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Indian power utility India Power Corporation Limited has partnered with Bhutan’s Green Energy Power Private Limited to develop a 70MWp solar power plant in Paro, Bhutan. 
The project will be developed on around 200 acres of south-facing land with high solar irradiation. The site is located approximately 3.5km from the Jamjee 220/33kV substation for efficient power supply. 
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According to the West Bengal-headquartered firm, the Tenchuka solar project aligns with IPCL’s plan to develop 1.5GW of solar capacity in Bhutan over five years as electricity demand continues to rise. IPCL said the site in Paro district was selected following detailed technical assessments. 
“The Tenchuka project represents both capacity expansion and our strategic objective of becoming a 1.5GW solar player by 2030,” said Somesh Dasgupta, whole-time director, IPCL. 
Meanwhile, the founder of Green Energy Power said the project would be Bhutan’s first independent power producer (IPP) solar initiative. 
Bhutan’s power demand is expected to more than double over the next two years, driven by major developments such as the Gelephu Mindful City project and the expansion of energy-intensive industries, including ferrosilicon manufacturing. While hydropower dominates the energy mix, the Royal Government of Bhutan aims to reach 25GW of installed renewable energy capacity by 2034, including 5GW of solar. 

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According to the International Renewable Energy Agency’s Renewable Capacity Statistics 2026, solar photovoltaic capacity saw the largest annual increase of any electricity generation source last year, with 510 gigawatts added. The global total for renewable energy capacity surpassed 5,000 gigawatts by the end of 2025, reaching 5,149 gigawatts.
Solar power constitutes the largest share of this operational renewable capacity, at 2,391 gigawatts, which is nearly double the 1,291 gigawatts from wind. Renewables broadly dominated new capacity installations, representing 85.6 percent of all new energy capacity built in 2025. Solar power alone was responsible for 75 percent of the 692 gigawatts of new renewable capacity added during the year.
The report’s foreword states that consistent growth demonstrates the economic strength and competitive resilience of renewable power, which has seen record additions for many years. Despite this global growth, deployment remains highly concentrated, with China, the United States, and the European Union together accounting for 79.5 percent of new renewable capacity installed in 2025. China held half of the world’s operational solar capacity at the end of last year.
Other regions showed notable progress, however. The Middle East increased its renewable energy additions by 28.9 percent from the previous year, adding over 12 gigawatts of new solar capacity between 2024 and 2025. This represents the largest annual solar increase ever recorded for the region and has expanded its operational solar capacity by nearly 24 times since 2016.
Saudi Arabia has been a significant contributor to this regional growth, with cumulative operational solar capacity reaching 11.9 gigawatts after adding more than 5 gigawatts in 2024. Recent developments in the country include the commissioning of a 349 megawatt solar photovoltaic project and agreements with international companies and governments.
This report provides a comprehensive view of the solar cells and light-emitting diodes industry in Middle East, tracking demand, supply, and trade flows across the regional value chain. It explains how demand across key channels and end-use segments shapes consumption patterns, while also mapping the role of input availability, production efficiency, and regulatory standards on supply.
Beyond headline metrics, the study benchmarks prices, margins, and trade routes so you can see where value is created and how it moves between exporters and importers within Middle East. The analysis is designed to support strategic planning, market entry, portfolio prioritization, and risk management in the solar cells and light-emitting diodes landscape in Middle East.
The report combines market sizing with trade intelligence and price analytics for Middle East. It covers both historical performance and the forward outlook to 2035, allowing you to compare cycles, structural shifts, and policy impacts across countries and sub-regions.
For the regional report, country profiles provide a consistent view of market size, trade balance, prices, and per-capita indicators across Middle East. The profiles highlight the largest consuming and producing markets and allow direct benchmarking across peers.
The analysis is built on a multi-source framework that combines official statistics, trade records, company disclosures, and expert validation. Data are standardized, reconciled, and cross-checked to ensure consistency across time series.
All data are normalized to a common product definition and mapped to a consistent set of codes. This ensures that comparisons across time are aligned and actionable.
The forecast horizon extends to 2035 and is based on a structured model that links solar cells and light-emitting diodes demand and supply to macroeconomic indicators, trade patterns, and sector-specific drivers. The model captures both cyclical and structural factors and reflects known policy and technology shifts within Middle East.
Each country projection is built from its own historical pattern and the regional context, allowing the report to show where growth is concentrated and where risks are elevated.
Prices are analyzed in detail, including export and import unit values, regional spreads, and changes in trade costs. The report highlights how seasonality, freight rates, exchange rates, and supply disruptions influence pricing and margins.
Key producers, exporters, and distributors are profiled with a focus on their operational scale, geographic footprint, product mix, and market positioning. This helps identify competitive pressure points, partnership opportunities, and routes to differentiation.
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Ever since its inception on 29th February, 2024, PM Surya Ghar: Muft Bijli Yojana (PMSGMBY) has been pivotal in increasing the share of solar rooftop capacity in India, and democratising renewable energy by empowering residential households to generate their own electricity. As intended, the scheme has helped increase rooftop solar energy in India’s energy mix, though not always equitably.
The official numbers on the scheme dashboard show that some of the biggest states are lagging on rooftop solar installations under the INR 75,021 crore scheme. While the numbers from small states are expected to be low, some of the big non-Himalayan states have underperformed far below others. Overall, India’s rooftop solar capacity under the scheme reached about 7.7 GW, with over 26,20,000 households covered. 
Here is a list of the top 5 worst-performing states of India for Rooftop Solar installations under the PMSGMBY. Note that, while these states may not be the lowest performers in absolute terms, their numbers lag sharply relative to their administrative size, urban infrastructure and renewable-energy maturity.
Karnataka
~60 
0.78
113 Cr
Telangana
~100
1.3
180 Cr
Jharkhand
~6
<0.1
9.76 Cr
Bihar
~51
0.66
102 Cr
Tamil Nadu
~183
2.37
354 Cr

Households Covered
Capacity (MW) 
Subsidy Released (Cr)
23,900
60
₹113.63

Karnataka is the biggest laggard, and surprise when it comes to overall rooftop solar installations, especially considering it is the biggest state with administrative area spanning 1,92,000 sqkm. Moreover, its geography makes it the best region for solar power generation. The state has possibly found its high share of renewables a drag on adding faster rooftop capacity. 
The Southern state has installed just over 60 MW of rooftop solar capacity under the PMSGMB scheme, covering roughly 24,000 households. The contrast is striking, considering that the state has shown a strong growth in other renewable verticles. Subsidy allotment – at over INR 113 crore – for the state does not seem to be an issue in terms of timely release.
Households Covered
Capacity (MW) 
Subsidy Released (Cr)
36,000
100
₹180.66
Another state with huge potential, but has so far been a rooftop laggard, is Telangana. The state has over 5 GW of installed solar power capacity, yet it hasn’t fared well in the segment under the PMGMB scheme. The state has achieved 100 MW of rooftop solar installation under the scheme, with roughly 36,000 households covered. A total amount of INR 180.66 crore in subsaidy payments has been released for the State. Considering its lack of large land parcels for utility scale solar, it needs to buckle up for faster rooftop additions.
To boost these numbers, the Telangana Electricity Regulatory Commission (TERC) has issued the Rooftop Solar PV Grid Interactive Systems Regulation, 2025. The policy replaces the previous 2016 framework and introduces comprehensive measures to facilitate multiple solar net metering models, provide financial clarity, and ensure technical and safety standards.
Households Covered
Capacity (MW) 
Subsidy Released (Cr)
1,462
5.84
₹9.76
Jharkhand is another large state that has been lagging behind much smaller states and UTs under the PMSGMB Yojana. The state has got INR 9.75 crore allotment under the scheme.
Amassing 79,714 sqkm of Area, the state has installed less than 6 MW of rooftop solar capacity under the scheme, which is less than even Goa (12.13 MW). 
In addition to the area, Jharkhand’s geography is also ideal for solar power generation, yet the state has contributed little to the segment. 
Households Covered
Capacity (MW) 
Subsidy Released (Cr)
14,900
51
₹102.27

