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Directed assembly of cathode interlayers enables efficient binary organic solar cells
Binary organic solar cells achieved a certified power conversion efficiency of 20.65% and a certified fill factor of 82.7% after researchers used a methanol-assisted, stepwise deposition process to control the orientation of cathode-interlayer molecules. The treated interface produced a stronger surface potential and lower charge-transport resistance in devices based on PDISNN and a PM6:Y6 active layer. Sum-frequency generation vibrational spectroscopy showed that the procedure changed the mean molecular tilt at the interface, supporting the conclusion that directing interlayer assembly can improve charge extraction without replacing the binary donor–acceptor combination.
The work focuses on the electrode-facing coating in an organic photovoltaic device, known as the cathode interlayer. Such layers can create interfacial dipoles and affect the electrical properties of the junction between the photoactive material and the metal electrode. Their performance, however, depends strongly on how their molecules are oriented, and that arrangement has been difficult to control during film deposition. The researchers addressed this problem by exploiting the amphiphilic character of the interlayer compounds and separating the deposition process into stages rather than applying the layer as a single conventional coating.
Under the reported Method III procedure, the researchers first spin-coated methanol onto the active layer before depositing the cathode-interlayer solution. The interlayer materials, dissolved in trifluoroethanol, were then applied at 3,000 revolutions per minute for 30 seconds. The authors described this as a methanol-templated film-deposition strategy that controls molecular packing orientation while overcoming the solubility limitations associated with conventional orthogonal deposition. Two comparison procedures were also tested: direct deposition of the interlayer onto the active layer, known as Method I, and methanol post-treatment after deposition, known as Method II.
Three related perylene diimide cathode-interlayer materials were evaluated: PDINN, PDISNN and PDI2SNN. The best certified result came from a binary device containing the PDISNN interlayer and a PM6:Y6 photoactive layer. For the orientation measurements, the investigators examined a representative device stack consisting of indium tin oxide, a 100-nanometre PM6:Y6 active layer and an approximately 11-nanometre PDI interlayer. Sum-frequency generation measurements on this full stack were intended to characterize the interlayer in a configuration relevant to an operating device rather than only as an isolated film.
Using several polarization combinations, including ssp, ppp and sps, the researchers derived tilt angles for the transition dipoles of the interlayer molecules relative to the substrate. The conventional Method I procedure gave a tilt angle of 31.6 ± 1.9°, while the hexane-pretreated case discussed in the analysis gave 35.8 ± 1.2°. The study concluded that the methanol-templated procedure produced a preferred perpendicular orientation for the ordered PDISNN molecules. Standard error propagation was used to estimate uncertainty from variations in the measured signal intensities, and agreement among the different polarization combinations supported the orientation analysis.
Other characterization methods examined why the altered molecular arrangement affected device operation. Surface-energy calculations based on contact angles with liquids of known dispersive and polar components were used to characterize the films. Ultraviolet photoelectron spectroscopy was applied to determine work-function-related properties, while molecular dynamics simulations and density functional theory were used to investigate molecular interactions, fragment dipoles and adsorption behavior. The results showed that the amphiphilic interlayer molecules interacted with the treated active-layer surface in a way that favored an ordered, more upright molecular arrangement and a stronger interfacial dipole.
According to the researchers’ interpretation of these measurements, orienting PDISNN more perpendicular to the substrate enhanced the surface potential and lowered the work function. They associated these electrostatic changes with a reduced interfacial Schottky barrier and an enhanced built-in electric field. The treated cathode interface also had lower charge-transport resistance. Electrical measurements on interlayer films used a defined electrode width of 11,000 micrometres and spacing of 500 micrometres, with conductivity calculated from current, voltage, electrode geometry and a film thickness of approximately 100 nanometres.
The photovoltaic measurements showed that the electrical and interfacial changes were accompanied by higher performance in devices made with the methanol-assisted deposition sequence than in the corresponding controls. The authors linked the improvement to reduced interfacial charge accumulation, which they identified as a primary source of trap-assisted non-radiative recombination. Suppression of that recombination was associated with a higher open-circuit voltage, while the reduced transport resistance contributed to the stronger fill factor. Devices were tested under simulated AM 1.5 illumination calibrated to 100 milliwatts per square centimetre, and external quantum efficiency was measured with wavelength-by-wavelength calibration against a standard single-crystal silicon cell.
The devices used either an approximately 30-nanometre PEDOT:PSS layer on indium tin oxide or a 2PACz layer deposited from ethanol, followed by the photoactive film, cathode interlayer and thermally evaporated silver electrode. The active layer was spin-coated at 4,000 revolutions per minute and thermally annealed at 100 degrees Celsius for 10 minutes to remove residual chloroform and control morphology. Small-area photovoltaic measurements used a masked aperture of 0.0256 square centimetres, while large-area measurements used 1 square centimetre. These details place the certified result within the study’s reported laboratory device structure rather than implying a commercial module or panel.
The researchers also reported that the stepwise deposition method was applicable to different cathode-interlayer and active-layer combinations, with the tested interlayers producing higher efficiencies than their conventional-processing counterparts. The architecture could be extended to ternary active-layer formulations. The principal certified performance remained the 20.65% efficiency and 82.7% fill factor of the binary PDISNN system, so the broader results should not be read as evidence that every material combination reached the same performance. Encapsulated devices were also prepared for operational-stability testing under continuous white light from a 410-to-850-nanometre LED array, operating at the maximum power point under 100 milliwatts per square centimetre in air near 25 degrees Celsius.
Subject of Research: Control of cathode-interlayer molecular orientation for high-efficiency binary organic solar cells
Article Title: Directed assembly of cathode interlayers enables efficient binary organic solar cells
Article References: Yao, J., Zhang, R., Zhang, M., Wang, T., Jain, N., Liu, Y., Liu, C., Liu, X., Zhang, Z., Meng, S., Song, A., Wang, Q., Chen, Q., Gao, F., Zhang, Z.-G., & Li, Y. (2026). Directed assembly of cathode interlayers enables efficient binary organic solar cells. Nature Energy. https://doi.org/10.1038/s41560-026-02148-w
Image Credits: AI Generated
DOI: 10.1038/s41560-026-02148-w
Keywords: organic solar cells, cathode interlayers, molecular orientation, power conversion efficiency, fill factor, interfacial dipole, PDISNN, PM6:Y6, sum-frequency spectroscopy, charge extraction, Directed, assembly
News Source: Denise Maddox. (October 20, 2026). Directed assembly of cathode interlayers enables efficient binary organic solar cells. Scienmag.
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Fossil fuels remain inextricably bound up in modern warfare as cause, weapon, and primary vulnerability. From military engagements aimed at securing foreign crude reserves to targeted strikes on energy infrastructure, volatile oil and gas assets continue to drive global instability.
Writing in a recent Substack post, environmental advocate Bill McKibben highlighted how substituting hydrocarbons with distributed renewable generation fundamentally alters the strategic calculus of international conflict. 
“If we lived on a planet that ran mostly on wind and solar power, war would be less likely,” McKibben noted. “It’s hard to fight over sunshine.”
The intersection of oil and military conflict is visible across active geopolitical flashpoints. U.S. intervention in Venezuela has focused heavily on securing governance and low-cost off-take rights to over 65 billion barrels of proven reserves. Similarly, military operations targeting Iranian energy nodes, including the Kharg Island oil terminal, demonstrate how central energy infrastructure remains in modern theater operations.
Beyond direct conflict, fuel supply disruptions serve as leverage for economic coercion. The ongoing U.S. oil blockade of Cuba has constrained the island grid, resulting in rolling blackouts that disrupt basic municipal services, healthcare, and industrial output. Meanwhile, attacks on energy infrastructure across Eastern Europe and the Middle East continue to destabilize regional power markets.
In response to grid vulnerability and fuel insecurity, nations and consumers are treating clean energy deployment as an operational hedge. Island nations like Cuba and war-impacted regions in Europe are accelerating rooftop solar and battery storage installations to build localized resilience against centralized fuel shocks.
Every solar system installed on a roof or balcony generates clean, decentralized power directly on site, bypassing the logistical vulnerabilities of imported fuel and insulated from geopolitical blockades. Because sunshine is ubiquitous and impossible to hoard or blockade, replacing centralized fuel supply chains with distributed solar assets strips petrostates and military aggressors of their primary economic leverage.
Simultaneously, clean energy adoption across transport and heating is eroding structural oil demand. European electric vehicle sales reached 600,000 units in September 2026, marking a 39% increase year-over-year. Key markets led the expansion, with France surging 78% year-over-year and Germany rising 61%.
In California, which represents the fourth largest economy in the world, the grid regularly achieves stretches where clean energy meets more than 100% of total demand. When the sun sets, the state increasingly relies on large scale battery storage systems that spent the afternoon soaking up cheap, excess solar generation. This dynamic battery buffer has allowed California to slash its natural gas consumption for electricity by 60% over a brief two year window.
“We live on a planet where the cheapest way to make power is to point a sheet of glass at the sun,” McKibben said on a recent appearance on the Ezra Klein podcast.
As McKibben emphasizes, every solar array, heat pump, and electric vehicle deployed directly reduces global reliance on centralized, vulnerable hydrocarbon supply chains. While regulatory friction and political shifts can affect short-term project timelines, the underlying economic dominance and security benefits of solar generation make the transition irreversible, establishing clean power infrastructure as a foundation for geopolitical stability.
“The solar panel is the new peace symbol. Pass it on,” McKibben said.
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Global solar supply chains are undergoing a profound transformation, driven by growing protectionism and industrial policies aimed at supporting domestic manufacturing. This is the key takeaway from an interview with pv magazine featuring Laura Sartore, CEO of Ecoprogetti, an Italian company specializing in machinery and production lines for solar module manufacturing.
According to Sartore, this trend is increasingly evident across major international markets. “All the world’s primary supply chains, with the exception of China’s, are shifting toward a form of protectionism and price floors,” she said, citing the United States as one of the most prominent examples.

The dynamics shaping global PV supply chains – including solar modules, inverters, and battery energy storage systems – will be discussed during the “Decoding solar supply chains” session at the NetZero event in Milan on Oct. 21.
The session will examine the forces reshaping clean energy supply chains, from manufacturing and sourcing strategies to shifting trade and regulatory requirements. It will also explore what these developments mean for companies procuring solar and energy storage equipment in an increasingly complex global market.
Join us in Milan to hear from industry experts and take part in the discussion on the future of solar supply chains.
The US market shows that introducing minimum price thresholds, even above the prices charged by Chinese manufacturers, does not necessarily slow demand. On the contrary, according to Sartore, the sector continues to grow despite rising component costs, supported by the development of a domestic supply chain.
In China, prices are also gradually rising across the supply chain following government efforts to curb overcapacity, a trend that was expected to continue into 2025. According to Sartore, this shift reflects a growing focus on the economic viability of manufacturing in a market where solar technology has already firmly established its competitiveness against other energy sources.
Among international markets, Sartore identifies India as one of the most compelling examples of industrial policy in the solar sector.
The Indian government is progressively expanding protectionist measures and domestic manufacturing requirements beyond modules to include cells, wafers and ingots, aiming to reduce dependence on Chinese imports and strengthen local production capacity.
“In my view, India has the most serious industrial policy. They have observed Europe’s mistakes, and they continue to monitor developments in the United States,” Sartore said, highlighting the clear industrial strategy pursued by Prime Minister Narendra Modi’s government.
A key element of this strategy is industry consolidation. Production capacity exceeding domestic demand is not necessarily seen as a problem. Instead, it can encourage mergers and direct investment toward segments of the supply chain that remain underdeveloped.
“The days of small-scale factories with a capacity of 200–500 MW are over; we are now seeing multi-gigawatt-scale facilities. And that is how it had to be—that is the only way forward for a continent-sized nation like India,” Sartore said.
This consolidation is helping create larger, more financially robust manufacturers capable of investing not only in solar cell and module production but also in the materials and components needed for manufacturing, including glass, encapsulants, backsheets and junction boxes.
According to Sartore, India now has the most comprehensive solar manufacturing supply chain outside China. However, domestic polysilicon production, a technically complex industrial process, remains underdeveloped.
“It will certainly be more challenging, because, beyond the raw material extraction phase, polysilicon production requires specialized technological expertise, capital-intensive facilities, and competitive access to energy. These industrial capabilities are currently lacking and must be developed and solidified; yet, India possesses the potential to scale them up,” Sartore explained.
Beyond technical expertise and investment, the environmental impact of manufacturing presents another challenge. Sartore stressed that developing a domestic polysilicon supply chain must also account for emissions from industrial processes.
“As India develops its polysilicon production, it must aim for high environmental standards and low-emission processes from the very outset. It is not enough to simply replicate production capacity—as seen in China—without prioritizing emissions; the goal must be to build an industrial supply chain that is competitive in terms of both energy efficiency and environmental impact,” Sartore added, noting that these requirements could lengthen the timeline for developing India’s domestic supply chain.
While India and the United States are focusing on large-scale factories and highly integrated supply chains, Sartore advocates a different approach for Europe.
She argues that Europe’s industrial model cannot be assessed using the same criteria as those applied in the United States or Asia. The continent’s manufacturing sector has historically been built around small and medium-sized enterprises (SMEs), industrial clusters and networks of specialized manufacturers.
“In Europe, we lack the ‘gigafactory’ or ‘mega-factory’ structure seen in India or the United States. Historically, our industrial fabric has been composed of small and medium-sized enterprises, across all sectors and fields,” she said.
Sartore points to Italy and Germany, where numerous industries have achieved international leadership through networks of relatively small but highly competitive companies.
According to Sartore, Europe’s solar manufacturing sector should build on this strength rather than attempt to replicate production models dominated by a handful of large manufacturers.
“The European multi-factory, network-based model is one that should not be abandoned,” she said.
However, this does not mean that small module assembly lines can remain competitive regardless of their production capacity. Manufacturers need to achieve a minimum production scale and invest in adequate levels of technology and automation to justify Capex and maintain competitive costs.
“A scale of 800 MW to 1 GW is the minimum threshold—necessary to make an investment sustainable—otherwise, the Capex burden becomes too heavy, making it impossible to reach competitive module price points,” Sartore explained.
Factory size is a key factor in the future of European solar module manufacturing.
According to Sartore, a production capacity of 1 GW to 3 GW offers an optimal balance between economies of scale, financial viability and operational complexity.
“A capacity of 1 to 3 GW is manageable,” she said, explaining that facilities of this size typically correspond to companies with annual revenue of €100 million ($112.2 million) to €200 million and approximately 150 to 300 employees.
Such companies are large enough to support industrial-scale manufacturing while remaining compatible with Europe’s existing industrial structure.
The challenge goes beyond the initial capital investment required to build a factory. Once production begins, manufacturers face substantial operating costs, particularly for raw material procurement.
Although increasing production capacity initially reduces module production costs per unit, there is a point beyond which the financial burden of operating a larger facility can offset these savings.
“In the European context, the 1 GW to 3 GW range captures the benefits of economies of scale. Beyond 3 GW, additional management costs and financial charges come into play; these weigh on the bottom line and do not necessarily lead to lower raw material procurement costs,” Sartore said.
For a 5 GW factory, working capital requirements can become particularly significant. Procuring and managing large volumes of raw materials requires substantial credit lines, bank guarantees and careful financial planning. These costs must be weighed against potential economies of scale, as greater production capacity does not necessarily translate into lower unit costs. Larger facilities also face greater financial exposure if demand falls short of production capacity.
“In Europe, without supply chain integration, if I need to purchase 5 GW worth of raw materials, I require structured bank collateral. There are high costs for credit guarantees and interest on cash flow—all of which weigh on the purchase price of the raw materials and on the company itself—potentially making the resulting photovoltaic module no more cost-effective than one produced by a smaller-scale manufacturer,” she explained.
As a result, a larger factory does not necessarily have lower production costs than a medium-sized facility, particularly when financing expenses and operating overheads are taken into account.
For medium-sized European manufacturers, a more moderate production scale can help limit financial exposure and make working capital requirements easier to manage, particularly given the financing conditions in Europe’s banking sector.
Production capacity should also reflect the characteristics of market demand.
According to Sartore, Europe’s solar market has a more fragmented structure than other major international markets, with projects generally smaller than gigawatt-scale installations and manufacturers required to handle a wider range of order sizes.
European solar projects often range from a few megawatts to several tens of megawatts, while installations approaching or exceeding 1 GW remain relatively rare.
Sartore argues that this further supports the development of a network of manufacturers capable of adapting production to individual customer requirements.
“There won’t be many gigawatt-scale solar power plant projects in Europe,” Sartore said. “The European market is defined by diverse requirements and local conditions, making the development of numerous medium-to-large-scale plants more likely than the creation of a large number of mega-installations.”
Production flexibility therefore becomes a key competitive factor alongside manufacturing costs and supply chain capabilities.
From this perspective, the future of European solar manufacturing may depend less on establishing a handful of massive gigafactories and more on developing a network of medium-sized manufacturers that are financially viable and capable of responding to diverse market requirements.
According to Sartore, this model is better suited to Europe’s industrial structure and the specific characteristics of its solar market.
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Grid operators across Germany are facing a growing number of connection requests for battery energy storage systems and rooftop solar installations. To manage the increasing workload, distribution system operators (DSOs), including Netze BW, are turning to digital solutions.
The southern German grid operator has unveiled an automated assessment process for PV systems with capacities of up to 15 kW. The system can reduce processing times from an average of 12 days to around five minutes in areas where sufficient grid capacity is available.
Netze BW launched the system in late July 2026, following a testing and rollout phase that began in November 2025. Since then, the company has received more than 16,000 grid connection requests for small-scale PV installations, according to Angelika Ruß, a Netze BW representative, speaking at a press briefing.
More than 5,000 applicants have already received automated responses within five minutes. Marc Schmidt, also of Netze BW, said these responses constitute binding grid connection approvals and specify the connection point for installations up to 15 kW.
Jörg Reichert, chairman of Netze BW’s management board, highlighted the company’s strong performance in a digitalization index published this summer by Germany’s Federal Network Agency (Bundesnetzagentur), the country’s energy regulator.
“The energy transition cannot be achieved with a single mouse click – but the right digital solutions can certainly speed things up significantly,” said Reichert. “Anyone wanting to connect a photovoltaic system should be able to reach their goal without paperwork, waiting on hold, or follow-up inquiries.”
In a recently published comparison of German DSOs, Netze BW recorded an average processing time of 12 days for manually assessed grid connection requests, compared with a median of 80 days across all operators. The automated system could further improve the company’s performance.
However, automated approvals are currently limited to installations in areas where grid capacity is not considered critical. In these locations, the entire process is handled through Netze BW’s online customer portal, which accepts and processes requests around the clock.
Schmidt said 99% of grid connection requests are now submitted through the portal.
The automated assessment relies on a digital grid model that maps power lines, substations and individual customer connections. The system calculates available grid capacity, checks technical constraints and accounts for previously approved connections.
Where the assessment identifies insufficient grid capacity, the application is referred for manual review. Netze BW staff then determine whether grid reinforcement is necessary or whether an alternative connection point is available. Such cases can take up to 12 days to process.
Applications for PV systems larger than 15 kW also continue to require manual assessment. Staff must review and verify the technical data before issuing a binding grid connection offer.
Netze BW plans to extend automation to additional connection processes while maintaining grid stability.
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Thursday, November 5, 2026
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The new issue of pv magazine Global is out now!
Available in print and digital – get your copy today!
pv magazine USA hosts its multi-day virtual event on U.S. solar and energy storage, covering domestic manufacturing, distributed energy and the growing role of solar-plus-storage in meeting AI-driven power demand.
pv magazine hosts its four-day virtual event on European solar and energy storage, exploring market opportunities, solar-plus-storage business cases, technical quality, and cybersecurity in the years ahead.
pv magazine Session returns to NetZero Milan as Knowledge Partner, organizing and moderating a two-hour conference on the evolving global solar supply chain.
Get your ticket at a discounted rate with pv magazine.
Join pv magazine for an expert session exploring quality, technology and the challenges of scaling India’s solar industry.
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A farmer tends to solar panels near mountain cabins as clouds drift over a highland pasture in Trabzon province, along Turkey’s Black Sea coast, Monday, Oct. 19, 2026.
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The EBRD has mobilized $265 million loan package for a solar and storage project in Egypt
The 1.2 GW solar plant will be paired with a 600 MWh BESS to store daytime electricity and meet peak demand after sunset
Egypt’s EETC will purchase the electricity generated by the project under a 25-year PPA
Infinity Power and HAU Energy B.V. have secured $265 million in financing from the European Bank for Reconstruction and Development (EBRD) for a 1.2 GW solar project in Egypt. The project is expected to become the ‘largest’ solar power plant in Egypt and Africa.
The solar power plant project will be accompanied by a 600 MWh battery energy storage system (BESS) to store electricity during the day to help meet peak demand after sunset. It has a Golden License from the Egyptian government to help fast-track the investment (see Egypt Approves 1 GW Solar PV & 600 MWh BESS Project).
The project is also co-financed by German development finance institution DEG, Dutch Entrepreneurial Development Bank (FMO), and France’s Proparco.
HAU Energy is co-owned by Hassan Allam Utilities, Meridiam and the EBRD. Infinity Power, a joint venture between Infinity and Masdar, says this project is part of its target to achieve 10 GW of operational renewable energy capacity by 2032.
“As the largest solar PV project in Egypt and Africa, paired with one of the country’s first utility-scale battery energy storage systems, Nefer Menya will strengthen energy security, enhance grid resilience and support Egypt’s transition to a low-carbon economy,” said Infinity Power’s Co-Founder and CEO Nayer Fouad.    
Nefer Menya for Renewable Energy, the special purpose vehicle (SPV), owned by Infinity and HAU, will secure $160 million A-loan from EBRD’s own funds, while $75 million B-loan has been mobilized by the bank from the Bank of Jordan. Another $30 million is concessional financing from the CIF Clean Technology Fund (CTF) under its Global Energy Storage program.
Chinese solar PV manufacturer AIKO is supplying its all-back-contact (ABC) solar modules for the Nefer Menya Solar Project located in Minya Governorate.
The Egyptian Electricity Transmission Company (EETC) will offtake power generated from the facility under a 25-year power purchase agreement (PPA). It will provide clean power at a lower cost than conventional generation, says EBRD.  
“Egypt continues to be a trailblazer in large-scale renewable energy deployment at affordable prices. By combining solar generation with utility-scale battery storage, this project will strengthen the country’s energy security and enhance grid resilience,” stated Aida Sitdikova, EBRD Director of Sustainable Infrastructure in the Middle East and Africa.
Egypt targets to achieve 42% share of renewable energy in its electricity mix by 2030. In 2023-2024, it was about 12%. The country has plans to facilitate 10 GW of new private-sector renewable energy capacity by 2028 while cutting down 5 GW of inefficient fossil-fuel capacity. In 2026, the country announced plans to add 3 GW of solar power capacity, along with 600 MW of new battery storage before summer (see Egypt To Bring Online 3 GW Solar Energy In 2026).   
TaiyangNews 2024

