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Maker Luke Ditria has once again revisited his Raspberry Pi Zero 2 W-powered bird-spotting wildlife camera project, this time upgrading it with a 3D-printed enclosure and a solar panel with custom-designed photovoltaic HAT add-on for full off-grid operation.
"I started this project last year and I've made a few videos about the previous versions, but I'm back and with some pretty big updates," Ditria says of the project's evolution. "The device is still built around Raspberry Pi's so-called AI Camera, which uses the Sony IMX500 intelligent image sensor. This sensor integrates a camera and a small neural network accelerator into a single chip, letting you run a small neural network model directly on the camera itself to process images at up to 30 frames a second. I've been using this sort of edge-compute AI detection for some time now, primarily for autonomously detecting and identifying wildlife."
The first version of Ditria's autonomous wildlife camera was unveiled a year ago, using a Raspberry Pi 5 single-board computer and the Raspberry Pi AI HAT+ Hailo-based accelerator board to run a custom-trained You Only Look Once (YOLO)-based neural network model designed to recognize around 30 different birds. The first major revision to the project shrunk both the power and space requirements considerably, swapping the Raspberry Pi 5 out for the smaller and cheaper Raspberry Pi Zero 2 W and shifting the neural model to the Raspberry Pi AI Camera's Sony IMX500 image sensor while dropping the solar panel entirely.
The latest version effectively combines the two, using the same Raspberry Pi Zero 2 W and Raspberry Pi AI Camera but with a return to solar charging rather than relying on manual intervention. "[The last version] could operate through daylight hours before being taken back inside to charge," Ditria notes. "Having to collect it and charge it and remember to put it outside every night was annoying." A large solar panel handled the energy harvesting, but off-the-shelf solutions for getting that into a battery and the Raspberry Pi proved inadequate — leading to Ditria and a friend to design their own Hardware Attached on Top (HAT) add-on, the PV Pi.
"It has true maximum power-point tracking [and] battery charging up to a peak of 10A for 12V lithium-iron-phosophate [LiFePO₄] battery packs, which means this caps out at about 140W of charging with sufficient cooling," Ditria says of the PV Pi HAT. "As for the solar input, the PV Pi works with 12V and most 24V solar panels, so it's quite flexible. And, importantly for remote Raspberry Pi projects, it can communicate directly with the Raspberry Pi to report things like battery voltage and charge current, and also has a real-time clock for power scheduling and more."
For the neural network model, Ditria trained it for 52 local species to minimize false positives. "I collected and labeled a bunch of images from online sources," he explains, "and then trained and exported a YOLO-11N [object detection] model. I've also included that bird model in my GitHub repo, that's exported and ready to run on the [Sony] IMX500 camera [module]."
Project source code is available on GitHub under an unspecified open-source license; 3D print files for the enclosure are available on Maker World under the site's Standard Digital File License.
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TAIGUA has installed 1,133 photovoltaic modules at the Can Boada and Can Poal reservoirs in Terrassa, with the aim of covering the electricity consumption of both facilities linked to water supply with its own generation. The project involved an investment of 260,000 euros, financed 50% with European funds managed through PERTE.
The installation, however, introduces two different scales within the same project. While Can Poal will cover its entire annual consumption and have a surplus of 22%, Can Boada, despite concentrating 713 panels and a power exceeding 300 kW, will cover 18% of the annual consumption of a facility that supplies two-thirds of the city.
At the Can Boada reservoir, TAIGUA has installed 713 panels over a surface area of 1,484 square meters. The installation exceeds 300 kW of power and will cover part of the energy demand of a facility that consumes 2,300,000 kW per year.
Pere Mora, manager of TAIGUA, highlighted the project’s significance by recalling that the facility supplies water to two-thirds of Terrassa. In his words, the new modules allow for the internal generation of energy that the company previously had to purchase.
“This facility supplies water to two-thirds of the city, and having these photovoltaic modules allows us to obtain over 300 kW and generate the energy ourselves that we previously had to buy” – Pere Mora, manager of TAIGUA
At Can Poal, on the other hand, the company has installed 420 modules with a total power of 100 kW. This production will cover 100% of the equipment’s annual consumption and, in addition, will leave an energy surplus of 22%.
Mora added that this surplus is intended to supply energy communities in the area. The destination of the surplus expands the scope of an initiative that is not limited to the self-consumption of the infrastructure itself.
The commissioning of the two reservoirs is part of a broader strategy for solar implementation in the city. Terrassa currently ranks third in Catalonia in terms of the number of panels, with around 45,500 modules installed.
This volume of generation allows for a reduction of 6,900 tons of carbon dioxide emissions. TAIGUA’s project is also part of the objectives set by the European Union for 2030, which require a 55% reduction in these emissions.
Jordi Ballart, mayor of Terrassa, linked the action with the municipal energy model and with the application of sustainable energies to public facilities linked to basic services such as water.
“This project is totally aligned with the city model we are working on, applying sustainable energies to municipal facilities, in this case, to the water supply” – Jordi Ballart, mayor of Terrassa
Beyond this action, TAIGUA has already set its next investments. The 2026-2029 Investment Plan foresees an annual allocation of five million euros for actions on the network and service infrastructure.
For 2026, the planned budget amounts to 5,659,911 euros and includes the renovation of the network, the purchase of new electric generators, the application of artificial intelligence in the new software, and the installation of more sensors for active leak detection.
Instances of cracks in PV module glass started appearing about five years ago. Spontaneous glass breakage is now one of the solar industry’s top issues, but manufacturing pressures and a lack of standards are hindering solutions.
Elizabeth Palmiotti uses a scattered light polariscope to measure the stress in PV glass.
Image: NLR
From the magazine
Solar glass is not supposed to break on its own – but increasingly, it does. Since about 2021, scientists, operators, and testing labs have been seeing glass breakage on solar modules with no apparent cause, such as impacts or extreme weather. This novel failure mode has been researched to some extent, but as its scientific name suggests, “spontaneous glass breakages” still occur without warning.
Spontaneous glass breakage in glass-glass modules is the most significant reliability issue affecting modules today, according to Kiwa PVEL. “We are aware of it occurring in multiple countries, with multiple module model types, mounted to multiple tracker/racking solutions,” the lab wrote in its 2025 PV scorecard.
Tristan Erion-Lorico, vice president of sales and marketing at Kiwa PVEL, said the phenomenon is directly related to the industry’s cost-saving efforts.
“Generally speaking, we have thinned the glass, frames, and encapsulant and gone to more aggressive mounting,” Erion-Lorico told pv magazine. “That probably all works on paper, where the ‘perfect module’ should be reliable over the expected lifetime. However, we have eroded the safety margins, and now microscopic defects along the glass edges or surface, improperly placed silicone or frame adhesive, edge pinch, pressure from the busbars, etc., can result in module breakage.”
In the second quarter of 2025, Kiwa PVEL’s mechanical stress sequence testing recorded a historic high, with about one-third of the modules’ glass breaking. In the last quarter of the year, the results got a bit better, with about one-quarter of the samples failing. But those are still unprecedented results in decades of commercial module manufacturing.
“While our test doesn’t provide the same breakage pattern as modules suffering spontaneous breakage in the field, it is a good indication of modules’ mechanical durability,” Erion-Lorico said. “A module that breaks after static mechanical load (SML) or dynamic mechanical load (DML) tests is likely not going to last 30 years in the field.”
New PV modules in power plants are now larger than ever. With glass on both sides representing more than half of a module’s weight, it is not surprising that manufacturers found room to cut costs by reducing its thickness. While previous PV module generations had 3.2 mm glass, current modules usually have around 2.0 mm.
“The shift to thinner glass is driven entirely by the customer. Glass manufacturers have had to invest significantly in new equipment to cater to this changed demand,” said Pradeep Kheruka, chairman of Borosil and Borosil Renewables, an Indian multinational solar glass manufacturer. “Glass manufacturers can safely handle large, thin glass, but as modules are now larger and heavier than in the past, they require specialized installation equipment.”
Kheruka added that responsibility for glass breakage is shared among different actors. “High pressure on the front and back glass from thick soldered joints is one factor that module manufacturers must address, while issues such as improper sealant filling leading to contact between the aluminum frame and the glass, or poorly finished holes in the backsheet, can also contribute,” he explained.
The US National Laboratory of the Rockies (NLR), formerly known as the National Renewable Energy Laboratory (NREL), surveyed potential causes of spontaneous glass breakage in late 2024. A range of contributing factors was identified, including reduced thermal strengthening in thinner modules, microscopic flaws at edges and surfaces, lamination-induced stresses such as edge pinch, increasing module size without corresponding changes to mounting and frames, and contact between the glass and the frame or trapped debris.
For a recent 2026 paper, NLR focused on the first cause and developed a non-destructive method to measure the glass surface directly on finished solar panels. Using this novel method, researchers collected data from numerous mass-produced panels from commercial fields, where glass has spontaneously broken. “We confirm that most 2.0 mm glass in PV modules is fully tempered, however, it remains weaker than traditional 3.2 mm glass. Our results show a clear correlation between lower surface stress and increased susceptibility to spontaneous breakage. This is an important consideration for modules that are supposed to survive in various environments for more than 30 years,” explained NLR module reliability researcher Elizabeth Palmiotti.
Palmiotti added that recent research found that although 2.0 mm glass can meet the threshold for fully tempered glass under certain glass standards, its surface compressive stress is generally lower, and the compressive layer itself is thinner.
“The thickness of this protective layer scales with general thickness. So, 2.0 mm glass inherently has a thinner layer of protection than 3.2 mm glass, meaning the same defect may break a thinner glass but not the thicker one,” she added, explaining it becomes more susceptible to defects caused by edge defects, impacts, and contact with the frame.
Henry Hieslmair, principal engineer for solar at DNV, an independent assurance and risk management provider, said investors are concerned about spontaneous glass breakage. “The general observation is that as safety margins are reduced, smaller and more nuanced factors begin to play a much larger role,” he said. Farid Samara, senior engineer for solar mounting at DNV, added that when projects with thinner glass and large module formats come to his desk, he usually requires a much deeper review of the module. “Module manufacturers often argue that structural testing should be the responsibility of tracker suppliers, while tracker manufacturers make the opposite claim,” he said.
This blame game ultimately points to a deeper issue: a lack of a clear, PV-specific standard for glass.
“There currently is no PV glass specific standard, meaning glass manufacturers and module manufacturers are not reporting their glass properties in any meaningful way,” NLR’s Palmiotti noted. “Having the community align on definitions for glass surface stress would be a huge step.”
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As Europe’s first generations of integrated PV systems age, researchers and industry actors are only beginning to explore the long-term realities of maintenance, compatibility and repair.
Image: Becquerel Institute
Across Europe, the first and second generations of building-integrated photovoltaic (BIPV) systems are now reaching ages where maintenance, refurbishment and component replacement are becoming unavoidable operational questions. At the same time, European policy discussions around circularity and resource efficiency are spotlighting long-term system serviceability. Within several ongoing European research projects, including SPHINX and EVERPV, investigations are underway to better understand the technical, economic and regulatory barriers that currently limit repair and recycling pathways for building-integrated photovoltaics.
In Europe, BIPV using building-integrated PV products such as tiles, shingles, and ventilated facades has been a small but steadily growing segment of the PV market since the early 2000’s. Even if the basic category of products has not fundamentally widened over the past 20 years there have been considerable improvements in technical features and performance, ease of integration and market uptake. First-generation systems with roof mounted BIPV products are approaching the end of their theoretical design life of 20 or 30 years, and larger volumes will enter phases that require curative maintenance in the coming years. Whilst maintenance requirements are more likely to originate from components other than the module or laminate itself, such as cables, junction boxes, and watertightness, the combination of form-factor constraints and specialised support and integration structures means that repair is a distinct challenge.
European standards such as EN 50583 and IEC 63092 explicitly frame BIPV modules as construction products subject to both PV and construction-product requirements, including mechanical resistance, fire safety, watertightness and durability. BIPV systems act as roofs, façades, skylights, shading devices or curtain walls while also generating electricity. This dual functionality changes maintenance logic because a failed BIPV module can trigger a building intervention rather than a simple electrical repair.
A building-applied rooftop module can generally be swapped relatively quickly if a compatible replacement module can still be sourced because conventional rooftop PV has followed the same module technology evolution than the utility-scale and commercial and industria (C&I) PV market, with the main difference being the use of modular racking integration systems. BIPV, however, has simultaneously evolved in a different direction, with a slower PV cell technology adaptation, and bespoke products developed to meet the requirements of a broad range of architectural designs and building typologies, especially in façade applications.
Building long-term compatibility into BIPV products
The central challenge is compatibility. Repairability in of systems using BIPV products is strongly constrained by what can be described as “form-factor lock-in”. Many BIPV products are designed around specific architectural requirements including dimensions, transparency, colour, mounting interfaces, glazing composition and electrical configuration. Once installed, these systems may require near-identical replacement products decades later to maintain both building compliance and aesthetic continuity. European technical approval systems already reflect this issue. In France, for example, ATEC technical approvals are delivered for a very specific combination of module, mounting system, dimensions and implementation conditions, meaning that even moderate design changes can invalidate the original approved configuration, potentially affecting building insurability.
Analysis indicates that warranties from European module and BIPV product manufacturers generally reserve the right to replace failed modules with “equivalent products available at the time of claim”, rather than identical products, implicitly acknowledging that exact continuity cannot be guaranteed over long building lifetimes. For many ageing BIPV systems, the problem is not whether a module still works, but whether a compatible replacement still exists.
How can repair become economically viable?
France installed roughly 300 000 systems using BIPV products, mostly in-roof mounting systems, between 2006 and 2014. A survey of French PV maintainers and repair professionals suggests that the main barriers to repairing systems integrated into buildings are often economic and contractual rather than purely technical. Economic and insurance-related concerns appeared among the most recurrent themes in maintainer responses. Respondents repeatedly cited the high cost of partial repair compared with full repowering, particularly where scaffolding, diagnostics, rewiring and façade intervention are required.
Insurance and warranty continuity also emerged as major concerns. Several maintainers indicated that replacing isolated components can create uncertainty regarding the ten-year mandatory watertightness liability insurance (décennale) on roofs, ATEC system conformity and building insurance coverage after intervention. Others noted that older systems frequently suffer from component obsolescence, making it difficult to source electrically and mechanically compatible replacement modules without redesigning larger parts of the installation.
The survey also highlights barriers that are more specific to systems using integrated PV products, such as in-roof systems, falling under the French definition of BIPV. Multiple respondents reported that building owners often lose confidence in the system’s ability to maintain its building-envelope function after a defect appears, particularly in cases involving water ingress on integrated roofing systems. Waterproofing failures, ageing integration kits and uncertainty regarding long-term performance were repeatedly associated with decisions to replace entire systems rather than repair isolated components.
Maintainers additionally pointed to the absence of structured refurbishment channels and limited availability of replacement components, suggesting that the broader repair ecosystem for BIPV remains underdeveloped. Interestingly, professionals that indicated repairing systems more frequently were also those with more extensive professional PV networks. Together, these findings suggest that improving long-term BIPV repairability will require not only more durable products, but also better compatibility strategies, stronger maintenance networks and clearer insurance and warranty frameworks.
Rethinking warranties and repair pathways
Whilst system owners ultimately decide whether to repair, replace or decommission a failed installation, manufacturers and installers strongly shape the available options. A review of warranty conditions for BIPV products commercialised in southern Europe shows that manufacturers generally retain control over the remedy applied to defective products, deciding whether systems are repaired, replaced or financially compensated. In many cases, warranties cover only the replacement component itself, while excluding or only partially covering labour, transport, access equipment, dismantling or waterproofing restoration. This distinction is critical because, in BIPV, intervention costs are often driven far more by site logistics than by the value of the module itself.
For systems integrated into buildings, replacing the module is sometimes the easiest part of the repair. Replacing a façade- or roof-integrated module can require scaffolding, temporary weather protection, dismantling surrounding building elements, specialised glazing operations and electrical safety procedures to maintain compliance with insurance, safety and building-performance requirements. In some contexts, particularly in France, remuneration schemes linked to BIPV feed-in tariffs restrict the extent to which systems can be modified while retaining tariff eligibility. If compatible replacement products are unavailable, producers may therefore face very limited repair options.