Positioned in the same geography as Jharkhand, Bihar also ranks among the states with one of the lowest installation levels under the scheme. The state has received INR 76.6 crore in subsidies. With roughly 15,000 households catered to with the service, resulting in an installed capacity of 51.33 MW. 
Bihar’s numbers account for less than 1 percent of the applications, and under 0.75 percent of installations so far, while accounting for over 9 percent of India’s population. The state had an existing solar capacity of 435 MW, as of November 30, 2025. Quite simply, shameful figures, but no surprise considering Bihar’s ranking on other critical metrics. 
Households Covered
Capacity (MW) 
Subsidy Released (Cr)
59,500
183
₹354.57
With 12 GW of wind power capacity and 11.5 GW of solar capacity, Tamil Nadu is a leader in India’s solar revolution. However, its rooftop solar segment under PMSGMBY has shown lacklustre progress as the state added just over 180 MW of power under the scheme so far. 
TN is the 3rd largest state in India, and its contribution to the segment is crucial. In addition to the central assistance under the scheme, the state is also providing the Chief Minister’s Solar Rooftop Capital Incentive Scheme that subsidises installations with INR 20,000 per kW. Still, the state remains a laggard.
The laggard states need to overcome several challenges before they realise their rooftop solar potential under the PM Surya Ghar Muft Bijli Yojana (PMSGMBY). These challenges are multifaceted.
The rooftop solar uptake on government infrastructure remains tepid in these states as a result of gaps in procurement processes, budget allocation across departments, and the absence of coordinated implementation. 
The new India’s domestic content requirement (DCR) rule raises another challenge. The rule mandates the use of locally made solar modules – DCR-compliant modules – which are 30–40 per cent costlier and harder to source. Thus, with only 25 GW of DCR cell capacity against 100 GW of module capacity, a shortage has emerged. 
The lack of ease in the installation process, while much improved opver say, 2022, remains a key. Customers cite long waiting periods, demands for money beyond the billed values, and fear of subsidy delays as key reasons for holding off. 
The government’s digital platform for PMSGY, which is designed for seamless approvals and subsidy tracking, also remains riddled with technical glitches and slow grievance redressal. Installers reported persistent data-entry errors and no clear escalation pathway.
Financing remains another sticking point. While public sector banks offer rooftop loans at 6-8 per cent interest, the cumbersome paperwork deters many middle-income consumers. NBFCs and fintechs fill the gap with faster but pricier loans, often at 10-14 per cent interest.
Competition from state policies is also one of the reasons for low PMSGMBY numbers. For instance, one reason for Karnataka’s underperformance is the introduction of the Gruha Jyothi scheme, which offers free electricity to households consuming up to 200 units per month. The central scheme also faced challenges in the vendor selection stage. At this stage of application, potential customers realised that they needed to take out a loan to get the subsidy, which is a less attractive option compared to the Gruha Jyothi scheme.
To accelerate deployment, the Union Ministry of New and Renewable Energy has begun capacity-building programmes to train over 300,000 solar technicians, and launched ‘Model Solar Village’ and ‘Solar City’ initiatives to take the mission deeper into rural India. However, none have yet been fully operationalised.
These laggard states need to speed up RTS installations to cater to the growing energy demand of their population. 
India is expected to add approximately 41.5 GW of new solar capacity by the end of fiscal 2026 (March 31, 2026), as per JMK research. About the milestone year of 2030, the India Rooftop Solar Market size in terms of installed base is expected to grow from 17.6 GW in 2025 to 41.52 GW by 2030, at a CAGR of 18.73 percent, the Mordor Intelligence noted. 
The bigger states, area- and population-wise, need to step up to do their part in country’s ambition for 2070. Some states, like Bihar, are now building up momentum. The state power distribution utility has issued a tender to develop grid-connected 275 MW rooftop solar projects. Going by the current trends of about 18 percent CAGR until 2030, Bihar is expected to add over 9 MW in 2026. Going by this CAGR, Tamil Nadu adds 33 MW, Telangana adds about 18 MW and Karnataka adds roughly 10 MW. The growth prediction for Jharkhand, by these numbers, is negligible (less than 1 MW).
Needless to say, the actual growth rate needs to be be much higher for these states to realise their true rooftop solar potential and contribute equitably to India’s renewable mix.
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CW Enerji Says It Decides To Increase Photovoltaic Solar Cell Production Capacity At Its Subsidiary Cw Solar Cell Enerji From 1.2 GW To 2.5 GW  TradingView
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Wire Covers Solar Cable Entry Gland Waterproof Double Entry Housing For Solar Pane RV Boat Solar Panel Housing  primetimes.id
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Solar PV in Australia’s National Electricity Market (NEM) made a strong showing across October 2025, reaching 4,715GWh – a 9.88% increase on the 4,291GWh recorded in October 2024.
This means that both utility-scale and rooftop solar PV managed to generate 424GWh more than they did a year ago, showcasing the rapid growth of the country’s solar sector, primarily driven by rooftop solar installations.
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Although it was to be expected that solar generation capacity was likely to beat last year’s performance, October 2025 has become the third-best month on record, trumped only by January 2025 (5,039GWh) and December 2024 (5,213GWh), both of which are the peak of Australia’s summer period.
However, with utility-scale and rooftop solar continuing to set new records several times a month now, the upcoming summer period will likely spell a dramatic increase year-on-year.
As detailed in the chart above, sourced from Open Electricity (formerly OpenNEM), both solar generation types experienced steady growth as seasonal conditions improved and daylight hours extended across the NEM.
It should also be noted that Australia’s solar PV sector recorded a 19.88% increase month-on-month; however, this was lower than the increase witnessed between the two corresponding months last year, which stood at 24.78%.
Across October 2025, much of the heavy lifting was done by the country’s rooftop solar sector, which broke the 3,000GWh threshold. This comes as no surprise, given that Queensland’s rooftop solar PV systems exceeded 5GW of output for the first time in October, marking a significant milestone in Australia’s distributed solar capacity expansion.
Meanwhile, utility-scale solar recorded its fourth-highest generation figure across the month, with 1,672GWh.
Recent analysis by the Australian Energy Market Operator (AEMO) revealed that grid-scale solar generation achieved an average output of 1,699MW in the third quarter of 2025.
Perhaps one of the most striking figures from October 2025 was that the average for rooftop solar PV generation reached 98.5GWh, while utility-scale solar averaged 53.6GWh.
As shown in the graph above, which breaks down the daily recorded generation figures for utility-scale and rooftop solar PV, the best day for combined generation was 15 October, with a combined total of 186GWh. This is 27GWh higher than last month’s best day, 29 September, when generation reached 159GWh.
It is worth noting that the daily totals range from a low of 108GWh on 28 October, with most days falling between 130GWh and 170GWh.
Rooftop solar PV consistently outperformed utility-scale generation, averaging 97.4 GWh daily compared to 54.4 GWh for utility-scale systems – a significant 79% higher output.
Utility-scale solar generation showed considerable variability, ranging from a low of 36GWh on 28 October to peaks of 72GWh on 24 October. The system demonstrated moderate consistency, with several days clustering around the 50-60GWh range. However, notable dips occurred on days 5, 9, 22 and 28 October, suggesting weather-related impacts or maintenance activities.
Rooftop solar PV generation exhibited greater stability and higher overall performance, with output ranging from 71GWh to 118GWh. Peak generation occurred on 15 October (118GWh), while the lowest output was recorded on 26 October (71GWh). The distributed nature of rooftop installations appears to provide more consistent generation, with most days producing between 90-115GWh.
The 31-day pricing data reveals significant volatility and contrasting patterns between utility-scale and rooftop solar markets in Australia. Both sectors experienced substantial price fluctuations, ranging from profoundly negative to strongly positive values, reflecting the complex dynamics of renewable energy markets.
Utility-scale solar pricing demonstrated extreme volatility, with prices ranging from AU$17.03/MWh (US$11.12/MWh) on 5 October to a peak of AU$73.51/MWh on 28 October.
The sector experienced extended periods of negative pricing during the first five days, indicating oversupply conditions where generators were paid to offload excess energy. However, the market showed remarkable recovery potential, with several days recording substantial favourable prices above AU$40/MWh, particularly on 9 October, 17 October, 21, 23, 25, 28, 29 and 31 October.
Rooftop solar pricing followed similar volatility patterns but with generally lower peak values, ranging from -AU$27.70/MWh on 5 October to AU$50.95/MWh on 31 October. Notably, rooftop systems experienced more severe negative pricing during oversupply periods, with intense discounts on 4 October and 5 October (-AU$22.81/MWh and -AU$27.70/MWh, respectively).
This suggests rooftop solar faces greater challenges during peak generation periods when grid absorption capacity is limited.
A price correlation was evident between the two sectors, with both experiencing negative pricing during the same periods (1-5, 11, 14, 16, and 19 October) and positive spikes often co-occurring.
However, the magnitude of price movements differed significantly, with utility-scale solar generally commanding higher favourable prices during favourable market conditions, likely due to its grid-scale integration advantages and more sophisticated market participation mechanisms.
You can explore previous solar generation performance in our NEM data spotlight series, with all entries available to PV Tech Premium subscribers.

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Queensland Investment Corporation (QIC) and EDP Renewables Australia have signed an agreement to develop a 400MWac solar-plus-storage project in Toowoomba, Queensland.
Punchs Creek Renewable Energy Project combines a 400MWac solar PV facility with a co-located 400MW/1,600MWh battery energy storage system (BESS).
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The partnership marks EDP’s first large utility-scale project in Australia and the first step toward a potential long-term collaboration between the Portuguese energy company and the Australian state-owned institutional investor.
QIC and EDP confirmed that the project is expected to reach financial close in 2026, with EDP currently in advanced discussions for a long-term offtake contract.
The Punchs Creek project comprises 480MWp (400MWac) of solar generation paired with the 4-hour duration battery energy storage component, positioning it among the larger hybrid renewable energy developments in Australia’s pipeline. It will be connected to Australia’s National Electricity Market (NEM).
Readers of Energy-Storage.news may be aware that, in October 2025, the project secured a generation revenue scheme under the Australian government’s Capacity Investment Scheme (CIS) Tender 4, which awarded 11.4GWh of solar-plus-storage projects across multiple developments.
The CIS framework provides revenue certainty for renewable energy projects by offering underwriting agreements that guarantee minimum revenue streams.
Miguel Fonseca, CEO of EDP Renewables APAC, described the partnership with QIC as marking another milestone in EDP’s strategy to expand its renewable energy portfolio across the Asia-Pacific region.
“EDPR views Queensland and Australia as key markets with strong fundamentals for renewables and is focusing on scaling hybrid projects, with the aim of deploying material capacity by 2030 as part of a longer-term pipeline of about 4GW,” Fonesca said.
QIC has a major presence across the Australian market. The Queensland-based institutional investor manages assets across multiple sectors and has established expertise in renewable energy project development and financing within the Australian market context.
The exclusivity agreement structure provides both parties with a framework to evaluate the potential of the partnership while advancing project development activities. This approach enables detailed due diligence and project optimisation before committing to final investment decisions and construction timelines.
Meanwhile, EDP Renewables operates renewable energy projects across four continents, bringing international expertise in large-scale solar and battery energy storage system development to the Australian market.
In other news, Octopus Australia has achieved financial close on a AU$900 million (US$587 million) DC-coupled hybrid facility that combines 300MW of solar generation with a 243MW/486MWh BESS in New South Wales.
The Blind Creek Solar Farm and Battery project, located 8km northeast of Bungendore, a historic village in the Southern Tablelands between Sydney and Canberra, represents one of the largest DC-coupled solar-battery hybrid developments to reach financial close in Australia’s renewable energy sector.
The facility will generate approximately 735GWh of renewable energy annually while providing grid stability services to the National Electricity Market (NEM).
The DC-coupled configuration at Blind Creek represents a major technical advancement in hybrid renewable energy systems, the company claimed. Unlike AC-coupled systems, where solar PV generation and battery storage operate through separate inverters, DC-coupling enables direct current flow from solar modules to the BESS through DC/DC converters before final conversion to alternating current for grid connection.
This architecture reduces conversion losses and connection costs while optimising energy delivery during peak pricing periods.
SMA will supply inverter technology, whilst Wärtsilä will provide the DC-coupled battery storage system.
DC-coupling has become a trending topic in Australia, with Wärtsilä at the heart of numerous developments across the NEM and Western Australia. The Blind Creek Solar Farm and Battery project also represents the second time the Finnish company has partnered with Octopus Australia for a DC-coupled project, following the 128MWh Fulham solar-plus-storage site in Victoria.
Both of these stories first appeared on our sister site Energy-Storage.news as the items ‘QIC, EDP partner for 1,600MWh solar-plus-storage project in Queensland, Australia’ and ‘Octopus Australia reaches financial close on 486MWh DC-coupled solar-plus-storage site’.

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Syracuse solar program saves on bills, no home install  InformNNY.com
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Spring weather may finally be arriving in here in Maryland and the mid-atlantic, but this winter’s impact is not done with us yet as truly massive power bills may still be coming at us in weeks ahead! So what can we do? Wyatt Everhart, meteorologist & advisor with Solar Energy World shares his insight and advise.
2026 Sinclair, Inc.

