awkward corners under low-slung steel. It is expensive and slow, and the grass never stops.
The alternative answer walked in on four legs. Sheep fit under the panels, graze in any weather, reach the crevices a mower can’t, and turn the site’s biggest maintenance headache into somebody’s ranch.
The animal selection was settled by process of elimination, and the failures are half the fun.
Goats, the more famous eaters, are a menace on a solar site. They climb, and a herd of goats will treat tilted panel rows as a playground, damaging the glass with their hooves. Worse, goats chew for entertainment, and a solar farm is thousands of acres of exposed cabling. As one Penn State extension guide puts it dryly, goats are not recommended for solar arrays, with reports of damage from both climbing and chewing.
Cattle fail the other direction. A cow is simply too tall and too heavy for standard panel rows, unable to graze the ground beneath the arrays and perfectly capable of bending mounts and equipment by leaning on them. Panels can be mounted high on pedestals for cattle, but that has to be designed in from the start, at extra cost.
Sheep pass every test. They fit under the lowest rows, they eat grass rather than infrastructure, they move calmly, and their appetite is relentless. As one North Carolina extension specialist summed it up: cows are too tall, goats climb, and sheep are the one domesticated grazer that can take care of business without damaging the goods.
Solar grazing exists across the country, but Texas has swallowed the industry. Sheep now graze more than 130,000 acres of solar sites across 30 states, and roughly 68,000 of those acres, more than half the national total, are in Texas, which also happens to lead the nation in solar construction.
The scale of individual operations has become genuinely ranch-sized. Texas Solar Sheep, a family company that started with a couple hundred animals, now runs more than 6,000 sheep across a dozen or so sites, with co-owner JR Howard telling Texas Monthly he has had to turn down work. At SB Energy’s 900-megawatt project in Milam County, about 3,000 sheep handle 4,000 acres. Operators say livestock now do 70 to 80 percent of the vegetation work, with mowers reduced to touch-up duty.
The money flows both ways. Solar companies report that sheep cost less than mowing crews while cutting diesel use and the noise that rural neighbors complain about. Ranchers get paid for grazing services on land they could never afford to buy, plus lamb sales on top. And the sheep get thousands of acres of pasture with something Texas grass has never offered before: shade in August.
Underneath the novelty is a serious land story. Texas lost more than 2 million acres of grazing land in just five years between the last two agricultural censuses, and solar development is one of the pressures eating at ranch country, a sore subject in many rural counties.
Solar grazing is the closest thing to a truce. The same acres make electricity above and lamb below, and advocates from groups like American Farmland Trust pitch it as the way to keep agriculture alive inside the solar boom rather than displaced by it. Field days at Texas solar sites now draw crowds of ranchers, energy staff and environmentalists to watch flocks work the rows, and university programs have sprung up to study which breeds, stocking rates and forage mixes suit life under glass.
It is a rare story where the interests line up almost embarrassingly well. The panels need the grass short. The sheep need the grass, full stop. And the rancher, who a decade ago might have seen the solar lease as the end of the land’s working life, now runs a bigger flock than ever, on grass he doesn’t own, under panels he doesn’t mind, in a business that exists because goats cannot be trusted around wiring.
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DOE eyes more solar installations amid streamlined processes  Philippine News Agency
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Kojadmal Jat and his family members (second from left) at the 600 kW Agri-PV pilot in Kundanpura village, Bassi, Rajasthan. Photo: Special Arrangement.
Kojadmal Jat’s solar farm is different from those surrounding it. In Kundanpura, a village in Bassi block, nearly an hour’s drive east of Jaipur, Rajasthan’s capital, the sight of fields dotted with rows of ground-mounted solar panels is now common. On 60-year-old Jat’s land, though, tender maize unfurls under the dark glass of the panels reflecting the afternoon light. The maize, in shades of pale yellow and green, fills a space that conventional solar farms leave barren.
Jat has been working with researchers of Indian Council for Research on International Economic Relations (ICRIER) on an agrophotovoltaics (APV) project.
Also known as agrivoltaics or agriPV, this is a practice in which the same land is used for agriculture and solar power generation.
Maize grows beneath elevated solar panels at Kojadmal Jat’s Agri-PV farm, where panels allow crops to be cultivated while the 600 kW plant continues to generate electricity. Photo: Special Arrangement
His farm is part of a pilot, spread across nearly 3 acres, roughly twice the size of a cricket ground. This is Rajasthan’s first farmer-owned APV, which generates 600 kW. The installation feeds enough electricity into a local grid to provide daytime irrigation power for around 250 farms.