Preliminary techno-economic analyses undertaken in the Horizon Europe SPHINX project indicate that intervention costs of several thousand euros are common even for relatively small systems, particularly where accessibility is difficult. However, robust comparative data on real-world BIPV repair, access and intervention costs remain extremely limited across Europe, particularly for ageing integrated systems.
Current research activities are therefore seeking to better document how labour, access constraints, insurance requirements cost influence repair decisions in practice. Under these conditions, repair rapidly becomes an economic rather than technical question.
Several maintainers interviewed within SPHINX project indicated that scaffolding and waterproofing interventions alone can exceed the residual economic value of continued electricity production for ageing small roof-integrated systems. Where no immediate safety or building-function issues exist, decommissioning or full repowering may therefore become financially more attractive than partial repair.
In practice, the key issue is rarely whether repair is technically possible, but whether any actor is willing to assume the operational, financial and insurance risks associated with carrying it out. Current warranty structures and maintenance practices often prioritise rapid restoration of production and contractual clarity over component-level repair.
Preserving compatibility through digital continuity
Because compatibility over several decades may become one of the main repairability barriers, manufacturers are increasingly exploring digital continuity strategies. For architecturally unique systems, digital archives can preserve dimensions, glazing composition, colour rendering, transparency levels, mounting interfaces and electrical characteristics, allowing replacement products to be reproduced even after the original production line has disappeared. This approach directly addresses one of the main repairability barriers identified in BIPV: the impossibility of sourcing visually and electrically compatible replacements years after installation.
New module architectures for maintainable BIPV products
Innovative module architectures such as matrix shingling may also improve long-term maintainability by reducing dependence on fixed electrical formats. Conventional PV modules and laminates are highly constrained by voltage and current compatibility requirements, making replacement difficult when older cell technologies disappear from the market. Matrix-based shingled architectures introduce greater flexibility in electrical configuration, potentially allowing replacement laminates to reproduce legacy electrical characteristics using newer cells and manufacturing technologies. Such adaptability could help maintain compatibility with existing inverters and strings while avoiding complete system replacement.
Long lifetimes matter
Many first-generation BIPV systems remain structurally functional even when their electrical performance declines or isolated failures occur. Yet without economically viable repair pathways, otherwise serviceable systems risk premature decommissioning and replacement. Repair and reuse may ultimately become just as important as recycling. However, second-life reuse pathways for BIPV remain limited by certification constraints, insurance requirements, the absence of standardised testing procedures for reused modules and the difficulty of guaranteeing long-term building-envelope compliance after reintegration into buildings.
In this context, future European BIPV products may need to be designed not only for efficiency and aesthetics, but also for maintainability, traceability and compatibility with long building life cycles.
The questions surrounding repairability are still emerging, and many of the operational practices, insurance frameworks and refurbishment pathways that may ultimately support long-life integrated PV systems remain under development. Across Europe, manufacturers, maintainers, insurers, researchers and building professionals are beginning to explore how future BIPV systems can better integrate maintainability, digital traceability and long-term service strategies from the design phase onward.
As part of this ongoing work, the Becquerel Institute and project partners are continuing to collect field feedback and operational data from manufacturers, installers and maintenance professionals in order to better quantify repair practices, intervention costs and long-term maintenance pathways for BIPV systems.
These topics will also be discussed during the upcoming EU co-financed SPHINX/FORESI workshop on BIPV repairability and circularity taking place on 16 June in Lyon, France.
Free registration: more information
Authors: Mélodie de l’Epine, Research & Innovation projects, Becquerel Institute & Jose Ma Vega de Seoane, Managing Director, Becquerel Institute España.
Funded by the European Union under Horizon Europe, Grant Agreement No. 101136094 — SPHINX and No. 101122208 – EVERPV. Views and opinions expressed are however those of the author(s) only and do not necessarily reflect those of the European Union or CINEA. Neither the European Union nor the granting authority can be held responsible for them.
Becquerel Institute is a strategic consulting company and applied research institute specialising in solar photovoltaics and energy transition. Founded in Brussels in 2014, with regional offices in France, Italy, and Spain, the company provides strategic advice to companies, public authorities and international organisations, across all segments of the PV value chain. Becquerel Institute is a recognised partner in European and international research programmes.
The views and opinions expressed in this article are the author’s own, and do not necessarily reflect those held by pv magazine.
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Research from Indiana University suggests that concerns over the impact of solar development on US agricultural production are largely exaggerated, with prices for maize, soybeans and wheat expected to increase by less than 5.6% if the build out of utility-scale solar on cropland is consistent with historical patterns.
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Expanding utility-scale solar in the United States is unlikely to compromise food security, according to new research.
Researchers Jerome Dumortier and Rafael M. Almeida, from Indiana University, used a county-level agricultural model to explore how replacing cropland with utility-scale solar farms could affect land allocation, crop prices, agricultural production and farm revenue for major crops across the United States.
A baseline solar expansion scenario found that if 40% of future solar development is placed on cropland, a rate the research paper says is consistent with historical patterns, prices for maize, soybeans and wheat would increase by less than 5.6%. This figure is around a third compared to long-term estimates associated with biofuel production.
Under a large solar expansion scenario which considered the impact if 80% of new solar development occurs on cropland, price increases were calculated at 9.6% and 8.8% for maize and soybeans, increasing to 18.4% for wheat. The differentiation is explained by wheat being located in areas with higher solar potential, the research paper says.
The paper explains that the effects on commodity prices are moderate due to total area of land being substantially larger than the area required for solar farms. “Notably, the scenarios modeled in this analysis are also unlikely since they rely on high shares of cropland replacement to meet future PV deployment targets, and they do not consider siting on pasture, grassland, or marginal cropland,” it adds.
Dumortier told pv magazine that a central goal of the research was to replace speculation with data as debates over where to build solar projects become more heated.
“Much of the public debate around solar development on farmland has been driven by incomplete comparisons. Some estimates reported in the media are comparing the solar land requirements to states the size of New Jersey, Maryland, or even West Virginia, which naturally triggers worries. Although the comparison to states is correct, it needs to be put in relation to the total amount of land available,” Dumortier explained.
“The United States has an enormous agricultural land base, and total cropland area has been declining for decades as productivity gains allow farmers to produce more from less land. Those market effects are leading to a decline crop prices trend in the absence of shifts in either demand or supply.”
Dumortier also said that meeting rising electricity demand with domestically-produced energy, rather than remaining exposed to price swings that come with globally-traded fossil fuels and the geopolitical instability that impacts them, is a matter of both economic and national security interest.
“Solar installations are domestic infrastructure and use fuel that is free and never subject to sanctions. Farmers understand this arithmetic well,” Dumortier said. “For generations, they have supported ethanol policy precisely because converting surplus crop production into fuel creates an additional source of domestic energy demand and supports crop prices in the process. Solar leasing offers a complementary opportunity on the supply side: land that market forces are already pulling out of crop production can generate stable, long-term lease income, diversifying farm revenue without compromising the broader agricultural system.”
“The data should give policymakers and the public alike reason to take a more measured view of a debate that has, until now, had more heat than light,” he added.
The research findings are presented in the research paper “Limited impact of solar energy expansion on agricultural production and crop prices in the United States,” available in the journal Land Use Policy.
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A bill that cleared the New Hampshire Legislature last week would create a framework for residents to be compensated for renewably generated electricity they feed into the grid from home battery systems.
It is a “modest step forward” for New Hampshire’s net metering policies, said Sam Evans-Brown, executive director of Clean Energy New Hampshire, at an April hearing before the Senate Committee on Energy and Natural Resources.
House Bill 1718, from prime sponsor Rep. Michael Vose, an Epping Republican, directs the New Hampshire Department of Energy and Public Utilities Commission to create a framework for crediting electric customers for power they export to the grid from batteries charged by renewable power generators, like solar panels.
The Senate passed the bill on Thursday, following House passage in March. It now heads to Gov. Kelly Ayotte.
“Logically, it makes sense,” Vose said of the bill in a phone call on Tuesday. “… If you can export the kilowatts, it doesn’t really matter whether you export them directly from your solar panels or from a battery, as long as you put those kilowatts in the battery with your solar panels.”
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A limited number of New Hampshire electric customers are already net-metering energy from batteries through a program run by Liberty Utilities. Vose said enshrining the practice in law would eliminate uncertainty.
“The legislation basically removes any doubt from anyone’s mind that if they choose to do this, if they choose to make this investment, that they’ll be able to recover their investment,” he said.
As proposed, the bill calls for the New Hampshire Department of Energy to craft rules to govern how battery systems are installed in customers’ homes and interconnected to the grid. Those rules may include safety requirements or size restrictions, according to the bill’s language. Meanwhile, the rate structure for how residents would be credited for energy from their batteries would be up to the Public Utilities Commission, which the bill says may develop “terms and conditions” for customers to export energy and be compensated.
Batteries eligible to participate in the program must be configured to charge only from on-site renewable generation, except in certain cases that Deana Dennis, director of regulatory affairs for the Community Power Coalition of New Hampshire, called “common sense” exemptions during the April hearing. Those include residential batteries that utilities may manage from offsite at certain times, such as in the lead-up to a severe storm or in preparation to offset demand peaks, she said.
Solar panels typically generate the most energy at midday when the sun is strongest, while demand for electricity in most homes and across the grid peaks in the morning and evening.
Batteries can help make renewably generated energy available at times of peak demand. And because of that, Vose said, they are an important part of making solar power pencil out.
“The only way that solar makes sense is if you can combine it with batteries,” Vose said. The combination of batteries and solar panels helps “ameliorate” the intermittent nature of solar energy, he said. At the April hearing, Evans-Brown made a similar statement, saying more widespread adoption of battery storage would “maximize the value” to the grid of variable distributed generation like solar panels.
Yet batteries are expensive, and that has posed a barrier to their widespread adoption. Industry and government groups estimate that the installation of residential solar batteries lags far behind the adoption of residential solar panel installations in New Hampshire.
A March report from the Solar Energy Industries Association estimated that 6.2% of New Hampshire homes have solar panels installed; Megan Stone, legislative liaison with the New Hampshire Department of Energy, cited data from the U.S. Energy Information Administration showing that 25,467, or 2.9%, of the state’s 878,680 residential electric customers participate in net metering.
Meanwhile, utilities reported far fewer residential batteries on their networks: The utilities Eversource and Unitil reported a combined total of fewer than 1,000 batteries in 2024, according to Stone, though data from Liberty was not included, and Stone noted the total may also exclude some installations that were not reported.
“It does cost more money to combine a battery with your solar system. But it should pay for itself in the long run, just by making the energy more available to yourself, and to the grid when it needs it,” Vose said.
In the past, Vose has criticized expansions to net metering. But he said this policy is not an expansion: The bill does not change the total amount of electricity that customers can get credits for, he said, just the time at which they may export the energy.
And in doing so, he said, it may help users recoup their investments while making solar energy more available to reduce peak load on the electric grid.
“It’s not that complicated,” he said.
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Macro-siting models that protect sensitive habitats and farmland from utility-scale development reduce permitting friction for a mere 0.17% cost premium.
New York solar installation
Image: Commercial Solar Guy
From pv magazine USA
A new geospatial modeling framework demonstrates that utility-scale solar buildouts can avoid critical ecological habitats with a virtually negligible impact on project economics.
The study, “Sustainability trade-offs at the nexus of solar energy, agriculture, and biodiversity,” published in the journal Geography and Sustainability, presents a transferable optimization framework to navigate the increasingly contentious intersections of clean energy deployment, agricultural preservation, and wildlife conservation. Led by researchers from Cornell University, The Nature Conservancy, the U.S. Geological Survey, and Central Michigan University, the team used New York State as a case study to model how competing land-use priorities alter the geography and financials of decarbonization.
The research team used a specialized computer mapping program that evaluates choices in a strict order of importance to analyze the land-use footprint under three distinct deployment strategies, which included minimizing capital costs, prioritizing agricultural preservation, and maximizing biodiversity conservation. Proximity to existing transmission lines, road access, slope, and local soil configurations were integrated to evaluate realistic developer constraints.
To build a rigorous framework, the researchers adopted the most aggressive utility-scale solar development projection from the New York State Energy Research and Development Authority (NYSERDA), which mandates the deployment of 46,216 MWdc of utility-scale solar capacity, a buildout requiring approximately 107,700 acres (43,584 hectares) of land.
The model revealed significant regional trade-offs depending on which stakeholder metric was prioritized. When developers optimize strictly for a least-cost scenario focused on the lowest capital expenditures and shortest interconnection distances, the model disproportionately clusters solar arrays on flat, cleared land, targeting more than 40,000 hectares of pasture and hay fields.
Nearly half of this land directly overlaps with critical grassland bird habitats, creating severe biodiversity conflicts. Conversely, enforcing a strict agricultural preservation scenario successfully spares about 80% of prime farmland, but pushes the solar footprint into alternative open spaces, resulting in the projected deforestation of over 41,000 hectares of timberland.
Finally, prioritizing a biodiversity-conscious scenario that avoids sensitive ecosystems forces the conversion of more pasture, hay fields, and cultivated croplands to fill the capacity deficit.
“There’s land-use conflict associated with solar energy development because there are different people interested in biodiversity, agriculture and energy, but in reality those things are interacting in a nexus,” said Steve Grodsky, the paper’s senior author and assistant professor at Cornell University. “This modeling gives us an opportunity to forecast potential interaction points and potential conflict zones, and allows communities and agencies to make more-informed choices in siting decisions.”
The study’s most significant finding challenges the industry assumption that stringent environmental constraints will derail project economics.
Restricting development on ecologically sensitive lands to prioritize biodiversity increased the annualized total system costs by a mere 0.17%. The finding suggests that smart macro-siting can mitigate local opposition and environmental degradation at an almost imperceptible premium to ratepayers and developers.
For utility-scale solar developers, EPCs, and asset managers, the optimization metrics offer actionable leverage to de-risk pipeline development early in the pre-construction phase. Utilizing dual-criterion macro-siting algorithms allows developers to proactively eliminate high-conflict parcels before submitting interconnection requests, substantially reducing long-term soft costs tied to permitting delays and environmental litigation.
Given that a biodiversity-first approach incurs a system-wide cost penalty of less than two-tenths of a percent, developers can present these optimized spatial configurations to local planning boards as a powerful tool to neutralize “not in my backyard” (NIMBY) resistance, securing faster local zoning approvals without eroding project internal rates of return.
“Traditionally, solar siting has been evaluated through a least-cost objective where the primary goal is to site the energy quickly, cost effectively and ensure reliability,” noted Adam Gallaher, lead author of the study. “What we’ve found is that it is possible, and minimally more expensive, to take into account multiple criteria that can inform just and ecologically responsible energy transitions.”
The authors said the framework can be calibrated by policymakers outside of New York to accommodate regional geographical realities, offering a mathematical pathway to balance multi-functional landscapes during the energy transition.
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RAPID CITY, S.D. (KOTA) – A newly revised alternative energy proposal in Pennington County would separate small-scale solar and wind systems meant to power a home or farm from utility-scale projects designed to feed electricity to the grid.
Under the proposal, homeowners could still install smaller systems, but with added limits, such as prohibiting solar panels or wind systems in residential front yards.
For larger projects, the rules would add new requirements. Developers would need a Conditional Use Permit and would be required to meet a noise limit near homes, along with other standards tied to siting and operations.
Some residents say shifting large-scale projects toward industrial-zoned areas does not automatically address neighborhood impacts—because many industrial zones sit close to Rapid City.
“A lot of the industrial zoning is adjacent to Rapid City,” said Rapid City resident Eileen Peterson. “So my concerns are the setbacks are not adequate… especially the battery storage facilities that have now been added to the ordinance.”
One of the biggest additions in the revised draft is a full set of regulations for Battery Energy Storage Systems, often called BESS. The proposal calls for stricter fire-safety standards, detailed emergency response plans and training, and a decommissioning plan backed by financial guarantees intended to prevent cleanup costs from falling on the county.
Peterson said she’s especially focused on what she sees as inadequate buffer distances if a battery storage facility were to catch fire.