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How going solar turns energy costs into tax benefits in India  tatapower.com
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The median system size for residential solar photovoltaics in the United States has increased over the last few years. In 2024, the median size of a home solar system in the U.S. stood at 7.2 kilowatts direct current. In comparison, the median size in 2010 was just over five kilowatts direct current. The cost of solar photovoltaics has declined steadily in the last decade.
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French independent power producer (IPP) Qair has secured PLN350 million (US$94 million) in funding from Bank Gospodarstwa Krajowego (BGK) to build renewable energy projects with a combined capacity of 203 MW in Poland. 
The funding will enable Qair to construct three renewable energy projects: an 80MW solar project in Wierzbica, a 105MW solar plant in Grudziądz, Kuyavian-Pomeranian Voivodeship, and an 18MW wind facility in Jenkowo, Lower Silesian Voivodeship.  
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Construction is scheduled to start in Q2 2026, with commissioning expected in 2027. The financing comes through Poland’s Energy Support Fund, a key pillar of the country’s National Recovery and Resilience Plan, backed by the EU’s Recovery and Resilience Facility. 
In other news, the French IPP has brought commisioned its 14.6 MW Beehive solar portfolio, comprising thirteen small-scale photovoltaic farms strategically distributed across the country.  
The portfolio combines multiple sites into an integrated system, optimising local energy production. The company said the project will strengthen the national grid while providing clean electricity to surrounding communities. 
As of early 2026, Qair has installed nearly 500MW of solar capacity. Across all markets, the firm has 1.7GW of renewables either in operation or under construction, with a 35GW development pipeline spanning 20 countries. 
Qair recently signed a power purchase agreement (PPA) with Brazilian LPG distributor Ultragaz for its 192MW Bom Jardim solar PV project in Ceará, northeastern Brazil. Construction on the plant began in 2024, and it reached commercial operations earlier this year. 

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Building an end-to-end solar manufacturing supply chain has become a “strategic imperative” for Australia, Stellar PV CEO Louise Hurll told PV Tech, describing it as a “transformational opportunity” for the nation to evolve from a consumer of clean energy technology into a global supplier. 
In an interview for PV Tech Premium, Hurll said Australia’s heavy reliance on imports – particularly from China, which produces over 90% of the world’s polysilicon and 98% of its wafers – exposes its renewable energy ambitions to global supply disruptions. 
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“We ship our quartz overseas to be processed, and by the time it returns as finished panels, its value has multiplied many times over,” she said. “With abundant renewable energy, strong ESG standards, and world-class research, Australia can capture that value at home.” 
Hurll emphasised that the government’s AU$1 billion (US$653 million) Solar Sunshot Programme, administered by Australian Renewable Energy Agency (ARENA), is essential to establishing domestic production. Stellar PV received AU$4.7 million in ARENA funding for feasibility and front-end engineering studies, which Hurll described as “a huge jump start” that has helped attract private investors by demonstrating government commitment. 
“Private investment alone could not have brought us this far,” she noted. “Every successful solar manufacturing nation has relied on strong government support – from China’s industrial policy to the US Inflation Reduction Act (IRA). Sunshot gives Australia the same foundation to build competitive manufacturing at scale.” 
Hurll said the programme marks a turning point for Australia, shifting it from a leader in solar deployment to a hub for solar manufacturing. “Australia helped pioneer modern solar cell technology, yet much of the manufacturing went offshore. Sunshot is helping to rebuild that capability.” 
While technical barriers are low, the key challenges lie in establishing the industrial base and navigating long approval timelines. Hurll believes success will come from leveraging Australia’s clean energy advantage, reliable trade access to the US and Europe, and a growing global preference for traceable, low-carbon materials. 
“With renewable-powered production and transparent sourcing, we can offer wafers that attract a green premium,” she said. “This is about turning Australia’s natural strengths into long-term economic leadership in the solar supply chain.” 
Read our full interview with Louise Hurll (subscription required). 

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Recurrent Energy, the development arm of Canadian Solar, has sold its 275MWdc Gunning hybrid solar-plus-storage project in New South Wales, Australia, to an undisclosed European infrastructure and investment group.
The transaction involves a 275MWdc solar PV power plant paired with a 120MW battery energy storage system (BESS) located approximately one hour north of Canberra. Recurrent Energy was granted consent for the Gunning solar-plus-storage project in late November 2024.
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The Gunning Energy Park will connect to Australia’s National Electricity Market (NEM) through a Transgrid transmission line, positioning it to provide grid services and energy arbitrage opportunities within the NEM framework.
Ismael Guerrero, CEO of Recurrent Energy, emphasised the project’s role in advancing Australia’s energy transition.
“This milestone builds on our continued success in the country, highlights our ability to develop innovative, large-scale renewable energy projects, and marks an important step in advancing Australia’s transition to a cleaner and more reliable energy system,” Guerrero added.
Recurrent Energy announced the transaction earlier this week; however, the financial terms and the specific identity of the European buyer remain undisclosed. The sale represents another significant divestment for Recurrent Energy as the company continues its develop-and-divest strategy across the Australian renewable energy market.
One of the most substantial projects included in this develop-and-divest strategy is the 100MW/200MWh Mannum BESS in South Australia, which was sold to Australian energy infrastructure developer Epic Energy in 2024. It was commissioned in May 2025.
The transaction builds on Recurrent Energy’s expanding presence in Australia’s renewable energy sector. The company reached financial close on a 171MW solar-plus-storage site in Victoria late last year, demonstrating continued investor confidence in Australian hybrid projects.
The Carwarp Energy Park in Victoria represents another example of Recurrent Energy’s hybrid development approach, combining solar generation with co-located battery storage systems.
It should also be noted that the 150MW Carwarp project recently joined AEMO’s Market Management System. The registration with AEMO’s system represents a critical step in the commissioning process, indicating readiness for testing and grid integration activities.
The Australian renewable energy market has attracted substantial international investment as the country transitions away from coal-fired generation toward renewable energy sources.
Hybrid projects that combine solar and battery storage have garnered particular attention from infrastructure investors seeking long-term, stable returns from essential grid infrastructure.
As a result, numerous solar-plus-storage projects are being pursued nationwide. As reported by PV Tech in October, the New South Wales Independent Planning Commission approved Ark Energy’s 435MW Richmond Valley solar-plus-storage project, while Global Power Generation advanced its 290MW Fraser Coast development through Queensland’s environmental approval process.

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Australia achieved a record-breaking 5.3GW of solar PV installations in 2024, marking a recovery for the market while highlighting the nation’s unique position as a rooftop-dominated solar economy.
According to figures from the International Energy Agency (IEA), utility-scale solar additions reached 2GW in 2024, bringing volumes back toward peak levels seen in 2018-2019. Rooftop installations across residential and commercial and industrial (C&I) sectors remained stable at 3.2GW, maintaining the distributed generation focus that distinguishes Australia from most global markets.
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Despite recording its highest annual installation volume, Australia failed to rank among the world’s top ten markets for the second consecutive year, ending a streak that had persisted since the IEA’s Photovoltaic Power Systems Programme (PVPS) began tracking market dynamics in the 1990s.
This shift reflects the rapid expansion of solar markets in other regions, while Australia’s growth has stabilised.
Despite this, it is worth noting that Australia’s rooftop solar industry remains among the world leaders, with installations surpassing 27GW in the first half of 2025, as shown in the graph below.
The Australian solar landscape remains fundamentally different from international markets, with rooftop installations continuing to drive demand.
Over 40% of Australian free-standing homes now operate rooftop solar systems, supported by government incentives that provide upfront capital cost reductions running until 2030. Solar power currently supplies approximately 20% of the nation’s total electricity demand.
The residential sector’s strength reflects the success of the Small-scale Renewable Energy Scheme (SRES), which creates trading certificates that can be redeemed as upfront capital subsidies for systems up to 100kW.
This mechanism has enabled Australia to achieve a world-leading installation rate exceeding 1.52kW per capita, with total installations now exceeding four million systems nationwide.
Regional variations demonstrate the technology’s broad adoption, with Queensland and South Australia approaching 50% penetration rates for free-standing homes equipped with solar systems. Some localities within these states report rooftop solar densities exceeding 60%. Tasmania, with lower solar irradiation levels of 3.7kWh per year, exhibits a more modest adoption rate of 20% among free-standing homes; these trends are shown in the graph below.
The average residential installation size has grown to nearly 10kW in 2024, peaking above 10kW in December and representing an increase from less than 9kW in 2021-2022.
This growth prompted a revision of market categorisation, with residential systems now classified as 0-15kW, expanded from the previous 0-10kW threshold. C&I installations are now categorised as 15-100kW systems.
System pricing continued its downward trajectory, with typical residential installations priced at AU$1.20 (US$0.78) per watt excluding subsidies, which provide an additional 40 Australian cents per watt reduction depending on solar irradiation levels.
Module prices reached record lows, with typical crystalline silicon modules priced at AU$0.20 per watt in 2024, down from AU$0.30 per watt in 2023, reflecting global manufacturing overcapacity.
Large-scale solar installations above 5MW contributed 2GW to the annual total, representing a recovery from recent years and bringing the cumulative centralised solar capacity to 13.4GW.
The utility-scale sector benefits from Large-Scale Generation Certificates under the Renewable Energy Target, which provides annual revenue based on energy generation rather than upfront subsidies.
The Australian government’s Capacity Investment Scheme (CIS) aims to deliver 40GW of additional electricity-generating capacity by 2030, up from an initial 32GW target announced in July 2025.
The scheme targets 23-26GW of renewable energy generation capacity and 9-14GW of clean, dispatchable capacity, creating a pipeline for continued utility-scale solar development.
Policy challenges persist around connection approvals, congestion management and fragmented access arrangements, which increase costs and risks for grid-scale projects.
The Australian Energy Market Operator (AEMO) implements strict curtailment rules that limit large-scale solar output to protect system strength. Regular curtailment occurs in South Australia, where large-scale solar capacity stands at 1,100MW, alongside more than 1,800MW of wind capacity.
Battery storage deployment accelerated alongside solar installations, with 31,120 residential battery units registered in 2024, averaging around 7kWh capacity.
The cumulative total reached 124,425 residential battery systems, indicating growing integration between solar generation and energy storage technologies. The introduction of the Cheaper Home Batteries Program in 2025 is expected to drive significant battery adoption, complementing the recovery of solar installations.
Australia’s solar manufacturing sector, which began in the 1990s with companies such as Tideland, Solarex and BP Solar, experienced renewed interest in 2024. The federal government announced the AU$1 billion Solar Sunshot Program in March 2024 to support the commercialisation of Australian solar innovations and enhance local supply chains.
The first round of the Solar Sunshot programme concluded with prefabricated solar structure provider 5B becoming the first recipient. Other recipients included Tindo Solar, an Australian module manufacturer, Solquartz, Energus and Stellar PV. A second round of the programme was launched earlier this year.
Current domestic manufacturing capacity remains limited to approximately 100MW from Tindo Solar; however, the policy framework aims to rebuild local capabilities that were previously competitive before production shifted to Germany and subsequently to China.
The cumulative installed capacity reached 40GW at the end of 2024, comprising 26.1GW of distributed solar and 13.4GW of centralised installations, as shown in the graph below.
With excellent solar irradiation conditions, this capacity now meets over 20% of national electricity demand, creating both opportunities and challenges for grid management.
South Australia demonstrates the potential and challenges of high solar penetration, where rooftop solar alone routinely powers the entire state during midday hours, with excess generation exported to neighbouring states.
This achievement in a jurisdiction with 1.77 million residents illustrates the scalability of distributed solar resources.
Grid access reform remains incomplete following the closure of the Energy Security Board in May 2023, with each jurisdiction developing separate approaches to access arrangements. This regulatory fragmentation creates complexity and administrative overlap that could impact future development.
Several large prospective projects aimed at energy exports and green minerals processing could add 4GW annually if implemented, representing potential step-change growth for the utility-scale sector. These developments would position Australia to leverage its solar resources for industrial applications and international energy trade.