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MNRE is contemplating a support scheme for agrivoltaics either under PM-KUSUM or separately
The ministry expects India could add around 5 GW of agrivoltaic capacity over the next three to four years
Financial and policy support could make solar deployment more widespread in the country via agrivoltaics
India is considering a financial support scheme to encourage agrivoltaics to encourage dual use of land for solar power generation and farming. The Ministry of New and Renewable Energy (MNRE) sees the potential to add around 5 GW of agrivoltaic capacity over the next three to four years.
MNRE Secretary Santosh Kumar Sarangi recently said that the government was working on a scheme to address the higher costs of agrivoltaic projects and incentivize stated to encourage their adoption. India’s technical agrivoltaics potential currently stands at between 1 TW to 2 TW (see TERI: India’s Agrivoltaic Potential May Reach 2.1 TW).
Under agrivoltaics, solar panels are installed on elevated structures, allowing crops to grow and farming activities to continue beneath them. The approach could help India expand solar power generation while reducing competition between renewable energy projects and agricultural land. Sarangi stressed that this approach could expand solar deployment beyond the top 5 states that currently account for 85% of deployment, to even those with less non-agricultural land.
Sarangi believes that agrivoltaic projects cost around 25% to 30% more than conventional ground-mounted solar installations because of the additional infrastructure needed to elevate the panels. The proposed scheme aims to address this cost difference and make projects more commercially viable. 
The projected addition of 5 GW would nevertheless depend partly on state governments introducing suitable feed-in tariffs (FIT), which determine the price paid for electricity generated by these projects.
As per the ministry’s estimates, the cost of power from agrivoltaics plants could range between INR 3.20 to INR 3.30 per kWh, compared with INR 2.80 to INR 3 per kWh for decentralized solar installations under PM-KUSUM.
The ministry is considering whether to include the support under the existing PM-KUSUM scheme or introduce a separate program. It is working with the Ministry of Finance to determine its structure. It is also working on a policy document to guide the development of agrivoltaics and engaging with electricity distribution companies to facilitate power purchases, according to the MNRE Secretary.
Speaking with the media ahead of the Agrivoltaics World Conference 2026 to be held in New Delhi, Sarangi shared that trials conducted with the Indian Agricultural Research Institute (IARI) have helped identify crops suited to agrivoltaic installations across different agro-climatic zones.
While fruits and leafy vegetables had shown encouraging results, the arrangement doesn’t seem to work as well for rice and sugarcane. He identified Madhya Pradesh, Odisha, Chhattisgarh, West Bengal and Uttar Pradesh as states with potential for deployment.
Earlier this year, India approved a new floating PV scheme to target 5 GW capacity, combined with 2-hour energy storage systems (see India Launches 5 GW Floating Solar Scheme With Storage).  
TaiyangNews 2024

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Italy awards over US$860 million to deploy 505MW of rooftop agriPV capacity  PV Tech
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Poland has changed its grid-connection rules to make it easier for households to pair PV systems with larger batteries, through an amendment to its Renewable Energy Sources Act that also revises the energy law.
From Dec. 1, the rated power of a battery connected with a micro-installation will not count toward the micro-installation’s installed power, as long as the battery’s power is no more than 2.2 times that of the PV system. Combined grid feed-in from the PV system and battery must also stay below the micro-installation’s installed power.
Under the previous rule, storage power was excluded only if it did not exceed the PV system’s power, effectively a 1:1 ratio. Above that, the battery’s power counted toward the microinstallation’s installed power.
The limit applies to rated power in kilowatts, not storage capacity in kilowatt-hours. A 10 kW PV system could therefore be paired with a battery of up to 22 kW, and the provision does not limit energy capacity. Owners will need export controls to keep feed-in below the PV system’s rating. If either condition is not met, the battery’s power counts toward installed capacity as before.
The amendment also requires electricity sellers to give prosumers more detailed monthly information, including grid imports and exports in kWh, the value of exported electricity and their prosumer deposit. It changes rules for energy cooperatives and introduces an auction system for biomethane plants above 1 MW. The act itself does not provide battery subsidies.
The Sejm passed the act on Sept. 4 by 380 votes to 2, with 53 abstentions, and the Senate approved it without amendments on Sept. 24.
In a government scenario in which 20% of new net-billing prosumers install batteries at up to the new limit, connected storage power would reach about 3.7 GW by the end of 2029.
Poland pulled back building rules in June that industry groups said would have restricted home and business battery storage. Separately, the Ministry of Climate and Environment has launched a PLN 1 billion ($256.9 million) home storage subsidy, with applications opening Oct. 20. It covers up to 30% of eligible battery costs, capped at PLN 800 per kWh, for batteries of at least 10 kWh. Storage already accounted for 60% of applications under the sixth round of the Mój Prąd rebate program.
From ESS News
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Panasonic Speeds Up Efforts to Turn Windows Into Solar Panels  Bloomberg.com
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NTPC Renewable Energy, a renewable energy arm of India-based NTPC, has invited bids from contractors who will build a 900 MW solar PV project near Kurnool. The package includes land, which means that the contractor will also have to acquire the site for the plant and for a battery that NTPC REL will own. Once the plant has been built and commissioned, the contractor will operate and maintain it for three years. The scope of work also covers a dedicated 400 kV transmission line, which will carry the power to the pooling substation of the Kurnool Solar Project. Only crystalline bifacial modules may be used, and the modules and their cells must both be taken from the ALMM lists of the Government of India. Every bid must be backed by a bid security of INR 50 crore (~ $5.26 million), and the bids are due by 16 November 2026.
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Study: Wind and solar boost rural economies without hurting agriculture  Wisconsin Farmer
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Gabriel Higgins2026-10-20T09:52:00+01:00
AGS Airports’ new Horizons strategy launches as Glasgow Airport’s 10MW solar farm begins meeting around 25 per cent of on-site electricity demand.

Glasgow Airport Solar Farm
Credit: AGS Airports
AGS Airports has launched Horizons, its new sustainability and environmental, social and governance (ESG) strategy, as the solar farm at Glasgow Airport (GLA) begins generating enough renewable electricity to meet around 25 per cent of the airport’s on-site demand.
The multi-million-pound project was developed by AGS Airports in partnership with energy transition adviser and developer Ikigai Group. The 10MW farm, located on Glasgow Airport land near Barnsford Road, was funded and delivered by Zestec Renewable Energy, which will manage and optimise the infrastructure over the long term.
Comprising more than 14,300 photovoltaic panels, the installation generates renewable energy to help power airport operations and reduce Glasgow Airport’s reliance on electricity from the grid.
Its completion means AGS Airports has achieved its target of generating 25 per cent of on-site renewable energy for its own use at Glasgow by the end of 2026. Based on grid electricity emissions, the solar farm is expected to save around 1,100 tonnes of carbon dioxide equivalent (tCO2e) per year.
Kam Jandu, Chief Executive Officer at AGS Airports, said: “By generating clean energy on-site, we are reducing our carbon footprint, strengthening our energy resilience and creating long-term value for the airport and the communities we serve.”
Toby Smith, Chief Operating Officer at Zestec, said: “We are pleased to have delivered this significant renewable energy project for Glasgow Airport. With the solar farm now operational, we look forward to managing and optimising it over the long term, helping the airport make the most of the renewable energy it generates.”
Helena Anderson, Chief Operating Officer at Ikigai, said: “We supported Glasgow Airport from inception to energisation, jointly developing the onsite generation project and securing the most competitive investor. It is rewarding to see that collaboration now delivering clean, competitively priced electricity for the airport.”

Glasgow Airport 10MW solar farm goes live
Credit: AGS Airports
The project was also supported by SP Energy Networks (SPEN), the electricity network operator for central and southern Scotland. Martin Maxwell, SPEN’s District General Manager for Ayrshire and Clyde South, said the network operator was proud to have played its part in bringing the solar farm to life.
The solar farm is a key initiative within Horizons, subtitled “Looking ahead, acting together”, which sets out the group’s long-term ambitions across four strategic pillars covering net zero, communities, people and innovation. Under the strategy, AGS Airports has reaffirmed its commitment to achieving net zero for its own emissions by 2035.
Fiona Smith, Executive Director of ESG and Sustainability at AGS Airports, said: “The launch of Horizons marks an important moment for AGS Airports as we set out a clear vision for building a more sustainable future for our airports. Looking ahead, acting together captures our belief that meaningful progress can only be achieved through collaboration. The solar farm is an example of that approach in action and a major milestone on our sustainability journey.”
AGS Airports is now examining how the Glasgow solar model can be replicated at Aberdeen International Airport (ABZ) and Southampton Airport (SOU). However, Fiona Smith told International Airport Review that the group was “in the very early stages of the process” at both airports, with specific schemes, grid requirements, generation capacities and delivery timescales yet to be confirmed.
“What we do know is that our commitment to achieving net-zero emissions from our own operations by 2035 means we must continue to explore every viable opportunity to generate more renewable energy on-site and reduce our dependence on the grid,” she said.
“Projects like these support decarbonisation, strengthen energy resilience, help ensure our airports are less exposed to energy market volatility and are better able to meet future operational demand.”
According to AGS Airports, a key consideration as it evaluates opportunities across the group will be how renewable generation works alongside battery energy storage. The group said storage technologies are likely to form an important part of future assessments at all three airports.
Fiona Smith added: “While there is no confirmed target date for achieving a similar level of on-site generation at Aberdeen or Southampton, we will continue to assess what is technically and commercially achievable at each location as part of our wider journey towards net zero.”
The group has also set its sights on helping to deliver the UK’s first scheduled zero-emission passenger route. Earlier this year, AGS Airports supported the UK’s first real-world electric aviation demonstration programme, which saw BETA Technologies’ all-electric ALIA aircraft complete flights across Scotland. According to AGS Airports, the trials showed how zero-emission aircraft could operate from existing airport infrastructure in the years ahead.
Fiona Smith said: “As zero-emission flight technologies mature, access to reliable, low-carbon electricity will become increasingly important. While the industry is still at an early stage and no specific routes or infrastructure requirements have been confirmed at our airports, we want to ensure we are building the foundations that will allow us to support these technologies as they become commercially viable.”
AGS Airports noted that this future demand could span electric aircraft charging, hydrogen infrastructure and the wider airport ecosystem. In the near term, however, the group expects the most immediate need for additional clean electricity to come from the electrification of airport operations themselves, including heating and cooling systems, ground support equipment, vehicle fleets, charging infrastructure and the requirements of airlines, tenants and other campus users.
“Investing in renewable energy, and potentially battery storage, helps us to meet this growing demand for additional clean energy across our airports while creating the flexibility and resilience needed to support future zero-emission aviation technologies as they emerge,” said Fiona Smith.
Jandu added: “Horizons reflects our ambition not only to reduce our environmental impact but also to help shape the future of sustainable aviation. Horizons and the targets we have set ensure AGS Airports continues to lead by example.”
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Panasonic Holdings is accelerating plans to mass-produce solar cells that can be embedded in glass, bolstering Japan’s push into the next-generation technology and expanding renewable energy deployment.
Large-scale production of glass-based perovskite solar cells will begin in April 2029 — a year earlier than previously planned — at a facility in Nagahama, Shiga prefecture, the company said in a statement on Tuesday. Panasonic started selling units made at its development site in Osaka in September.