“Right now, I think setbacks are less than one hundred feet or less than three hundred feet,” Peterson said. “If there’s a fire in a battery storage facility that’s not far enough away from schools, let alone residences. So we’re going to try to talk them into that or try to talk them into a moratorium on battery storage altogether.”
Other residents say their biggest question is what happens decades from now, when equipment needs to be removed and land restored.
One resident argued that leasing arrangements could leave communities exposed if companies dissolve or walk away.
“The solar company leases the land for more money than what they could purchase it for. And who would do that?” the resident said. “If you’re a business owner, you’re not going to spend more money on purpose unless there’s a hidden agenda there… We believe those companies would rather lease for more money because… they’re not going to clean the mess up when they’re done. They’re just going to abandon it and it’s going to be our problem.”
The ordinance is expected to face more public comment as county commissioners weigh the updated standards, particularly the new battery storage rules, setback distances, and long-term cleanup responsibility.
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Bluetti has launched the Balco 260 and Balco 500, two integrated balcony PV storage systems combining MPPT, inverter, battery storage and smart control in a plug-and-play architecture for urban households.
Image: Bluetti
Bluetti, a California-based provider of portable solar-plus-storage systems, has launched two new energy storage systems for balcony PV applications.
The Balco 260 and Balco 500 integrate core power electronics—including maximum power point tracking (MPPT) controllers, micro-inverters, battery storage and safety modules—into a unified architecture.
The Balco 260 is positioned as an entry-to-mid-tier unit targeting apartment and small household applications. It features a 2.56 kWh lithium iron phosphate (LFP) battery with integrated heating and supports expansion up to 15 kWh via additional modules. The system provides up to 2,400 W of solar input across four MPPT channels, along with 1,100 W of AC input for charging.
For output, it delivers 1,200 W of AC power for both on-grid and off-grid operation, while a 2,300 W AC bypass enables higher pass-through loads. The unit measures 476 mm × 260 mm × 336.3 mm and weighs 28.5 kg.
The Balco 500 is the higher-capacity model, designed for larger apartments and whole-home backup applications. It is equipped with a 5.02 kWh LFP battery with integrated heating.
At system level, up to three Balco 500 units can be connected in parallel to a home distribution panel, enabling up to 11 kW of output capacity and 15 kWh of storage. On the solar side, the system supports up to 4.36 kW of input within a 70–470 V range via a single MPPT channel, and up to 3.68 kW of AC input.
For output, it offers two operating modes: a balcony plug-and-play mode with up to 800 W output, and a whole-home backup mode enabling up to 3.68 kW bidirectional input/output. The system measures 450 mm × 190 mm × 580 mm and weighs 65 kg.
Both systems use a built-in inverter supporting on-grid and off-grid operation. They are rated IP65 and operate in temperatures ranging from −20 C to 55 C. Smart energy integration is supported via compatibility with BLUETTI, Shelly and Everhome smart meters, with Wi-Fi and Bluetooth connectivity for app-based control and monitoring.
The company provides a 10-year warranty for both products.
The Balco series is complemented by the Balco Transfer Hub, a grid-tied controller that allows existing portable power stations—including Bluetti and third-party devices—to be integrated into balcony PV systems, enabling up to 800 W of grid-compliant output while retaining off-grid functionality.
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Battle lines have been drawn over a massive M4 solar farm – but what happens next?
After a noisy start one month ago, when protesters gathered in Chippenham to mark the beginning of a government examination into plans for a massive solar park in the Wiltshire countryside, most activity has moved behind closed doors.
The preliminary meeting of the Planning Inspectorate’s Lime Down examination opened on April 21, with dozens of local people gathered outside to protest against the proposed development.
Since then, the Planning Inspectorate’s examining authority has begun the formal six-month examination process for the proposed 500-megawatt solar farm north of the M4 near Malmesbury.
The preliminary meeting was followed by the first open floor hearing, where interested parties presented their views to inspectors.
Read more
Battle over huge solar farm begins as protesters meet planning inspectors
Hated plans for solar farm near M4 ‘will not benefit Wiltshire people’
Fight against massive solar park near M4 gets boost
On April 22, the first issue-specific hearing took place, focusing on the project’s scope.
Barrister Joel Semakula appeared for Wiltshire Council, the host authority, which has formally objected to the scheme.
Wiltshire Council was one of nearly 5,000 individuals or bodies that formally objected to the development, citing “significant unresolved concerns” including emissions from construction activities and potential job losses.
The deadline for public comments on written representations is May 22, following which the Examining Authority will publish its first written questions on 1 June, with responses due by 15 June.
A site inspection is scheduled for June 11, and further hearings are scheduled between June 30 and July 3.
A second set of written questions will be issued on July 27, followed by further opportunities to comment in August.
Additional hearings may then be held in September if required, with final submissions due in early October.
Following examination, the examining authority will have three months to write a recommendation report for Secretary of State for Energy Ed Miliband, who will make the final decision.
A final decision is expected in late 2026 or early 2027.
The independent examination, led by the Planning Inspectorate as the Examining Authority, began in April and is expected to continue through to the autumn.
Over this period, the Examining Authority will consider written submissions, hold hearings and ask further questions before making its recommendation.
Cllr Adrian Foster, Wiltshire Council’s cabinet member for strategic planning, development management, and housing, said: “Wiltshire Council is not the decision‑maker on this application, but our officers remain fully engaged throughout the examination, ensuring that the views of our communities and the potential impacts on the county are clearly and robustly represented.”
If granted permission, Lime Down Solar Park would cover 3,000 acres of countryside, with the entire site covering an area four miles wide and two miles deep.
There would be thousands of solar panels, each measuring 4.5 metres – the height of a double-decker bus – with 42 acres dedicated to battery storage containers, inverters, and substations, all behind three-metre-high metal fencing with CCTV.
A 22km (14 mile) cable would connect the site to the National Grid at Melksham, passing under the M4 and the Bristol-to-London railway line.
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The applicant, Island Green Power, says the scheme would provide enough electricity to power 115,000 homes.
Island Green Power is registered in Bermuda and owned by Australian venture capital group Macquarie Asset Management – a former owner of Thames Water.
The constituency MP Roz Savage has criticised the ownership of the applicant, calling the scheme “the wrong scale, in the wrong place, under the wrong kind of ownership.”
In November she said: “Macquarie’s ownership of Thames Water led to soaring debt, crumbling infrastructure, and increased pollution, hardly a reassuring track record.
“To now see the same company fully acquire Island Green Power, with no local accountability or long-term stewardship, is deeply troubling.”
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Norwegian classification society DNV has published two new guidelines covering the structural design of floats for floating solar systems and their mooring and station keeping systems.
Image: Scotra
DNV has released two new guidelines related to floating solar systems. The independent energy expert says the new documents are aimed at improving the safety, reliability and long-term performance of such systems amid the rapid global growth and expansion of renewables.
DNV-ST-C108 covers the structural design of floats for floating PV systems. It defines technical requirements for the structural design and qualification of floating PV float structures and features a design approach that considers the potential consequences of float failure.
The standard includes requirements covering safety classification, design basis, material qualification, structural design, testing and corrosion protection, with emphasis on non‑metallic materials and degradation due to solar irradiation.
DNV-ST-E309 covers principles and methodologies for the design of mooring and station keeping systems for floating PV.
The standard offers guidance on design loads, load combinations and analysis procedures, alongside details on system configurations to reduce the risk of failure across the station keeping system and a related risk assessment.
“Floating solar is moving from niche applications to large-scale infrastructure,” commented Ditlev Engel, CEO, Energy Systems at DNV. “These new standards are designed to help the industry manage risk, improve reliability and enable innovation while maintaining appropriate safety margins.”
DNV’s latest update adds that the two new standards are designed to complement its recommended practice guidelines for solar PV systems, first released in 2021. The company says an update to its original guidance is due this June.
According to analysis by Wood Mackenzie, global floating solar capacity could reach 77 GW by 2033 led by deployments in India, China and Indonesia.
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Aura Power Receives Approval for 25-MW Solar Farm in England, Strengthening UK Clean Energy Pipeline Amid Net-Zero Push SolarQuarter
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Airports Authority Of India Invites Tender For 1.5 MW Rooftop Solar PV Plant O&M At Chennai Airport SolarQuarter
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Under the Sun
Solar generation is expected to reach 78 billion kilowatt-hours in 2026 in the ERCOT grid.
Solar power promises to shine even brighter in Texas this year. A new forecast from the U.S. Energy Information Administration (EIA) indicates that for the first time, annual power generation from utility-scale solar will surpass annual power generation from coal across the territory covered by the Electric Reliability Council of Texas (ERCOT).
Solar generation is expected to reach 78 billion kilowatt-hours in 2026 in the ERCOT grid, compared with 60 billion kilowatt-hours for coal, the EIA forecast says. The ERCOT grid supplies power to about 90 percent of Texas.
“Utility-scale solar generation has been increasing steadily in ERCOT as solar capacity additions help meet rapid electricity demand growth,” the forecast says.
Although natural gas remains the dominant source of electricity generation in ERCOT, accounting for an average 44 percent of electricity generation from 2021 to 2025, solar’s share of the generation mix rose from four percent to 12 percent. During the same period, coal’s share dropped from 19 percent to 13 percent.
EIA predicts about 40 percent of U.S. solar capacity, or 14 billion kilowatt-hours, added in 2026 will come from Texas.
Although EIA expects annual solar generation to exceed annual coal generation in 2026, solar surpassed coal in ERCOT on a monthly basis for the first time in March 2025, when solar generation totaled 4.33 billion kilowatt-hours and coal’s totaled 4.16 billion kilowatt-hours. Solar generation continued to exceed that of coal until August of that year.
“In 2026, we estimate that solar exceeded coal for the first time in March, and we forecast generation from solar installations in ERCOT will continue to exceed that from coal until December, when coal generation exceeds solar,” says EIA. “We expect solar generation to exceed that of coal for every month in 2027 except January and December.”
For 2027, EIA forecasts annual solar generation of 99 billion kilowatt-hours in the ERCOT grid, compared with 66 billion kilowatt-hours of annual coal generation.
In April, ERCOT projected almost 368 billion kilowatt-hours of demand in ERCOT’s territory by 2032. ERCOT’s all-time peak demand hit 85.5 billion kilowatt-hours in August 2023.
“Texas is experiencing exceptional growth and development, which is reshaping how large load demand is identified, verified, and incorporated into long-term planning,” ERCOT President and CEO Pablo Vegas said. “As a result of a changing landscape, we believe this forecast to be higher than expected … load growth.”
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This article first appeared on our sister site, EnergyCapitalHTX.
career hotspot
Austin is a city full of success stories, from small businesses to restaurants, so it should come as no surprise that the city has emerged as the third-best city for starting a career. That's according to a new study from WalletHub.
The ranking was awarded for Austin's high quality of life and its vast opportunities for new college graduates transitioning into the workforce. The study compared 182 U.S. cities based on 25 relevant metrics, like the availability of entry-level jobs, each city's annual job growth rate, workforce diversity, median annual income, housing affordability, and others.
Atlanta and Orlando were the two cities that ranked just slightly higher on the list for early career professionals. Austin claimed the top spot in Texas, and No. 3 spot nationally. Last year, Austin ranked fifth in the U.S.
Austin boasts the best quality of life out of all 182 cities in the report, and the 10th best professional opportunities. Austin also outperforms all other U.S. cities with the highest monthly average starting salaries for early career workers after being adjusted for the city's cost of living. Austin also offers the 15th highest number of entry level jobs per capita, the report said.
In a separate comparison of the cities with the largest share of residents aged 25 to 34, Austin ranked No. 5 nationally.
"In addition, Austin’s median annual household income is the 10th-highest in the nation, providing strong earning potential for those starting a career or a business," the report said. "Austin is also the sixth best city for singles, offering a vibrant social scene alongside strong career opportunities for young professionals."
Early career professionals aren't the only ones that can benefit from a move to Austin. Earlier this year, WalletHub dubbed Austin one of the 10 best U.S. cities for finding a job, citing the city's favorable socioeconomic status and ample job opportunities across all career stages.
Elsewhere in Texas, Dallas ranked as the second-best city in Texas for new grads to start a career and 12th nationally. Additional cities that made it into the top 100 best U.S. cities for early career professionals include Plano (No. 32), Irving (No. 42), Houston (No. 51), Fort Worth (No. 64), Amarillo (No. 73), and San Antonio (No. 85).
The top 10 best cities for starting a career are:
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MADISON, Wis. — The founders of a defunct Waukesha-based solar panel installation company face felony theft charges after allegedly taking thousands of dollars for work they never completed.
Trevor Sumner — the president of Sun Badger Solar, LLC — and his co-founder Kristoper Sipe are each charged with two felony counts of theft by contractor. According to a criminal complaint filed in Dane County, a Fitchburg company signed a contract with Sun Badger in 2022 worth over $98,000 to install solar panels on their roof.
The company paid Sun Badger half of the contract up front, but Sun Badger allegedly never installed the panels. In 2023, when Sun Badger shut down and went to court for its debts, it was found that Sun Badger could not repay the money it owed people.
A Fitchburg couple also entered into an agreement with Sun Badger to install panels on the roof of their home in 2022. According to the complaint, the couple paid $11,417 up front for panels. The couple got through the design stage for the project, but in January 2023 the company allegedly sent a letter saying the work was being delayed because of problems in the company.
The couple tried repeatedly to get their up-front payment back, going so far as to dispute the payment with their bank. That dispute was successful, and the couple were allegedly told that there were about 80 other Dane County residents who had similar issues with Sun Badger.
Fitchburg police subpoenaed Sun Badger’s bank records, allegedly finding that Sipe made monthly transfers of $15,000 from his company’s checking account into his own to pay off credit cards.
Sipe allegedly routed about $17,500 per month from Sun Badger’s checking account to his own persoal checking account to pay for things like liquor, massages and luxury hotel stays.
Sipe and Sumner agreed to a settlement with the Minnesota Attorney General’s Office in 2024 to avoid prosecution for allegedly failing to install promised solar panels and forcing customers to renegotiate interest rates on solar loans. As part of the settlement, Sipe and Sumner were barred from doing business in Minnesota.
Minnesota Attorney General Keith Ellison said Sipe and Sumner previously worked at Able Energy, which allegedly stole $1 million by charging for unfinished work.
Sipe and Sumner were both issued signature bonds earlier this year. A preliminary hearing in the case is set for July 9.
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MADISON, Wis. — As the weather warms up, solar salespeople are once again fanning out across Wisconsin neighborhoods, and consumer advocates s…
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Plug a microwave into a wall outlet. That’s legal. Plug a solar panel into the same outlet, and until 14 months ago, you’d have been breaking the rules in all 50 states. Utah flipped that switch in March 2025, and as of May 15, 2026, four more states have followed.
That’s the real story behind the balcony solar surge, not cheaper panels and not better batteries. A handful of legislators rewrote the definition of “small solar device” so renters and condo owners can finally do what 1.3 million German households now do with a balcony solar panel and a microinverter, according to the German plug-in solar association BVSS.
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Five US states now allow plug-in solar systems without permits or interconnection agreements. Utah, Maryland, Maine, and Virginia cap systems at 1,200W per residential meter. Colorado, the latest to sign, allows up to 1,920W, the highest of any state, per Bright Saver’s legislation tracker. The kits get treated like an appliance, not a power plant.
Maine carves out a second tier: DIY installs cap at 420W, and anything above that requires a licensed electrician and a 30-day utility notice, per pv magazine USA. Plug in, generate, and save $180 to $800 a year on your electric bill, per Solar United Neighbors’ plug-in solar estimate.
The five states with plug-in solar laws signed as of May 15, 2026:
Utah and Maryland are in effect today. Maine, Virginia, and Colorado are signed but not yet active.
Outside those five, you’re still in a legal gray zone. More than 30 states plus the District of Columbia have introduced plug-in solar bills, per Bright Saver’s legislation tracker, though at least seven have failed or stalled. Until your state signs, plugging a panel into a standard outlet may violate your utility’s interconnection rules.
Bright Saver’s pluginsolarusa.com tracker is the cleanest place to check status before you buy. The kits below are the strongest US-shipping options right now, organized by who they fit best.