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PowerBank Advances Pennsylvania Community Solar Project as Key Regulatory Decision Looms  tipranks.com
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At the Vercar industrial site in Castelfranco Veneto, Italy, rooftop solar has become a core part of the company’s operational strategy. By installing a 97,76 kW photovoltaic system using 208 AIKO Neostar 470 W N-Type ABC modules, the factory has transformed limited rooftop space into a high-efficiency energy asset that supports both cost reduction and long-term sustainability objectives.
“We chose AIKO modules because they combine the highest efficiency with excellent reliability, ensuring maximum energy yield on our rooftop. The project allowed us to drastically reduce our energy bills and improve our environmental profile,” commented Vercar spokesperson Carla Trevisan.
The system is expected to generate approximately 107,500 kWh in its first year and 3.05 GWh over a 30-year lifecycle, supported by a low annual degradation rate of 0.35%, with on-site generation now enabling Vercar to reduce its annual electricity outlay by some €45,000.  
AIKO’s ABC technology is particularly suited to industrial rooftops where space efficiency, long-term reliability and predictable performance are critical.
Company CEO Franco Bolzon added: “Since the installation, the AIKO system has exceeded our expectations. The energy output is higher than anticipated, and our electricity bills have dropped by more than 40%. The modules are extremely reliable, and we are fully satisfied with the performance and the partnership.”

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Victoria’s first state-owned solar-plus-storage project has reached a major construction milestone, with the installation of all 212,296 PV modules at the SEC Renewable Energy Park in Horsham, Australia.
The project represents a step in the State Electricity Commission’s (SEC) return to energy generation, following the Victorian government’s revival of the entity to drive the state’s renewable energy transition.
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The 119MW solar-plus-storage site, which features a co-located 100MW/200MWh battery energy storage system (BESS), has also accepted delivery of a 162.5-tonne transformer that will connect the facility to the grid and the wider National Electricity Market (NEM).
As reported previously by our colleagues at Energy-Storage.news, energy storage system integrator Energy Vault will supply the BESS. The system will be built using the company’s X-Vault integration platform and its UL9540 and AS3000-certified B-VAULT integrated BESS enclosures.
Energy Vault, which also provides a proprietary gravity energy storage technology, has been employed by several developers for energy storage sites in Australia.
Once commercially operational in 2027, the project is expected to generate approximately 242,000MWh of renewable energy annually.
“This project represents a new chapter for Victoria’s energy future,” said Victorian Premier Jacinta Allan. “The SEC Renewable Energy Park will deliver clean, reliable energy while keeping profits in public hands to reinvest in more renewable energy projects.”
The Horsham facility marks Australia’s first 100% government-owned integrated solar and battery project, connecting through a single grid connection point approximately 5km east of Horsham’s central business district.
The site selection leveraged proximity to the Horsham Terminal Substation, established road network access and flat terrain free from native vegetation.
Originally known as the Horsham Solar Farm, the development won the Victorian government’s VRET2 renewables auction in 2022 under Esco Pacific ownership. The project subsequently changed hands to Swedish developer OX2 before being acquired by the SEC in September 2024, with the state entity doubling the planned battery component from the original design.
The SEC is constructing the facility in partnership with OX2, which continues as the development partner following the ownership transfer. This collaboration represents part of the SEC’s broader AU$370 million (US$242 million) investment in the Horsham project, which forms a cornerstone of Victoria’s renewable energy expansion strategy.
The Horsham development will operate in conjunction with the SEC’s larger Melbourne Renewable Energy Hub, a 600MW/1.6GWh facility currently under construction in Melton, Melbourne’s outer west. Together, these projects position the SEC to supply approximately 5% of Victoria’s electricity market when it re-enters the retail market.
The SEC has committed to reinvesting all profits from its renewable energy operations back into Victoria’s energy transition, establishing a AU$3 million community benefit fund for local projects and initiatives in the Horsham region. This will span the project’s 30-year operational lifecycle.

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Australia’s National Electricity Market (NEM) faces a fundamental transformation as solar PV generation and battery energy storage systems (BESS) drive the country’s transition to a low-emissions energy system, according to AEMO’s 2025 Transition Plan for System Security.
AEMO CEO Daniel Westerman described the plan as “the most comprehensive plan to meet system security requirements as well as consumer needs for the NEM” as Australia’s energy system undergoes rapid change with coal-fired power stations retiring and being replaced by renewable energy, storage and gas-powered generators.
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The report states that rooftop PV capacity will expand from 25.1GW in 2026 to 42.5GW by 2036, while non-scheduled PV generation between 100kW and 30MW will grow from 1.9GW to 4.8GW over the same period.
This expansion reflects the rapid adoption of distributed energy resources (DERs) by Australian households and businesses, driven by policy incentives, declining technology costs, and consumer demand for energy independence.
Westerman emphasised that Australian consumers continue to invest in rooftop solar “at a world-leading pace” and are now adding home battery storage systems and electric vehicles (EVs) to their energy systems.
The growth trajectory positions solar PV as a cornerstone of Australia’s renewable energy strategy, with both grid-scale and rooftop installations contributing to the energy mix.
However, the increasing penetration of solar PV presents challenges for grid management, particularly regarding the variability of solar generation during peak sunlight hours and its rapid decline during evening periods.
AEMO’s report emphasises the importance of improving the visibility and predictability of DERs to ensure both long-term planning and real-time operational stability.
Battery storage systems equipped with grid-forming inverters have emerged as essential components for maintaining system stability as renewable energy penetration increases.
AEMo said that the NEM currently operates 10 grid-forming BESS sites with a combined capacity of 1,070MW, while the development pipeline includes 94 projects comprising 78 standalone battery systems and 16 hybrid installations.
Grid-forming technology provides essential system services, including synthetic inertia, system strength, and frequency control capabilities that traditional synchronous generators have historically supplied.
AEMO’s analysis highlights the importance of grid-forming inverters in stabilising the grid, though current technology provides lower fault current contributions compared to synchronous machines.
This limitation underscores the need for ongoing technological advancements to replace conventional generation capabilities fully.
The transition to high renewable energy penetration poses challenges for maintaining system strength and inertia as coal-fired power plants retire. AEMO has identified eight key transition points related to coal plant retirements that require targeted investments in system strength solutions.
The planned exit of 1,680MW coal-fired Gladstone Power Station in 2029 exemplifies these challenges, necessitating the deployment of synchronous condensers and other system strength measures to ensure grid stability in Central Queensland.
Grid-forming BESS represents a key component of AEMO’s strategy to address these requirements through advanced inverter technology.
Type 2 Transitional Services trials evaluate grid-forming inverter performance under diverse system conditions, including assessments of protection-quality fault current, system restart capabilities under high distributed photovoltaic conditions, and operation without synchronous generation.
Trial findings will inform future standards and procurement strategies, ensuring battery systems can contribute to system security.
Embedded energy storage capacity is expected to expand from 2.2GW in 2026 to 9.8GW by 2036, driven by the adoption of residential and commercial battery systems. These DERs offer potential for grid support during periods of high demand or low renewable energy generation; however, their integration requires robust technical standards and effective coordination mechanisms.
AEMO collaborates with distribution network service providers to develop functional requirements for operating a high DER power system, with key focus areas including improving data quality in the DER Register, enhancing compliance with inverter standards, and implementing emergency backstop mechanisms for distributed PV curtailment.
The increasing penetration of DERs necessitates enhanced visibility and predictability to ensure both long-term planning and real-time operational stability.
Advanced forecasting tools and flexible grid management strategies become essential as solar generation variability impacts system operations. The integration of DERs into the grid requires coordination mechanisms that can effectively harness their potential while maintaining system security.
The rapid growth of solar PV and battery systems requires reforms to the National Electricity Rules to facilitate efficient deployment of system strength and inertia resources.
AEMO submitted a rule change request to the Australian Energy Market Commission in November 2025 to address gaps in current planning and procurement frameworks.
The System Strength Impact Assessment Guidelines allow market participants to self-remediate their impacts using grid-forming technology, spurring a wave of grid-forming BESS projects.
Transmission network service providers plan to contract for over 8GW of grid-forming battery capacity by 2034, although AEMO cautions that poorly coordinated investments could create inefficiencies such as duplicative infrastructure or project delivery delays.
The proposed rule changes aim to provide greater flexibility and certainty for market participants, enabling them to make confident investments in system security solutions while advocating for integrated approaches to planning and investment coordination.
Grid-forming technology development requires continued refinement of technical standards and testing frameworks to unlock the full potential for widespread deployment.
AEMO’s voluntary specification for grid-forming inverters establishes performance benchmarks for system security contributions; however, gaps remain in current access standards, which are primarily designed for grid-following systems.
The ongoing Grid-forming Technology Access Standards Review addresses these gaps to facilitate the delivery of grid-forming services.
Parameter tuning studies suggest that grid-forming BESS have enhanced performance potential, particularly in weak grid conditions where advanced inverter capabilities prove most valuable.
Protection system design faces complications from variability in inverter-based resource behaviour, with transmission network service provider surveys revealing instances of relay maloperations and inconsistent fault current provision.
Improved modelling techniques and dynamic protection assessments become essential for maintaining grid reliability as inverter-based generation increases.
Australia’s energy transition highlights the crucial role of integrating solar PV and battery storage in achieving sustainability and reliability goals.
The 2025 Transition Plan provides a roadmap for addressing technical, operational, and policy challenges associated with this transformation. With a robust project pipeline and a focus on innovation, the NEM positions itself to lead in the global integration of renewable energy.
Technical advancement in grid-forming inverter technology, combined with appropriate policy frameworks, will determine the pace and effectiveness of Australia’s renewable energy transformation as the country moves toward its decarbonisation targets.