Japan is betting on thin and lightweight perovskite cells that can be installed on surfaces unsuitable for conventional solar panels, helping the mountainous and densely populated country add more renewables. Panasonic is targeting windows and exterior walls with “power-generating glass” that can be customized in size, transparency and design.
“Particularly in urban areas, many buildings have limited roof space available for solar panel installation, leading to increased expectations for building-integrated photovoltaics,” Panasonic said in the statement, without stating how many units it aimed to produce at the new plant.
Japan is attempting to carve out a share of the emerging market, putting it in competition with China, which dominates the global solar industry and is also developing perovskite technology. The cells are also more expensive than conventional solar panels, a key hurdle to widespread deployment.
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Abstract:
Flow-Accelerated Corrosion (FAC) is an emerging concern in high-temperature thermal systems employing molten solar salts (60 wt% NaNO₃, 40 wt% KNO₃). Despite their extensive use in Concentrated Solar Power (CSP) plants, the behaviour of FAC in these media remains largely unexplored. This review provides the first integrated synthesis of hydrodynamic-driven corrosion in molten nitrate salts, linking flow conditions, electrochemical pathways, and welded material behaviour—an aspect absent from prior studies focused soley on static general corrosion. Emphasis is given to welded stainless steels (AISI 304 and AISI 347), where FeCr₂O₄ spinel formation governs corrosion resistance. The role of hydrodynamics and mass transfer, expressed through Sherwood, Reynolds, and Schmidt numbers, is highlighted as a key factor accelerating FAC in CSP systems.
Mauricio Lague, Atul Sagade, Susana Leiva-Guajardo, Álvaro Soliz, Norman Toro, Edward Fuentealba, Felipe M. Galleguillos Madrid, Short overview of flow-accelerated corrosion in CSP systems using molten nitrate salts: Mechanisms, challenges and outlook, Solar Energy, Volume 303, 2026, 114116, ISSN 0038-092X, https://doi.org/10.1016/j.solener.2025.114116
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Solar fuels are made using thermochemistry driven by direct heat from the sun In this process, solar thermal energy provides the heat for thermochemical reactions to produce new compounds such as green hydrogen or sustainable aviation fuel. Highly concentrated solar…
Here’s what dispatchable solar looks like. This gigantic solar thermal energy storage tank holds enough stored sunlight to generate 1,100 MWh/day from stored solar power. The cheapest way to store solar energy over many hours, such as the five to seven hour evening…
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Better equipment eventually changed his setup.
Photo Credit: iStock
In Dubapara, a village in Assam, India, a schoolteacher has used rooftop solar for the past 15 years, proving it can do more than back up the grid.
According to The Assam Tribune, Shozim Uddin’s interest in home solar took shape after he saw small lighting systems in remote char areas where grid service was weak or absent. He asked the crews behind those installations how solar panels and batteries functioned, then used that knowledge to create a solar-panel system for his own house.
With Dubapara dealing with repeated outages and unstable electricity that interrupted everyday routines, solar looked like a practical answer. Uddin began with six solar panels brought in from Bengaluru.
Better equipment eventually changed his setup. He has transitioned from the original off-grid setup to a PM Surya Ghar rooftop system that generates electricity at home and reduces his reliance on Assam Power Distribution Company Limited.
With energy prices through the roof, there’s never been a better time to go solar — and EasyHome can help you find the best prices from the best installers in your area.
EasyHome takes the guesswork and headaches out of energy upgrades by showing you estimated savings from a network of vetted local partners. To get started, just enter your ZIP and share a few details about your home — seeing your estimate is really that easy.
Going solar is one of the best ways to save money on home energy. If you’re comparing options, EnergySage can help you get free solar installation estimates and compare quotes.
Uddin’s shift from an off-grid system to an on-grid rooftop installation through the PM Surya Ghar program built on his earlier investment instead of replacing it.
If you’re considering a similar switch, EnergySage offers free tools that let homeowners compare competitive bids from local installers without sharing their contact information unless they choose to move forward. With EnergySage’s help, the average person can save up to $10,000 on solar purchases and installations. EnergySage’s solar map also shows the average cost of a home solar panel system by state, along with solar panel incentives for each state, helping homeowners get the best possible price.
Adding battery storage to a solar setup is a sure way to protect your home during outages, save money on energy, and go off-grid. Batteries also let households store daytime solar production for use after sunset or during service interruptions. Homeowners can explore EnergySage for information about home battery storage options, including competitive installation estimates.
Switching to solar can cut bills, reduce outage stress, and give homeowners more control over where their power comes from.
• An off-grid homeowner showed that snow-covered solar panels can still produce useful power.
• In Tennessee, one family built a high-tech system that could sideline generators for decades.
• As utility costs climb, rooftop solar can save you on bills for years.
💡Go deep on the latest news and trends shaping the residential solar landscape
• More homeowners are pairing panels with home battery storage to ride through outages.
• At EnergySage, price quotes show how interconnected solar costs shape what homeowners ultimately pay.
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Starlight Energy, the project development arm of NextEnergy Group, has submitted four utility-scale solar and battery storage projects to the Alberta Electric System Operator’s (AESO) Cluster 3 interconnection process in Canada. The projects, with a combined generation capacity of 725 MW AC, comprise the 150 MW AC Lamoureux Agri-Solar Battery Project, the 250 MW AC Castor North Solar Battery Project, the 100 MW AC Rich Valley Agri-Solar Battery Project, and the 225 MW AC St. Albert Agri-Solar Battery Project. Starlight says these projects are intended to supply competitively priced electricity as the province’s power market evolves and electricity demand grows.  
The New York State Energy Research and Development Authority (NYSERDA) has announced a framework to deploy $200 million in solar incentives through its NY-Sun program. The funding is expected to support more than 565 MW of new solar capacity. Specifically, about $116 million is allocated for around 450 MW of large commercial and community solar projects larger than 1 MW, $31 million will support 75 MW of midsize rooftop installations, and $20 million will facilitate 40 MW on-site solar for low- and moderate-income households. The program also includes incentives for projects located on rooftops, parking canopies, brownfields, landfills, floating solar sites, and agricultural land where solar generation can coexist with farming.  
energyRe has closed an $815 million financing package for five utility-scale solar projects totaling approximately 360 MW in South Carolina. It covers projects backed by 25-year power purchase agreements (PPAs). Bank of America, Canadian Imperial Bank of Commerce (CIBC), and Santander supported the transaction, which energyRe says is among the largest solar-only project financing deals in South Carolina’s history. The company aims to invest $2 billion in the state by 2030.  
Singapore-headquartered renewable energy developer Concord New Energy Group has closed $400 million in financing for its US clean energy and digital infrastructure portfolio. The financing includes $310 million in debt and letter of credit facilities and $90 million in preferred equity for Project Chisme, the company’s first utility-scale project in the US. Located in Texas, the project comprises 215 MW of solar capacity and a 147 MW/358 MWh battery energy storage system (BESS). First Citizens Bank, Goldman Sachs Alternatives and Associated Bank led the financing. Concord says this transaction supports its expansion in the US market. 
Global investment firm KKR and TotalEnergies recently agreed to add 700 MW of utility-scale solar capacity to their 50:50 US joint venture. The expansion covers three solar projects in Texas and Ohio, which are expected to begin commercial operations by Q1 2027. Electricity produced is either already sold to third parties or will be marketed by TotalEnergies. The portfolio has an enterprise value of $1.2 billion. TotalEnergies will continue to operate the assets following completion of the transaction, which is expected in 2026, subject to customary conditions. The joint venture currently holds 1.4 GW of capacity. 
CleanChoice Energy has secured an up to $85 million term loan facility from Aiga Capital Partners. The financing will support CleanChoice’s solar project development and help advance projects toward construction. It follows a separate $166 million financing CleanChoice raised earlier in October for two solar projects in New York and Pennsylvania. CleanChoice said that the new funding will provide financial flexibility to the company as it expands its power generation business beyond retail electricity supply. 
US-based space technology startup Reflect Orbital has secured two dedicated launches from Skyroot Aerospace, an Indian private space launch company. Reflect Orbital builds and operates orbital mirrors that enable controlled lighting without ground infrastructure. It says the agreement will support the deployment of Reflect Orbital’s future spacecraft, which aim to provide additional lighting for applications including solar power generation and search-and-rescue operations. The first mission will use Skyroot’s Vikram-1 rocket, while the second will use the Vikram-1U vehicle, which is under development. The companies have not disclosed launch dates or financial terms, but the US firm said that these launches provide it with an assured schedule and capacity, and complement Reflect Orbital’s other planned launches from sites in the US.  
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China has proposed export controls on 12 solar manufacturing technologies, citing national security. Open for consultation until 15 November 2026, the draft could influence India’s efforts to strengthen domestic solar manufacturing.
 

 
China has proposed export controls on 12 solar photovoltaic (PV) manufacturing technologies, raising concerns about access to advanced production processes across the global solar industry. Announced on October 16, 2026, the proposal cites national security concerns, noting the growing use of solar technologies in sensitive sectors such as aerospace and defence. The proposed measures would prohibit exports of certain technologies used in thin silicon wafer, polysilicon, perovskite and tandem solar cell manufacturing, while restricting selected advanced crystalline-silicon cell technologies.
 
The draft is open for public consultation until November 15, 2026, and the proposed prohibitions and restrictions have not yet formally taken effect. However, interim registration requirements apply to certain overseas technology transfers. Although the proposal does not impose a blanket ban on finished solar panels, it could affect access to manufacturing know-how and equipment-related technologies. This development is particularly relevant to India and other countries seeking to strengthen domestic solar manufacturing and reduce dependence on overseas technology suppliers.
 
What Has China Proposed?
The proposal would add 12 solar-related technologies to China’s Catalogue of Technologies Prohibited or Restricted from Export. Stakeholders have until November 15, 2026 to submit feedback, and temporary pre-export registration requirements took effect on October 16, remaining in force until the revised catalogue is formally issued. The registration rules already apply to technology ownership transfers, intellectual property licensing arrangements, and changes in control over domestic technologies transferred to foreign entities.
 
The 12 technologies are divided into two tiers. Prohibited exports cover technologies for manufacturing silicon wafers 70 micrometres thick or less, perovskite and perovskite-silicon tandem solar cells capable of conversion efficiencies of at least 30%, and large-scale fluidised-bed polysilicon production technologies. Restricted exports — requiring licensing rather than outright prohibition — cover specific advanced cell manufacturing processes, including selected TOPCon, XBC, and HJT production technologies, along with associated equipment designs, algorithm models, and programme codes. This two-tier structure means the practical impact will vary by technology and by the final scope of the catalogue after consultation.
 
Which Solar Manufacturing Technologies Are Affected?
Thin silicon wafers sit at the upstream end of the chain. Wafers thinner than 70 micrometres reduce silicon consumption and production costs, making the technology strategically valuable for cell manufacturers. Perovskite and tandem solar cells represent the next frontier of efficiency: tandem cells stack perovskite on silicon to achieve conversion efficiencies above 30%, well beyond the limits of conventional crystalline-silicon cells. Fluidised-bed polysilicon production is a more efficient route to high-purity polysilicon, the feedstock for wafers.
 
For TOPCon, XBC, and HJT cells, the restrictions target the specific deposition, diffusion, and electrode-manufacturing processes that determine cell performance and production throughput. Crucially, the proposal governs manufacturing technology and technical know-how, not the export of finished solar modules. A Chinese company could still sell panels abroad; what becomes harder is transferring the processes and equipment drawings needed to replicate advanced production locally. This distinction matters because it targets the longer-term objective of building independent manufacturing capability rather than the immediate availability of solar products.
 
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Potential Implications for India’s Solar Manufacturing Industry
India’s dependence on imported solar components makes the proposed controls relevant to its domestic manufacturing ambitions. China supplies approximately 95% of India’s solar cell imports, valued at around US$1.86 billion in FY2026, an increase of 37%. China also accounted for more than 99% of India’s undiffused silicon wafer imports. Separately, India imported 8.01 billion solar cells in FY2026, up 58% from the previous year, while total solar cell import expenditure increased 95% to ₹27,133.68 crore. Meanwhile, India’s solar module manufacturing capacity reached approximately 233 GW by June 2026, compared with around 38 GW of reported solar cell capacity. This gap highlights the imbalance between module assembly and upstream manufacturing, particularly solar cells and wafers.
 
The proposed Chinese export controls could create additional challenges for Indian manufacturers seeking to expand domestic cell, wafer, and polysilicon production, especially if new facilities depend on restricted technologies. Existing supply-chain delays have already disrupted some Indian module producers and put investment at risk. However, these disruptions predate the October 2026 proposal, and its additional impact will depend on the final rules and the technologies covered. India’s target of 500 GW of non-fossil electricity capacity by 2030, including approximately 292 GW of solar capacity, strengthens the case for developing a more integrated domestic solar supply chain and reducing reliance on imported manufacturing technologies and components.
 
Major Indian Solar Manufacturers and Their Expansion Strategies
Effects on Global Renewable Energy Supply Chains
China’s proposed export controls could reshape global solar supply chains by restricting access to selected manufacturing technologies rather than finished solar panels. Countries such as India, the United States, and those in Europe seeking to expand domestic solar production may face additional challenges in developing advanced cell, wafer, and polysilicon manufacturing. Although the proposal could create opportunities for alternative technology providers, its impact will depend on the final restrictions and available substitutes. For manufacturers and investors, technology access, licensing requirements, and upstream capacity expansion will be key factors to monitor. Ultimately, the proposal highlights the growing strategic importance of solar manufacturing knowledge.
 
What Does the Proposal Mean for Solar Manufacturers and Investors?
 
 
 
Future Outlook
The final scope of China’s proposed export controls following the November 15, 2026, consultation will determine how licensing requirements or export prohibitions affect technology transfers. For India, the outlook will depend partly on whether it can expand solar cell manufacturing capacity to 60 GW by December 2026 and 100 GW by mid-2027 with access to the required technologies and expertise. Globally, manufacturers may accelerate alternative technology partnerships and domestic research and development to reduce dependence on Chinese processes. A key uncertainty is whether non-Chinese equipment and technology suppliers can scale sufficiently to support advanced cell and wafer production without delaying solar manufacturing expansion.
 