EcoFlow says STREAM is the first US plug-and-play home solar system designed for apartments and condos in addition to single family homes. As of May 2026, it’s the most polished kit shipping under the new rules. The catch is geography: the STREAM Ultra is only sold and installable in Utah right now, per Utah’s HB 340 restrictions. EcoFlow’s North American business development head Brian Essenmacher told Solar Builder the company expects to expand STREAM’s US availability beyond Utah later in 2026, without committing to specific states yet.
Price: From $1,199
Where to Buy: Ecoflow
The Ultra bundles a 1.92 kWh LFP battery, an integrated microinverter, and four MPPT inputs supporting up to 2,000W of solar. Output to the home is capped at 1,200W AC on a dedicated 15-amp circuit. EcoFlow lists a $1,199 early-bird price (MSRP $1,899) and a 10-year warranty backed by 6,000 cycles to 70 percent capacity.
The standalone STREAM Microinverter goes for $299 early-bird ($599 MSRP) if you already own panels and want grid-tied output without storage. EcoFlow says the system can save up to $385 a year on electricity, though that figure depends on your kWh rate and how much daytime load you actually offset.
CraftStrom is a Houston-based plug-in solar company, founded in 2018, that pitches its system as legal in all 50 states via a zero-export smart meter design, per the brand’s website and LinkedIn profile. CraftStrom built and shipped UL- and NEC-compliant kits ahead of the 2025 to 2026 wave of state legalization laws, per CleanTechnica’s April 2025 coverage, though the brand doesn’t publish a unit count on its site.
Price: $2,031
Where to Buy: Craftstrom
The 800W kit pairs four 200W bifacial semi-flexible panels with two 400W ETL-certified smart inverters (ETL listed to UL 1741 and IEEE 1547 standards, per CraftStrom), a smart power meter, and all cabling for $2,031. CraftStrom estimates up to 1,872 kWh of generation a year and backs the kit with a 10-year warranty. It’s pricier than EcoFlow up front, but it’s the only major US-market kit that doesn’t depend on a 2025 or 2026 state law to operate legally.
The 810W Balcony Solar Kit from US Solar Supplier bundles two Runergy 405W panels (HY-DH108P8B) with an APsystems EZ1 microinverter, a 120V AC power cord, and SunModo SunShield awning-mount racking with 93-inch rails and clamps. It ships from a US distributor in Louisville, KY (with pickup in Houston and Dallas) and runs on the same EZ1 platform Germany’s Steckersolar market has used for years, here in the US-spec EZ1-LV 120V variant. That makes the parts list straightforward to validate against UL 1741 and IEEE 1547 standards.
Price: From $969
Where to Buy: Craftstrom
Pricing is published openly on the product page at $969 on sale, $1,188.50 MSRP (18 percent off as of May 2026). The kit puts out up to 900VA AC at 120V across dual MPPT, and the warranties stack at 15 years product / 30 years performance on the panels (Runergy), 10 years on the inverter (APsystems), and 20 years on the racking (SunModo).
The kit’s appeal is the modular hardware path: start with 810W, then swap or expand panels and rails later without ripping anything out. Storage isn’t built in, and the EZ1 is grid-tied only, so adding a battery means layering on a separate AC-coupled system (like BigBlue’s R800 plus C2500 hub) rather than bolting one onto this kit.
The POWAFREE H1 pairs a 2,560 Wh Cell-Pack 2500 (C2500) battery with BigBlue’s R800 microinverter and Bi-Flex panels, supports 800W of solar input across three MPPTs, and carries an IP67 rating for outdoor use. BigBlue lists the R800 plus C2500 bundle on its US store at $699.99 on sale ($1,399 MSRP), with EU listings in a similar €1,099 to €1,199 range.
Price: From €1,099 (About $1,278)
Where to Buy: BigBlue
The pitch is storage at roughly a third of the cost of an EcoFlow STREAM Ultra. The trade-off is a younger product with less independent testing data than EcoFlow or CraftStrom can show. BigBlue’s user manual rates the H1 for operation from -20°C to 45°C (-4°F to 113°F), with the C2500 carrying an IP65 weather-resistance rating, and the brand pitches plug-and-play install with app control. The H1 doesn’t publish an explicit cycle count, though BigBlue’s broader POWAFREE line cites a 10-year LFP lifespan.
Bluetti’s Balco line debuted in Paris on May 12, 2026, with two flagship products: the Balco 260 (four MPPT channels, 2,400W total PV input) and the Balco 500 (high-voltage MPPT, 4,300W PV input, expandable to 15 kWh and 11 kW output when three units are paralleled). The pitch is whole-home balcony solar, which sounds contradictory until you see the parallel architecture.
Price: TBD
Where to Buy: Bluetti
The third piece of the Balco lineup is the Transfer Hub, a grid-tied controller that takes any portable power station, Bluetti’s own or a third party’s, and turns it into an 800W grid-connected balcony PV system. For renters who already own a Bluetti or a comparable power station, that’s the cheapest way into balcony solar without buying a whole new ecosystem.
Anker’s Solix balcony solar with storage (the RS40P 820W kit and the newer Solarbank 4 E5000 Pro, with 5 kWh of LFP storage expandable to 30 kWh and up to 2,500W output through a professional Wieland install, €1,999 MSRP per Anker EU) is currently EU-only. The Solarbank 4 E5000 Pro opened EU pre-orders on May 12, 2026 with an official market launch of June 12, 2026, per Anker Solix. Anker has confirmed a UK launch once regulations allow, with no US release date announced, per Anker Solix. The Anker SOLIX E10 whole-home backup is shipping in the US, but it’s a backup system, not a balcony plug-in kit.
Jackery’s US lineup includes the Explorer 600 v2 portable power station (640 Wh) and the 2 kW Solar Gazebo (around $12,000 to $15,000, US launch second half of 2026 starting in California). Jackery’s actual balcony product, the HomePower 2000 Ultra, is EU-only and currently ships to the Netherlands and Austria at €1,268 (€2,158 RRP) per Jackery EU, with no announced US release. The Explorer line pairs with portable panels, which sits closer to camping gear than a 24/7 grid-tied install.
GoSun’s 2026 push is the Solar EV Charger and the SolarPanel 100, not a balcony plug-in kit. If you see roundups recommending these brands as balcony solar without the qualifier, treat it as wishful thinking until brand sources confirm a US-market plug-in product.
State legality is the first check. If you’re outside Utah, Maine, Virginia, Colorado, or Maryland, your utility’s interconnection rules still apply, and a plug-in system that backfeeds to the grid may violate them. Bright Saver maintains a current tracker of state bills at their website if yours is in progress.
Building-level rules come next. Some HOAs and condo boards have language banning anything visible from the exterior, though Colorado’s law explicitly overrides HOA bans for plug-in solar. Read your CC&Rs, then write your board before you buy. Landlords in some states must allow plug-in solar with tenant notification, but the rules vary by state.
Electrical capacity is the part most buyers skip. A standard 15-amp circuit can handle a 1,200W kit if nothing else demanding sits on the same line, but a kitchen circuit shared with a microwave or coffee maker can trip. Brands recommend a dedicated 15-amp outlet, ideally on an exterior wall with a clear sightline from the panel to the inverter.
The certifications check is the last gate. Look for UL 1741 listing or an equivalent nationally recognized testing laboratory mark on the microinverter, not just the balcony solar panel itself. That’s the part that interacts with your home wiring, and it’s the spec that state laws lean on when they exempt small systems from interconnection rules.
Balcony solar isn’t a rooftop replacement. An 800W kit will trim $180 to $800 a year off an apartment’s electric bill depending on your location and rate, per Solar United Neighbors’ plug-in solar estimate, not zero it out. The payback math gets interesting after year three, when the kit’s cost is offset by the kWh you didn’t buy from your utility. After year five, most renters are net positive.
For Utah residents, the choice is mostly EcoFlow STREAM today. For buyers outside the five legal states, CraftStrom is the kit that pitches itself as nationally legal via its zero-export design, though always confirm with your utility first. For everyone else, watch your state tracker, confirm your utility’s rules, and bookmark Bluetti’s Balco rollout. The next 18 months will look very different from the past year.
Is balcony solar legal in my state? As of May 15, 2026, five US states allow plug-in balcony solar without permits or interconnection agreements: Utah and Maryland are in effect today, and Maine, Virginia, and Colorado are signed but not yet active. More than 30 other states plus DC have bills in progress, per Bright Saver’s legislation tracker at pluginsolarusa.com. Outside the five legal states, your utility’s interconnection rules still apply, so check with both your state and your utility before plugging in.
Do I need an electrician to install a balcony solar panel? In most cases, no. The kits covered here plug into a standard 120V outlet and are designed for DIY install. Maine is the exception: its law caps DIY installs at 420W, and anything above 420W requires a licensed electrician plus a 30-day utility notice, per pv magazine USA. Brands recommend a dedicated 15-amp outlet, ideally on an exterior wall, to avoid sharing a circuit with high-draw appliances.
What does an 800W balcony solar kit actually cost? Pricing in May 2026 runs from roughly $700 to $2,100 depending on whether storage is included.
BigBlue’s POWAFREE H1 lists at $699.99 on sale ($1,399 MSRP) for the R800 plus C2500 bundle with a 2,560 Wh battery. The US Solar Supplier 810W kit is $969 on sale ($1,188.50 MSRP), grid-tied only. EcoFlow’s STREAM Ultra is $1,199 early-bird ($1,899 MSRP) for the Utah-only kit with storage. CraftStrom’s 800W zero-export kit runs $2,031.
Hi! I wanted to let the team at The Gadgeteer know that there is incorrect information regarding this article.
I work at Bright Saver, and the information + link to our tracker is incorrect. Though recent, 7 states have signed legislation as of today, per our tracker. Also, here is the link to Bright Saver’s tracker. https://www.brightsaver.org/legislation-tracker?srsltid=AfmBOorV6N5tRVgljkhhTG6S15H7uR45JwcOFBTaWex0hj-VB5awukBw
The link used in the article is from pluginsolarusa, different than ours. Our policy team works with the bill drafting and legislation directly, and our tracker reflects that.
I hope we can have this updated as soon as possible! Thanks!
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Kane County is taking a forward-thinking step in climate resilience and public safety with the introduction of a new solar-powered flood warning system, an initiative that blends clean energy with real-time hazard alerts.
Flooding is an increasing concern across the Midwest due to heavier rainfall and more frequent extreme weather events. It is also among the most common and costly natural disasters in the United States. According to FEMA’s FloodSmart website, flooding can occur almost anywhere and causes billions of dollars in damage each year.
According to NOAA and the National Weather Service’s Turn Around Don’t Drown® campaign, more than half of all flood-related drownings occur when a vehicle is driven into hazardous floodwaters. Just 12 inches of rushing water can carry away most cars, and 6 inches of fast-moving water can knock over an adult.
Local projections included in the Kane County Climate Action Implementation Plan indicate the county could experience up to a 30 percent increase in heavy downpours in the coming decades, increasing the risk of flash flooding and hazardous roadway conditions.
To address this challenge, the county secured the Powering Safe Communities grant through a partnership involving ComEd and Metropolitan Mayors Caucus to deploy solar-powered flood warning signs designed to alert drivers when water levels become dangerous. These systems are particularly important because flash floods can develop rapidly, leaving little time for traditional warnings to reach people in harm’s way.
The signs will be installed on Dauberman Road in Kaneville Township at the end of May. This section of roadway has been identified by the Kane County Division of Transportation as an area that has experienced roadway overtopping and flooding during past storm events.
The new warning system relies on a combination of renewable energy and real-time monitoring technology:
The solar flood warning system represents more than a technological upgrade; it reflects a broader strategy within Kane County’s Climate Action Implementation Plan. The county has prioritized:
As climate patterns continue to shift, innovations like solar-powered warning systems could become a model for other communities seeking to protect residents while reducing their environmental footprint.
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Gov. Gavin Newsom proposed funding the Demand Side Grid Support program through this year before moving participants to a separate, utility-run framework. Clean energy groups oppose the plan.
DSGS is one of the United States’ largest consumer demand response programs, and it has grown rapidly since its launch by the California Energy Commission in 2022. During organized test events last July, its aggregated distributed energy resources dispatched more than 539 MW of average output over two hours.
In a February trailer bill, Newsom proposed using funds from an expiring school energy efficiency program to keep DSGS running through the end of 2026. In 2027, the DSGS program would cease to exist as currently structured, though a successor program operated by the California Public Utilities Commission could eventually take its place.
In the meantime, existing DSGS customers would transfer to the ELRP program, which the CPUC launched in 2021 and is now overseen by Pacific Gas & Electric, San Diego Gas & Electric and Southern California Edison — the state’s three largest investor-owned utilities.
Advanced Energy United, one of the signatories on the March 25 letter, said last week that the change would be “a significant setback for the state’s clean energy leadership” and would call into question California’s “commitment to delivering a modern, flexible and affordable energy system.”
A 2025 Brattle Group study commissioned by Tesla and Sunrun, the biggest DSGS participants, said the program could produce up to $206 million in net system savings if allowed to run through 2028.
Brandon Garcia, California director for Advanced Energy United, said in a statement that his group appreciates the proposed 2026 funding but worries about shifting to a utility-run framework.
“We have serious concerns about transferring the program to the CPUC due to the higher administration costs and lower enrollment capacity,” Garcia said.
In an email to Utility Dive, Garcia said DSGS was critical not only for reliability but for addressing what he called an “affordability crisis” in California. The Golden State has one of the highest average retail electricity rates in the country, driven by an array of factors including wildfire mitigation and transmission and distribution infrastructure investment.
Distributed energy resources “have the potential to expand capacity without saddling ratepayers with high infrastructure costs,” he said. “We need to seriously address the affordability crisis, and part of that means modernizing our approach to procuring power.”
DSGS relies heavily on residential battery energy storage systems, whose popularity soared in California after the CPUC reduced net metering compensation for solar-only customers three years ago. About 2% of California customers had onsite batteries last year, and total behind-the-meter storage capacity could double to nearly 4 GW over the next 10 years, according to the Brattle report.
Unlike DSGS, which called upon enrolled assets 16 times during the summer of 2024, ELRP is a “last resort” to be used when the California Independent System Operator declares a grid emergency, CPUC says. Residential participants receive $1/kWh and nonresidential participants receive $2/kWh of incremental load reduction after each event.
Newsom’s latest state budget revision is not the final word on DSGS. California’s fiscal year begins on July 1, and the 2027-28 package is subject to revision until then, according to a “general schedule” published by the California Department of Finance.
Advanced Energy United “hopes to work with the legislature and the Governor’s office to ensure funding in the final budget and stability for the program in 2027-28,” the group said last week.
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Houston is now “firmly established as a location of choice for some of the world's largest hyperscalers,” CenterPoint CEO Jason Wells said in the company’s first-quarter earnings call.
In the first part of a two-phase plan, the grid operator would help match buyers, including data centers and other large loads, with sellers of new generation. States and utilities may seek to lower the procurement target over affordability concerns.
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Capacity offered in the Midcontinent Independent System Operator’s summer auction jumped 3.4%, to 141 GW from 136.3 GW a year ago, partly driven by solar additions.
Houston is now “firmly established as a location of choice for some of the world's largest hyperscalers,” CenterPoint CEO Jason Wells said in the company’s first-quarter earnings call.
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Bryant Parker opens the gate of his trailer in Dunlap, Illinois, and lets his flock out to pasture.
The sheep step out, gingerly at first, then loping as a herd toward green fields. If they notice the rows of solar panels overhead, the 75 lambs and ewes don’t show it. They’re too busy chowing down.
“They like eating grass,” Parker said. “As long as they’ve got good, clean grass in front of them, it don’t matter to them where they’re at.”
The sheep are grazing a 7.1-megawatt solar farm that came online late last year. It covers about 35 acres of what used to be fields of corn and soybeans, and produces enough energy to power about 1,200 homes
Parker, who runs Tin Can Farms with his wife Jessica Parker out of nearby Glasford, brings his sheep to graze at several solar sites around central Illinois. He had been seeking more pasture for his growing herd when he had an idea.