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Perovskite solar cells have long been seen as the most promising thin-film technology. With the launch of Perovion Technologies, TNO is taking the leap toward industrialization – and a revival of solar cell manufacturing in Europe.
Low-cost and widely available raw materials, energy-efficient production and high performance: for years, perovskite-based solar cells have been touted as the next big thing in solar. After an extended development phase, TNO now believes the technology is ready to deliver on that promise. The research institute is spinning out Perovion Technologies to bring perovskite solar cells into commercial production.
In a 2009 publication – largely overlooked at the time but now frequently cited – Japanese researchers reported a perovskite solar cell with an efficiency of 3.8 percent. In just over fifteen years, that figure has climbed beyond 27 percent, a faster rise than any solar technology before it.
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The Will County Board Planning and Zoning Commission is seen Tuesday before the start of the second night of a public hearing on Earthrise Energy’s plan for a 6,100-acre solar complex in Will County. The hearing was held at the Renaissance Center in Joliet on March 31, 2026 (Bob Okon)
An advisory panel to the Will County Board on Tuesday voted against plans for a 6,100-acre solar project.
The vote does not stop the project, which next goes to a county board committee on Thursday for review.
But the negative recommendation from the Planning and Zoning Commission was a morale boost for dozens of residents and township officials who spoke against the project.
“I’m not anti-green,” Wilton Township Highway Commissioner Ray Nugent Jr. told the commission. “I’m against the way this is being shoved down our throats by the state of Illinois.”
His comment was one of many during two nights of a public hearing that started Monday objecting to a state law aimed at encouraging development of solar power while restricting local control.
People line up at one of two microphones set up for those who wanted to speak Monday at a public hearing for Earthrise Energy’s plan for a 6,100-acre solar complex in Will County. March 30, 2026 (Bob Okon)
The commission’s 4-2 vote, however, advises against giving Earthrise the special use permit that the county would require for the solar complex to be built.
The full county board will have the final vote on the project.
The solar complex woiuld be scattered on 96 different farm properties in an area southeast of the village of Manhattan and spreading into Manhattan, Green Garden and Wilton townships.
Officials and residents from all three townships spoke against the project at the public hearing.
Manhattan Township Trustee Paul Woodcock speaks against the Earthrise Energy’s Pride of the Prairie solar plan during a public hearing on Tuesday. March 31, 2026 (Bob Okon)
But it also got substantial backing from building trades unions, solar advocates, and farmers.
Earthrise would primarily lease land from farmers for the solar project, which would generate 600 construction jobs if it is built, according to the company.
“This is not about politics,” Joe Sweeney said, speaking on behalf of the International Union of Operating Engineers Local 150. “It’s about using all the tools in our toolbox to the meet the rising demand for energy.”
The Pride of the Prairie project is just one of two large solar project Earthrise plans for Will County farm land.
The company also wants to build what it calls Plum Valley Solar, a solar complex that would cover 2,400 acres in Crete, Monee, Will, and Washington townships.
Rob Kalbouss, director of development for Earthrise Energy, (left) and Ben Jacobi, an attorney representing the company, listen to comments made during a public hearing Tuesday on the company’s plan to build a 6,100-acre solar complex in Will County. March 31, 2026 (Bob Okon)
The Planning and Zoning Commission after a separate public hearing earlier in March recommended approval of the Plum Valley Solar plan.
The County Board Land Use and Development Committee will review both Earthrise projects when it meets at 11 a.m. Thursday.
The meeting is likely to bring out many of the speakers for and against the projects.
The County Board committee meeting, like the planning and zoning hearing, is being moved to the Renaissance Center to accommodate what is expected to be a large public showing.
The Renaissance Center has a banquet hall, which accommodated what appeared to be about 300 people on Monday. It is located at 214 N. Ottawa St. in downtown Joliet.
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Bob Okon covers local government for The Herald-News

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And solar power accounted for about three quarters of the renewables.
On Wednesday, the International Renewable Energy Agency (IRENA) released its numbers on what was built in 2025. And much as we saw in the US, solar power is the primary driver of change. The numbers show that the world installed an average of 1.4 gigawatts of solar capacity every day last year, for a total of 511 GW. That brings the total solar capacity up to 2.4 Terawatts, making it the largest single source of renewable capacity by far, at more than a Terawatt above either wind or hydro.
Obviously, the actual power generated will be less than the rated capacity. And because solar panels have become so cheap, the economics now favor installing panels in areas that get far less sunlight—places in which photovoltaics would have been a questionable decision just five years earlier. So we’re likely to see the energy produced for each unit of capacity (termed the capacity factor) decline over the coming years.
How much of a factor is that? 2025’s power-generation numbers are not yet available, but data from 2024 shows photovoltaics generating 7 percent of the world’s power, with wind at 8 percent and nuclear at 9. That’s despite having 1.9 times as much solar capacity as wind capacity. Still, despite the lower capacity factor, solar is catching up fast. As these numbers don’t include concentrated solar power or last year’s data, it’s possible that solar has already become the second-largest source of carbon-free electricity (after hydropower). If not, we’re certain to see that happen before the decade is out.
This is all happening at a time when other renewables aren’t standing still. Wind power saw an additional 160 GW of capacity installed and hydro another 18 GW. The rest, meaning things like geothermal and biofuels, grew by a bit under four gigawatts.
Totaling it all up means that renewable capacity grew by roughly 700 GW last year, an increase of 16 percent. That number represents 86 percent of the overall growth in global generating capacity.
“In the midst of uncertain time, renewable energy remains consistent and steadfast in its expansion,” said Francesco La Camera in a statement that referenced the current fossil fuel price shocks. “This not only indicates market preference but also makes a strong case for renewable energy resilience with brutal clarity… Countries that invested in the energy transition are weathering this crisis with less economic damage, as they boost energy security, resilience and competitiveness.”
Overall, renewable generating capacity is now a bit over 5.1 terawatts. Over half of that (2.9 TW) is in Asia, driven by the massive expansion of wind and solar in China. Regionally, Europe is in second place, with a bit under a terawatt of capacity installed.
The data these numbers are based on is available if you want to check things out for yourself.
Ars Technica has been separating the signal from the noise for over 25 years. With our unique combination of technical savvy and wide-ranging interest in the technological arts and sciences, Ars is the trusted source in a sea of information. After all, you don’t need to know everything, only what’s important.

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Solar power soared to a record level last year, as Britain’s sunniest year was coupled with a surge in the number of panels installed by householders.
Retailers including Amazon and Lidl hope to sell plug-in solar panels within months, which are likely to lead to a further boost in solar power generation.
Solar power has been a minnow in the country’s electricity mix, but the amount of electricity generated by panels surged by 37 per cent last year. It reached 6.9 per cent of supply, according to government figures published on Thursday.
The weather played a key role. Last year was the sunniest since records began in 1910: there were 1,649 hours of sunshine, 61.4 more than the previous record set in 2003.
The UK has become sunnier since the 1980s along with the rest of Europe. Researchers believe it is because of reductions in the pollutants released from cars and fossil fuel power stations, which reflect sunlight back to space. 
Solar output was also boosted by a 15 per cent expansion in energy capacity last year, to 21.7 gigawatts. Solar power accounted for roughly three quarters of all new renewable energy capacity added last year. It marks a shift from previous years, when new capacity was typically dominated by wind power.
Alongside new panels on more than 180,000 homes, solar power was boosted by several new large solar farms coming online. Those included Clifton Solar Farm in Dorset. 
Overall, renewable sources including solar, wind and biomass provided more than 52.5 per cent of the country’s electricity last year.
With analysts predicting that the Iran conflict will push a typical energy bill to £1,929 a year in July, householders have rushed to install solar panels. 
Octopus Energy reported a 54 per cent increase in solar sales in the first three weeks of March compared to the month before. It said people had been “supersizing” systems, installing 12 panels instead of the more typical ten in the past.
Consumers could soon be able to buy solar panels from the “middle aisle” of Lidl that require no expert installation. The government is racing to change regulations that prevent people connecting plug-in panels rated 800 watts and less to domestic mains sockets. 
Such “balcony solar”, named because it is often hung over balconies, is popular in Germany and Spain. Pricing is not confirmed for Britain yet but in Germany some can cost £200, rising to around £2,000 for a complete system.
Solar panel uptake should be boosted further this year by loans with zero and low interest rates for people installing them. The loans are expected to be offered by private lenders such as banks, subsidised with around £2 billion of government funding.
A new analysis has suggested that wind and solar generation last month saved the UK £1 billion in avoided gas imports. Wind generation was up 38 per cent compared to March 2025, while solar output was also high. 
The electricity generated by the two technologies was estimated to avert imports of about 21 terawatt hours of gas, or about 18 ships loaded with liquefied natural gas. At the high market prices due to the Iran war, the gas would have cost around £1 billion, the website Carbon Brief said. 
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The Dutch research institute has presented what it describes as the world’s first perovskite-based roof tile, achieving up to 13.8% efficiency on standalone modules and 12.4% when installed on a curved surface. The flexible modules were produced using TNO’s experimental roll-to-roll platform,
Image: TNO
The Netherlands Organization for Applied Scientific Research (TNO) has unveiled today a building-integrated photovoltaic (BIPV) tile based on perovskite solar cell technology.
The new product is billed as the world’s first perovskite solar tile.
“This demonstrator is supported by the Province of North Brabant through the project ‘Solar manufacturing industry to Brabant, Solliance 2.0’. Additional funding was received from the European Union’s Horizon Europe programme for the Luminosity project,” TNO said in a statement. “The work was also partly funded by the National Growth Fund programme SolarNL.”
The Dutch research institute partnered with Netherlands-based BIPV specialist Asat BV in deploying 10 cm x 10 cm perovskite solar modules built on flexible foil onto a curved composite roof tile. Testing indicates that bending the modules to fit the curved surface has minimal impact on their performance.
Standalone modules reached energy conversion efficiencies of up to 13.8%, while the modules retained an efficiency of 12.4% after installation on the curved roof tile.
Image: TNO
The perovksite modules were encapsulated with an experimental roll-to-roll manufacturing platform developed by TNO itself. Roll-to-roll manufacturing – similar to the process used in newspaper printing – enables continuous production of solar cells on long rolls of flexible material. The technique is widely seen as a potential pathway to lower production costs and high-volume manufacturing for emerging thin-film technologies such as perovskites.
More technical details about the solar tile were not disclosed. TNO said it will be commercialized by its spinoff Perovion Technologies, which was launched last month. 
TNO’s recent research on perovskite solar cells, includes developing roll-to-roll and spatial atomic layer deposition (SALD) processes for the deposition of functional materials, solar cell layers, and flexible foils.
In July, Solarge, a manufacturer of lightweight silicon PV modules based in the Netherlands, and TNO unveiled a 32 cm x 34 cm lightweight prototype perovskite solar panel.
A month earlier, Japan’s Sekisui Solar Film, part of Sekisui Chemical, the Brabant Development Agency (BOM), which serves the Dutch province of Noord-Brabant, and TNO signed a letter of intent in Osaka, Japan to explore collaboration related to flexible perovskite solar PV module technologies.
As pv magazine has reported, Sekisui Solar Film is developing technology for lightweight, flexible perovskite solar module manufacturing using an advanced roll-to-roll process. It is working on a 100 MW plant in Japan for large-scale production, is undertaking field demonstrations, and signed a perovskite solar-related memorandum of understanding with Slovakia.
 