Conclusion
China’s proposed export controls on 12 solar manufacturing technologies highlight a strategic shift toward greater control over advanced manufacturing know-how. Although the proposal does not impose a blanket ban on finished solar panels, restrictions on selected technologies could create challenges for countries seeking to strengthen domestic solar production. For India, the development underscores the importance of expanding solar cell, wafer, and polysilicon manufacturing to reduce supply-chain dependence. The final impact will depend on the scope of the controls following the November 15, 2026, consultation. Ultimately, access to advanced technologies will remain crucial to global solar manufacturing competitiveness and renewable energy expansion.
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“I’m highly skeptical of that payback period of 11 years.”
Photo Credit: iStock
A Michigan homeowner’s $71,000 solar-and-battery quote sparked an online debate.
Some people on Reddit’s r/Solar forum believed the system was fairly priced, while others thought the batteries would push the payoff too far into the future.
The main sticking point was not the panels themselves. Instead, commenters focused on whether an 11-year payback is realistic under DTE’s time-of-use structure.
In a Reddit thread, the homeowner in southeast Michigan asked for input on a proposed 18.06-kilowatt rooftop solar array paired with two Powerwall 3 batteries at a total price of $71,000. The package also covered permits, interconnection, sales tax, and a Gateway 3.
With energy prices through the roof, there’s never been a better time to go solar — and EasyHome can help you find the best prices from the best installers in your area.
EasyHome takes the guesswork and headaches out of energy upgrades by showing you estimated savings from a network of vetted local partners. To get started, just enter your ZIP and share a few details about your home — seeing your estimate is really that easy.
The original poster added that their household uses about 30,500 kilowatt-hours each year, with more than half of that tied to their two EVs. The installer estimated output at 22,926 kilowatt-hours annually, which would offset about 75% of their use.
The proposal came out to about $2.68 per watt for the solar portion by itself and roughly $4.03 per watt once the batteries were included. The OP then wrote, “Payback pencils out around 11 years at 4 to 5% DTE escalation.”
That projection quickly drew skepticism from other users, who zeroed in on export compensation and rate-growth assumptions. One commenter wrote, “DTE buys your excess energy at wholesale rates so keep that in mind,” while another questioned whether 4% to 5% annual utility rate increases were too optimistic.
Because the homeowner planned to pay cash, the conversation was mostly about long-term returns rather than loan terms or monthly financing costs.
One user wrote, “I’m highly skeptical of that payback period of 11 years. I think it’s closer to 14 years… But solar only and cash payment gets you in the sub-10yr payback. Without storage, your ROI actually looks really good… I would walk from this deal.”
The OP clarified that, “I already have a whole home generator, so the Powerwall’s are for TOU and self consumption under DTE’s outflow credit, not backup.” With that in mind, some commenters said the economics could improve by dropping storage, even if batteries still provide added flexibility.
Some commenters took a middle ground, arguing that while the quote is “not a great price, [it’s] not horrible either, get a system that will produce 100% of your needs.”
For homeowners looking at a similar quote, the discussion pointed to a few practical steps: collect more bids, check the assumptions yourself, and compare a battery-backed system against a solar-only version. 
💡Go deep on the latest news and trends shaping the residential solar landscape
Still, going solar is one of the best ways to save money on home energy, and homeowners can try EnergySage to get free solar installation estimates and compare quotes. With EnergySage’s help, the average person can save up to $10,000 on solar purchases and installations.
Plus, EnergySage’s solar map shows the average cost of a home solar panel system by state, along with details on solar panel incentives for each state. 
And if you are interested in home backups, adding battery storage to a solar setup is one of the best ways to protect your home during outages, save money on energy, and go off-grid. Homeowners weighing systems like two Powerwall 3 units can explore EnergySage for information about home battery storage options, including competitive installation estimates.
These stories look at the costs, incentives, and savings that can make or break a solar payback. 
• Across the U.S., homeowners could save about $700 a year with solar, with bigger gains elsewhere.
• In Australia, a homeowner said a 20kW solar setup erased blackout worries and earned them credits.
• For many U.S. households, rooftop solar can save $50,000 over time.
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“The past 3 years the production has not even been half of the contracted amount.”
Photo Credit: iStock
A homeowner who inherited a Tesla solar lease when buying their house said the panels produced just 20 kilowatt-hours in a month while the household’s electric bill rose to nearly $600.
According to a Reddit post from the homeowner, the solar PPA transferred with the home purchase and was already 11 years into a 20-year term. They said the agreement cost $250 a month, but utility bills began climbing after about a year and a half.
They estimated they were owed about $6,000 for underproduction and reported that the system generated only 20 kilowatt-hours in a month. They wrote that “The past 3 years the production has not even been half of the contracted amount.”
Going solar is still one of the best ways to save money on home energy, but this case highlights why comparing terms matters. A commenter identifying themselves as a lawyer warned, “Declaring you’re not paying may push them to throw a lien on the property and you’re in worse shape than before. Get a lawyer and find out what the correct next steps are.” 
With energy prices through the roof, there’s never been a better time to go solar — and EasyHome can help you find the best prices from the best installers in your area.
EasyHome takes the guesswork and headaches out of energy upgrades by showing you estimated savings from a network of vetted local partners. To get started, just enter your ZIP and share a few details about your home — seeing your estimate is really that easy.
Homeowners can also use EnergySage to get free solar installation estimates and compare quotes.
Because PPAs and solar leases can stay with a property, buying this house also meant taking on the existing contract. The poster said nine years remained, so the monthly payment and the provider’s service obligations carried over.
After seeing the high bill, the homeowner said they asked the electric company to check whether the issue was on the utility side. According to the post, the company “confirmed everything is connected correctly and they are getting correct information from the panels.” That appears to point back to the solar equipment rather than the utility bill alone.
The inverter displayed “riso low,” the homeowner said, as they also calculated what they believed the provider still owed under the production terms. They said they received one reimbursement check but that roughly $6,000 more remained unpaid.
Before withholding payments, you may need to document everything and get legal advice. The homeowner described app alerts, monthly output, billing spikes, and an inverter error — the kinds of records owners need when pushing a company to honor a production guarantee.
If you’re shopping for solar instead of inheriting a contract, EnergySage lets you compare bids from local installers without sharing your contact information unless you choose to move forward. With EnergySage’s help, the average person can save up to $10,000 on solar purchases and installations.
EnergySage’s solar map shows the average cost of a home solar panel system by state, plus state-specific solar panel incentives. Together, those tools can help homeowners get the best price for rooftop solar panels and access available incentives.
Adding battery storage to a solar setup is one of the best ways to protect your home during outages, save on energy costs, and go off-grid. Homeowners can explore EnergySage for home battery storage options, including competitive installation estimates.
💡Go deep on the latest news and trends shaping the residential solar landscape
Other homeowners have reported confusing bills, contract issues, and mixed results with rooftop solar setups, and these articles cover a few of them.
• One homeowner said a strange solar policy left them staring at a $6,000 power bill.
• After solar service, another resident received a strange energy bill that sparked confusion.
• Some Tesla customers say impressive Solar Roof earnings can bring in $350 each month.
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NTPC Limited, India’s largest electric utility, has signed a power purchase agreement with 247 Solar and will deploy that company’s Concentrated Solar Power (CSP) technology as part of its energy strategy.
The companies on October 15 said it will mark the first commercial project for 247 Solar and its solar thermal tech. The Virginia-based company has said the deal is a milestone as 247 Solar improves on the first generation of its technology, which is designed to overcome the intermittency of conventional solar power.
NTPC said it will test whether 247 Solar’s system can help the utility reduce its reliance on coal-fired power generation as India expands its use of renewable energy. Officials said the project, if successful, would likely enable an expansion of 247 Solar’s technology across India.
“This new version of solar thermal solves the problem of intermittent solar and wind power, and avoids spending more on outdated, costly, and dirty coal plants,” said Bruce Anderson, founder and CEO of 247Solar. “India’s rapid growth plainly requires more clean, reliable and affordable energy. Our system can help meet that demand. I’m thrilled that after several years of deep due diligence, NTPC is working with us to bring this promising technology into wider use.”
247Solar has said its technology removes the drawbacks of previous CSP technology. The system still captures the sun’s heat with mirrors focused on towers, but the new version is simplified, modular, and scalable. It simultaneously provides heat up to 1,000C (more than 1,800F) for industrial processes, according to the company.

The system, according to 247 Solar, “stores heat for up to 20 hours in ceramic pellets, using hot air to generate electricity around the clock with unique turbines that operate without combustion under normal conditions. If the stored heat runs low overnight or during extended cloudy weather, the same turbines can also run on liquid or gaseous fuels, including natural gas, green hydrogen, or diesel, so the plant can keep producing power without interruption.”
247 Solar said the new technology has several benefits compared with traditional CSP:
The company said the NTPC project is a ~1MW hybrid, integrating one 400-kW modular 247Solar Plant with several hundred kilowatts of photovoltaic solar. It is being installed at Rajasthan’s Bhadla Solar Park, which is among the world’s largest solar energy hubs, in an arid region in northwestern India. The project is backed by the Rajasthan Renewable Energy Corporation Limited, which has approved preliminary studies, site surveys, and structural tests. NTPC and 247Solar said the companies selected the location for its abundant sunshine, and for its easy interconnection for offtake of its energy output.
The groups said the demonstration “marks an early step toward round-the-clock clean power for industry and residents in India,” and added that “success will position Rajasthan as a proving ground for the technology and give NTPC a new tool as it works to meet the country’s growing power demand while reducing reliance on coal, cutting costs and carbon emissions simultaneously.”
—Darrell Proctor is a senior editor for POWER.
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A BESS factory with a capacity of 1.8 GWh is to come up in India as Sahaj Solar, an India-based solar panel manufacturer, moves into battery storage. The board of the company approved the plan for the site at Dakor in Gujarat, India, on 19 October 2026. The factory is intended to integrate the solar systems business of Sahaj Solar vertically, and that business sells solar modules, water pumps and off-grid power plants. Because the company has reported its existing BESS capacity as nil, the Dakor factory will be its first in the segment. The new capacity is to be added within 12 months, and BESS is to be launched in the same period for domestic and international buyers. The investment has been estimated at about INR 25 crore (~ $2.63 million), which excludes the factory premises that have already been built. The amount is to be financed through debt and internal accruals.
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Mozambique Commissions Solar Power Plant To Electrify Rural Nsadzu Community  SolarQuarter
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Renewable energy developer Swift Current Energy is suing First Solar in New York state court, alleging the manufacturer knowingly supplied defective solar modules and used deceptive testing to hide significant performance issues.
The complaint, filed in Sept. 2026, alleges that First Solar supplied over 2.4 million defective Series 6 Plus and Series 7 thin-film cadmium telluride modules across three major U.S. solar installations, including the 800 MW Double Black Diamond project in Illinois. 
The developer states it paid more than $360 million for the equipment, which it claims has consistently failed to meet promised power output metrics.
According to the complaint, the modules experienced increased degradation and significantly lower-than-expected output immediately upon installation in 2023 and 2024. Swift Current says it initially submitted formal warranty claims on Dec. 23, 2024, after discovering the widespread underperformance. 
First Solar formally responded on May 2, 2025, stating that the developer had not adequately described or provided evidence of the claimed defects, and noted that evaluating power output claims based on system-level performance data is invalid under the warranty terms.
The module maker requested that Swift Current coordinate with its technical support to conduct individual module power output measurements in a laboratory. Swift Current’s court filing called this proposed remedy “commercially impossible,” arguing it would require shipping more than 1.5 million modules back to First Solar at a cost exceeding the value of the claims.
In the complaint, Swift Current points to its inability to meet commitments to its commercial offtakers under power purchase agreements as a result of the power output loss. In addition, the developer says it has lost revenue from decreased compensation under capacity contracts it signed for two of the projects in question.
Swift Current claims that First Solar identified two primary errors in its manufacturing process that led to lower power output in 1.6 million of the modules it purchased from the module maker.
The developer alleges First Solar knew about the defects at the time it shipped modules to its sites, but concealed them from the developer until October 2024. Importantly, one of the defects alleged in the complaint appears never to have been publicly acknowledged by the module maker.
The first type of these errors, which Swift Current calls “Edge Grind Defects” is related to a flaw in the manufacturing process for Series 7 modules first publicly disclosed by First Solar in an Oct. 2024 earnings call. 
In the call, First Solar CEO Mark Widmar provided details how the company identified the issue early in Series 7 production, in which materials that have been ground from the edge of module glass “calcify” onto the glass during the “dwell time” between the grinding step and a module washing step that occurs after.
At the time, First Solar said it had identified and taken actions to address the edge grind issues and was taking a warranty charge of $50 million in anticipation of providing service to buyers of affected modules.
The second, previously-undisclosed type of defect is referred to in the complaint as “Substrate Defects,” which Swift Current alleges arose from a change to the manufacturing process initiated by First Solar in 2021, which prevented the absorber layer for its Series 6 Plus and 7 modules from forming as designed. The complaint states these defects “impacted the annealing process, film quality, recombination rates, and ultimately, module power output.”
Swift Current says it was presented with an investigative report First Solar commissioned from Leidos Engineering, LLC to examine its Series 7 modules, which identifies the two defects being present in the modules. The complaint says the Leidos report found an average power loss of approximately 8 percent for modules tested after nearly one year of field deployment.
The complaint also goes further, alleging “metastability losses inherent in First Solar’s thin film cadmium telluride technology,” which can result in seasonal loss of power output during cold periods of the year. 
Swift Current alleges that First Solar artificially inflates its modules’ nameplate power ratings using a secret, proprietary “preconditioning” testing method that masks the metastability loss by testing module power output immediately after subjecting the panels to at least eight hours of extreme heat, voltage and irradiance.
The complaint says that while the edge grind and substrate defects were present in more than 1.6 million of the modules it received, all 2.4 million failed to perform as promised, with the alleged metastability issues solely at fault for lower-than expected production from the remaining modules. 
Swift Current is seeking damages and restitution due to the alleged defects. In addition, it has asked the New York court to apply penalties under a Massachusetts law regarding willful misconduct, because the Swift Current employees who evaluated the modules and negotiated the deal to purchase them are based at the company’s headquarters in Massachusetts and the commercial relationship between the two companies was managed there.
The case is active and ongoing, with the parties scheduled to appear before Justice Andrew Borrok of the New York county commercial division of the New York state supreme court on Nov. 16, 2026.
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Italy falling behind 2030 energy transition targets, report says  Reuters
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Solar energy is becoming increasingly important for bolstering sub-Saharan Africa’s trading potential, with supply chain executives telling The Loadstar that Kenya and Nigeria are two of the fastest-growing markets for the technology.
By the end of the first quarter, Nigeria had climbed into the top 10 of solar panel suppliers to the US, with some 40% of the country’s total exports of the technology, totalling $64bn, ending up in the US.
That growth has been felt by forwarders and logistics partners. DHL Express’s chief executive for Sub-Saharan Africa, Hennie Heymans, told The Loadstar the company was seeing “incredible growth” in solar-panel exports out of Nigeria – and nor is that country alone.
“We actually see an incredible growth in solar panel exports towards the United States from Nigeria and Kenya,” he said, pointing out that for Africa in general the “new energy” vertical was proving something of a winner, experiencing 20% growth year on year.
Interestingly, local forwarders told The Loadstar solar panels were also proffering volumes in the reverse direction for Kenya, although there was debate around whether the volumes were part of a local redevelopment of energy infrastructure or the result of chaos in the supply chains.
One forwarder told The Loadstar that, amid the situation in Hormuz and growing pockets of congestion at typical transhipment hubs, volumes were routing via Kenya in an effort to avoid being caught up in the chaos.
Mr Heymans, however, believes the growth in solar typifies the present story across Africa, noting that DHL had experienced a recent uptick in enquiries about special economic zones (SEZs) in several African countries, particularly Kenya and South Africa.
Without stating just how many SEZ-related enquiries his office had handled, Mr Heymans said: “In Kenya, we have seen interest focused specifically on Mombasa, as well as Nairobi, and we have seen new entrants in both locations.”
And he is not alone in noting this: businesses the world over are reassessing international supply chains amid geopolitical tension and changing trade policies, with growing indications that the continent is more than well suited as a base for production.
 