“At the time, solar farms were popping up around our area,” he said, “and I kept looking at them thinking, ‘Man, that’s a lot of grass. There’s something that could be done with that.’”
Parker cold-called solar companies until he found someone willing to let his sheep mow their lawn.
“I am now fattening my lambs using somebody else’s grass, and getting paid in the process,” he said.
Angie Burke, director of operations and maintenance at the Denver-based Pivot Energy, the developer of this site, said Parker’s flock provides a service.
“We want good establishment of vegetation on site to avoid erosion concerns. But then we also don’t want the vegetation to get too high so that it’s shading the solar panels and we’re losing energy production,” Burke said. “Sheep kind of meet in the middle and strike the right balance.”
Community-scale solar farms are booming in Illinois thanks to state incentives. Pivot Energy has developed dozens of similar projects in Illinois and elsewhere, almost all of which combine solar power and farming in a practice called agrivoltaics.
The company signed a lease for at least 20 years, Burke said, agreeing to pay the landowner several times more than they had been earning from corn and soybeans. Faced with rising costs and tanking prices for their products, many farmers and rural landowners are making that trade when renewable energy developers come knocking.
Agrivoltaics could help states meet renewable energy goals while preserving farmland and benefit some small farmers by diversifying their businesses. As of 2024, however, they accounted for less than 5% of the country’s solar power.
The American Solar Grazing Association said at least 113,050 sheep are grazing about 129,000 acres of solar sites across the U.S. Cows can graze around panels, too, but goats have a tendency to climb where they’re not supposed to and chew on wires.
“It was attempted, and I think enough lessons were learned,” said Angie Burke, director of land stewardship at Pivot Energy. “We’ve defaulted back to sheep.”
There are additional costs for solar developers pursuing solar grazing, but Burke said there is a business case for keeping the land agriculturally productive.
“We spend a little more on fencing, maybe burying wires or more time on wire management,” she said, “but then in the long run, we’re saving about 10% to 15% year over year by using sheep instead of mechanical mowing. Yes, these sheep are cute – and they’re effective at doing the job that we’re paying their grazers to do for us.”
Brooke and Chauncey Watson IV also raise sheep and shop them to solar farms with their business Illinois Solar Grazing. With solar expanding in the Midwest, the Watsons encouraged other farmers interested in solar grazing to pitch their services before developers break ground.
“You’re more likely to have success the earlier you get connected with the energy company,” Brooke Watson said. “No one wants to go back and revisit the permitting process, or mess with something once it’s already done.”
While graziers like the Watsons and the Parkers see solar farms as a win-win, the Trump administration has cast renewable energy as a threat to American farmland. Agriculture Secretary Brooke Rollins said last year that the agency “will no longer fund taxpayer dollars for solar panels on productive farmland,” and ended federal loan guarantees for some wind and solar development.
The number of U.S. farms is in decline, and in some rural areas there has been a backlash to solar development. The American Farm Bureau Federation estimates 1.25 million acres of farmland have been converted for solar – less than half of 1% of the country’s farmland, and about as much land as is lost every year to urban sprawl.
While they often compete for the same land, renewable energy and agriculture can also work together. In the Midwest, 70% of solar farms built between 2012 and 2020 were on cropland, but according to the U.S. Department of Agriculture, it had little effect on agriculture in the area.
“It’s no secret that farmers are facing economic challenges right now,” said Bill Bodine, director of business and regulatory affairs for the Illinois Farm Bureau. “If they’re being approached by a developer, they may look at that as an opportunity. Others look at it differently, and nothing forces them to be a part of it.”
Agrivoltaics could reassure rural communities and local regulators that renewables and farms can coexist, said Paul Mwebaze, an economist at the University of Illinois Urbana-Champaign.
“Allocating the whole land to doing solar means taking land away from agriculture. And so agrivoltaics can ease community opposition,” Mwebaze said. “We’ve been attending county hearings, Champaign County public hearings, and that question comes up a lot.”
Grazing sheep between rows of solar panels may be the most efficient form of agrivoltaics – Mwebaze called it “a marriage in heaven” – but he and his colleagues are also studying designs that incorporate crops.
“If you choose the right crops, the right land, agrivoltaics will work,” he said. “It’s not about whether it’s feasible or not, but under what conditions.”
Researchers are studying that question at the University of Illinois and at the University of Arizona, testing taller solar arrays that leave room for crops, but cost more to build. They are breeding short-stature “dwarf” corn that won’t block as much sunlight, and crunching the numbers on vegetables and herbs that benefit from shade under the panels, like spinach and basil.
“This land is all competing for the same sunlight,” said Tim Mies, director of the University of Illinois’ Energy Farm in Urbana. “So what’s the trade-off? How far do you have to space them apart? We have to understand that balance to properly make recommendations and let the community know how they can apply this.”
Bill Bodine of the Illinois Farm Bureau said agrivoltaics will need to be adapted for row crops before the idea can scale in the Midwest.
“I do think there are some challenges for agrivoltaics,” he said. “Are there ways to grow more traditional row crops, things that could be mechanized to cover larger areas? A lot of what’s happening, at least in Illinois, is at a smaller scale and a lot of it is associated with livestock grazing, specifically sheep. So that is a bit of a limited universe.”
Scientists studying agrivoltaic systems in Indiana found they “could play an important role” in producing food and energy in the Corn Belt, but are likely to remain niche without government subsidies because of higher costs.
For farmers who can make it work, however, agrivoltaics can be an opportunity.
The Riggs family has been farming in Champaign County since 1874. Fifth-generation farmers Matt and Darin Riggs have turned the family farm into a laboratory for higher-value products — mainly beer.
“Growing up, my brother and I knew that we would have to add more value to our farm’s products than just selling commodity corn and soybeans,” Matt Riggs said. “We saw that coming.”
They run Riggs Beer Company almost entirely on solar power and grow their own grain. Now they’re waiting on approval for an 18-acre agrivoltaic array next to the beer garden. In between rows of solar panels, the Riggs want to test new cash crops, like berries, lettuce and edamame.
“It’s more labor-intensive, but you can cover down on those costs,” Matt Riggs said. “If the sun stops shining, we’re in trouble for a lot of reasons. And if it is shining, you’re getting paid. I like that math, it’s pretty low risk.”
He can afford to experiment thanks to income from the brewery. Even without that backstop, Riggs said the money solar companies pay to lease farmland is enough to keep some small farmers in business.
“Without these agrivoltaics, we’re going to lose more family farms,” he said. “Every one that I see built as a single-use, I think if that was awarded to the family farm down the road and they built it as a dual-use, we would be making more revenue, keeping it more local, and that family would stay on their farm instead of selling.”
Illinois is one of at least nine states with laws guiding solar development on farmland, from fast-tracking community-scale installations and incentivizing those with agrivoltaics, to requiring developers to set aside money for decommissioning so land isn’t permanently taken out of production. Illinois also joined New York and California in preempting local bans on solar installations, giving the state more control over renewable energy siting.
While there are efforts to roll back some of those laws, rural communities are reaping tax benefits from renewables, said David Loomis, president of Strategic Economic Research, an economic consultant for renewable energy projects across the U.S. based in Bloomington, Illinois.
“The number one benefit to the local community is property tax revenue. If you look at the increase in the assessed value of farmland versus the assessed value of utility-scale solar, it is orders of magnitude higher to the local community,” Loomis said. “Communities have to decide for themselves whether those benefits outweigh the perceived costs of having wind and solar. I live in McClean County. We have more wind turbines than any other county in Illinois. Once you get used to wind or solar in your community, you kind of stop seeing it, like you don’t see telephone poles and cell towers. It’s just part of the landscape.”
Kiersten Sheets develops community solar installations with Trajectory Energy Partners, and serves on the Peoria County Farm Bureau. She said rural America could benefit from solar developers spreading the wealth.
“We need more power sources, and we need clean power sources,” she said. “These really small projects have really high tax revenue for the surrounding community. They’re like little popcorn energy plants — they’re here, there, and everywhere.”
Those “popcorn energy plants” include the solar farm where Bryant Parker is rounding up sheep with the help of his border collie, Pearl. His sheep will graze this land until winter. Some of them will go to market, the rest will return to the Parkers’ farm, and he’ll bring another flock back next spring.
Grazing power plants is not how Parker expected to be farming when he started out, but he said it works for him. In addition to raising sheep, Parker and his wife Jessica grow corn, soybeans and pumpkins. They still have jobs off the farm, too, but Parker said if this business of grazing between solar panels keeps growing, they can focus all of their time on the family farm.
“The way we farm now, it is night and day different than it was 50 years ago. So farming 50 years from now is going to look a lot different,” Parker said, “and I believe this will be part of it.”
Chris Bentley is a producer for Here & Now, where he has produced daily news and features since 2015. Chris came to the show from Chicago.
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Published 12:58 pm Wednesday, May 20, 2026
By Steve Hunter shunter@soundpublishing.com
Crews begin work on a solar installation project at Messiah Lutheran Church in Auburn funded by a state Department of Commerce grant. COURTESY PHOTO, Messiah Lutheran Church
One church in Auburn and another one in Kent will be installing solar panels after receiving grants from the state Department of Commerce.
St. Columba Episcopal Church, 26715 Military Road S., in Kent, and Messiah Lutheran Church, 410 H St., in Auburn, are among the nearly 100 clean energy projects across Washington funded from a $60.4 million investment by Commerce.
St. Columba received a grant of $202,793 while Messiah Lutheran was awarded $432,966, according to a May 19 news release from Commerce.
“These investments demonstrate Commerce’s commitment to moving projects quickly from concept to construction,” said Commerce Interim Director Sarah Clifthorne. “I’m excited we’re helping neighborhoods become more resilient and helping make clean energy more affordable.”
The 96 new awards are in addition to $16.8 million for tribal clean energy awards announced in April. In total, Commerce has invested $77.2 million in 118 community clean energy projects this spring.
The awards are from several Commerce programs: Clean Energy Grants, Clean Energy Siting and Permitting, Thermal Energy Networks, Clean Energy Technical Assistance and the Washington Grid Resilience Program.
The two churches are part of the Clean Energy Grants program. Commerce awarded $34.8 million to 57 projects in 33 counties supporting solar installations, battery energy storage systems, microgrids, biomass facilities and renewable hydrogen technologies.
Many projects will provide backup power for community facilities such as schools, emergency centers and fire districts, while reducing greenhouse gas emissions, according to Commerce. The program streamlines access to funding by combining multiple state funding sources into a single application.
Funding for these projects comes from the U.S. Department of Energy’s Grid Resilience State and Tribal Formula Grants Program, State Building Construction Account and from Washington’s Climate Commitment Act (CCA). The CCA reinvests cap-and-invest dollars that reduce climate pollution, create jobs and improve public health. Information about the CCA is available at climate.wa.gov.
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AMEA Power, one of the fastest growing renewable energy companies in the region, announced the successful commissioning of its 120 MWp solar PV plant in South Africa. This milestone positions the 120MW solar PV plant, as the first project under Bid Window 6 of the Renewable Energy Independent Power Producer Procurement Programme (REIPPPP) to reach commercial operations, underscoring AMEA Power’s proven execution capability and leadership in delivering large-scale, renewable energy projects.
Located near the town of Klerksdorp in South Africa’s North West Province, the Doornhoek Solar PV Project will generate approximately 325GWh of clean electricity annually, supplying power to an estimated 97,000 households and offsetting more than 330,000 tonnes of carbon emissions each year.
The US$120 million facility has officially reached commercial operation under AMEA Power as an IPP, in partnership with Ziyanda Energy and Dzimuzwo Energy, both wholly owned by African women.This partnership reflects AMEA Power’s continued commitment to inclusive economic participation and meaningful transformation within South Africa’s energy sector.
Hussain Al Nowais, Chairman of AMEA Power, commented: “Reaching completion of our 120MW solar PV project in South Africa, is a significant milestone for AMEA Power and a meaningful contribution to South Africa’s energy transition objectives. As the first project under Bid Window 6 to reach this stage, it demonstrates what can be achieved through strong collaboration between government, financiers, and the private sector in delivering nationally prioritised infrastructure.
South Africa is a key market for AMEA Power, where we are proud to have an established local office serving the wider Southern African region. This project reflects our long-term commitment to the country and our ability to deliver complex utility-scale renewable energy projects with discipline, precision, and speed. It is now feeding reliable, clean electricity to the grid, strengthening energy security, and supporting tangible socio-economic development in local communities.”
The project was financed through US$100 million (approximately ZAR1.8 billion) in debt provided by Standard Bank South Africa, alongside US$8 million (approximately ZAR150 million) in equity funding from the Industrial Development Corporation (IDC) to support the participation of local partners.
In line with AMEA Power’s Community Investment and Development Program, the company has implemented a range of initiatives designed to support educational philanthropic initatives, skills development for vulnerable groups such as youth and the elderly, supporting local Non Profit Organisations “NPOs” with social enterprise and cohesion initatives; these initiatives will contribute towards the long-term socio-economic growth within the surrounding communities. In addition six schools, four Early Childhood Development “ECD” centres and fiftenn local NPOs are beneficaires of AMEA Power’s educational initativatives.
At peak construction, the project employed approximately 1,050 people, contributing towards job creation in Klerksdorp and the surrounding areas. In addition, the project contributed to the upliftment of local businesses.
The successful delivery of the 120MW solar PV project marks AMEA Power’s first operational asset in South Africa and reinforces the company’s growing footprint across the African continent, where it continues to play a pivotal role in accelerating the energy transition. Furthermore, AMEA Power was awarded two additional projects through Bid Window 2 of the Battery Energy Storage Independent Power Producers Procurement Programme (BESIPPPP) in South Africa. Both projects are located in the North West Province, and will each have a capacity of more than 300MWh.
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The best portable power stations keep you online and charged up when you need it most. Pack one along for a weekend at the campground, use one to keep the refrigerator running during a power outage, or carry one into the backyard for an outdoor movie night. They can also serve as a cleaner and quieter generator alternative. Plus, you can safely use a portable power station inside your home.
I talked with three experts and tested models from top brands to uncover the six best portable power stations. Our top pick, the Jackery Explorer 1000 V2 combines ease of use with all-around solid performance. If you’re looking for a budget model, consider the Bluetti Elite 30 V2. It’s best suited for shorter outages or for keeping smaller devices charged up. We also found models that are great for quick recharging, using with solar panels, taking to the campground, as a home backup, and for heavy-duty situations like a job site or DIY home projects.
Best overall: Jackery Explorer 1000 V2 – See at Amazon
Best budget Bluetti Elite 30 V2 – See at Amazon
Best home backup: Anker Solix F3800 – See at Amazon
Fastest recharging: Anker Solix C2000 Gen 2 – See at Amazon
Best for camping: Bluetti AC180 – See at Amazon
Best heavy-duty: Goal Zero Yeti 1500 – See at Amazon
This ultraportable generator can reach a full charge within an hour and supports solar charging with optional add-on solar panels. It weighs just 23 pounds and can support one to three days of minor off-grid activity, such as powering small appliances and charging phones and laptops.
Specifics
Reliable power with an easy-to-carry design. The Jackery Explorer 1000 V2 can power up devices on the go. The 24-pound device has a compact footprint that’s easy to carry, thanks to a foldable handle that lets you carry it with one hand, unlike models with built-in side handles, which tend to be easiest to carry with both hands. In our testing, it was one of the best performers in actual power output relative to stated power output, achieving 90% efficiency. When stress-tested, the Jackery 1000 V2 powered a space heater for 42 minutes that pulled 1,376W. This high-draw test is useful for stress testing high-wattage, but in the real world,the Jackery Explorer 1000 V2 can recharge smaller items like your phone, wireless earbuds, portable speaker, and your laptop. If your phone supports 15W charging, the Jackery 1000 V2 will take about 29 hours to recharge. If you plan to use it during a power outage, it’ll keep a 200W refrigerator operating for close to four hours.