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India’s Ministry of New and Renewable Energy has released the fourth revision of its Approved List of Models and Manufacturers (ALMM) II for solar cells, increasing the total enlisted manufacturing capacity to 26GW. 
The fourth revision added just over 3GW of new eligible cell manufacturing capacity. The policy aims to incentivise domestic manufacturing across all segments of solar production. The updated list features domestic manufacturers such as Premier Energies and Adani Group, both of which have secured approvals for additional cell models. Evervolt Solar Technology marks a fresh entry in the latest revision, expanding the roster of India-based cell producers under the programme. 
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Bengaluru headquartered Evervolt, a subsidiary of Evervolt Green Energy, has been included in the updated list with 1,074MW of cell manufacturing capacity. The company operates a facility in Tirupati district, Andhra Pradesh, producing bifacial monocrystalline passivated emitter rear contact (PERC) cells in a 182.2mm × 182.2mm format with a 10-busbar configuration.  
The approved model, EVT-M10-BR-PERC, delivers an average conversion efficiency of 23.10% and a nominal power output of 7.66W per cell. Efficiency spans 22% to 23.50%, with output ranging between 7.26W and 7.75W. The enlistment is valid from February 2026 through February 2030. 
Premier Energies has obtained clearance for the inclusion of an additional cell model, expanding its total approved capacity by 607MW. The newly registered product is a bifacial N-type tunnel oxide passivated contact (TOPCon) solar cell in the G12R format, measuring 182.3mm × 210mm and configured with 16 busbars.  
According to the company’s specifications, the cell achieves an average efficiency of 25.37% and a mean power output of 9.71W. Reported performance ranges between 24% and 26% efficiency, with power output spanning 9.18W to 9.95W. The listing carries a validity period from July 2025 to July 2029. 
Mundra Solar PV, part of the Adani Group, has received clearance to include an additional solar cell model under the ALMM framework, expanding its approved capacity by 405MW. 
The newly cleared TPRB16 is a bifacial n-type TOPCon cell based on the 182.3mm × 210mm G12R format and incorporates a 16-busbar design. It posts an average efficiency of 25.35% with a typical power output of 9.70W per cell. Efficiency ratings range between 24.5% and 25.7%, while output spans 9.37W to 9.82W. The certification remains in force from July 2025 until July 2029. 
Sriperumbudur-headquartered FS India Solar Ventures has secured inclusion in ALMM List-II for solar cells, extending its compliance footprint beyond its existing module approval under List-I. The certification is effective from July 2025 until May 2029. Under the latest update, the company has been allocated an additional 221MW of approved cell capacity, lifting its cumulative listed capacity to 3,433MW. 
In December 2025, MNRE updated ALMM List-II for solar cells, expanding total enlisted capacity to 23.7 GW. The second revision in September 2025 had raised capacity from 4.8 GW to 17.88 GW.  
MNRE mandates that all government-backed ALMM projects source modules from List-I, cells from List-II, and wafers from the forthcoming List-III, which was first published in August with an initial 13 GW of capacity. From June 2028, solar wafers will be formally included in the ALMM, a step broadly welcomed by Indian PV manufacturers.

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China-based solar manufacturer Longi is shifting from a multi-vendor system design to a unified solar-plus-storage architecture built around in-house technologies.
Image: Longi
China’s Longi has unveiled “Longi One,” an integrated solar-plus-storage strategy that it said will replace conventional multi-vendor project architectures with a unified system design.
The strategy, announced in Beijing on April 1, marks a shift from what the company described as fragmented, “assembled” systems toward full-stack integration. Longi said the approach combines its back-contact (BC) solar technology with its “5S” storage technology into a single platform it calls a “Solar Generator.”
The company summarized the concept as “One System, One Platform, One Responsibility,” positioning itself as the single provider across project delivery and operations.
Longi said the integrated architecture is intended to reduce system losses, improve performance, and shorten deployment times. The company added that its AI-driven control platform can coordinate generation, storage, and consumption, while the “One Responsibility” model is designed to streamline accountability across the project lifecycle.
The strategy includes products for utility-scale and commercial and industrial (C&I) segments.
For utility-scale projects, Longi introduced “OneBank 2.0,” an integrated AC/DC storage system. The company said its proprietary iCCS technology enables millisecond-scale fault detection and isolation, reducing system-level failure rates by 60% and pre-commissioning time by more than 30%.
It also launched “OneMatrix 2.0,” a modular plant-level solution for two-hour, four-hour, and eight-hour storage durations. Longi said the system can reduce deployment time by 20% to 30% and lower lifecycle costs.
For the C&I segment, Longi presented “Hi-MO One,” paired with the “EnergyOne” platform. The company said the solution delivers module efficiency of 24.8% and system efficiency of up to 90.3%, with response times below 20 milliseconds and AI-based energy management.
Alongside the product rollout, Longi announced a global service initiative called the “2830 Plan,” which aims to establish 30 localized service centers in key overseas markets by 2028. The company said the plan builds on 13 GWh of delivery experience across more than 120 countries and will provide lifecycle support.
The launch also marks Longi’s first comprehensive storage strategy since acquiring Suzhou-based energy storage company Potis Edge, signaling a broader move from PV manufacturing toward integrated energy systems.
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The South African Photovoltaic Industry Association has welcomed the utility’s decision to extend its registration fee waiver for solar systems until the end of September, as it calls for the country’s municipal distributors to streamline their own processes for small-scale embedded generation systems.
Cape Town, South Africa
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South African utility Eskom has extended the current registration fee waiver for small-scale embedded generation (SSEG) systems until September 30.
Eskom originally planned to waive the registration fee for SSEGs up to 50 kW until the end of March in an attempt to boost the number of registered installations. The utility requires that all SSEG installations operating alongside its supply, including those not exporting power to the grid, are registered with Eskom or the National Energy Regulator of South Africa. 
It announced a simplification of the registration process last October, with customers currently required to only submit a certificate of compliance, inverter test certificate and test report for the installation.
In the company’s latest update, Eskom says registration is not intended to discourage people from installing solar, but to support responsible, safe and compliant connection of customer‑owned generation.
Eskom has also announced plans to introduce a prepaid option for residential customers who wish to install rooftop solar while remaining on prepaid metering. It says the option is currently being tested, with intent to proceed to broader rollout once initial implementation requirements are confirmed.
In a statement to pv magazine, the South African Photovoltaic Industry Association (SAPVIA) says it welcomes the fee waiver extension, advising that is not merely a bureaucratic requirement but a critical safety and technical necessity ensuring grid stability and worker safety.
“By extending the waiver and introducing a prepaid-friendly path, [Eskom is] removing the compliance tax that has previously deterred many households from registering their systems,” commented SAPVIA Technical and Policy Manager, Sim Khuluse. “However, this is only half of the puzzle. While Eskom is making strides, the inconsistent, often delayed and cumbersome approval processes at a municipal level continue to act as a drag on our national energy transition.”
SAPVIA’s statement explains that South Africans living in municipal supply areas face registration fees and months of administrative delays and is calling on municipal distributors to streamline their own SSEG processes.
Khuluse said South Africa needs a unified, digital-first approach across all provinces. “Inconsistent municipal by-laws create a cumulative backlog that intensifies pressure on the national grid’s technical interface and frustrates the very citizens who are investing their own capital to ensure energy security,” he told pv magazine. 
Last month, Eskom announced plans to issue notices against selected South African municipalities over outstanding municipal debts.
South Africa‘s cumulative solar capacity now stands in excess of 10 GW, after deploying 1.6 GW last year. The country’s largest solar project currently under development recently reached financial close.
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Croatia’s HEP opens tender for 56 MW solar project backed by EBRD  SeeNews
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Indian Solar Cells Market (By Material: Crystalline, N Material, P Material, Thin Film; By Product: BSF, PERC/PERL/PERT/TOPCON, HJT, IBC & MWT, Others; By Technology: Monocrystalline, Polycrystalline, Cadmium Telluride (CDTE), Amorphous Silicon (A-Si), Copper Indium Gallium Diselenide; By Installation Type: Residential, Commercial, Utility) – Industry Analysis, Size, Trends, Leading Companies, Regional Outlook, and Forecast 2026 to 2035
The Indian solar cells market size was calculated at USD 10.98 billion in 2025 and is predicted to increase from USD 12.47 billion in 2026 to approximately USD 39.43 billion by 2035, expanding at a CAGR of 13.67% from 2026 to 2035.The indian solar cells market is experiencing robust growth, driven by the country’s goal to reach 500 GW of renewable energy by 2030. The growing awareness of natural energy sources, high electricity use, and the shifting trend towards reduced fossil fuel consumption.
The Indian solar cells market refers to the development and large-scale manufacturing of solar cells to fulfill local needs. India has become one of the fastest-growing renewable energy sectors globally, due to the nation’s aggressive climate goals and dedication to sustainable development. It has enormous solar potential because of its geographical position, which receives sufficient sunlight throughout the year, making it an ideal location for large-scale solar deployment.
Solar energy adoption has been further driven by government programs like the National Solar Mission, production-linked incentives (PLI) for solar manufacturing, and favorable regulations. It is becoming increasingly appealing to residential, commercial, and industrial users due to the falling rates of solar panels and inverters, as well as the rising cost of conventional electricity. Various states, including Rajasthan, Gujarat, Tamil Nadu, and Karnataka, are leading in solar cell development, and their dependability is being further increased through the integration of cutting-edge technologies like energy storage systems and smart inverters.
Artificial Intelligence (AI) is becoming a transformative force in the development and commercialization of solar cells. Testing various materials, developing manufacturing techniques, and predicting long-term performance would particularly take months or years, but the emergence of AI tools has since accelerated the process. In the research domain, machine learning (ML) tools analyze huge amounts of datasets, pinpointing the best performance results. In the manufacturing domain, integrating AI with computer vision systems enables real-time monitoring of processes and detects minor defects that can potentially compromise the whole batch.
Which Material Segment Dominated the Indian Solar Cells Market?
The crystalline segment dominated the market in 2025, due to higher efficiency levels, durability, and better performance in India’s diverse climate conditions, especially in high temperatures and dust exposure. Various government-backed projects also favor crystalline technology due to its mature supply chain and cost-effective nature. Monocrystalline cells are further favored for high-utility scale solar parks and large rooftop projects. The PLI has also prioritized its production, thus creating a strong domestic manufacturing base.
The thin film segment is expected to be the fastest-growing segment in the coming years, due to their lightweight structure, flexibility, and comparatively lower material costs, making them a popular choice for new-age applications such as building-integrated photovoltaics, portable power, and small-scale residential installation processes. Their advantage lies in their ability to perform better in diffuse light and high-temperature conditions.
Why Did the BSF Segment Dominate the Indian Solar Cells Market?
The BSF segment contributed the biggest revenue share of the market in 2025, due to their low production costs, simplistic manufacturing processes, and a well-established supply chain. Several Indian companies continue to produce BSF cells in bulk, mainly because they are economical and suitable for large-scale and cost-sensitive utility projects. These types of cells are also popular in government-backed rural projects.
The HJT segment is expected to account for the highest growth in the forthcoming years, due to its ability to deliver higher efficiency, bifacial capability, and high performance in hot climates, making it attractive for premium as well as export-oriented projects. This segment continues to gain traction due to a growing interest in manufacturers and increasing research and development efforts.
How the Monocrystalline Segment Dominated the Indian Solar Cells Market?
The monocrystalline segment held a dominant revenue share of the market in 2025, as monocrystalline cells are produced using a single-crystal growing process, which lowers the entire unit cost and makes them more economical compared to other options. They offer high efficiency, durability, embedded energy, and lower operational costs, making them a popular option. Monocrystalline cells have a longer life span and provide space-saving benefits, further optimizing their efficiency.
The CDTE segment is expected to grow at the fastest CAGR in the coming years. This type of technology is better suited for India’s hot and humid temperatures, as these panels perform better than any other material. Additionally, it requires less material for production, which is a critical point as India aims to reduce its reliance on imported materials.
Which Installation Type Segment Led the Indian Solar Cells Market?
The utility segment led the market in 2025, due to the country’s aggressive push towards large-scale solar parks under national programs and schemes. Utility projects often benefit from economies of scale, lower costs per watt, and easier land acquisition in rural belts, thus making them attractive for both public and private investments. Various states, such as Rajasthan and Gujarat, have already become hubs for solar farms, boosting up utility scale installations.
The residential segment is expected to witness the fastest growth over the studied years. This growth is driven by decreased rooftop solar prices, supportive subsidies, net metering policies, and the rising cost of electricity in households. Increasing urbanization and the government’s push towards 40+ GW of rooftop capacity are further accelerating this segment’s growth. There are also EMI-based systems and leasing models that further increase awareness, making it accessible to middle-class households.
The Indian solar cells value chain begins with the sourcing of critical raw materials such as polysilicon, wafers, glass sheets, EVA encapsulates and silver paste. Currently, India remains heavily dependent on imports, especially from China, due to limited domestic production. However, new government schemes are aiming to build a fully integrated local production ecosystem, reducing reliance on global suppliers.
Key players: Adani Solar, Waaree Energies, Tata Power Solar
This stage involves converting wafers and raw materials into photovoltaic cells through processes such as diffusion, doping, metallization, and coating application. The government has recently approved 50+ GW of new integrated manufacturing capacity, which is expected to begin in full force from 2026, boosting local cell production.
Key players: Adani Solar, Vikram Solar, Premier Energies
The next stage involves assembling modules by interconnecting solar cells and encapsulating them with EVA, then sealing them with glass and a back sheet. This is India’s strongest segment with more than 40+ GW of installed capacity. Indian manufacturers are increasingly investing in advanced systems and fully integrated assembly lines to improve quality and reduce costs.
Key players:RenewSys India, Waaree Energies, Adani Solar
The major players in the indian solar cells market include Adani Solar, Emmvee Solar, Mahindra Susten Pvt. Ltd., Sterling and Wilson Pvt. Ltd., Tata Power Solar Systems Ltd., Vikram Solar Limited, ReNew Power Pvt. Ltd., NTPC Ltd., Azure Power Global Ltd., Websol Energy System Limited (WESL), RenewSys India Pvt. Ltd, Premier Solar Systems Pvt Ltd
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Laxmi Narayan is a strategic research analyst with five years of hands-on experience in market intelligence, encompassing primary research, secondary research, and consulting engagements. He specializes in the semiconductor, automotive, transport & logistics, and machinery & equipment sectors, providing actionable insights on evolving industry trends,technological advancements, regulatory shifts, and competitive landscapes. Laxmi’s research helps global clients identify growth opportunities, optimize operational strategies, and make informed investment decisions. Known for his analytical rigor and strategic foresight, he translates complex market data into practical recommendations that drive business impact and long-term value.
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Dutch research institute TNO has developed what it said is the world’s first solar roof tile based on perovskite technology.
TNO researchers, in partnership with thin-film PV specialist ASAT, applied a perovskite PV module on foil to a curved composite roof tile, achieving a 12.4% conversion efficiency when combined.
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The scientists said the tile’s curved shape had only a minimal impact on the performance of the individual modules, which stood at 13.8% before being applied to the tile.
Ilke Dogan, senior scientist at TNO, said: “To the best of my knowledge, this is the world’s first electrically functioning solar roof tile concept based on flexible perovskite solar cells.”
TNO said the combination of flexible perovskite technology with a building material marked a step forward in integrating solar energy into the built environment more effectively.
The organisation also said the materials and processes used in the trial were ready for industrial application, operating under normal conditions and suitable for large-scale roll-to-roll production of flexible solar foils.
“This research line enables both customised solutions and large‑scale application of flexible solar foils. TNO has completed the full development pathway: from small test cells in the laboratory, to flexible modules measuring 10 by 10 centimetres, and ultimately to a perovskite solar roof tile that can be directly applied in practice,” TNO said in a statement.
Dogan added: “This allows roofs and infrastructure to generate sustainable electricity without compromising on design or aesthetics. This makes it an important step in the further development of solar energy in the built environment.”
Karl Kiel, founder of ASAT, said: “This demonstrator of perovskite solar PV integrated into our roof tiles shows that a commercial introduction is on the short-term horizon.”
TNO said its next step would be to continue improving the technology’s lifetime, reliability, and scalability, laying the foundations for the transition of flexible perovskite solar modules into commercial applications.
Last month TNO established a spin-out company, Perovion Technologies, to lead the commercialisation of flexible perovskite technologies.