In 2023, inspired by the growing solar-panel-covered fields of his neighbours, Jat exchanged the uncertainties of each harvest for the predictability of monthly income. His decision exposes a dilemma at the heart of the energy transition: should productive farmland generate food or electricity? Jat was anguished by this trade-off. “My farm was generating solar power, but at the end of the day, I am a farmer. I could not come to terms with the fact that I was no longer able to cultivate my land because of the solar panels.”
India ranks 102nd out of 123 countries, on the 2025 Global Hunger Index. Converting productive farmlands to solar power plants risks intensifying food insecurity.
APV works on the principle that partial shading from solar panels can reduce heat stress and evaporation while creating a more stable microclimate, potentially valuable for farming in dry and arid regions. Laxmi Sharma, a research associate with the ICRIER team, was assigned the job of helping Jat explore the APV model. “When we showed him that he could combine farming with solar energy generation, he was delighted by the prospect of being able to do both,” she recalls.
By diversifying farm income, the model reduces dependence on a single source of livelihood and strengthens resilience to both climatic and market risks. But the economics that make APV attractive also constrain its wider adoption. APV can increase farmers’ annual returns of roughly ₹3 lakh to ₹4 lakh per acre, but elevated mounting structures add nearly ₹35 lakh over a conventional installation. For many smallholder farmers, this is simply out of reach
Jat had spent a lifetime farming before turning to solar energy. Through farming he was able to earn close to ₹40,000 a year, but with these panels, his annual income has increased nearly eightfold, to about ₹3 lakh.
Retrofitting the completed plant in phases enables cultivation to begin beneath the solar array while energy generation continues uninterrupted. Photo: Special Arrangement
In mid-2024, a young team of researchers in New Delhi set out to study the viability of a farmer-owned agrivoltaics model. “When we started, there were only around two dozen agrivoltaics pilots in India,” says Sharma, who joined ICRIER in 2024 for this project. “Most were led by academic institutions or private developers and very few were actually owned by farmers.”
In Madhya Pradesh, Anand Jain, an MTech graduate from IIT Roorkee and a farmer since the 1990s, had arrived at the same question from a different direction. He started studying agrivoltaic projects in Germany and other parts of Europe, collecting data on panel height, spacing, and the microclimate created beneath them.
“Because I am a farmer, I wanted to save every inch of my land,” he says. The panels, he reasoned, should adapt to the farm, not force the farm out.
His own experiment became an early example of the kind of farmer-led model that ICRIER would later seek to study more systematically.
Maize, typically harvested in Rajasthan in September–October, growing beneath 11-foot-high solar panels in May, with enough clearance for tractors to plough and cultivate beneath. Photo: Special Arrangement
The ICRIER team distilled its findings in an April 2025 report titled ‘Solar as a Third Crop to Augment Farmers’ Income’. They then set out to test this idea in the field.
Rajasthan was their natural choice because the State has India’s highest solar irradiation. It was among the leading implementers of the PM-KUSUM, a Central government scheme, which offers incentives to farmers using solar energy. The ICRIER team partnered with a grassroots organisation to find a farmer willing to test the model. Their search led them to Jat.
Jat and his family were intrigued but cautious. “My first question was about trust,” he says. “We are often shown ambitious schemes and glossy promises, but when things go south, we are left to navigate the uncertainty and financial risk on our own,” recalls Shiv, 36, Jat’s son, who was closely involved with his father in the APV project.
The researchers, meanwhile, had their own doubts. They wanted to know whether Jat was serious enough about farming to continue cultivating the land for the next 25 years. “For us, Kojadmal was a stranger. For Kojadmal, we were just another group of experts. Trust had to be built through multiple conversations,” recalls Laxmi.
Jat and his son say that their experience with ICRIER’s earlier work made the difference. The team had already been working with farmers on a net-house project, and they had seen their efforts first-hand. “They didn’t just come and tell us about a plan, they were there, working with us and showing us what they were doing. I had seen their team’s hard work on the ground. That is what earned our trust,” says Shiv.
They worked through the technical and financial details together, but Jat knew that the final risk would still be his. “This wasn’t free money,” says Subhodeep Basu, a researcher at ICRIER, who worked on the ‘Solar as a Third Crop…’ study. If agrivoltaics were to create farmer-entrepreneurs rather than grant recipients, Jat had to invest in the project himself and share its risks.