Various port options and a built-in light. The Jackery power station has three standard AC ports, two USB-C ports, and one USB-A port. That should give most people plenty of recharging versatility. One of the USB-C ports can output a hefty 100W, ideal for charging laptops. The unit can handle a sustained output of 1500W, making it capable of powering up numerous devices at once. During a power outage, it could power a table lamp and a CPAP machine, and recharge a phone for about a day if sleeping for eight hours, using a lamp for 10 hours, and recharging the phone twice. The built-in LED light is useful during a power outage or to illuminate a dark campsite. The power drawn from using the light is negligible, so there’s no worry about using it as you desire.
Recharging options are plentiful and can maximize battery health. It’s easy to plug the Jackery into a wall outlet for standard AC charging. In our testing, the Jackery Explorer 1000 V2 charged back to 100% in about 80 minutes. From the app, you can also choose a fast, emergency recharge option that gets back to full charge in about one hour. The feature is useful in situations that require a quick charge, but Jackery doesn’t recommend using it regularly since it can damage the battery with long-term use. The app also has a slower recharging option that focuses on keeping sound to a minimum.
If you’re on a budget or don’t need massive amounts of power, the Bluetti Elite 30 V2 has a compact design and great port options. It’s easy to carry around, and we also like the range of colorway options.
Specifics
Reliable portable power station under $500. At full price, the Bluetti Elite 30 V2 sells for $299 (and it’s often on sale for as low as $220), and it offers a great value-to-power ratio. In our testing, it ran a small 458W space heater for about 30 minutes. Bluetti claims it has a 10-millisecond uninterrupted power supply (UPS), meaning it’ll take over in 10 milliseconds or less if grid power cuts, giving uninterrupted power to a WiFi router or a desktop computer.
Emergency power supply that’s easy to carry around with plenty of ports. Those using a portable power station for home backup can make use of the Bluetti Elite 30 V2’s compact and lightweight design. Since it weighs under 10 pounds, it’s easy to move from room to room. The dual AC ports, dual high-wattage USB-C, and dual USB-A ports offer a great variety, given its lower price point and small physical size. I also appreciate that Bluetti made this model in a range of colorways. Instead of offering the standard black option, the Elite 30 V2 comes in fun colorways like blue, green, and purple. If you plan to use a power station in a kids’ room during an outage or while camping, this could be a fun element.
Best for light use or short power interruptions. The Bluetti Elite 30 V2 is ideal for a short weekend away or for locations that don’t typically experience prolonged power outages. Take it camping for the weekend, and you can recharge a phone about a dozen times when pulling 15W per charge. If you’re hoping for whole-home backup or plan to use heavy-draw appliances during an outage, like an air fryer or espresso machine, and keep the refrigerator running, you’ll likely want a larger battery capacity.
The Anker Solix F3800 Portable Power Station combines power capacity and versatility with future expandability and solar charging potential. It’s an excellent option to have on hand for power outages.
Specifics
Big power for when the house goes offline. In our testing, the Anker Solix F3800 produced 3,300 Wh of AC power and offers an impressive 14 ports and outlets. For those who live in an area where the power goes out often, the Solix F3800 provides reassurance that the refrigerated and frozen food won’t spoil and that you’ll be able to keep phones charged and use the coffee maker come morning.
It’s powerful enough to keep many appliances juiced up at once. Our tester plugged in a mini fridge, a fan, and a light into the fully charged Solix F3800, drawing a combined 170W for 20 hours before the battery ran out. In another instance, that battery power would keep a CPAP machine running for about 55 hours. Connect the Solix F3800 with up to 2,400W of solar input, and you get a powerful solar generator for home backup.
If you want to use as a whole-home backup, you’ll need to purchase a power panel to connect the F3800 to your home’s electrical system.
Port versatility is plentiful. The Solix F3800 falls into the category of a portable power station, but it’s only barely portable. At 132 pounds, it’s a chore to get it up stairs, but Anker added heavy-duty wheels and a telescoping handle that makes it easy to roll on a level surface.
Given its larger size, Anker took advantage of the space to add plentiful ports. It has six standard AC outlets (all grounded three-prong), a NEMA L14-30R AC outlet (typical for dryers), a NEMA 14-50 AC outlet (useful for RVs and EVs), three USB-C, two USB-A, and a car socket outlet. Our tester also noted the convenience of not needing to use a 240-volt adapter when powering up heavy appliances like an oven, dryer, or EV charging. The Solix F3800 can handle those directly in their appropriate outlets.
If the goal is whole-home backup, but you lack the space to store the Solix F3800, consider the EcoFlow Delta 3 Ultra Plus. It offers slightly less battery capacity at 3,072Wh, but it’s also significantly smaller and easier to stash away when not in use. If you’re shopping for a portable power station for an apartment, the EcoFlow might be a better fit.
Read our Anker Solix F3800 review.
The Anker Solix C2000 Gen 2 offers about 2,000Wh in a relatively compact and portable unit. Its quick recharge speed of about 80 minutes has made this my go-to model for everything from camping to power outages.
Specifics
A powerhouse ratio of battery capacity vs. size. The Anker Solix C2000 Gen 2 has a stated capacity of 2,048Wh with very comparable dimensions to the Solix C1000 Gen 2, which has exactly half the power of the C2000 Gen 2. After testing dozens of portable power stations over the years, the Anker Solix C2000 Gen 2 is my go-to unit because of its power-to-size ratio. It’s not the lightest model, weighing almost 42 pounds, but I find it portable enough to carry around the house or lift into my car’s trunk. Smaller and lighter models exist, but I prefer to overestimate my power needs rather than fall short.
The medium-sized power station I gravitate toward most. When I take the Solix C2000 Gen 2 on a two-night camping trip, I use it to recharge two phones once a day, the portable projector I use for movie nights, and an electric kettle. If the menu plan calls for it, I’ll even pack along the air fryer. I’ve never come close to running out of battery on the Solix C2000 Gen 2. I suspect I could easily stretch this power to work for a three-night trip.
Speedy recharging given its capacity. With over 2,000Wh, the Solix C2000 Gen 2 offers impressive charging times of about 80 minutes with a standard wall AC adapter. Anker claims that connecting the unit to 800W of solar input will fully charge in about three hours if the panels are capable of pulling 100% power potential. It’s also able to recharge with a gas generator, the car alternator, and a car’s cigarette port. This versatility and speedy times are ideal for those who require quick turnaround between uses.
Quiet enough for use at night. Despite its power output, the Anker Solix C2000 Gen 2 remained quiet during testing. Anker states it gets to about 30 decibels when powering 1,000W. Our space heater pulled about 1,350W, and the noise level from the C2000 Gen 2 was barely noticeable. The fan gets louder during recharging, which is standard with almost all power stations. If desired, the Anker app allows you to choose a slower charging mode, which lowers fan noise.
The Bluetti AC180 is camping-friendly and off-grid friendly because it’s portable at about 35 pounds and also capable of recharging with up to 500W of solar input in under three hours. In addition to numerous port options, it also features a wireless charging pad.
Specifics
Solar power ready. Especially relevant when camping, the Bluetti AC180 is ready to recharge via up to 500W of solar panel power. After purchasing the solar panel, connect it to the station,and set the panel(s) in the sun during the day. Come back in about three hours to a fully charged Bluetti AC180. Connecting solar panels to the power station is as easy as plugging in a phone to recharge, and you can monitor the recharging percentage from the Bluetti app. It also supports dual recharging at the same time. When plugged into standard AC wall power and 500W of solar panels, the station can get a full charge in under two hours.
The wireless charging pad is great for campsite hangs. Uniquely, the Bluetti AC180 features a wireless charging pad on top, freeing up the onboard USB-C port for recharging another device. Set your phone down when cooking dinner or telling campfire stories, and it’ll recharge at 15W.
Manageable in both weight and price. Clocking in at about 35 pounds, the Bluetti AC180 is fairly easy to carry around, and the side handles add to its portability. It’s chunkier than a few of its competitors, but it’s still a reasonable size given the battery capacity. If you’re looking for a portable power station under $500, this Bluetti is one to consider. It’s comparable in price to my top pick, the Jackery Explorer 1000 V2, but with slightly more battery and solar capacity and a wireless charging pad, though it’s heavier and slower to recharge.
Unique among portable power stations, the Goal Zero Yeti 1500 features water resistance, making it an ideal model for working in the yard, taking to the jobsite, or camping in wet weather.
Specifics
Water-resistant exterior with port covers. Not many portable power stations can handle getting wet, which is one of the reasons we recommend the Goal Zero Yeti 1500 for those who need a rugged power station. It carries an IPX4 rating, indicating the device can withstand splashes or light rain. It’s not suitable for use in a downpour or submerged in water. Goal Zero states, “Always keep the port doors fully closed when outdoors, and we strongly advise against operating live loads in rain, heavy moisture, or other wet conditions due to the risk of electrical shock.” While you won’t be able to set it in a mud puddle at the campground, it comes with the reassurance that a light drizzle won’t deem it unusable.
Efficient power for the worksite. When testing for the best portable power station, we measured the stated battery capacity against the actual battery capacity. The Goal Zero Yeti 1500 scored an impressive 91% efficiency, the most accurate stated power that we tested in this round. It ran a Vornado AVH10 space heater for about 62 minutes while pulling about 1,350W.
High surge power and solar input. Goal Zero got serious about versatility and power with the Yeti 1500. It has four USB-C ports, one of which supports 140W for higher-powered devices like laptops, and four AC ports. Its 3,600W surge power makes it ideal for powering up heavier appliances. In addition, it can handle up to 900W of solar recharging.
Battery capacity, measured in watt-hours (Wh), tells you how much energy the power station can store. The higher the Wh number, the longer it can run your devices. As a rough estimate, divide the station’s usable watt-hours by the watts your device uses. A 1,000Wh station running a 100W device may last around 8 to 10 hours after efficiency losses. The price of portable power stations increases with Wh. Determining what you want to power with the station and how long you’d like it to last can help you choose the best portable power station for your needs.
A small and lightweight portable power station, under 500Wh, is ideal for keeping small devices charged up, like a phone, tablet, or a side lamp. David Dodgen, an emergency preparedness expert and founder at AquaStorage, recommends power stations between 500Wh and 1,000Wh for short-term emergencies like power outages that last a handful of hours. Larger capacities are ideal for whole-home backup, off-grid living, or camping trips that span several days.
Each power station will list its overall capacity in Wh and its power output in Watts (W). Capacity tells you how long the battery lasts. Output indicates what it can power. A phone needs very little output, about 20W or less, while a microwave, space heater, fridge, or power tool needs much more. Some appliances also have a brief startup surge. That burst is called surge wattage. A power station may run a fridge once it’s on, but still fail if it can’t handle the fridge’s startup surge.
Matching your desired ports to the port selection on a power station is another major consideration. Smaller stations might only contain USB-A, USB-C, and a car port. Larger models incorporate AC outlets, and many stations over 2,000Wh include outlets for higher-power appliances like NEMA L14-30R AC outlets for dryers and NEMA 14-50 AC outlets, which are useful for RVs and charging EVs.
Nearly all come with versatile charging options, including standard wall AC recharging and solar panels. Some smaller models don’t have solar compatibility and instead use a USB-C, like your phone charger, or a car accessory socket to recharge. Despite its convenience, solar power is almost always slower than AC wall recharging. Some models come with a quick-recharging option found in the app, which can get the power station back to full juice quicker, but it’s not recommended for use with every recharge, as it can negatively impact the battery’s lifespan.
If you’re looking for a portable power station for camping, solar recharging might be a priority. A fast-charging power station like the Anker Solix C2000 Gen 2 might be more important if you’ll be using it in emergency situations.
Power stations can get heavy, so look for models that come with handles. If you plan to camp or travel with a power station, it should be easy to carry since you’ll load it from the house into the car and then to the campsite. Portable power stations for home backup can get not only heavy but also large. Models that reach 3,000Wh and beyond tend to come with wheels and a telescoping handle, similar to what you’d find on a suitcase. Keep weight and added portability in mind when buying, especially if you’ll need to carry the station up and down stairs or over distances.
Opting for a portable power station that can function as a solar generator is a big advantage. Instead of requiring grid power, solar compatibility lets you recharge via solar panels whenever there’s sunlight. Alexis Abramson, dean at Columbia Climate School, also explains that using solar power to recharge produces zero direct emissions while functioning as a self-renewing energy system. “After purchase, sunlight is free — making it a low ongoing-cost solution,” she said.
Each portable power station will come with a maximum solar input, listed in watts. The higher the solar input wattage, the quicker it’ll recharge the power station. “This matters enormously if you’re relying on it daily or recovering after a cloudy stretch,” explained Abramson.
Buying a portable power station bundled with a solar panel can sometimes be a cheaper option compared to buying the two separately. However, adding solar panels later is always an option.
Unlike standard gas generators, portable power stations are a quieter alternative. Many models can run a lamp, recharge a phone, or operate a CPAP machine while staying under about 30 decibels. The main noise source of a portable power station is its internal fan, which helps keep the unit cool. Power stations tend to get louder when recharging or operating at their surge output level.
Expansion ability is helpful if you’re sure how much power you want or if you want to add more power and functionality down the line. Some larger models also allow you to connect to your home’s power system for backup during outages or to tap into an existing solar panel setup.
One of the main criteria to consider before buying a portable power station is determining your power needs. These days, portable power stations can get quite compact, fitting into a backpack to keep phones charged up during a day at the beach. They can also weigh well over 100 pounds and come with wheels and a telescoping handle to roll around.
Here’s a quick guide to help determine your power needs:
I put each model through real-world testing to get a clearer picture of how it performs. James Brains also contributed to testing insights.
To get a more accurate view of usability, I tested each portable power station as if we’d be using it during a camping trip or during a power outage. I recharged my phone, headphones, and laptop with each unit. I also ran a space heater and a fan, and powered the refrigerator with models powerful enough to handle those appliances.
To test battery performance and calculate efficiency — how much of each power station’s listed capacity was actually available to power devices — I ran a 1500W space heater in conjunction with a Kill-A-Watt meter to get an accurate estimate of the battery’s capacity. The space heater consistently pulled about 1350W throughout the testing. I then compared the actual battery capacity as measured by the Kill-A-Watt meter to the listed battery capacity provided by the brand. Since factors such as unit temperature, environmental temperature, and previous battery use can alter its efficiency, I repeated the test three times to get an average. It’s worth noting that I used a high-draw space heater to drain the battery quickly and for stress testing. In general, portable power stations, especially smaller models, aren’t well-suited for this use.
I ran each power station down to 0% battery and then timed its recharging time with standard AC power. I repeated this test three times to get an average, since the unit’s temperature, as well as ambient temperature, affects recharging time. Many models support quick-charge mode, which is often activated in the app. That’s useful if a storm arrives unexpectedly or if you realize the station isn’t fully charged when packing for camping.
Before testing each power station, I noted any challenges with initial setup and app connectivity. I also carried each station around the house, up the stairs, and around the yard to get an accurate view of how portable each station feels. If the unit had wheels, I took it around on flat surfaces inside, on grass, and on loose gravel to note how it performed. I also took note of the on-board display and controls, making sure it felt user-friendly and easy to understand.
As I tested each portable power station, I observed its build quality, handle durability, and noted features that made it more appropriate for outdoor use. I considered elements such as rubber feet, wheels, telescoping handles, and protective shields for the ports.
Batteries can get hot, so I monitored temperature via the app during my space heater test and during recharging. I also observed the noise level during operation and recharging, since the internal fan can get noisy. The Goal Zero Yeti 1500 was the only model that was notably louder than other models, but its internal temperature remained the coolest, which could be optimal if using outside in warmer weather.
Lauren Allain, contributor: I’ve been using portable power stations for several years and testing them for over a year. I take frequent camping trips and spend time at a cabin that tends to lose power for weeks in wind/rain storms and experiences rolling blackouts in extreme heat waves. I also pack a portable power station when I visit my parents’ house, which has 1950s wiring, seemingly one outlet per room, and zero three-prong outlets in most rooms.
When writing this guide for the best portable power stations, I consulted with three experts. Kristina Zagame, a Senior Home Energy Researcher at EnergySage; Alexis Abramson, dean at Columbia Climate School; and David Dodgen, an emergency preparedness expert and founder at AquaStorage.