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Latest figures from the International Renewable Energy Agency find solar contributed the majority of a record 692 GW of renewables capacity added worldwide last year. 
Image: Trina Solar
A total 511 GW of solar was added globally across 2025, according to the latest report from the International Renewable Energy Agency (IRENA).
IRENA’s Renewable capacity statistics 2026 finds solar energy remained the fastest-growing source of renewable energy last year, accounting for around 75% of the 692 GW of renewables added worldwide in 2025.
The figures represent a record in a calendar year for both global solar deployments and total renewables deployment, outperforming the previous 452 GW of solar and 585 GW of renewables records featured in last year’s equivalent report.
Total worldwide renewable power capacity reached 5.14 TW by the end of 2025, IRENA’s report adds, equivalent to 49% of global installed power capacity, with solar accounting for around 2.4 TW of the total.
Renewable energy accounted for an 85.6% share of all power capacity expansion worldwide in 2025, down on the 92.5% quoted in IRENA’s report last year.
Asia continued to lead renewables deployment in 2025 with a 74.2% contribution to all new renewable capacity, while both Africa and the Middle East recorded their largest annual growth in renewables deployment to date, increasing by 15.9% and 28.9% year-on-year respectively.

Uptake was slower in other parts of the world, with Central America and the Caribbean recording the lowest renewables capacity with a total 21 GW in 2025. IRENA says this disparity exposes the vulnerability of economies with low share of renewables and underscores the urgent need to increase the share for their energy security.
The agency adds that with escalation in the Middle East raising fresh concerns over supply security and fossil fuel price volatility, increasing the share of renewable energy in national energy systems can help to reduce countries exposure to international fuel markets.
IRENA Director-General, Francesco La Camera, commented that renewable energy remains consistent and steadfast in its expansion in the midst of uncertain times, indicating both market preference and a strong case for renewable energy resilience. In the report’s forward, he added that the world needs to see a much faster pace of growth in the stock of renewable power plants and distributed electricity generation.
“A more decentralized energy system, with a growing share of renewables and more market players, is structurally more resilient,” La Camera explained. “Countries that invested in the energy transition are weathering this crisis with less economic damage, as they boost energy security, resilience and competitiveness.”
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The Australian Renewable Energy Agency (ARENA) has announced up to AU$151 million (US$98 million) in conditional funding for Sunman Energy to establish a 500MW solar module manufacturing facility in the Hunter Valley, New South Wales (NSW).
This marks the largest single commitment under the federal government’s AU$1 billion Solar Sunshot programme.
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The Hunter Valley Solar Foundry project, led by the Sunman Group and founded by solar pioneer Dr Zhengrong Shi, will develop an advanced manufacturing facility utilising the company’s lightweight solar technology, which highlights domestic innovation in solar technology, according to industry stakeholders.
The facility will reduce solar module costs by approximately 15% by eliminating import expenses, while supporting Australia’s position as a global leader in solar research and deployment.
The NSW government has provided an additional AU$20 million investment to support the project, which aims to commence operations by 2029.
ARENA CEO Darren Miller stated the new Hunter Valley facility will help build Australia’s solar manufacturing capability, reduce reliance on imports and expand the nation’s role in global clean energy supply chains. The project represents a transformation of the former coal-mining region into a hub for renewable energy manufacturing.
Sunman already operates a 1GW manufacturing facility in China and a 500MW facility under construction in the US.
The funding announcement follows Sunman subsidiary Energus’ receipt of AU$1.3 million through the Solar Sunshot programme earlier this year to support a feasibility study for a 50,000 tonne per annum solar-grade polysilicon production facility in the Hunter Valley.
The study assessed the technical, commercial and environmental viability of producing high-purity polysilicon in Australia.
The Solar Sunshot programme, announced by the Australian government in March 2024, aims to increase Australia’s role in the global solar PV manufacturing supply chain.
Despite Australia having the world’s highest household solar adoption rate, with one in three homes installing rooftop solar PV systems, only 1% of the modules are manufactured domestically.
5B became the first recipient of Solar Sunshot funding, securing up to AU$46 million to expand the manufacturing capacity of its Maverick solar deployment system. The Sydney-headquartered company’s prefabricated solar array system enables rapid deployment of utility-scale projects.
Tindo Solar received AU$34.5 million under the programme to upgrade its Mawson Lakes facility in Adelaide’s northern suburbs, scaling annual output from 20MW to 180MW.
The South Australia-headquartered manufacturer will invest in automation and expand its product range to include premium n-type solar modules, while conducting a feasibility study for a future 1GW gigafactory.
ARENA supported three additional feasibility studies, worth AU$11 million, to explore the local production of polysilicon, ingots and wafers, which are critical upstream components in solar module manufacturing.
These studies examine the technical and commercial viability of establishing domestic supply chains for essential materials used in solar manufacturing.
ARENA launched a AU$150 million second round of the Solar Sunshot programme in September 2025, targeting commercial domestic manufacture of critical segments of the solar supply chain.
The programme provides production subsidies and grants to support innovation across the solar manufacturing sector, with the first phase launching capital and production-linked funding for solar PV manufacturing innovation.
The initiative focuses on modules, inputs to modules and deployment systems to create a comprehensive domestic manufacturing ecosystem.
The Solar Sunshot programme could reshape Australia from a solar consumer to a manufacturing hub, leveraging the country’s abundant renewable energy resources, high-quality raw materials and research excellence.
The initiative also aims to help ARENA achieve its goal of developing ultra-low-cost solar energy. Readers of PV Tech will be aware that ARENA is working towards its vision for ultra-low-cost solar, arguing that a ‘30-30-30’ approach to solar—representing 30% solar module efficiency and an installed cost of AU$0.30 per watt by 2030—could help Australia become a renewable energy superpower.