The next challenge lay in retrofitting an operational solar plant. “A lot of individual farmers told us, ‘We already have a steady source of income. If construction means losing energy revenue during that period, we’re not interested,’” recalls Subhodeep. Hence, instead of shutting down the entire plant, they retrofitted it, one inverter at a time, allowing the remaining sections to continue generating electricity. “That way we could minimise this energy loss,” says Subhodeep.
The ICRIER team decided to advise farmers on which crops were most likely to thrive beneath the panels, while leaving the final choice to them. They would shoulder the risk and reap the returns. Jat chose maize, hoping to grow it during the off season under the cooler microclimate created by the panels, when supplies were thin and prices higher. “In May, the heat made planting impossible but this year, we harvested an abundant maize crop with much less water. The panels have made it possible to farm where it was once impossible,” says Shiv.
With the engineering finalised and the crop chosen, the last question was whether the economics could make the model viable. Like the conventional solar project, 70% of the upfront cost would come from a commercial bank loan carrying an interest rate of 10.25%. For this pilot, the additional cost of retrofitting, i.e., ₹35.3 lakh, was provided by Kotak Mahindra through their CSR programme Kotak Karma.
The electricity generated by the plant would continue to flow into the grid, where Rajasthan’s distribution utility, Jaipur Vidyut Vitran Nigam Ltd. (JVVNL), would purchase it at ₹3.14 per unit for 25 years. The plant would generate electricity every day of the year. “To understand the financial feasibility of the pilot, we modelled two scenarios, one with viability gap funding (VGF, a government scheme) and another without it,” adds Subhodeep. Without VGF, Jat would have had to wait nearly 12 years to recover his investment. With VGF covering part of the upfront cost, that wait was cut almost in half, to just over six years. The project also became substantially more rewarding as annual profits increased from ₹3.76 lakh to ₹4.48 lakh per acre, while the expected return on investment rose from 12% to 18%.
GIZ India, a German development agency that funded the project, found that 54% of the 1,700 farmers it engaged through workshops expressed interest in adopting agriPV systems.
Another farmer who had watched Jat’s project evolve from its earliest days admitted he had often imagined replicating it on his own land. “Kojadmal could take the risk,” he says. “I’d like to as well. I already have a ground-mounted solar plant. But I don’t have the appetite to take such a big loan or put in that kind of money.”
High capital costs continue to deter participation, says Ashok Gulati, an agricultural economist and professor at ICRIER. With lending rates hovering around 10.5%, the economics remain challenging for most farmers, he adds.
“Many state distribution companies remain reluctant to sign long-term power-purchase agreements because of financial stress or surplus power. Land approvals, bureaucratic delays and shifting policy guidelines have slowed implementation,” explains Gulati.
He also suggests that a credit guarantee backed by the National Bank for Agriculture and Rural Development (NABARD) could make smaller agriPV projects easier to finance. But for now, no such financing window exists, a NABARD official confirmed. What does exist is a carefully structured repayment system that gives banks confidence to lend.
Jain sees the implementation gap from the ground. PM-KUSUM is a Central scheme, but execution is entirely at the State level. “There should be a single-window system under the Ministry of New and Renewable Energy (MNRE), so farmers are not left navigating this maze on their own.”
He took more than nine months to get the power-purchase agreement done. Meters added another hidden cost: at around ₹5 lakh each, four meters meant ₹20 lakh before the plant could even begin generating returns. “How is this feasible for an ordinary farmer?” he asks.
Further, the paperwork carries a steep price: stamp duty on registered mortgage agreements for solar projects can run into lakhs of rupees, adding another upfront cost to an already capital-intensive investment.
Rajasthan’s energy department, however, says the process has been streamlined, with nodal officers, standardised procedures, simpler land acquisition processes and the shifting of implementation from the Rajasthan Renewable Energy Corporation to power distribution companies. The State now has over 3,000 MW of installed solar capacity and daytime power reaching farmers across at least 22 districts. But that ease is not uniform across States. In Madhya Pradesh, Jain had to deal with three separate energy departments.
Even in Rajasthan, agriPV has no dedicated procurement pathway and must compete with conventional ground-mounted solar in tenders designed around lower-cost PV, despite its higher capital costs and added agricultural benefits.
Financing is only one constraint. A senior NABARD official, speaking anonymously, says weak rural-grid capacity and concerns about absorbing decentralised solar power have made NABARD cautious about dedicated agriPV financing.
Rajasthan sanctions PM-KUSUM plants only where substations have capacity and is planning large-scale battery energy storage systems to absorb surplus daytime generation, though storage adds capital costs.