Port congestion is putting pressure on global supply chains from West Africa and Europe to …
DHL Group has committed €300m in investment across Africa through to 2030, as the logistics …
Wenzhou’s launch of a direct container shipping service to West Africa highlights a broader transformation …
Some forwarders on Europe-SubSaharan Africa trades are continuing to report strong momentum, their feelings backed …
‘DHL Express, Capital Market Briefing 2026’ (CMB) was held y’day in London. In short: it was …
Data and sentiment finally appear to be aligning on the Africa-Far East tradelane, with growth …
Lusaka Airport is attracting dedicated freighter capacity from two very different airlines, raising questions over …
Brazilian forwarders appear optimistic about the way trade opportunities are shaping up in Africa, and …
…capacity tailwind fading, however?
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Energy storage manufacturer HiTHIUM has announced that its cumulative energy storage product shipments have surpassed 200 GWh. Having begun shipments in late 2021, the company reached the 100 GWh milestone in August 2025 and added another 100 GWh in just over a year. HiTHIUM said it ranked among the world’s top 2 suppliers by energy storage battery shipments in 2025 and the first half of 2026.
Looking ahead, the company said it would remain focused on energy storage, with long-duration energy storage (LDES) as a strategic priority. Recall that HiTHIUM started mass production at its integrated LDES industrial park in Heze, Shandong Province, in August (see China Solar PV News Snippets).
It aims to promote large-scale global deployment of its first integrated long-duration energy storage solution, featuring 1,000 Ah-class cells, and to develop integrated solutions that cover the value chain from battery cells to the grid.
In its earnings forecast, Chinese inverter and energy storage equipment manufacturer Deye expects a net profit of RMB 4.22 billion to RMB 4.32 billion in the first nine months of 2026, up 79.81% to 84.07% year-over-year (YoY). Net profit excluding non-recurring items is projected to be RMB 3.95 billion to RMB 4.06 billion, up 73.33% to 78.16% YoY.
The company attributed the expected earnings growth primarily to rising overseas demand for energy storage. Supported by energy security policies and tighter electricity supply-demand conditions in several countries, sales revenue from its residential and commercial and industrial (C&I) energy storage products increased significantly YoY. Deye also cited its global sales network and supply-chain cost management as contributing factors.
Deye released its earnings results for H1 2026, reporting that its revenue rose over 92% during the period (see China Solar PV News Snippets).
Power equipment manufacturers CEEG and SINEXCEL have jointly developed a 13,800 kVA transformer for energy storage applications. The oil-immersed, self-cooled, dual-split transformer is designed for a 40-foot high-cube containerized AC/DC integrated energy storage system (ESS), enabling a rated continuous output of 13.8 MW per container.
According to CEEG, the transformer achieves 99.66% efficiency, exceeding the EU Tier 2 benchmark of 99.645%. Its design reduces overall weight by ~10% and is intended to be maintenance-free. The product series now covers single-unit power ratings from 6 MW to 13.8 MW, with grid-side voltage options of 13.8 kV, 22 kV, and 33 kV. The products target GW-scale energy storage and renewable energy projects with integrated storage.
Guangdong’s provincial development and reform commission and energy administration have issued pricing rules for local renewable energy consumption projects, including direct green power supply, integrated source-grid-load-storage projects, and zero-carbon industrial parks.
Under the policy, annual self-consumed renewable generation must account for at least 60% of total available generation and at least 30% of total electricity consumption. The minimum share of electricity consumption supplied by self-consumed renewable generation will rise to 35% for new projects from 2030.
Projects connected to the public grid must pay capacity- or demand-based transmission and distribution charges. Electricity imported from the grid will no longer incur separate system reserve charges or energy-based transmission and distribution fees. Other applicable charges, including system operation fees, government funds, and surcharges, will continue to apply under the relevant rules.
China’s renewable energy price settlement mechanism will not cover electricity exported by these projects. Renewable energy projects already covered by the mechanism price that switch to local consumption arrangements will be deemed to have voluntarily withdrawn from the mechanism.
Guangdong recently launched a mechanism price auction for 2026 renewable energy projects, with a volume of 7.934 billion kWh for distributed PV (see China Solar PV News Snippets).
TaiyangNews 2024

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SMA Solar develops photovoltaic system technology for decentralized energy supply, according to its investor-relations materials. SMA Solar stock trades pre-market at EUR 54.73 at 8:46 a.m. CEST at Lang & Schwarz on October 20, 2026, 1.21 percent below the Xetra close of October 19, 2026 (EUR 55.40).
The pre-market indication is EUR 0.67 below the Xetra reference. The further course from the Xetra open at 9:00 a.m. CEST is shown by the continuously updated real-time quote of SMA Solar stock.
The company provides photovoltaic solutions for decentralized, digital and renewable energy supply, as described on its investor-relations page. The financial calendar lists the release of the quarterly statement for January through September 2026 and an analyst conference call on November 12, 2026. Market context: Market report SDAX.
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What is solar thermal energy, and how does it differ from photovoltaics?
The transition to a more efficient energy model calls for technologies capable of supplying energy that is not only sustainable but also consistent. With that in mind, we take a closer look at two renewable energy sources that are both powered by the sun yet differ in important ways: photovoltaic and solar thermal energy.
 
Although both draw on the same source, they don’t work the same way. They are often confused, but in reality they take different paths toward the same goal: turning solar radiation into the electricity we use every day.
 
In short, the main difference between solar thermal and photovoltaic energy lies in how each one converts the sun’s energy into electricity: photovoltaics uses light directly, whereas solar thermal harnesses the heat in solar radiation.
 
Photovoltaics is a technology that converts solar energy using solar panels. Its silicon panels capture the particles that make up light (photons) and convert them directly into electricity through the photovoltaic effect. It is an instantaneous physical process with no moving parts. Notably, the technology has advanced considerably in recent years, paving the way for new solutions built on more energy-efficient materials, such as perovskite, that are expanding its renewable potential.
 
Solar thermal energy, on the other hand, is known technically as concentrated solar power (CSP). Unlike photovoltaics, it does not convert sunlight directly into electricity. Instead, it concentrates solar radiation to generate heat, which is then used to produce electricity for a wide range of applications.
 
Whereas the silicon cells in conventional solar panels convert photons directly into electrons via the photovoltaic effect, solar thermal systems use fields of movable mirrors, such as heliostats or parabolic troughs, to concentrate solar radiation onto a receiver.
 
How does it work? As explained by IDAE, Spain’s Institute for Energy Diversification and Saving, the heat produced in this process is typically transferred to a fluid and then used to drive a turbine that generates electricity. That said, the two technologies also differ in cost-effectiveness and efficiency. Photovoltaics delivers better performance because its direct conversion process avoids intermediate losses and gives it greater durability.
 
In fact, unlike small-scale photovoltaic systems for residential self-consumption, the challenge with solar thermal technology is that it requires large tracts of land and substantial upfront investment. As a result, it is mainly deployed in large-scale power infrastructure projects and to supply heat for industrial processes.
 
Ultimately, the key difference between photovoltaics and solar thermal comes down to light versus heat. The former turns sunlight directly into electric current with nothing more than a static panel, while the latter relies on a more complex system of mirrors and mechanical turbines. This difference in processes helps explain why photovoltaics, rather than solar thermal, dominates the global energy landscape today.
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Puget Sound Energy in Bellevue, Wash., announced it has broken ground on its Battle Butte Solar Project, a 130 MW solar facility near Rapelje, MT.
Officials said the project will significantly contribute to the company’s clean energy goals. The project is expected to generate enough energy to power 20,000 homes each year. Located near PSE’s existing Beaver Creek wind facility in Stillwater County, MT, the facility is positioned to leverage existing transmission infrastructure.
“Battle Butte solar represents a critical component of our clean energy strategy,” Craig Pospisil, Senior Vice President and Chief Development Officer for PSE, said. “This project will give us the opportunity to build upon the positive relationships we’ve forged with our neighbors in Stillwater County through the development of the Beaver Creek Wind facility and it positions PSE to meet our customers’ growing clean energy needs.”
Since the 1970s, PSE has been a partner in Montana’s energy economy. The Battle Butte Solar Project is expected to generate positive economic impacts to the local community through construction and operational phases, while supporting regional economic development by putting more power on the grid. PSE anticipates the construction will require nearly 250 skilled workers, and a small number of permanent on-site staff for continuing operational support.
“We look forward to Battle Butte bringing construction jobs, tax revenue and new economic activity to Stillwater County while adding another important piece to Montana’s all-of-the-above energy portfolio,” Roger Webb, Stillwater County Commissioner, said. “Throughout the process of developing both Beaver Creek and Battle Butte, PSE has shown a commitment to working with our county and investing in Montana while being a good neighbor – we look forward to the ongoing partnership.”
Construction on the project is expected to start this fall and be completed in mid-2028.

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Small-scale solar photovoltaic generation in the United States has increased nearly fivefold over the past decade, rising from 18,812 gigawatt-hours (GWh) in 2016 to 92,979 GWh in 2025, according to the U.S. Energy Information Administration (EIA).
In an analysis published, the EIA attributes the growth to the expansion of rooftop solar capacity, with the four largest state producers — California, Arizona, Texas and Florida — benefiting from abundant solar resources. New York ranks fifth despite lower solar resources, supported by capacity growth, technology improvements and state incentives.
California was the largest producer of small-scale solar electricity in 2025, accounting for 37% of the U.S. total, or 34,411 GWh. Generation in the state increased by 8% year on year, largely due to capacity growth, with installed small-scale solar capacity rising from 18 gigawatts (GW) in 2024 to 20 GW in 2025.
Arizona ranked second, generating 5,795 GWh, equivalent to more than 6% of the national total. Its small-scale solar generation grew by 6% in 2025. The largest annual increase in the state occurred between 2022 and 2023, when generation rose by 22%. The EIA notes that Arizona offers customers a 25% state income-tax credit and other incentives for installing rooftop solar systems.
Texas and Florida have also recorded substantial growth over the past decade as additional capacity has been installed. Small-scale solar generation in Texas rose from 391 GWh in 2016 to 5,408 GWh in 2025. In Florida, it increased from 205 GWh to 5,198 GWh over the same period. Both states offer property tax exemptions and other incentive programmes, some of which are specific to individual states or utilities.
The EIA also highlights the role of incentive programmes in states with lower solar irradiance. New York, the fifth-largest producer of small-scale solar electricity, has supported deployment through incentives, while New Jersey, Massachusetts and Illinois also operate programmes aimed at encouraging rooftop solar adoption.
In California, changes to net energy metering policies partly explain the particularly strong growth recorded in 2022. U.S. small-scale solar generation increased by 25% that year amid record capacity growth. California’s Net Energy Metering (NEM) 2.0 programme, which offered higher compensation for electricity exported to the grid than the subsequent Net Billing Tariff, or NEM 3.0, remained available through April 2023. Capacity installed under NEM 2.0 was grandfathered in, encouraging installations before the new tariff took effect.
Despite the continued annual increase in small-scale solar generation, the EIA reports that the growth rate has declined since 2022.
The EIA defines small-scale solar as photovoltaic systems with a capacity of less than 1 megawatt (MW). Its estimates draw on surveys of electric utilities to collect data on the number of customers with small-scale solar systems and their aggregated capacity.
Because utilities do not necessarily know how much electricity rooftop solar systems generate across their distribution networks, the agency estimates generation using tools including the National Renewable Energy Laboratory’s System Advisor Model and PVWatts. The EIA also uses data on commonly applied tilt angles and orientations for small-scale solar systems in California as inputs to represent these characteristics in other states.
The analysis is based on the EIA’s Annual Electric Power Industry Report and was published in its Today in Energy series on 16 October 2026.
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WATKINS, Colo. — One of Colorado’s largest solar farms is coming to Adams County.
On Oct. 13, the county’s board of commissioners approved 2,800 acres in Watkins for the project, allowing Lightsource bp, a leading solar developer owned by British oil and gas giant BP, to use the land for the solar facility for the next 40 years.
The $675 million project, named Big Bronco Solar and Storage, will sit just east of Denver International Airport. It will include an 1,800-acre solar farm, a utility substation, a transmission line and a battery storage system. 
“Power from this project can easily flow into Denver, where most of Xcel's load is, without the need for Xcel to build costly new transmission or make costly transmission upgrades,” said Will Vaughan, a development manager for Renewables at Lightsource bp. “So this contributes to keeping everybody’s power prices lower.” 
The solar farm is expected to generate 300 megawatts of electricity — enough to power about 99,000 homes, according to the company. The battery system will store excess energy for later use and can deliver up to 300 megawatts of power.
A 2026 report released by Lazard finds that renewables remain the cheapest sources of new power generation, even without subsidies. Due to their relatively low costs and shorter construction times than natural gas, nuclear and coal plants, wind, solar and battery storage are expected to account for most new U.S. power sources in the coming years. 
Colorado reflects this national trend. In 2025, wind, solar and geothermal sources supplied about 44% of the state’s electricity. By 2030, Colorado aims to increase that share to more than 80%. 
Despite the Trump administration’s efforts to restrict the growth of renewable energy, the U.S. clean energy sector continues to boom. In 2025, wind and solar generated a record 17% of U.S. electricity. Wind power generation rose 3% from the previous year, while utility scale solar generation jumped 34%.
Some of the largest renewable energy projects, particularly wind, are concentrated in Colorado’s eastern plains. Kit Carson is home to eight wind farms and is becoming a giant hub for green energy, with two new projects under construction and a few more planned. The county generates 3.3 terawatt-hours (TWh) of electricity annually from wind power. 
Other wind projects in the eastern plains include Limon Wind Energy Center, a 600-megawatt wind farm in Limon that stretches across 104,000 acres and came online in 2014. It can power about 114,000 homes. The Niyol Wind Energy Center in Logan County is a 200-megawatt wind farm that came online in 2021 and generates enough electricity to power approximately 60,000 homes. 
Solar energy is also expanding across the region, with solar farms in Logan and Weld counties. Pueblo County in southern Colorado is a major solar hub, accounting for nearly half of the state’s solar farm acreage as of 2024.
Since 2010, the state has more than tripled renewable energy generation driven by the growth of wind farms on the Eastern Plains and solar installations across the state. Colorado became the fourth state to legalize small, plug-in solar systems, allowing residents to install up to four solar panels on balconies, patios and yards. The law takes effect Jan. 1, 2027.
The proposed Big Bronco Solar and Storage project would add to the state’s solar capacity. According to Lightsource bp, the project is expected to generate about $40 million in property tax revenue for Adams County special districts over its lifespan and employ up to 400 workers during peak construction, with many hired locally. 
There was no local opposition to the project during public hearings. 
Dennis Davis, who manages Davis Farm LLC, a 320-acre dryland farm north of the proposed site that has been in his family for five generations, said he supports the project.
“Farmers out there are at the whim of Mother Nature and Mother Nature’s been getting more and more cruel,” Davis said. “As a neighboring property, I feel it [the solar farm] would be a very positive use for the property.”
Adams County resident Charles Cipriani also voiced support for the project, but recommended a bond related to the decommissioning of the lithium iron phosphate cells of the batteries.
“It is not economically viable to recycle lithium iron phosphate cells and so someone will have to pay for it or it will not be done, so I would highly recommend that you have a bond in place,” Cipriani said at the public hearing. “It is environmentally exhaustive and unsafe to dispose of the batteries without property managing the recycling of them.” 
Adams County planners with the community and economic development department said it is something they will follow up on. 
A proposed 900-acre solar farm near Mesa Verde National Park is also facing scrutiny over battery storage. Some residents are concerned about the project’s size and the batteries’ proximity to the park and nearby communities, particularly following a January 2025 fire at a battery storage facility in Moss Landing, California. Though not a solar farm, the battery that caught fire stored electricity for later use. 
Construction for Big Bronco Solar and Storage is not expected to begin for another two years and the company is still seeking a buyer for the electricity the project would generate.
Site management will also play a role in how the project is developed, the company outlined in their development plan. Because the land was a former dryland farming area, Lightsource bp plans to restore native vegetation, manage erosion and conserve topsoil to protect the site during all project phases.
​​Lightsource bp operates two other large-scale solar projects in Colorado, both in Pueblo County. The company reports conserving more than 3,000 acres of native shortgrass prairie across the two sites. Bighorn Solar, a 300-megawatt facility, began operating in 2021, followed by the 293-megawatt Sun Mountain Solar facility in 2022.
Currently ​​Lightsource bp has 33 projects operating across 11 states.
Beulah residents navigate a ‘quadruple whammy’ of fire and floods
'The worst I've ever seen': Fourth-generation chile farmer reflects on a difficult growing season
Tarantula biologist finds research haven in southeastern Colorado
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The recently opened Carwash A27 in Nieuwegein is now operational with 274 kWp of solar panels and 964 kWh of battery storage. This combination is necessary to power the car wash, seven wash bays and fast chargers. This is despite the limited grid connection.
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The range of additional services available at car washes is growing. However, simply introducing an extra facility does not automatically mean that motorists will actually use it. Research shows that relevance, speed and clear pricing play a key role. For car wash operators, the challenge therefore lies not only in what they offer, but above…
Anyone who, like petrol station, charging point or car wash operators, works with a large number of installations knows that maintenance is vital. However, rather than carrying out repairs, it is even better to take action before anything goes wrong. And in this regard, more and more operators are turning to digital tools. Yet not…
The Avia Xpress station on Verzetslaan in Purmerend has won the 2026 Arie Keppler Prize. In addition to an unmanned petrol station, the service station also features car wash bays and a car repair workshop. The biennial prize is awarded to projects that contribute to the quality of the living environment in North Holland.
The third issue of Mobility Energy for 2026 focuses on digitalisation, a trend that is evident across all areas of the sector – from retail outlets to car washes and charging points. In this issue, we look at, amongst other things, the pros and cons of remote maintenance, the sales potential of the order kiosk…
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A research team in Germany has investigated whether compressive stress relaxation measurement (CSRM) can be used to monitor polymer degradation in aging photovoltaic modules. The technique is typically used in manufacturing quality control to assess the degree of encapsulant cross-linking after lamination.
“This publication uses the CSRM not only for lamination control, but also to monitor the mechanical response of the mini-modules’ rear side,” the researchers explained. “To achieve a higher resolution and sample throughput, the cross-linking density will be used to calibrate the CSRM. The influence of encapsulants and backsheet degradation on the CSRM during weathering is of interest. Therefore, the degradation of the encapsulant and the backsheet will be decoupled.”
CSRM is a non-destructive technique commonly used to assess encapsulant curing after PV module lamination. It involves pressing a tip into the rear surface of a module and measuring how the force decreases while the indentation depth remains constant. The response reflects the mechanical properties of both the encapsulant and the backsheet.
To evaluate CSRM as a method for monitoring aging, the researchers fabricated 200 mm × 200 mm mini-modules incorporating passivated emitter and rear contact (PERC) solar cells, ethylene vinyl acetate (EVA) encapsulants, and polyethylene/polyethylene terephthalate (PET) backsheets. They varied lamination times at 155 C to achieve different degrees of cross-linking.
For each CSRM measurement, they heated the test location to 89 C, pressed a 4 mm steel tip approximately 100 µm into the module’s rear surface, applied a force of less than 20 N, and recorded the decline in force while holding the tip in place.
The modules were subjected to damp heat (DH) testing at 85 C and 85% relative humidity for up to 3,500 hours, or combined heat and ultraviolet (UV) irradiation at 85 C, 60% relative humidity, and an irradiance of 227 W/m2 for up to 2,000 hours. At 250-hour intervals, the team used CSRM to monitor mechanical changes and measured the modules’ electrical performance. Additional solvent tests and thermal analyses helped distinguish changes in encapsulant cross-linking from backsheet degradation.
“After the first 250 h of the DH test, the encapsulants showed an increase in the degree of cross-linking but maintained differences between the samples throughout the test,” the researchers said. “As a result, the PV module power degradation correlated with the initial cross-linking state. By the end of the test, the encapsulant and the backsheet had degraded, resulting in a drop in the CSRM response.”
The results also showed that the encapsulant’s cross-linking density subsequently decreased, while the backsheet underwent post-crystallization and exhibited chain scission.
“The combined DH+UV weathering test caused post-cross-linking within the first 250 h, leading to leveling of the cross-linking states,” the researchers concluded. “The canceled chemical differences in the encapsulants became reflected in a similar module power degradation. Thus, overacceleration shall be avoided by all means to deliver realistic reliability predictions.”
The findings are presented in the study, “Non-destructive monitoring of polymer degradation in PV modules by compressive stress relaxation measurement and implications for the PV module reliability,” published in Polymer Testing. The research team included scientists from Germany’s Anhalt University of Applied Sciences and Fraunhofer CSP.
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Thursday, October 29, 2026
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This week on Projects Weekly, Distributed Energy Infrastructure is celebrating the cranberry harvest at two Massachusetts-based agrivoltaics projects. Also in the Bay State, Flatiron Energy has closed on financing of a gigawatt-scale battery project in the Boston area. A solar financing spree is taking place around the U.S., with energyRe inking a deal for $815 million in South Carolina, and Arevon securing three 20-year renewable energy credit contracts in Illinois. Aligned Climate Capital has also secured financing for a community solar portfolio split between Maryland and Illinois once again, and Clearway Energy Group and PacifiCorp have signed an addition to their Utah partnership worth 210 MW in battery storage. Finally, Puget Sound Energy is working on one of the largest solar installations in the state of Montana. Keep reading for all the details!