Runtime depends on both the size of the power station and the amount of power your device draws. As a rough estimate, divide the power station’s watt-hours by the device’s watts. Heat-producing appliances like space heaters, kettles, coffee makers, and hair dryers drain batteries much faster than phones, laptops, lamps, or routers. Smaller power stations are useful for recharging phones and laptops or running fans while larger capacity designs can power a refrigerator during emergencies, and some models are even designed to work as a whole-home backup.
While we used a space heater to stress-test each battery, high-draw items like heaters, hair dryers, microwaves, kettles, and other heat-producing appliances are among the least efficient to run on a portable power station. They can drain even large models quickly. If you must use these items, do use for short periods, not continuously.
No battery lasts forever. Over time, battery cells in a portable power station will become less efficient. Modern portable power stations are equipped with long-lasting lithium-iron phosphate battery cells. You’ll see this abbreviated to both LFP and LiFePO4. Power station manufacturers state how long each battery should last before it begins to deteriorate. Modern-day models with LiFePO4 battery technology can last for 3,000 to 4,000 cycles or more before they’ll only recharge to about 80% of their original capacity. One cycle is running the battery from 100% charged down to 0%. That’s over eight years of using one cycle per day.
To get the longest lifespan out of a portable power station, check with the manufacturer for storage recommendations. When not in regular use, some brands recommend keeping the station charged at 100%, while others say something in a lower range is ideal.
Portable power stations can be well worth the investment for plenty of people. They’re useful for any off-grid situation, like camping or during power outages. They’re also useful when working away from grid power, like in a backyard or at a worksite.
Portable power stations can keep phones and other communication devices charged up. Those who sleep with a CPAP machine or use other medical devices can find a portable power station a necessity during a power outage. Larger stations can also keep the refrigerator running, preventing food spoilage.
With a large power station setup and solar panels, it’s possible to live off-grid entirely.
Most portable power stations are compatible with solar panels for recharging. Before buying, check the exact wattage a power station can accept and if it uses a standard connector or if you will need to purchase an adapter. The higher the solar input, the faster it’ll be to recharge. Be cautious not to go over the unit’s stated solar input. Doing so can harm the station. Abramson warns, “If your panel pushes too much voltage into it, you can permanently fry the device.”
You can mix and match solar panel brands with portable power stations brands. For example, you could use an Anker solar panel to recharge an EcoFlow power station. But keep in mind solar panel ports vary by brand and you might need to purchase an adapter.
You might prefer a portable power station over a generator if noise is a concern. While generators tend to be loud, portable power stations can operate at levels under 30 decibels. You can also safely use portable power stations inside. They also produce fewer emissions. Abramson said, “A gas generator burns fossil fuels, releasing CO2 into the environment, contributing to climate change. Gas generators also can emit carbon monoxide, nitrogen oxides, and unburned hydrocarbons, which can also be concerning.”
Zagame also points out that generators need regular maintenance and rely on fuel sources that might not be available in an emergency. Portable power paired with solar recharging could be a more reliable option during an emergency.
Portable power stations come with their own requirements, though, and you’ll want to keep them dry and away from damp conditions. It’s also important to give a power station clearance near the fans to ensure they’re able to keep the battery as cool as possible. Always use a power station within the manufacturer’s listed wattage limit and check on storage recommendations.
Our story to portable generators versus power stations compares the use cases of both.
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The new system takes advantage of sunrise and sunset to better balance daily electricity demand.
SINN Power GmbH has launched a project that could redefine solar power generation: the world’s first vertically installed floating photovoltaic plant. The new system was unveiled during an institutional event that demonstrated its potential in a practical way, combining energy efficiency, environmental sustainability, and economic viability.
The installation was built in Starnberg, where the company installed 2,500 vertically arranged solar panels. The system has a capacity of 1.87 megawatts and partially supplies power to a nearby industrial facility, according to multiple reports. Because the panels are mounted vertically, they can generate electricity during sunrise and sunset, extending the useful hours of daily energy production.
To maintain structural stability, the system uses a technology known as Skipp-Float, which functions like a keel beneath the water to provide resistance against wind and waves. Thanks to this design, the risk of damage is reduced and the lifespan of the modules is extended. The system also helps reduce energy intermittency by capturing solar radiation at different times throughout the day.
In the Northern Hemisphere, traditional solar panels are typically oriented toward the south and concentrate most of their energy production around midday, when electricity demand is often lower. In contrast, vertical bifacial panels generate power in both the morning and late afternoon using their east- and west-facing sides. This creates a more evenly distributed energy output throughout the day and reduces the need for battery storage.
Installing solar panels on water does more than save space. The lake reflects light onto the underside of the bifacial modules, increasing energy production through the albedo effect. In addition, the water and natural airflow help cool the panels, preventing overheating, improving efficiency, and extending their operational lifespan.
Vertical structures on water must withstand strong winds, so each platform includes a 5.2-foot keel that improves stability. The panels also use flexible cables that absorb and redistribute wind forces, allowing slight movement without damaging the installation.
Vertical floating solar panel technology requires a significant upfront investment due to the use of corrosion-resistant materials and waterproof components. Although the system is designed to minimize environmental impact, researchers are still studying its long-term effects on lake ecosystems.
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PV-SMaRT field-testing equipment monitoring underground soil moisture at a New York PV facility. Photo from Scott McArt, Cornell University
The Photovoltaic Stormwater Management Research and Testing (PV-SMaRT) project is developing and disseminating research-based, PV-specific tools and best practices for stormwater management and water quality at ground-mounted PV sites.
To achieve PV-SMaRT’s goal, NLR is partnering with the University of Minnesota, Great Plains Institute, and Fresh Energy.
Many jurisdictions treat ground-mounted PV facilities as predominantly impervious surfaces or surfaces that do not allow water to soak into the ground. However, rather than acting like a paved surface, rainwater can generally infiltrate under elevated PV arrays.
Because current stormwater runoff models used by local and state jurisdictions were not designed for ground-mounted PV, the stormwater permitting process can impose costly additional stormwater infrastructure requirements. Often, additional land must be leased or purchased for stormwater mitigation measures, such as detention ponds. The permitting process also often lacks accuracy and leaves unanswered questions for jurisdictions when they attempt to evaluate applications for risks and opportunities associated with ground-mounted PV facilities.
Through its research and analysis, the PV-SMaRT project aims to address the stormwater and water quality challenges facing PV facilities in most jurisdictions.
PV-SMaRT’s research and modeling highlight four factors that should be considered in stormwater management and water quality permitting for PV arrays (in order of greatest impact):
Compaction—managing soil compaction and bulk density across the site
Soil depth—including soil depth (rooting depth) in stormwater modeling and design
Ground cover—installing, establishing, and maintaining appropriate vegetated ground cover between and under the arrays to facilitate infiltration
Disconnection—ensuring appropriate distance between arrays for infiltration.
These factors are drawn from the report Best Practices: Photovoltaic Stormwater Management Research and Testing (PV-SMaRT), published by the Great Plains Institute, a PV-SMaRT partner.
PV-SMaRT has developed an easy-to-use calculator to estimate stormwater runoff from ground-mounted PV arrays. This calculator is based on research and hydrologic modeling conducted at a set of research sites featuring diverse climatic, topographic, and soil conditions, with either fixed or tracking solar arrays, and vegetation that included pollinators, grass, or cover crops.
Climatic and hydrologic field measurements at each site were used to develop a two-dimensional numerical model for stormwater runoff based on specific combinations of a wide range in 24-hour design storms, soil textures, crop rooting depth, soil bulk densities, presence or absence of solar arrays, spacing of solar arrays, type of ground cover, and slope steepness values.
To learn how to use the calculator, watch this recording of a webinar hosted by Fresh Energy.
The PV-SMaRT project is using five ground-mounted PV sites in the United States to study stormwater infiltration and runoff. These sites represent a range of elevations, slopes, soil types, and geographical locations. The unique conditions at each site are being characterized, and measurements are being taken of soil infiltration, runoff, site vegetation density, speciation and rooting depth, precipitation, and drip edge runoff.
Minnesota’s site has a 3.4-megawatt (MW) DC, fixed-mount, two-in-portrait PV array. It has sandy soil with a pollinator mix dominated by black-eyed Susan daisies and receives 37 in. of annual rainfall. Equipment was installed in June 2020 and will operate for 2 years.
New York’s site has an 18-MW DC, fixed-mount, two-in-portrait PV array. It has silt loam soil with a tall grass and clover mix, is ungrazed or grazed by sheep, and receives 49 in. of annual rainfall. Equipment was installed in June 2020 and will operate for 2 years.
Oregon’s site has a 9.9-MW DC, tracking, two-in-portrait PV array. It’s a flat site with clay soil, a diverse pollinator seed mix, and 16 in. of annual rainfall. Equipment was installed in August 2020 and will operate for 2 years.
Colorado’s site has a 1-MW DC, tracking, one-in-portrait PV array. It has clay soil and pollinator-friendly vegetation and receives 16 in. of annual rainfall. Equipment was installed in September 2020 and will operate for 2 years.
Georgia’s site has a 1.3-MW DC, tracking, one-in-portrait PV array. It’s a flat site with sandy clay soil, mowed cover crops, a high-diversity pollinator mix, and 49 in. of annual rainfall. Equipment was installed in September 2020 and will operate for 2 years.
The PV-SMaRT water quality task force works closely with the project team to provide feedback and guidance on the technical analysis, modeling, validation, and creation of water quality best practices. The task force is made up of individuals who represent a variety of views and stakeholder groups, including water quality experts, stormwater professionals, and solar industry representatives. Task force members understand the landscape of technical, strategic, permitting, and ground-mounted PV site development issues to meeting water quality goals.
Task force members include:
Measuring and Modeling Soil Moisture and Runoff at Solar Farms Using a Disconnected Impervious Surface Approach, Vadose Zone Journal (2024)
Best Practices: Photovoltaic Stormwater Management Research and Testing (PV-SMaRT), Great Plains Institute Report (2023)
Creating Water Quality Value in Ground-Mounted Solar Photovoltaic Sites, International Erosion Control Association News Story (2022)
PV-SMaRT: Potential Stormwater Barriers and Opportunities, Great Plains Institute (2021)
InSPIRE: Innovative Solar Practices Integrated With Rural Economies and Ecosystems Website, OpenEI
James McCall
Energy and Environment Analyst
[email protected]
303-275-3759
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Last Updated May 7, 2026
The National Laboratory of the Rockies is a national laboratory of the U.S. Department of Energy, Office of Critical Minerals and Energy Innovation, operated under Contract No. DE-AC36-08GO28308.
Emilio Padoan, left, FITT’s vice president of operations, shows Gov. Mike Braun around the Anderson factory Friday afternoon.
The Herald Bulletin
Emilio Padoan, left, FITT’s vice president of operations, shows Gov. Mike Braun around the Anderson factory Friday afternoon.
ANDERSON — Since it opened in Anderson, FITT USA has continued to expand its local operations, and executives recently announced plans to install solar panels at the facility.
Gov. Mike Braun, along with Anderson Mayor Thomas Broderick Jr. and Madison County Commissioner Olivia Pratt, toured the facility last Friday.
The Italian company that owns FITT USA has invested $30 million in the Anderson facility, which was built on a former General Motors property along Raible Avenue. Sixty people are employed at the facility.
The company plans an $8.2 million expansion that would employ an additional 30 people with a starting salary of $21.71 per hour.
The company is currently designing an 8,000-square-foot expansion that will be used to store product for distribution in the spring.
“I think it’s a success story,” Braun said. “They have room to expand and the fact that Italian companies are interested in coming to Madison and Delaware counties is important. There is an effort to do that and I think it’s a great connection. They made quality products, and I’ve learned a little more about the hose business.”
Braun said the company is planning to cover the entire roof of the facility with solar panels.
“They said there would be a three- to four-year payback in doing it,” Braun said.
Emilio Padoan, FITT USA vice president of operations, said the company which manufactures garden hoses is expected to sell $110 million worth of product in 2027.
The Anderson facility is the only one operating in the United States.
FITT USA purchased the property in 2023 for $200,000 from the RACER Trust, which was formed to sell former GM properties on brownfield sites in Anderson and across 14 states.
The company produces a variety of plastic hoses and has sold $50 million in products to companies in the United States. FITT USA plans to add as many as 90 jobs in Anderson by 2027.
The company receives raw material for its products from Anderson-based Sirmax, which is also located on a former GM property.
Follow Ken de la Bastide on Twitter @KendelaBastide, or call 765-640-4863.
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Producing polysilicon in Europe remains challenging due to its energy-intensive, ultra-high-purity nature and the cost advantages of established Asian supply chains. However, Dutch startup Resilicon argues Europe can still make polysilicon by leveraging innovation and policy support. The company’s CEO, Remco Rijn, tells pv magazine how polysilicon factories could compete through cheap renewable energy supply and diversification.
Render of Resilicon’s polysilicon plant
Image: Resilicon
Producing polysilicon for the photovoltaic industry in Europe remains a major industrial challenge, as its manufacture relies on highly energy-intensive, ultra-high-purity processes that require consistently low-cost and reliable electricity as well as deeply integrated chemical supply chains – advantages that are already firmly established and significantly more cost-competitive in regions such as China than within the European industrial landscape.
Despite these difficulties, the CEO of Dutch startup Resilicon, Remco Rijn, is confident that Europe can still establish a competitive and strategically important foothold in polysilicon production by leveraging low-carbon electricity, advances in process efficiency, and a more circular, localized supply chain model. He argues that, while Europe may struggle to match existing cost structures in Asia, it can instead differentiate through cleaner production methods and supply security aligned with the continent’s broader energy transition and industrial resilience goals.
Resilicon is planning to build a polysilicon factory within the Groningen Sea Ports area of northeastern Netherlands. For this project, it already secured over €14 million ($16.3 million) in funding and the support of the Dutch government.
“We started with a small team and we secured some funding to do what we call the first basic engineering. And we are now almost the end of this phase,” Rijn told pv magazine. “We are aiming to produce what is known as 11N or 12N purity silicon, which means a purite of 99.999999999% and 99.9999999999%, respectively. We are going to use the Siemens process and buy almost all production equipment in Europe.”
Diversification
Resilicon is targeting three key markets: the semiconductor industry, the solar PV industry, and the silane market, which also serves fast-growing applications such battery anodes. PV is expected to remain the dominant outlet for polysilicon, as is already the case across the industry, but the company plans to adopt a more flexible product strategy.
“By diversifying our product mix, we can adjust output between polysilicon, silane, and other specialty gases depending on market demand, particularly to better serve the semiconductor industry,” the company’s strategic advisor Jan Vesseur said. “Nevertheless, a substantial share of our volumes will still be directed to solar PV applications.”
The startup is currently targeting around 13 kilotons of annual production capacity, with plans to scale up to approximately 26 kilotons. In industry terms, 13 kilotons corresponds to roughly 6–7 GW of solar capacity, using the rule of thumb that about 2 kilotons of polysilicon are required per gigawatt. “At full commercial scale, we are ultimately aiming for around 30,000 metric tons of annual production capacity,” Vesseur added.
Pressure on prices
At present, polysilicon prices remain highly volatile, with Chinese producers driving extremely low price levels, often at a loss, in what is widely seen as an unsustainable market situation. Despite reports of plant closures, significant overcapacity persists and the industry remains stuck in a cycle of oversupply, with no clear short-term resolution in sight. In this environment, competing on cost alone is neither realistic nor strategically viable for new entrants in Europe.
“Rather than competing purely on price, the focus is shifting toward higher-value segments of the market,” Rijn said. “Demand for high-grade, premium polysilicon is growing, particularly for advanced solar applications and semiconductor use. This is the segment where we aim to position ourselves, alongside established players such as Wacker Chemie. We are already in discussions with customers specifically seeking this premium material.”
With polysilicon prices currently hovering around $5/kg, Rijn argues that this level does not reflect a stable market equilibrium, but rather a distortion driven by global overcapacity and aggressive pricing strategies that are not sustainable in the long term.
“If you look at the United States, where import tariffs have been introduced, prices can reach as high as around $26/kg,” he added. “This shows that even relatively simple policy measures can help create a more level playing field for companies. With such a framework in place, businesses could operate competitively under comparable conditions.”