While PM-KUSUM has been in operation since 2019, there is no centralised monitoring or grievance redressal cell.
Gulati argues that the next phase of PM-KUSUM must strengthen the ecosystem that supports farmers by identifying crop varieties and establishing a centralised agriPV monitoring portal under MNRE to track project commissioning, power exports, and payment timelines. It must also create a single platform for grievance redressal and coordination among DISCOMs, state nodal agencies and implementation partners.
Shirish Garud, now a consultant with The Energy and Resources Institute and a former senior fellow and director, argues that India needs a dedicated Renewable Purchase Obligation for agrivoltaics.
While the Electricity Act, 2003, already requires distribution companies to procure a fixed share of their electricity from renewable sources, the mandate makes no distinction between conventional solar and agriPV.
Subrahmanyam Pulipaka, CEO, National Solar Energy Federation of India, says that for agriPV to move beyond pilots, India must first establish a clear definition of what constitutes an agriPV project. Unlike countries such as Germany, France and Japan, which have clear standards governing agrivoltaics, India does not yet have formal standards, technical benchmarks, or eligibility criteria.
The next priority is to build a robust evidence base. “We should now scale it across all agro-climatic regions and generate reliable data on agricultural productivity, solar generation, and project economics,” Pulipaka says.
Krishi Vigyan Kendras and agricultural universities, he says, should lead these demonstrations by training farmers in identifying locally suitable cropping patterns and building confidence in the technology.
Pulipaka says farmer-producer organisations and cooperatives are fundamental to this capital-intensive, knowledge-intensive model. “FPOs can aggregate farmers, build awareness, provide technical support, and make project implementation more efficient,” he adds.
vanitabhatnagar6@gmail.com
Published – August 23, 2026 05:44 am IST
solar / Spotlight / Rajasthan / Jaipur / India / energy resources
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Global renewable energy developer BNRG is in discussions with Longford County Council on a large solar energy farm on a site near Lanesborough.
The project, known as Carrowroe Solar Farm, has the potential to generate enough energy to meet the needs of about 18,400 households and save almost 28,000 tonnes of carbon from being emitted each year, the developer says.
It would be built on a 98-hectare (242-acre) site bordering the Shannon.
Once operational, the land would remain suitable for some types of farming, particularly sheep grazing.
Carrowroe, which would be less than a kilometre south of Lanesborough, is the second large-scale solar farm planned for the area following the ESB’s Middleton House Solar Farm.
Middleton House Solar Farm is already under construction on a 85.92-hectare site about 6km north of the village.
The ESB said it could generate enough energy to power more than 15,000 homes.
Lanesborough has emerged as an attractive base for renewable energy projects because of its proximity to a former power station, which has an existing grid connection for electricity transmission.
The flat peatland terrain and regional “Just Transition” programmes supporting green energy replacements for peat harvesting also offer incentives to green energy developers.
BNRG is developing the Carrowroe project in partnership with Plan Energy Developments, an independent team of renewable energy experts
A public consultation programme took place in July and discussions are continuing with Longford County Council. The developers have also developed a project website at http://www.bnrgcarrowroe.com.
The website says the project would avoid seasonal flooding, use natural planting as screening and employ low-lying panels positioned to limit visual impact. The developers estimate, with planning permission, the construction could begin in 2028, with the project operational by 2029.
The backers say the project would establish a community benefit fund, with an estimated value of €2.45 million over the project’s lifetime.
This year Longford County Council approved plans by BNRG Ballymahon Ltd for a solar farm on a site across the townlands of Tirlickeen, Cartronbrack, Clogh, Corryena and Lismacmorrough, near Ballymahon.
However, the planning permission has been appealed to An Coimisiún Pleanála. The appeal cites traffic management and visual and residential amenity impacts as well as reflected glare, environmental and archaeological issues.
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YORK — Almost seven years after York County approved a solar project on a former Navy underground fuel store, the site remains overgrown, only partially accessible, and plagued by a host of issues.
The King’s Creek solar farm has been delayed by the complex nature of the site, ground pollution, an interconnection delay, and Dominion parting ways with the contractor, Will McCahill, a project manager told the York County Board of Supervisors on Aug. 18.
The former Navy fuel storage site off Penniman Road to the east of Williamsburg is earmarked for a 20-megawatt solar facility. York County’s Board of Supervisors approved the project in late 2019.
In 2023, Crystal Bright of Dominion Energy told neighbors that construction was scheduled to begin in the first quarter of 2024.