energyRe inks $815 million solar financing deal in South Carolina

Energy infrastructure firm energyRe has closed financing on an $815 million financing package for a collection of five utility-scale projects based in South Carolina, officials announced Oct. 12.
Totaling 360 MW, the five-project portfolio’s price tag marks one of the largest solar-only financing deals in the history of the Palmetto State. The financing package is “a giant step” toward energyRe’s established goal of turning the southern state into the lynchpin of its corporate growth strategy.
“This portfolio financing is our largest to date, and it reflects the confidence our lenders have in both the quality of our assets and our team’s ability to deliver,” says energyRe CFO Pedro Pereira. “South Carolina is at the center of our growth strategy, and this closing moves us meaningfully closer to our goal of investing $2 billion in the state by 2030. These projects will create jobs during construction and operations and deliver affordable, reliable power to South Carolina homes and businesses for decades to come.”
Bright spot: energyRe has broken ground on about 450 MW of renewable energy projects in the past year, with an additional 700 MW either in operation or in late-stage development. The company sports a total portfolio of more than 1.8 GW, which spans 20 projects across the Carolinas, Nebraska, and Oklahoma.
In total, energyRe has raised more than $1.9 billion in support of its solar portfolio since its founding.
“This financing secures the capital to advance these projects and demonstrates energyRe’s ability to finance its development portfolio at scale,” says Surya Mohan, SVP of M&A and capital markets at energyRe. “I’m proud of our M&A and Capital Markets team for leading this transaction, and grateful to our lenders, tax equity partner, advisors and colleagues across energyRe for the work that brought it together.”

Clearway and PacifiCorp add onto partnership with 210 MW BESS project in Utah

Renewable energy project developer Clearway Energy Group and electrical utility PacifiCorp have expanded their partnership, signing a deal for an extra 210 MW battery storage addition to Clearway’s Honeycomb Energy Center.
Located in southern Utah, the new storage capacity will help the Beehive State balance its electrical grid for supply and demand. The energy center’s $400 million price tag will see funding from a consortium of major banks which will invest in the project upon commercial operation, including U.S. Bank and NordLB.
“We’re proud to expand our Honeycomb storage portfolio in partnership with PacifiCorp to support Utah’s growing economy,” says Valerie Wooley, SVP of origination at Clearway. “This new energy storage infrastructure will help ensure grid and cost resiliency as power demand grows in the region.”
Bright spot: The new energy contract with Pacificorp will enable three new energy storage facilities to advance Honeycomb’s “second phase,” Clearway says. In total, the new project will push Clearway’s Utah-based storage fleet to seven systems, capable of deploying 2.1 GWh.
“Clearway Energy has become an important part of Beaver County’s growing energy economy, bringing investment, jobs, and new revenue that benefits our communities and residents,” says Matt Sterzer, the economic development manager of Beaver County, Utah.

Arevon locks in three 20-year renewable energy credit contracts in Illinois

Arevon Energy is advancing its efforts in the Land of Lincoln, securing three 20-year Indexed Renewable Energy Credit (REC) contracts for its 275 MWdc Panther Energy Project in southern Illinois.
The agreements with Ameren Illinois, ComEd, and MidAmerican Energy will support the Midwestern state’s energy transition efforts, as well as the Panther project. Arevon expects to begin construction on the project in 2027, with commercial operations planned for 2028.
“Arevon is proud to work with Ameren Illinois, ComEd, and MidAmerican through the IPA procurement to move Panther Energy closer to construction and contribute to Illinois’s energy goals,” says Arevon CCO Tommy Greer. “We appreciate the collaboration of Perry County residents, landowners, and local officials throughout the project’s development.
“We look forward to delivering reliable, homegrown energy to the grid while creating jobs, generating long-term economic benefits, and investing in the local community.”
Bright spot: Arevon is actively growing its portfolio in the Midwest region of the U.S., with the Panther Energy Project expected to create 200 jobs during construction. Once operational, the firm expects the Panther project to generate enough electricity to power 37,000 Illinoisan homes each year.
Arevon has also established a local office in Pinckneyville, Illinois, allowing landowners, residents, and other community members direct access to the project development team.

DEI celebrates cranberry harvest at Massachusetts agrivoltaics projects

Utility-scale EPC provider Distributed Energy Infrastructure (DEI) is celebrating a successful harvest at two cranberry agrivoltaics projects in Massachusetts.
Owned by developer Greenbacker Renewables, the two projects are the first of their kind, DEI says. The North Carolinian firm says the projects are “a milestone for expanding agrivoltaic applications into challenging wetland environments.”
“Building solar projects over active perennial wetland crops was an exciting challenge, and we’re thrilled to see the success of these harvests,” says Prateek Tare, EVP and co-founder of DEI. “Iain’s collaboration and input at every stage was essential for us to ensure a reliable, cost-effective build while safeguarding the productivity of these heritage bogs.”
Bright spot: The two projects — Black Cat Agrivoltaics in Plymouth, Massachusetts, and Ring Road Agrivoltaics in Kingston, Massachusetts — come in at 1 MW and 4.4 MW respectively. Ring Road also comes equipped with a 13.5 MWh battery system, and Black Cat has an installed energy capacity of 2.7 MWh.
“The DEI team was phenomenal at understanding and adapting solar construction so that energy production could coexist without damage to the perennial cropping system,” says Massachusetts-based cranberry farmer Iain Ward. “These projects prove that with the right approach, dual-use solar can be applied to a wide variety of agricultural environments.
“If we can build over such challenging wetland areas and have successful harvests, we can build almost anywhere.”

Flatiron Energy closes on Boston-based battery project

Flatiron Energy has closed on approximately $850 million in financing commitments for its Energizar Project, located in Chelsea, Massachusetts.
Bright spot: At 1.2 GWh of battery storage, Energizar will be the largest battery energy storage system (BESS) asset on the East Coast of the U.S. once complete. That wattage is also enough to make Energizar one of the largest urban BESS facilities on the planet, as it provides “critical capacity” and energy resources for the city of Boston’s power grid.
“Energizar represents the culmination of years of work by many stakeholders. Projects of this complexity and scale only happen because of the support of the local community, policy makers, equipment and EPC providers, offtakers, and financing counterparties,” says Flatiron CFO Dan Myers. “We are incredibly grateful for such robust support and proud to contribute to the next phase of the region’s grid reliability and capacity resources.”
Flatiron expects Energizar to reach full commercial operation by Q4 2027, providing peaking energy resources for a Northeast grid that continues to undergo record levels of strain.
“Battery storage assets are playing an increasingly critical role in supporting grid stability and facilitating the integration of energy resources across the United States,” says Santander managing director Andrew Platt. “We are proud to have supported the successful financing of Energizar, an important milestone for the ISO New England market that will contribute to a more reliable and resilient power system.”

Aligned Climate Capital secures financing for community solar portfolio

Renewable energy investment firm Aligned Climate Capital has closed on $387 million in construction-to-permanent financing for a community solar portfolio spanning 20 projects in Illinois and Maryland.
Led by Apterra Infrastructure Capital, the financing will support a 126 MW portfolio in total, according to Aligned Climate Capital officials. The lion’s share of the portfolio will be comprised of projects across Illinois, with 18 sites and 115 MWdc going to the Prairie State. The other two sites, good for 11 MWdc, will go to Maryland.
“We’re seeing an important shift in distributed energy,” says Aligned Climate Capital CEO Peter Davidson. “Individual projects may be too small for traditional infrastructure investors. But when you bring those projects together into a larger portfolio, you can attract institutional financing that would otherwise be difficult to access. That helps move more projects from development into operation.”
Bright spot: The two Maryland-based projects will participate in the state’s Community Solar Energy Generating Systems program, officials say. The program reserves “at least 40%” of each project’s capacity for low- and moderate-incoming community solar subscribers.
“Community solar is an important and fast-growing part of the distributed generation market, and this portfolio benefits from scale, contracted revenue, and experienced sponsorship,” says Apterra co-CEO Ralph Cho. “We are pleased to lead this facility for Aligned as it brings these projects online across Illinois and Maryland.”

Puget Sound Energy announces development of new project in Montana

Puget Sound Energy (PSE) has broken ground on the Battle Butte Solar Project, a new 130 MW solar facility in southern central Montana.
Located near the small town of Rapelje, the project will be one of the largest solar installations in Montana once complete. Strategically located to leverage existing grid interconnection infrastructure, the project will generate enough energy to power 20,000 homes every year, PSE representatives say.
“Battle Butte solar represents a critical component of our clean energy strategy,” says Craig Pospisil, SVP and chief development officer of PSE. “This project will give us the opportunity to build upon the positive relationships we’ve forged with our neighbors in Stillwater County through the development of the Beaver Creek Wind facility and it positions PSE to meet our customers’ growing clean energy needs.”
Bright spot: PSE has already eliminated coal from its energy portfolio, going renewables-forward at the end of 2025. The company has also added 22 long-term renewable energy projects totaling 4 GW since the state of Washington passed the Clean Energy Transformation Act in 2019.
The new project’s construction will create about 250 jobs in the Treasure State, representatives say. Additionally, PSE anticipates an ongoing need for a few on-site staffers once operations commence. Both of these, the company adds, will help the project generate benefits through project spending, impact fees, and property taxes for the region.
“We look forward to Battle Butte bringing construction jobs, tax revenue and new economic activity to Stillwater County while adding another important piece to Montana’s all-of-the-above energy portfolio,” says Stillwater County Commissioner Roger Webb. “Throughout the process of developing both Beaver Creek and Battle Butte, PSE has shown a commitment to working with our county and investing in Montana while being a good neighbor – we look forward to the ongoing partnership.” 

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20 Oct 2026
Author: Nibal Zgheib
The European Bank for Reconstruction and Development (EBRD) is strengthening Egypt’s renewable energy capacity and energy security by helping to finance a new large-scale solar power plant and battery energy storage system (BESS) in Minya. The facility is set to become the largest solar power plant in Egypt and Africa, with a capacity of 1.2 GW.
The Bank is arranging a loan of up to US$ 265 million (€232 million) to Nefer Menya for Renewable Energy S.A.E. (Nefer Menya), a special purpose vehicle owned by Infinity Power and HAU Energy B.V. The funding will consist of a US$ 160 million (€140.1 million) A-loan from the EBRD’s own funds, a US$ 75 million (€65.7 million) B-loan mobilised from Bank of Jordan and up to US$ 30 million (€26.3 million) in concessional financing from the CIF Clean Technology Fund (CTF) under its Global Energy Storage Program.
Nefer Menya is being co-financed by German development finance institution DEG, the Dutch Entrepreneurial Development Bank (FMO) and France’s Proparco as part of an aggregate debt financing package of up to US$ 566 million (€494.7 million).
The funds to Nefer Menya will be used for the construction and operation of a 1.2 GW solar power plant with a 600 MWh BESS, one of Egypt’s first projects to combine large-scale solar generation with battery storage. The battery system will store solar power generated during the day for use during peak demand after sunset, helping to strengthen grid stability and reliability.
Electricity will be sold to the Egyptian Electricity Transmission Company under a 25-year power purchase agreement, providing clean, renewable power at a lower cost than conventional generation. The project is expected to avoid more than 1.5 million tonnes of CO2 emissions per year and to power more than 1.4 million homes.
The investment supports the EBRD-led Energy Pillar of Egypt’s flagship Nexus of Water, Food and Energy, launched at COP27. The initiative aims to facilitate 10 GW of new private-sector renewable energy capacity while cutting 5 GW of inefficient fossil-fuel capacity.
Infinity Power, a joint venture established in 2019 by Infinity and Masdar, is Africa’s largest pure-play renewable energy provider. The EBRD holds an equity stake in Infinity Power. HAU Energy B.V. was established in 2024 to develop renewable energy projects in Egypt and is owned by Meridiam, Hassan Allam Utilities and the EBRD.
In addition to the concessional loan, the CTF will provide technical cooperation funding to introduce two nationally accredited technical training programmes focused on green skills for young labour-market entrants in Minya governorate, equipping them with future-ready skills and enhancing their employability in Egypt’s growing renewable energy sector. The CTF funding will also help Hassan Allam Utilities to strengthen its human resources policies and practices, embed gender equality into its workforce management strategy and enhance women’s access to technical and leadership roles in the traditionally male-dominated energy sector.
Aida Sitdikova, EBRD Director of Sustainable Infrastructure in the Middle East and Africa, said: “The EBRD is proud to lead the financing of this landmark 1.2 GW solar PV and 600 MWh battery storage project, the largest in Egypt and Africa to date. Egypt continues to be a trailblazer in large-scale renewable energy deployment at affordable prices. By combining solar generation with utility-scale battery storage, this project will strengthen the country’s energy security and enhance grid resilience. We are delighted to partner once again with Infinity Power and Hassan Allam Utilities to support Egypt’s ambitious energy transition goals.”
Samer Mirai, Regional Head of Corpoate Banking and Syndications of Bank of Jordan, said: “The Bank is proud to partner with the EBRD in financing this landmark renewable energy project, an important step in advancing Egypt’s energy transition and strengthening energy security. Our participation as both a B-loan lender and original hedge counterparty reflects our strong partnership with the EBRD and our growing role in supporting strategic, large-scale sustainable infrastructure across the region. The transaction is closely aligned with Bank of Jordan’s sustainability and green finance strategy, and reinforces our commitment to mobilising capital towards projects that contribute to a more sustainable and resilient energy future.”
Eng. Nayer Fouad, Co-Founder and CEO of Infinity Power, said: “This landmark financing reflects strong confidence in Egypt’s renewable energy sector and Infinity Power’s ability to deliver large-scale clean energy infrastructure. As the largest solar PV project in Egypt and Africa, paired with one of the country’s first utility-scale battery energy storage systems, Nefer Menya will strengthen energy security, enhance grid resilience and support Egypt’s transition to a low-carbon economy. Together with HAU Energy and our financing partners, we are proud to deliver this flagship project as we advance towards our goal of 10 GW of operational renewable energy capacity by 2032 and expand access to affordable, reliable clean energy across Africa.”
Dalia Wahba, CEO of Hassan Allam Utilities, said: “Securing this financing package shows what strong partnerships can achieve in mobilising capital for transformative energy infrastructure. Egypt has set a clear ambition to generate 42 per cent of its electricity from renewable sources by 2030, and Hassan Allam Utilities is committed to helping drive that agenda by delivering green, reliable infrastructure across the country. Through HAU Energy, alongside Infinity Power and our financing partners, we are combining large-scale solar generation with battery storage to provide clean power that is available when the grid needs it most. Every megawatt-hour we produce reduces reliance on imported fuel, strengthens Egypt’s energy security and builds a more competitive foundation for sustainable growth.”
The EBRD is a leading institutional investor in Egypt. Since starting operations there in 2012, it has invested more than €16 billion through 238 projects.