“It also raises an important question,” he continued. “What would be the actual impact of a higher input cost, such as $26/kg, on the final price of solar panels? From a macroeconomic perspective, this creates a clear win-win dynamic. End consumers may see a modest temporary increase in solar panel prices, but this can be offset over time through innovation and scale.”
Cheap power
A key element of the company’s strategy is the use of renewable electricity, particularly from offshore wind farms in the North Sea. The expectation is that wind power prices will fall significantly over time as new capacity comes online. This is particularly relevant toward 2029, when additional projects from auctions, as well as UK-linked supply, are expected to increase surplus electricity.
“Today, energy costs remain a challenge, and grid expansion is still needed. However, as wind and solar build-out progresses, prices should decline and create structural benefits for electrification across sectors, including household appliances,” Vesseur said. “Lower energy prices could accelerate demand for electric devices and broader electrification trends in homes and industry. This reinforces the long-term logic of locating energy-intensive production close to renewable sources.”
The same dynamic could support industrial relocation to regions with abundant green power, such as Spain. “If successful, our project may also expand to other European countries in the future,” Rijn said. “Our concept links low-energy silicon production with renewable energy ecosystems, aiming to produce silicon and silane using clean electricity at scale, and this approach could be replicated elsewhere.”
Policy
Both Rija and Vesseur argue that establishing polysilicon production in Europe depends fundamentally on a stable and coherent policy framework. In their view, silicon should be formally recognized as a strategically critical material under EU industrial and raw materials strategies.
They stress that a predictable regulatory environment is essential to unlock financing, as current uncertainty significantly deters large-scale investment. The fragmented implementation of existing frameworks, including instruments such as the NZIA, is seen as insufficient to support investor confidence, leading to project delays or cancellations.
“To make European production viable, we need temporary protective measures such as tariffs or equivalent trade instruments to create a level playing field with low-cost global competitors,” Rijn said. “Targeted public support, including grants and demand-side incentives, is necessary to bridge the initial market ramp-up phase.”
Both interviewees also converge on the view that policymakers face a trade-off between short-term cost increases and long-term industrial sovereignty. They argue that, without coordinated policy support, Europe risks missing the opportunity to rebuild capacity in a strategically important sector.
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Australia is world-leading in solar adoption, with one in 3 homes equipped with a rooftop solar system. Ongoing volatility in fuel and energy prices is prompting Australian households to rethink how they power their homes and vehicles, with solar emerging as a way to buffer against rising costs.
Image: pv magazine Australia/AI Generated
Australia’s solar capacity has grown so rapidly that we now generate more midday solar power than the grid can comfortably absorb. And not all households have the option to install solar. To address these two issues the Australian Government is introducing Solar Sharer.
It will offer a daily period of free electricity for millions of Australians – but do they even know about the scheme? If they’re eligible? And what do they think about this opportunity?
Solar Sharer will be available from July 2026 in South East Queensland, New South Wales (NSW) and South Australia (SA).
Energy retailers will offer households with a smart meter the option to receive three hours of free electricity in the middle of the day – when solar generation peaks – irrespective of whether they have a rooftop solar system or not.
Solar Sharer could help overcome issues with excess midday solar production and make the benefits of solar more accessible to the wider Australian population. But the scheme can only work if Australians actively opt in and shift their electricity use.
This is unlikely to happen unless Australians are aware of the scheme, know exactly how it will work, trust the key stakeholders (government and electricity retailers) and see the scheme as benefiting them.
Less than three months before the intended rollout, we know little about whether people are aware of the scheme; what they think about it; their intended engagement with it; and if they are even in a position to shift their electricity use into the free window.
As part of our ongoing research, we have conducted a survey to answer those questions.
Despite millions of Australians becoming eligible for Solar Sharer from July, knowledge about it is limited. At the time of the survey (March 2026), less than half of the people surveyed had heard of the scheme.
People living in states where the scheme will be introduced in July didn’t show higher levels of awareness of the scheme. So, when it comes to informing people about Solar Sharer, there is a lot more work to be done.
Surveyed Australians generally see benefits in Solar Sharer but were unsure about actively opting in and shifting their electricity use.
While people were primarily attracted to the cost-saving potential, to a lesser extent, some also recognised the environmental benefits, increased equity of benefits from solar rooftop systems and potential to ease strain on the electricity grid.
The concerns raised about the scheme focused mostly on implementation issues, including its availability only in some states, the need to opt in, operating hours, a lack of information about the scheme, concerns to be locked into the scheme and prices going up during other usage periods.
While many Australian are excited about Solar Sharer, we also found some significant limited to shifting electricity use to midday:
While many Australians are excited about Solar Sharer, we also found some significiant limitations to shifting electricity use to midday:
From this first insight into our Solar Sharer data, it is clear that while Australians are open to the scheme, many are currently unaware of it and there is limited knowledge on how they can benefit.
How the government will pitch Solar Sharer and inform the public about the specifics of the scheme will determine its success.
Read more on Solar Sharer from the authors in Nature Energy.
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Authors: Dr Anna Zinn and Professor Sara Dolnicar are behavioural scientists at The University of Queensland Business School.
The views and opinions expressed in this article are the author’s own, and do not necessarily reflect those held by pv magazine.
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Despite funding winter, Stride attracts investors in Southeast Asia's top solar hub
Solar panels on rooftops are drawing attention as Vietnam faces power shortages and rising electricity demand. (Stride)
HO CHI MINH CITY — Vietnamese solar startup Stride said it raised $15 million from investors including an affiliate of United Overseas Bank (UOB), defying a funding winter as the country pushes solar power to cope with energy shocks linked to tensions in the Middle East.
Villagers and a council have vowed to oppose plans to create a 80-acre solar farm on scenic land near the River Wye.
The proposed 30MW farm could be built either side of the B4399 through Dinedor, southeast of Hereford, in Herefordshire.
Applicant's ILOS New Energy UK were told by the county council in April it did not need a full environmental impact assessment (EIA) to proceed with the scheme, which is not guaranteed for development, ILOS said.
Dinedor Parish Council said a full EIA should be required, given the proposal "involves a major land-take of productive farmland" and had "understated the heritage and archaeological sensitivity of the area" and its closeness to the river.
The authority added the scheme would also "intensify traffic hazards" on the "already constrained" B4399.
Local residents have formed the Dinedor Village Action Group to oppose the scheme progressing further.
"Everyone's quite upset about it," group spokesperson Matthew Parkin said.
"As a settlement, Dinedor has always been dotted around, and the solar farm would effectively be in the middle of the village."
His own objection pointed out the scheme's elevated position in the landscape would also "be very visible from across the Wye valley, from Woolhope, Hampton Bishop and beyond".
The group plans to hold a meeting at the village hall, on 27 May at 19:00 BST, to determine how to progress its campaign.
An ILOS New Energy UK spokesperson added: "It's early days and it's not guaranteed that we will take that site forward."
This news was gathered by the Local Democracy Reporting Service which covers councils and other public service organisations.
Follow BBC Hereford & Worcester on BBC Sounds, Facebook, X and Instagram.
Panels will be installed across greenbelt land at Owlers Farm, between Ossett and Kirkhamgate.
Residents of the Durham village bemoan a Planning Inspectorate decision to allow a huge solar farm.
One director, who has just bought 2,000 panels, hopes to safeguard the company's future bills.
There are plans to install solar panels on the roofs of buildings at Lady Victoria Colliery at Newtongrange.
The plan prompted 150 objections by local residents who raised concerns for the environment.
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The Hands-On Photovoltaic Experience (HOPE) Workshop will be held July 12–17, 2026.
The HOPE Workshop is designed to strengthen photovoltaic (PV) research at universities in the United States. HOPE is designed for graduate student participants, with participation from the faculty members overseeing each student’s dissertation.
HOPE provides opportunities for professors and graduate students to:
The HOPE program offers students expertise in a variety of PV-related characterization techniques, including secondary ion mass spectrometry, time-resolved photoluminescence, X-ray and ultraviolet photoelectron spectroscopy, and scanning probe techniques.
In previous years, HOPE students learned about the fabrication of Si, III-V, CdTe, and perovskite solar cells as well as quantum efficiency and current-voltage characterization of these cells. Participants also gained valuable insight surrounding commercialization and entrepreneurship while learning about PV module fabrication and characterization, and outdoor testing of photovoltaic modules.
The program agenda will include a track for learning aspects of PV modules at the system level, including performance, reliability, and grid considerations.
For more details, check out this Hands-On PV Experience Workshop YouTube video.
HOPE is aimed at doctoral students pursuing PV-related research in the U.S. who would like to learn more about fabrication, measurement, and study of photovoltaic materials and devices, while connecting with NLR’s staff and other students and faculty in this research space.
Participants do not need to be U.S. citizens but must be enrolled in a doctoral program in the U.S. NLR cannot accept students from foreign universities, students pursuing a master’s degree only, or postdoctoral researchers. While we accept students at any point during their doctoral research, the program tends to be most beneficial to students toward the middle (second–fourth year). To ensure a small-group experience and close interactions with NLR staff , we are unable to accept all applicants but encourage application in a second year for those who are not accepted on their first application, the previous year.
HOPE 2026 will be held in person at NLR and Colorado School of Mines July 12 to July 17, 2026. HOPE requires students to pay for travel from their graduate institution to Golden, Colorado; for housing at Colorado School of Mines (CSM) and dinners not provided by the program. The cost of housing at CSM for the 2026 workshop has not been finalized. However, for reference, the cost of housing from Sunday night through Saturday morning, with breakfast at CSM each morning, was $505 during the 2025 workshop.
Faculty are required to contribute to HOPE through either an in-person activity during the workshop week or a local outreach activity at their home institution. Proposed activities are submitted and agreed upon in the application. While agenda slots for faculty-led sessions are limited, we encourage faculty to join us onsite, attend most sessions, and take advantage of opportunities to engage with NLR staff and explore potential collaborations.
The application deadline for HOPE 2026 is March 13, 2026.
Apply now by submitting a student application.
All applications must include a professor application.
Strong applicants will show evidence of:
The workshop is sponsored by the U.S. Department of Energy Solar Energy Technologies Office.
The workshop content changes year to year depending on the interests of the participants; however, the schedule for the 2024 HOPE Workshop offers a sense of the workshop’s usual content.
Interested in current-voltage and quantum efficiency measurements on solar cells? View slides from Colorado State University’s Jim Sites, who presented a tutorial on solar cell measurements.
Spectral mismatch between lamps used for testing photovoltaic cells and the actual solar spectrum can lead to measurement errors if they are not corrected for. Students at the 2017 Hands-On Photovoltaics Experience Workshop at NLR learned how to do proper spectral mismatch corrections when testing photovoltaic cells, and then made the video below to explain the technique. Watch this video to learn how to implement spectral mismatch corrections in your own lab.
Want to learn the basics of some of the leading PV technologies? The other videos below are lectures from NLR scientists on various technology areas.
Spectral Mismatch: Students at the 2017 Hands-On Photovoltaics Experience Workshop at NLR learned how to do proper spectral mismatch corrections when testing photovoltaic cells, and then made a video to explain the technique.
Silicon PV: Paul Stradins gives an overview of how solar cells work, and then gets into the fundamentals of silicon photovoltaics, the market-leading technology.
III-V Multijunctions: Myles Steiner explains how III-V and multijunction solar cells work. These devices are the basis for the highest efficiency photovoltaics.
Hybrid Perovskites: Joe Berry discusses the exciting new field of hybrid perovskite photovoltaics, which have emerged recently as a leading contender for widespread PV deployment.
Cadmium Telluride PV: Matt Reese discusses the history and recent developments in cadmium telluride thin film solar cells.
For more information, contact Silvana Ovaitt at [email protected].
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Last Updated April 20, 2026
The National Laboratory of the Rockies is a national laboratory of the U.S. Department of Energy, Office of Critical Minerals and Energy Innovation, operated under Contract No. DE-AC36-08GO28308.
First Solar Inc. shares have been volatile in 2026, with the solar specialist recently drawing attention after a strategic partnership and notable price swings. What is driving the stock, and how does the business model generate revenue?
First Solar Inc. has been back in the spotlight in recent weeks as the solar technology specialist’s share price swung sharply and the company announced a new strategic partnership. According to Investing.com as of 05/14/2026, First Solar stock surged about 6.7% in one session after the group unveiled a strategic collaboration with GameChange Solar aimed at combining its thin?film modules with GameChange’s tracker systems for utility?scale projects.
Market performance has been choppy. First Solar shares were trading at around 261.23 USD at the beginning of 2026 and recently changed hands near 221–238 USD, implying a double?digit percentage decline year to date, based on data from MarketBeat as of 05/19/2026. This combination of partnership news and volatility keeps the stock on the radar of many investors following the US renewable energy sector.
As of: 21.05.2026
By the editorial team – specialized in equity coverage.
First Solar Inc. is a US?based solar technology company that designs and manufactures thin?film photovoltaic modules using cadmium telluride (CdTe) semiconductor technology, according to company information summarized by MarketBeat as of 05/19/2026. Unlike many rivals that rely on crystalline silicon, First Solar’s CdTe platform is designed specifically for large, utility?scale power plants, where land availability and system design can be optimized for this technology.
The company’s business model spans the development, manufacturing, and sale of these modules to project developers, utilities, and independent power producers. First Solar positions itself as a provider of both components and integrated solar power solutions, meaning it can support customers not only with panels but also with system?level engineering and performance optimization. This helps deepen customer relationships and can create recurring service and replacement demand over a project’s life.
Historically, First Solar was also involved more heavily in project development and ownership, but over time it refocused on its core competence as a module and technology supplier. This shift aimed to improve capital efficiency by limiting balance?sheet exposure to project assets while still benefiting from the strong demand for utility?scale solar, particularly in the United States where policy frameworks such as tax incentives support renewable deployment.
The company emphasizes long?term supply contracts with large customers, which can improve visibility on future manufacturing volumes. At the same time, these agreements often embed price and performance conditions that reflect both the competitive landscape and expectations for technology improvements. As a result, First Solar’s business model is closely tied to its ability to keep advancing module efficiency while managing production costs in a cyclical and policy?sensitive industry.
First Solar’s primary revenue driver is the sale of its thin?film photovoltaic modules for utility?scale solar projects. These modules are designed to operate efficiently in hot climates and under diffuse light conditions, characteristics that can be valuable in many of the company’s target regions. Revenue is influenced by a combination of shipment volumes, average selling prices, and the product mix across different module generations and wattage classes.
Beyond module sales, First Solar generates income from services such as project support, operations assistance, and sometimes from the monetization of development rights on projects it has helped to structure. However, over recent years, the relative importance of pure module manufacturing has increased as the firm concentrated more tightly on its technology platform. The strategic partnership with GameChange Solar mentioned by Investing.com as of 05/14/2026 illustrates how alliances with tracker and mounting system providers can help the company embed its products more deeply into complete power?plant solutions.
Policy support, particularly in the United States, is another indirect revenue driver. Tax credits and incentives for domestic manufacturing and renewable generation can influence customer purchasing decisions and project economics. First Solar’s US manufacturing footprint means it can potentially benefit where frameworks favor locally produced modules. At the same time, competition from global module manufacturers keeps pricing pressure present, making cost discipline and scale critical for sustaining margins.
Over the medium term, revenue potential is also linked to the pace at which electric utilities and large corporates commit to decarbonization and add solar to their generation mix. Long?term power?purchase agreements for solar farms can underpin multi?year module supply contracts. For First Solar, converting this structural demand into profitable growth depends on balancing capacity expansion with market cycles, as well as managing raw?material and logistics costs that can fluctuate significantly.
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Additional news and developments on the stock can be explored via the linked overview pages.
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First Solar Inc. combines a focused thin?film technology platform with exposure to large, utility?scale solar projects, particularly in the United States. Recent market attention has been driven by a strategic partnership with GameChange Solar and by notable share?price swings so far in 2026, according to reports from Investing.com and MarketBeat. For US?based investors following the renewable energy transition, the stock offers a way to track developments in utility?scale solar manufacturing, but outcomes remain closely tied to policy frameworks, competition, and execution on cost and technology roadmaps.
Disclaimer: This article does not constitute investment advice. Stocks are volatile financial instruments.
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