However, minimal work has taken place. Some roads are barely accessible, according to McCahill.
He said Dominion received land disturbance approval in August 2025. Work should begin in March 2027 with “substantial completion in the third quarter of ‘28,” he said.
“Some of the timelines have slipped for this project,” McCahill said.
“There’s large underground storage tanks,” he said. The preliminary plan approved by the board entailed building solar arrays above the subterranean tanks. It has been changed to “mitigate any risk,” McCahill said.
“We don’t want any heavy equipment falling through 100-year-old concrete tanks,” McCahill told the board. “There’s also a lot of open valve pits.” He said the holes will have to be covered or ringed with fences to make sure operators and construction crews remain safe.
McCahill said the site is covered in kudzu and bamboo and needs to be stabilized. “We need to prevent the spread of invasive species within our site.” He said a robust vegetation management plan is required. He said roads will have to be cleared.
The site also suffers from hydrocarbon contamination, McCahill said. “We have done additional diligence on the site and confirmed there are some hydrocarbon-impacted soils,” he said. “We are planning to take additional measures beyond the normal erosion and sediment control to prevent any infiltration of groundwater into our stormwater.”
The project has also been delayed by connection issues. “Approximately a year ago, in coordination with our distribution partners, we identified that we do not have rights to install communication fiber on the distribution line we are connecting to. That line runs through the Navy property,” McCahill said. A real estate permission process will soon begin with the Navy, taking about 18 months. The line will take about six months to complete.
McCahill said Dominion executed the asset purchase agreement in 2021. However, the project is unlikely to be substantially completed until late 2028 or early 2029, according to graphics shown to the board.
He said Dominion ended the original contract due to the issues with the site and the contractor’s performance on other Dominion projects. “We are beginning a new RFP process to identify a new contractor,” he said.
McCahill promised to keep the Board of Supervisors updated on the progress.
David Macaulay, davidmacaulayva@gmail.com
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By: Luis Reyes
Published: Aug 22, at 8:03am ET
Deserts are just about the perfect place to put solar panels. The sun barely takes a day off, land is cheap, and there’s not much standing around to cast a shadow. They’re also the single worst place on the planet to keep anything made of glass clean, and the traditional fix, washing it with water, runs into the obvious problem that you’re in a desert.
The industry calls the dirt problem soiling, and it’s not a rounding error. Annual energy losses from dirty panels run around 7% in parts of the US and can reach 50% in dusty regions like the Middle East, according to the National Renewable Energy Laboratory. After a single dust storm, losses can spike as high as 80%.
So the solar industry did something that sounds like science fiction and is actually just good plumbing-free engineering. It put fleets of autonomous robots on the panel rows themselves. They live up there permanently, wake up after dark, brush the glass dry, and park themselves back at the end of the row to recharge off their own solar panel. No water, no crew, no truck.
Here’s the part that makes desert soiling genuinely nasty. Panels cool down overnight and attract morning dew, and that little bit of moisture reacts with the minerals in the dust sitting on the glass. NREL calls the process cementation, and the name is not a metaphor.
“Once it goes through the cementation process, it can become much more difficult to remove to where even a strong rain won’t remove it,” says Lin Simpson, a senior scientist at NREL who co-led a $6 million Department of Energy research effort into soiling. His prescription is blunt: brush the dust off every day or every other day, before the dew gets to it.
Which immediately kills the traditional approach. A one-time cleaning of a 10-megawatt solar farm costs an estimated $5,000, per NREL. That’s one pass. The dust starts coming back the next morning, and nobody is sending a water truck and a crew into 110-degree heat every 48 hours.
Then there’s the water itself. Large solar plants tend to sit exactly where rain doesn’t, and researchers are literally testing whether a big enough solar farm can manufacture its own rainfall, which tells you how scarce the natural kind is out there. Hauling millions of gallons into that landscape just to rinse glass was never going to scale.
The machines that solved this don’t look like much. Picture a slim gantry that spans a row of panels, rides along the frame edges on small wheels, and carries rotating microfiber cylinders plus a controlled flow of air that pushes dust down and off the bottom edge. No liquid anywhere in the system. Each unit has its own small solar panel on top, so it charges itself during the day and works at night, when the plant isn’t producing and the dew hasn’t formed yet.