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1.2 GW plant and 600 MWh battery storage to strengthen energy security
20 Oct 2026
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We estimate that U.S. generation from small-scale or rooftop solar photovoltaic systems (smaller than 1 megawatt of capacity) has increased from 18,812 gigawatthours (GWh) to 92,979 GWh over the last decade. The four states with the highest generation of small-scale solar in the country—California, Arizona, Texas, and Florida—are in regions with more abundant solar resources. Even though it is in a region with lower solar resources, New York ranks as the fifth-largest rooftop solar generation producer as a result of capacity growth supported by technology improvements and state incentives.
The year-over-year change in generation was particularly high in 2022, when total generation grew by 25% compared with the previous year amid record capacity growth. Changes in different programs supporting rooftop solar partly explain this increase in generation. For example, California’s Net Energy Metering (NEM) 2.0 program was available through April 2023. This net metering program offered higher export compensation than the subsequent Net Billing Tariff, or NEM 3.0. All the capacity built under the NEM 2.0 program was grandfathered in, incentivizing higher capacity installation before the current NEM 3.0 took effect.
California accounted for 37% (34,411 GWh) of total U.S. small-scale solar generation in 2025. Between 2024 and 2025, rooftop solar generation in the state grew by 8%, largely due to an increase in capacity. Small-scale solar capacity in California increased from 18 gigawatts in 2024 to 20 gigawatts in 2025.
The state with the next largest amount of small-scale solar power generation is Arizona, accounting for over 6% of total U.S. generation, or 5,795 GWh. Year-over-year generation in Arizona grew only 6% in 2025. The largest increase happened between 2022 and 2023 when generation from small-scale solar grew by 22% in the state. Arizona customers can access a 25% state income-tax credit and other incentives for adding rooftop solar to their properties.
States such as Florida and Texas have seen rapid growth in small-scale solar generation in the last decade as more capacity has been added. Generation in Texas grew from 391 GWh in 2016 to 5,408 GWh last year. Over the same period, Florida’s generation grew from 205 GWh in 2016 to 5,198 GWh in 2025. These two states provide incentives through property tax exemptions and other programs specific to each state and, in some cases, utility.
Programs in states with lower irradiance levels are also supporting growth in rooftop solar generation. New York offers incentives, which have encouraged small-scale solar growth in the state. Other states with similar programs include New Jersey, Massachusetts, and Illinois.
Although generation from small-scale solar continues to grow year over year, the rate of growth has declined since 2022.
EIA uses its surveys of electric utilities to collect information on the number of customers with small-scale solar systems and the aggregated capacity. Electric utilities do not necessarily know how much electricity is generated by rooftop solar on their distribution systems, so generation must be estimated. To develop estimates of generation, we rely on tools such as the National Renewable Energy Laboratory’s System Advisor Model and PVWatts. Data on commonly used tilt angles and orientations for small-scale solar systems in California were used as inputs to be representative of tilt angles and orientations in other states.
Article from Today in Energy. Principal contributors: Lindsay Aramayo, Marc Harnish
The EIA collects, analyzes, and disseminates independent and impartial energy information to promote sound policymaking, efficient markets, and public understanding of energy and its interaction with the economy and the environment.
US Energy Information Administration has 353 posts and counting. See all posts by US Energy Information Administration

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Whether I’m camping or off the grid, a portable power station is my preferred way to stay charged up. But eventually, the battery runs out. I’ve found that one of the best ways to recharge small tech gadgets is with a solar panel. The exceptionally lightweight and portable Jackery SolarSaga 40W Air has become my favorite tool for keeping my phone and essential devices topped off off-grid.
Unlike power banks, solar panels don’t store power; they convert sunlight into usable energy in real time. Weighing under two pounds and folding down to the footprint of a book, this panel is built specifically for portability. It features a rugged IP68 waterproof rating, operates in extreme temperatures, and has direct USB-A and USB-C charging ports, making it an ideal companion for backpackers, campers, and field creators who need reliable power without added weight.
This ultra-portable solar panel folds down to the size of a book. It’s a great option for charging small devices, like a phone, while camping or hiking. In a pinch, it can also recharge small portable power stations and power banks, but it’ll be slow.
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Unlike most rigid and bulky solar panels, the Jackery SolarSaga 40W Air consists of four panels that fold down to a portable size — about 1 inch thick, with the footprint of a standard sheet of paper — that easily slips into a backpack. It only weighs about two pounds, and it comes with four mounting rivets and two carabiners to hang it off a backpack while hiking or attach it to the side of a tent while camping. Since it’s only about three feet long when unfolded, it sits well on my backpack without getting in the way.
On top of its portability, Jackery made this solar panel a cinch to use. Jackery included a solar charging cable with both a USB-A and USB-C port inside the box that can directly recharge devices from the solar panel, like phones, camera batteries, flashlights, and portable speakers. There’s also an adapter to recharge Jackery power stations via the solar panel and an accessory pouch to hold the cables.
Jackery added a bullseye indicator to the solar panel to help get maximum sun exposure. Once the shaded dot lands in the middle of the bullseye, you know the panel is positioned correctly to maximize sun exposure and will deliver the highest wattage output. While it has the rivets for hanging, it doesn’t have a kickstand to angle it in the sun. I typically draped it over a camping chair or found something sturdy to prop it up.
The SolarSaga 40W Air gets bonus points for being a bifacial model. Instead of absorbing light only from the front, the solar panel can absorb sunlight from both sides to deliver maximum power. Light reflected off the ground, snow, or surroundings can help to get the maximum 40 watts.
As long as you have access to full sun, the SolarSaga will pull in 40 watts of power. That’s enough to recharge smaller gadgets in almost the same amount of time as it would take with standard wall power at home. The USB-C port outputs up to 15W and the USB-A port up to 12W. On the SolarSaga, my Google Pixel 8 recharged in about 100 minutes—only 20 minutes slower than plugging into a standard wall outlet at home.
Many small devices need under 40W, like e-readers, earbuds, and camping accessories like walkie-talkies. Bigger tech items like laptops or more powerful phones like the iPhone 17 Pro need more than 40W for fast charging. Using only 40W from the Jackery will result in longer recharge times compared to plugging into a wall outlet. Instead, I use the solar panel to charge a portable power bank that can power higher-wattage devices like laptops.
The most obvious drawback is the maximum 40W input. This low amount is suitable for recharging small devices but struggles with larger ones. When testing the solar panel, it recharged my phone in the same amount of time as when plugged into the wall. It was a different story when I went to recharge the Jackery Explorer 600 Plus portable power station, which has a capacity of 632Wh. With the full 40W of solar input, it would take 15 hours to charge from 26% battery capacity back to 100% in direct sunlight. However, the Explorer 600 Plus is designed for a more powerful solar panel. It’s rated to recharge from 0 to 100% in four hours with a 200W solar panel.
My other complaint about the SolarSaga 40W Air is that the solar panel itself gets hot to the touch when left out in the sun. At times, it’s been hard for me to fold it up and touch the metal snaps to pack it up. That happened even after it sat in the intense Georgia sun for only about 15 minutes.
To test the Jackery SolarSaga 40W Air, I packed it along for a weekend camping trip and a day hike at my local park and have continued to use it on three camping trips. I also used it as much as possible outside, in the yard, to check recharge times and power input. I was happy to find that the panel could easily draw the stated 40W when I placed it in full sun. Even when the bullseye was slightly misaligned, I could get about 38W of input.
I used the panel to recharge my phone, portable power stations, a device aimed at repelling mosquitoes, and an Ember mug.
The $80 Anker PS30 solar panel is a more affordable alternative. The dimensions and weight are almost identical to the $109 Jackery SolarSaga 40W Air, but the Anker has a smaller input, maxing out at 30W.
But if you don’t need a solar panel small enough to fit in a backpack, going with a larger, higher-output model might make more sense. The Jackery SolarSaga 100 Air offers over twice the solar input wattage but is still small and light enough to take camping or pack along on an RV trip.
If you’re not planning to travel with a solar panel and instead want one for your emergency kit or for use in the yard, even larger models, such as 200W or 400W, offer better performance. As a general rule of thumb, the more power a solar panel can provide, the more expensive it is. Larger panels also don’t support USB-A or USB-C charging directly, which is what gives the Solar Saga 40W Air an edge for small devices.
With a focus on durability and portability, I love packing along the Jackery SolarSaga 40W Air on outdoor adventures. It’s small enough to tuck into my backpack, and powerful enough to recharge my phone with sunlight. Plus, it’s much lighter than packing a power bank or a portable power station.
Buy if: you need a lightweight, compact way to recharge small devices. It also works well for recharging larger items like portable power stations as long as you’re not in a hurry.
Skip if you don’t need a compact solar panel; you can get a larger, more powerful model for a similar price. For example, the 100W Renogy solar panel costs $124.99 and delivers over twice the power and recharge capacity.
Beyond smartphones, the panel’s 40W output and direct USB-A and USB-C ports can power small trail electronics like handheld GPS units, satellite messengers, smartwatches, headlamps, camera batteries, e-readers, headphones, and camping fans. It’s also ideal for topping off small 10,000-20,000 mAh power banks during the day to power larger devices later.
The Jackery SolarSaga 40W Air comes with an IP68 rating, meaning it’s both water- and dust-proof. It’ll be fine to leave outside and be exposed to morning dew or rain. It’s also fine in humid environments. However, it’s not suitable for submersion in water, and it will not charge if there is cloud cover and no direct sunlight.

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Sunrun is sliding toward a one-year low while the broader market climbs, and with earnings weeks away the question is whether the stock can hold before the next catalyst arrives.
Market Movers desk. Editor: David Moadel.