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The biggest name in this business is Ecoppia, an Israeli company founded in 2013 that builds several versions of the machine. The T4 is a lightweight unit for single-axis trackers that can cross between neighboring rows over dedicated bridges using onboard sensors. The H4 cleans in a spiral motion the company calls Helix, works in both directions, and covers up to 2 kilometers of panels per robot. The firm says the machines remove about 99% of accumulated dust, and that nothing rigid ever touches the glass, just the microfiber.
If you want the peer-reviewed version of the concept, a team of Italian engineers published the design of an autonomous desert-cleaning robot in the journal Mechatronics: a half-tracked unit with two helical brushes spinning at opposite angles, ultrasonic sensors handling position and speed in real time. Different hardware, same conclusion. In a desert, cleaning has to be waterless, constant, and unmanned, or the math doesn’t work.
One important distinction while we’re here: these are not the same machines as the robot fleet that recently clamped down 100 megawatts of panels in the California desert. Those install. These maintain. The panels get bolted down once and then dusted roughly 10,000 times over their working lives, so if anything, the cleaning robots got the longer contract.
The proving ground was the Middle East. One of the early flagship deployments was Ketura Solar, a 40 MW plant on the Israel-Jordan border jointly owned by EDF Renewable Energy and Arava Power. The site sits in the Arava desert next to dust-heavy farmland, gets hit by regular sandstorms, and sees virtually no rain. If a dry-cleaning robot was going to fail anywhere, it was there.
It didn’t, and the fleet went global. In 2021 the company completed an installation at an AES solar site in California, billed at the time as belonging to the largest private owner of operating solar assets in the US. That matters because California’s Central Valley is one of the places Simpson singles out, where soiling rates run high enough and rain low enough that frequent cleaning pays for itself. A 2023 deal with Matrix Renewables then took the robots to four plants in Spain and Chile, the Spanish sites being the company’s first in that country.
The cumulative numbers are the kind you have to attribute carefully, because they come from the manufacturer. Ecoppia says its fleet operates across more than 35 large-scale sites, has cleaned over 15.7 billion panels to date, and has saved nearly 1.8 billion gallons of water by never using any. Those are company figures, not audited ones. But even discounted generously, that’s a lot of glass wiped by machines nobody supervises.
Two honest footnotes before you conclude the problem is solved. First, soiling varies wildly by location, even within one desert. A year-long study across Chile’s Atacama measured annual energy losses peaking at 39% on the northern coast while high-altitude sites in the same desert lost 3% or less. So the “dust eats a third of your farm” scenario is real, but it’s a worst case with a specific address, not a universal rule.
Second, automated cleaning isn’t automatically harmless. A study by German testing house PI Berlin, reported by PV Tech back in 2015, found some automated cleaning solutions had the potential to damage module performance, though it made no reference to Ecoppia’s system. Ten thousand brush passes over 25 years is a durability question the industry keeps having to answer, which is exactly why the serious players lean so hard on soft microfiber and air instead of anything stiffer.
Still, step back and the picture is hard to argue with. Robots now put the panels in the ground, robots keep them clean for decades, and when the modules finally wear out, a plant in Georgia strips them back down to silver, copper and glass. Somewhere in the middle of all that, a small solar-powered machine finishes its nightly run across a dark field in the Arava, rolls back to its docking station, and starts charging for tomorrow. It’s the one shift in the energy business nobody ever calls in sick for.
What do you think?
Luis Reyes · Jul 28, 2026
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80-90 MW project aims to meet full energy needs, supply surplus to Italy
The Vatican will build a roughly 100 million ($117 million) renewable energy plant that could power the Holy See within two years via a system combining solar power and agriculture, sources involved in discussions on the project said.
The agrivoltaic plant is expected to have a capacity of 80 to 90 megawatts, making it one of Italy's largest such installations, the sources added. In such plants, solar panels are mounted several metres above the ground so crops can grow beneath them, with the shade helping to reduce evaporation and shielding plants from extreme weather.
A joint Italian-Vatican commission met earlier this month to launch the project at the Vatican-owned Santa Maria di Galeria estate on Rome's northwestern outskirts, after Italy ratified a 2025 bilateral agreement for development of the site this year.
Officials disclosed no details of the project's cost, capacity or timeline after the meeting. The sources involved in the discussions said the plant could take 18 to 24 months to complete, including permitting and administrative procedures.
The plant is designed to supply power to Vatican Radio's transmission station and help make Vatican City State fully energy self-sufficient.
The sources said the power could also be used by Holy See-linked properties including Rome's Bambino Gesù hospital. The Vatican will not benefit from the financial incentives available to Italian households and businesses that install solar power. Any surplus electricity would be made available to Italy.
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