Selling in solar names is concentrating on Sunrun (NASDAQ:RUN), the home solar and battery provider that’s falling harder than the rest of its sector. Sunrun stock is at $6.93, down 5% this afternoon after touching $6.91, its lowest price of the past year.
Meanwhile, Enphase Energy (NASDAQ:ENPH | ENPH Price Prediction) stock is down 1% to $30.30, a far softer slide than the one hitting Sunrun stock. First Solar (NASDAQ:FSLR) shares are down 1% to $170.70, moving in step with Enphase Energy stock.
The Invesco Solar ETF (NYSEARCA:TAN) is down 2%, showing that the weakness extends across the solar group. Against that background, the SPDR S&P 500 ETF Trust (NYSEARCA:SPY) is up 0.6%, leaving solar out of step with a rising broad market.
Sunrun stock is falling harder than Enphase Energy stock, First Solar shares and the Invesco Solar ETF, which sets its move apart from the sector’s broader slip. No fresh press release from Sunrun accompanied the decline, so the stock’s own trend carries more weight in reading the move. That makes the Q3 2026 results Sunrun is scheduled to report in early November the next clear checkpoint.
The three companies earn money differently, which explains why they don’t always trade in tandem: Sunrun installs home solar and battery systems, largely under long-term leases it finances, while Enphase Energy sells microinverters and First Solar makes utility-scale panels. Sunrun’s economics therefore hinge on borrowing costs as well as on what homeowners will sign.
For Sunrun, the no-upfront-cost subscription model is sold through power purchase agreements, leases and direct purchases. It is funded by non-recourse asset-level debt securitizations, tax equity partnerships and investment tax credit transfers, so higher capital costs flow straight into unit economics.
Customer agreements generate the recurring revenue that supports Sunrun’s business. Meanwhile, a third-party asset sale arrangement has driven rapid growth in product sales.
Home solar has faced softer residential demand and tariff and trade policy uncertainty on panels and batteries, along with the expiration of the federal Section 25D residential clean energy tax credit and modifications under the One Big Beautiful Bill Act of 2025. Net metering changes remain another risk.
Facing that pressure, Sunrun trimmed its full-year outlook for subscriber value and cash generation, citing softer affiliate channel volumes and a slower-than-expected direct sales ramp. Management expects its expanded sales force to reach full productivity, which it says would let the company exit the year at a robust growth rate with higher unit margins.
Battery storage is the brighter spot for Sunrun, which describes itself as America’s largest provider of home battery storage and cites strong customer demand for storage-first offerings. Its distributed fleet also supplies on-demand dispatchable power through distributed power plant programs for utilities and hyperscalers. Beyond that, Sunrun is piloting a distributed AI data center program that places compute nodes in customer homes.
Sunrun’s early November results may indicate if the expanded sales force is reaching full productivity. A steadier read on subscriber additions and cash generation could help Sunrun shares find stronger ground.
It’s worth tracking whether Sunrun stock holds its one-year low before the report, and keeping position sizes modest. Strong home battery interest and new grid programs offer a credible upside case, but policy and demand risks weigh heavily on Sunrun shares.
Contact [email protected] for any questions or corrections.
David Moadel is financial writer specializing in stocks, ETFs, options, precious metals, and Bitcoin. David has written well over 1,000 articles for leading online publications, helping investors understand markets, income strategies, and risk.His work has appeared in The Motley Fool, InvestorPlace, U.S. News & World Report, TipRanks, ValueWalk, Benzinga, Market Realist, TalkMarkets, Finmasters, 24/7 Wall St., and others.With a master’s degree in education, David has taught at the elementary, high school, and college levels. That teaching background shapes his writing style: clear, educational, and practical. David has also built a loyal social-media audience by providing trustworthy financial content on YouTube, X/Twitter, and StockTwits.
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LONDON, Oct. 19, 2026 /PRNewswire/ — The global perovskite solar cell market was valued at USD 58.2 million in 2025 and is projected to reach USD 1.73 billion by 2035, according to Credence Research. The report states a 40.41% compound annual growth rate for 2025-2035. Asia Pacific held the largest regional share at 70.0% in 2025, while North America is the fastest-growing region at a modeled 47.00% annual rate. Market sizes, segment shares and regional allocations are Credence Research estimates.
Key Takeaways
Scope & Segmentation – Perovskite Solar Cell Market
The market counts manufacturer selling value of single-junction perovskite modules and tandem products combining perovskite with silicon or other photovoltaic materials. It includes rigid, flexible and lightweight products used in utility projects, rooftops, building-integrated photovoltaics and specialized devices. It excludes conventional silicon modules, raw precursors, coating tools, licensing fees and research grants.
Read the full report and request a sample:  https://www.credenceresearch.com/report/perovskite-solar-cell-market 
Why This Report Matters
Market Overview
Perovskite materials can absorb light in a thin layer and be paired with silicon to improve the conversion efficiency of solar cells. The market is emerging from research and pilot production toward limited commercial orders, especially for tandem modules and specialty building surfaces.
Higher conversion efficiency can increase output from space-constrained rooftops and facades. Yet durability, moisture resistance, heat stability and long-term warranty support remain decisive for lenders and utility-scale buyers. A laboratory cell record does not by itself demonstrate a bankable 25-year field product.
Market Insights
Key Attributes
Attribute
Details
Historical reference
2018-2025 (source report)
Base year
2025
Market size, 2025
USD 58.2 million
Market size, 2026 (source estimate)
USD 80.3 million
Market size, 2035
USD 1.73 billion
Reported CAGR and measurement interval
40.41% (2025-2035)
Largest regional share
Asia Pacific (70.0%, 2025)
Fastest-growing region
North America (47.00%)
Segments covered
Cell and module type, Application
Geographic coverage
North America, Europe, Asia Pacific, Latin America, Middle East and Africa
Market Segmentation
The segmentation below follows the current report taxonomy and separates products, applications and buyers to avoid overlapping revenue definitions.
Market Drivers
Tandem designs capture more of the solar spectrum than conventional single-junction silicon cells. This creates a potential output advantage where roof or land area is constrained, although certified module performance must translate into real-world energy yield.
Chinese manufacturers have invested in early perovskite lines and demonstration projects. Large silicon manufacturers are evaluating tandem upgrades that could reuse parts of established production and distribution networks.
Third-party stress testing and intellectual property licensing can make commercialization easier by giving buyers more confidence in product durability and manufacturers clearer routes to scale.
Regional Analysis
The following regional shares represent Credence Research estimates of 2025 market value. They are not independently audited supplier sales totals.
Asia Pacific | 70.0% share in 2025
China hosts several early commercial lines and utility demonstration fields, while Japan and South Korea contribute research and flexible-module programs.
Europe | 15.5% share in 2025
Germany and other European markets support tandem pilot lines, intellectual property development and building-integrated applications.
North America | 11.2% share in 2025
Domestic module initiatives and specialty rooftop uses support the fastest modeled growth from a smaller base.
Middle East and Africa | 2.4% share in 2025
High-temperature outdoor testing and utility pilots assess durability under demanding solar conditions.
Latin America | 0.9% share in 2025
Early pilot projects in Brazil, Chile and Mexico create a small commercial base for future deployments.
Market Challenges
Perovskite cells can degrade under moisture, heat and prolonged exposure to sunlight. Commercial adoption requires long-duration field data and warranties that financiers consider credible.
Lead-containing chemistries raise encapsulation, handling and end-of-life recycling questions. Low-cost crystalline silicon modules also limit the price premium that early perovskite products can command.
Future Outlook
Tandem products are likely to gain commercial traction before stand-alone perovskite modules become a mass-market substitute for silicon. Large manufacturers with certification, warranty capacity and distribution channels have advantages.
The market forecast remains sensitive to module lifetime, production yield, intellectual property access and project finance. Early high growth comes from a very small revenue base and should not be interpreted as evidence of broad grid-scale deployment today.
Competitive Landscape
The supplier landscape includes perovskite specialists such as Oxford PV, UtmoLight, Microquanta and GCL Perovskite, alongside established photovoltaic manufacturers including LONGi, Qcells and Trina Solar. Caelux develops perovskite-coated glass for tandem applications. These businesses occupy different stages of commercialization; research records and announced capacity should not be treated as realized market sales. A reliable company revenue ranking is not available from comparable public disclosures, so the release does not assign individual supplier shares.
Key Players
Recent Developments
April 9, 2025: Oxford PV and Trinasolar announced an exclusive patent licensing agreement covering the manufacture or sale of perovskite photovoltaic products in China, with sublicensing rights.
May 2025: The Credence Research report records that Qcells tandem modules passed specified IEC and UL stress-test sequences. This is presented as a report-sourced milestone, not independent proof of a 25-year service life.  
Report Coverage
The study analyzes market size, the base-year product and application mix, regional demand, technology adoption, competitive positioning, constraints and dated industry developments. It also examines commercialization, customer economics and the factors that could change the pace of adoption through 2035.
Forecasts and regional shares are proprietary Credence Research model estimates. Company announcements and regulatory materials are used for industry context; they do not independently validate the modeled global revenue totals. The report’s market definition and exclusions should be considered when comparing it with broader adjacent industries.
Read the full report and request a sample:  https://www.credenceresearch.com/report/perovskite-solar-cell-market 
Related Reports
About Us
Credence Research Inc. is a global market intelligence and consulting firm founded in 2015. It provides quantitative market research, competitive intelligence and strategic advisory services to organizations assessing new products, investment decisions and regional opportunities. The firm combines primary and secondary research with industry interviews and structured market models.
Its research spans industrial technology, semiconductors, energy, health care, consumer markets and other sectors. Credence Research evaluates market size, segmentation, growth drivers, supply-chain risks, regional policy and competitive positioning to help clients make evidence-led decisions.
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Website: Credence Research
The global 3d tsv and 2.5d market was valued at USD 9.46 billion in 2025 and is projected to reach USD 21.50 billion by 2035, according to Credence…
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The San Joaquin kit fox has adapted to residing alongside solar panels in California’s San Joaquin Valley. Researchers discovered that a purposely designed gap in the fencing permits safe access for the foxes while keeping larger predators at bay. Their studies indicate that the survival rates and home ranges of these foxes are comparable to those in nearby habitats, highlighting the viability of renewable energy coexistence with wildlife.
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“Formula rate plans have resulted in large rate increases with very few rate decreases.”
Photo Credit: iStock
Arizona Southwest Gas customers could face another increase. The utility has asked state regulators to approve a $101 million hike that would raise residential bills by almost 10.5%, according to the Energy and Policy Institute. 
The request follows the Arizona Corporation Commission’s approval of a 7.5% increase.
In the same filing, Southwest Gas seeks to raise its authorized return on equity from the 9.47% the commission approved in 2025 to 10.25%.
Because Southwest Gas hasn’t had an Arizona rate case since the Arizona Corporation Commission adopted its 2024 policy statement on formula rates, the company is now asking to use that mechanism. 
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Consumer advocates argue the approach could allow rates to change more often between major rate cases while reducing oversight.
“A formula rate plan uses a pre-approved formula to adjust base rates between general rate cases, usually on an annual basis,” the Residential Utility Consumer Office said in testimony.
RUCO also held that Southwest Gas should receive a 9.2% return on equity if formula rates are approved, arguing that the system would reduce the company’s risk by giving it “guaranteed revenues and income” and more predictable cost recovery.
For homeowners worried about rising utility bills, going solar is one of the best ways to save money on home energy. EnergySage offers free solar installation estimates and quote comparisons to streamline the process.
A wider Arizona dispute over formula rates is also shaping this case. 
RUCO is among the plaintiffs challenging the commission’s policy statement, arguing that it adopted the policy through a policy statement rather than formal rulemaking and therefore bypassed stakeholder input, impact studies, and public comment.
Then-Chairman Jim O’Connor said the policy drew opposition in more than 600 comments, while Commissioner Kevin Thompson dismissed critics’ concerns as “alarmism.” 
“It’s part of the misconceptions that media and other people are feeding into that they just don’t understand,” Thompson alleged.
💡Go deep on the latest news and trends shaping the residential solar landscape
RUCO also urged regulators to remove at least part of Southwest Gas’ dues to the American Gas Association and Western States and Tribal Nations from customer charges, citing advocacy for expanded gas use.
Coal and natural gas power plants contribute to air and water pollution linked to asthma, heart disease, cancer, and premature death. 
They keep household energy costs elevated for families that remain dependent on those fuels instead of more abundant energy sources such as wind and sunlight, while industry lobbying slows cleaner, cheaper energy solutions that would better protect families and lower costs.
RUCO and ACC staff also raised concerns about other costs Southwest Gas wants customers to absorb, including 56% of board expenses totaling $1,864,765, $400,000 in rate case expenses, and $565,061 in employee meal costs. 
In Nevada, the company faced scrutiny for trying to pass on costs for luxury hotels, alcohol, limo rides, and a $5,088 dinner attended by 13 guests for former President and CEO Karen Haller.
Consumer advocates are challenging the proposal directly in the case. 
RUCO recommended removing 100% of board fees from rates and argued that requiring customers to pay a return on the company’s own rate-case spending would “unfairly enrich shareholders.” 
ACC staff similarly said some executive perks are “beyond the normal compensation paid to employees.” Regulators and advocates in other states are also scrutinizing fast-tracked gas infrastructure spending. 
Southwest Gas wants to raise the annual cap on its Arizona system integrity mechanism from $50 million to $100 million, but a Future of Heat Initiative report found gas distribution spending climbed 200% over 15 years without measurable safety improvement. 
In Massachusetts, the Department of Public Utilities lowered a similar spending cap in 2025 to prioritize leak repair over full pipe replacement.
If higher gas costs are pushing you to look at alternatives, EnergySage is especially useful. It can help the average person save up to $10,000 on solar purchases and installations. 
EnergySage’s solar map shows the average cost of a home solar panel system by state, along with state-specific solar panel incentives; together, these resources get homeowners the best price on rooftop solar panels and allow them to take advantage of all available incentives. 
Adding battery storage to a solar setup is one of the best ways to protect your home during outages, save money on energy, and go off-grid. EnergySage provides information on home battery storage options and competitive installation estimates.
With Southwest Gas rebuttal testimony due Nov. 2 and intervenor responses due Nov. 20, ACC staff witness Michael Deupree of Acadian Consulting Group cited one of the central concerns.
“Formula rate plans have resulted in large rate increases with very few rate decreases and no measurable improvement in reliability of service.”
These stories show how utility decisions in several states affect what customers pay. They cover Arizona efficiency rollbacks, utility cost-recovery fights, and surging power bills.
• Arizona regulators gutted energy efficiency standards that had saved ratepayers $1.7 billion.
• In Oregon, lawmakers weighed major changes to how utilities operate as bills rise.
• PacifiCorp sought approval to bill customers for $1.7 billion in wildfire damages.
• In Missouri, cities fought pollution, then watched their power bills soar 191%.
Get TCD’s free newsletters for easy tips, smart advice, and a chance to earn $5,000 toward home upgrades. To see more stories like this one, change your Google preferences here.
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Solar Power World
By Billy Ludt | October 19, 2026
Pepco approved ConnectDER‘s meter collar products for solar, battery storage and EV charging installations for installation across its service territory in Washington, D.C. D.C. joins ConnectDER’s national footprint of 54 utilities reaching nearly 40 million households, with further utility expansion in progress.
ConnectDER’s adapters plug directly into the existing meter socket on the outside of the home. By establishing a safe connection point at the meter, it bypasses the need for main panel upgrades, service upsizing, circuit relocations or adding backup loads panels and system controllers, which can cause labor costs increases and project timelines delays.
“Demand for residential solar, battery backup and electric vehicles across Washington, D.C. continues to surge, but the physical challenge of older electrical infrastructure slows down installations,” said Ivo Steklac, ConnectDER president and CEO. “With Pepco approving our adapters for installation outside the home at the meter socket, installers don’t need to re-engineer the entire panel and home wiring to get these systems up and running. They can deliver clean energy resilience to district residents more efficiently, saving them thousands of dollars off total costs and days of labor. That directly translates to increased installation capacity and fewer barriers—keys for achieving D.C.’s ambitious electrification goals.”
D.C.’s clean energy market is propelled by its Clean Energy DC mandates, which include a renewable portfolio standard with a dedicated 15% local solar carve-out. The District’s unique urban building stock — primarily historic row homes with aging electrical infrastructure — frequently features 100-A electrical panels that require main service upgrades costing thousands before solar, battery storage or EV charging equipment can be interconnected.
“ConnectDER’s approval by Pepco DC is a big win for district residents and installation companies, following dedicated work from several CHESSA members to pass enabling regulations,” said Robin Dutta, executive director of the Chesapeake Solar and Storage Association (CHESSA). “This makes solar and battery storage more accessible for everyday homeowners, which is exactly the type of change we want to see more of.”
ConnectDER’s IslandDER MSA is engineered specifically for whole-home backup and battery storage, and integrates a Microgrid Interconnect Device, CTs, voltage sensing and real-time grid disconnect capability into a single compact device mounted outside at the meter. IslandDER is installed without reconfiguring panels or rerouting household circuits.
News item from ConnectDER
Billy Ludt is managing editor of Solar Power World and currently covers topics on mounting, inverters, installation and operations.

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Energies Media
A pond the size of a city lot now keeps an entire California winery running.
It sits behind the vines at a family farm in Mendocino County.
No new land was cleared for it.
No rooftop was torn up either.
Instead, panels went straight onto the water the vineyard already used for irrigation.
So how does a pond barely a quarter acre wide end up carrying the full electric load of a 1,800 acre farm?
A solar panel loses efficiency as it heats up, and a rooftop or a gravel field offers nothing to cool it. Floating the same panel a few inches above a pond changes that completely.
The water beneath acts as a natural heat sink, pulling warmth away from the panel’s underside and letting it keep converting sunlight efficiently through the hottest part of a Mendocino afternoon. A panel that runs cooler also degrades more slowly, which matters on a farm expecting decades of use from the same hardware.
That cooling effect is the entire reason floating photovoltaics has spread from reservoirs to quarry lakes to farm ponds over the past decade. The pond at Nelson Family Vineyards already existed as an irrigation source, so the array needed no new footprint at all.
Tyler Nelson, who owns the vineyard, put the land logic plainly: “Because the system floats on a pond, it does not take a single acre of land out of production.”
The hardware itself is modest by utility standards. The installer, a Sacramento area firm called Noria Energy, placed 252 solar panels on pontoons covering 0.28 acres of a retention pond, anchored to the bank, in water up to 10 feet deep.
That translates to a system rated at 136 kilowatts of capacity, which sounds small next to a utility scale solar farm. But paired with an existing rooftop array on the winery building, the combination now produces what the property needs to run.
Together the floating array and rooftop panels are expected to generate around 200,000 kWh of electricity annually, enough to power the winery, agricultural pumps, tasting room, shop and 12 on-site homes. For a 74 year old working farm, that is not a demonstration project. It is the entire electric bill, replaced.
The vineyard’s leadership did not frame this as an environmental statement first. The move toward renewable energy is expected to yield substantial financial benefits, with Nelson highlighting the impact of energy independence in an era of rising electricity costs, saying the shift would have “a major and immediate impact on our operation.”
That impact has a dollar figure attached. The project is projected to save Nelson Family Vineyards an estimated $90,000 annually, significantly reducing operating costs while also supporting its commitment to sustainable operation.
On a farm that has run for 74 years across 1,800 acres, that is real money taken straight off the utility ledger every year. Floating solar is still unusual enough in American agriculture that this winery’s installer calls it a milestone, marking one of the company’s first winery projects. Other growers watching the shift toward on site generation have seen similar logic play out elsewhere, including a Michigan solar farm built to help power nearby manufacturing demand.
The project’s second life is as a laboratory. Beyond the electricity, the installation is serving as a field site for an ecological study led by scientists from a university backed wild energy research center.
That matters because most floating solar research to date comes from much larger reservoirs and lakes, not farm scale ponds used for irrigation. Scientists from the UC Davis Wild Energy Center will use the system to examine how floating solar installations influence water quality, aquatic species, microclimates, and biodiversity in an agricultural setting. A major strand of that work, as the original project report describes, looks at whether the panels’ shade can curb invasive water fleas and weeds that clog the vineyard’s drip irrigation filters.
That data could shape how the next wave of American vineyards and farms decide where to put their own panels, whether that means a dedicated solar project or something closer to the scale of the Swan Solar build underway in Missouri.
Nobody is calling a quarter acre pond the future of utility scale solar. The project’s own backers describe it as a model for diversified operations rather than a template for gigawatt scale power plants.
A resource the vineyard already owned did double duty without displacing a single row of grapes. A 136 kilowatt floating array will never show up on a regional grid operator’s dashboard the way a far larger solar build does. Its significance is local, measured in one farm’s bill and one family’s margin, not in megawatts exported to the wider grid.
Still, the arithmetic is hard to argue with. A pond that once did one job now does two, and the vineyard’s own power bill is the proof. As more water rights holders and growers watch how that quarter acre performs, the real test will be whether researchers find anything in the water that complicates the picture, or whether the pond simply keeps doing what it was already doing, just with panels riding on top.
Hugo is an engineer with strong technical expertise. Multilingual from an early age, his writing combines technical clarity with a strong interest in science and energy.
Hugo is an engineer with strong technical expertise. Multilingual from an early age, his writing combines technical clarity with a strong interest in science and energy.
Hugo is an engineer with strong technical expertise. Multilingual from an early age, his writing combines technical clarity with a strong interest in science and energy.

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