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Rooftop solar capacity in Puerto Rico reached around 1.5 GW in 2025, passing natural gas and becoming the territory’s second-largest generation source, said the Energy Information Administration.
EIA noted that distributed battery storage has increased alongside rooftop solar in Puerto Rico, with data from the Puerto Rico Energy Bureau showing that “171,372 households and businesses had a distributed battery storage system at the end of 2025, with a total energy capacity of 2,864 megawatt hours.”
Rooftop solar generation in Puerto Rico has increased each year since 2017, when Hurricane Maria battered the island and rendered 80% of its grid inoperable, according to a 2019 EIA report.
After Hurricane Maria, Puerto Rico’s “net generation dropped from 1.57 million megawatt hours (MWh) in August 2017 to 0.27 million MWh in October 2017,” said EIA. A year later, generation had recovered, but renewables still made up a small share of total generation.
While the capacity of other generation sources on the island remained steady, increases in rooftop solar generation since 2017 have brought Puerto Rico’s total generation capacity from below 6 GW to well over 7 GW. 
In January, the Trump administration canceled $300 million of funding for solar energy installations in Puerto Rico, citing its increased share of the island’s generation mix. 
“The Puerto Rico grid cannot afford to run on more distributed solar power,” the Department of Energy said in an email, according to reporting from the Associated Press. “The rapid, widespread deployment of rooftop solar has created fluctuations in Puerto Rico’s grid, leading to unacceptable instability and fragility.”
However, LUMA has been leveraging Puerto Rico’s network of distributed resources to bolster the grid, EIA said.
In summer 2025, LUMA “expanded the Customer Battery Energy Sharing program, allowing power stored in distributed battery storage units to supply power to the grid when the operator forecasts electricity supply shortages,” creating virtual power plants which LUMA works with companies like Sunrun and Tesla to manage, said EIA.
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Calling it the largest loan in the agency’s history, DOE said it aims to deliver over $7 billion in cost savings for Georgia Power and Alabama Power customers.
Dominion Energy utility lands $4.8-billion, high-voltage, direct-current underground project in Virginia as NextEra Energy-Exelon is awarded a $1.7-billion project in Pennsylvania.
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Calling it the largest loan in the agency’s history, DOE said it aims to deliver over $7 billion in cost savings for Georgia Power and Alabama Power customers.
Dominion Energy utility lands $4.8-billion, high-voltage, direct-current underground project in Virginia as NextEra Energy-Exelon is awarded a $1.7-billion project in Pennsylvania.
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Australia generated 5,271GWh of utility-scale solar PV and wind power in November 2025, a 28% increase from the same period last year.
This is according to figures from analyst Rystad Energy, which published data on Australia’s electricity generation this week. The top three solar projects by capacity factor—SUN Energy’s 132MW Merredin project, Synergy and Potentia Energy’s 10MW Greenough River facility and Lightsource bp’s 300MW Wellington North project—are located in Western Australia and New South Wales, demonstrating the geographic diversity among Australia’s top-performing solar projects.
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This compares to the wind sector, where the top three projects by capacity factor are located in Western Australia, as reflected in the graph below.
Rystad noted that New South Wales also led the country in utility-scale PV generation, with 891GWh, compared to 715GWh of wind generation. New South Wales is home to a 300MW solar farm owned by Octopus Australia, the largest PV project to begin construction this year, and the Blind Creek solar-plus-storage project, which began construction earlier this year and is the largest such project to commence this year.
Other noteworthy events highlighted by Rystad include 9.03TWh of renewable energy generation in Australia’s National Energy Market (NEM) during November, the second-highest monthly total on record. This follows a strong performance in October, during which all NEM PV projects, across both the utility-scale and distributed sectors, generated 4,715 GWh of electricity, representing a 9.88% year-on-year increase from the 4,291 GWh recorded in October 2024.
Rystad said 2025 was also shaping up to be a record-breaking year for the NEM overall. The consultancy said it had tracked over 9GW of new solar and wind capacity additions between January and November 2025, and predicted 10GW of new NEM capacity would be energised by the end of the year. Should it meet this forecast, it will be the first time the market has added over 10GW of capacity in a single year.
However, Rystad also noted that November was a record for negative hours in South Australia (346 hours, accounting for 48% of the month), Victoria (320 hours for 44%) and New South Wales (214 hours for 30%).
Power prices pushed into the negatives is a common occurrence for regions that are deploying significant renewable energy capacity, and is often tackled with the integration of more battery energy storage systems (BESS); Australia added close to 3GW of new BESS in the year to the third quarter of 2025, and will need to continue this pace of installation to limit the impacts of negative hours going forward.

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Recently, the government of India announced its Union Budget 2026-27, reinforcing support for renewables and energy storage with a 32% increase in solar funding. 
Key measures include extending duty exemptions on capital goods for lithium-ion cell production to battery energy storage systems (BESS), removing Basic Customs Duty (BCD) on sodium antimonate used in solar glass, and supporting critical mineral processing. 
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The budget also announced a INR200 billion (US$2.3 billion) Carbon Capture, Utilisation and Storage (CCUS) scheme targeting hard-to-abate industrial emissions. 
A series of customs duty exemptions, aimed at strengthening domestic clean-energy manufacturing, was also welcomed by the Indian solar sector, and Charith Konda, energy specialist, Institute for Energy Economics and Financial Analysis (IEEFA), who spoke to PV Tech Premium about the budget. 
According to Konda, the budget focuses on “establishing of a stronger supply chain within the solar and PV cell and module manufacturing sector in India.”  
A key issue being addressed is India’s longstanding inverted duty framework. 
“India is famously known for its inverted tax structure, where upstream materials and raw materials are charged at a higher tax rate than the finished product,” Konda told PV Tech Premium. “This budget will change that.” 
Previous policy efforts, Konda noted, had prioritised downstream products, reducing duties on finished modules while leaving higher taxes in place on upstream inputs. The latest measures, including reductions in BCD on materials used in solar glass and other components, seek to lower production costs and improve competitiveness. The same logic has been extended to lithium-ion cells used in battery energy storage systems (BESS). 
“We cannot differentiate. Nowadays, we hardly see standalone solar or wind auctions. Ultimately, it’s the cell manufacturing capacity that will come into play,” he said, referring to the decision to align incentives for stationary batteries with those already available for electric vehicle cells. 
The move comes as storage becomes increasingly embedded in India’s renewable tenders. The country’s energy storage market saw strong growth in 2025, with a total of 69 tenders issued, representing 102 GWh, a 35% increase from 2024. Commissioning during the year stood at 0.5 GWh, while 60 GWh are under execution and 115 GWh in various tendering or awarded stages.  
However, this shift in tax prioritisation is unlikely to deliver any cost relief for module buyers in the short term, according to Konda. 
“It will take some time, and we will not see an immediate reflection in the module or cell or module prices. At least we should give it three to six months,” noted Konda. “Even then, the scale of any price reduction remains uncertain. How much of it will translate into cost reduction for module prices remains uncertain.” 
Beyond domestic market dynamics, the measures also have implications for India’s positioning in global supply chains, particularly as Western economies pursue diversification away from China. 
Konda noted that the push reflects geopolitical realignments and supply chain vulnerabilities, including trade barriers, tariff risks and regulatory scrutiny. Indian solar manufacturers must navigate complex compliance requirements, diversify markets and maintain competitiveness against low-cost producers, particularly from China. 
He added that the capacity being built is not solely for domestic deployment. Lowering upstream input costs, he said, improves India’s ability to compete internationally, even as price gaps remain.
“The capacity that we build is just not for Indian domestic consumption, but also for export … although we cannot compete with them on the price,” Konda said, referring to Chinese manufacturers. He noted that the budget measures are aimed at “improving our competitiveness, increasing our competitiveness in the global markets.” 
At the same time, he stressed that the budget reforms will strengthen domestic supply chains over time. 
“My expectation is that the budget will improve India’s situation in terms of supply chain security and strengths, maybe not immediately. It will be a very gradual progress.” 
However, Konda cautioned that strengthening domestic supply chains will be a gradual process. “Supply chains cannot be built overnight. They require ecosystem changes. These require systemic changes,” added the analyst.
He pointed to broader challenges including land acquisition, electricity costs, labour availability and technical expertise, arguing that fiscal tweaks alone will not deliver rapid transformation. Policy stability will be critical for investors, he stressed. 
The implementation of India’s solar policies continues to face significant hurdles. According to Konda, the key challenges that remain include inadequate infrastructure, slow land acquisition, high compliance and monitoring costs, complex bureaucracy, labour constraints and difficulties in accessing policy subsidies, all of which can hinder the effective rollout of renewable manufacturing and storage projects. 
He also flagged the tight timelines under such government schemes: “Two years for any policy to come on to the ground is a short time,” adding that “at least we need five –to-seven years of policy window.” He stressed that “Execution is as important as the policy itself.” 
Beyond timelines, systemic challenges remain a key barrier. “Monitoring and compliance costs should be lowered and free from bureaucracy,” said Konda. “Incentives are in place, but companies shouldn’t ignore them or operate outside the system. Doing so defeats the purpose and wastes the allocated funds.” 
Giving an example of one such case, the analyst noted that the ACC (advanced chemistry cell) PLI (production-linked incentive) scheme for ACC battery storage, launched in October 2021 to establish 50GWh of domestic manufacturing capacity, saw some companies like Amar Raja and Exide pursue capacity building independently after missing out on incentives. 
Konda underscored that “execution is critical” to ensure policies effectively support manufacturers. 

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The world added a massive 692 gigawatts (GW) of renewable power in 2025, pushing total global capacity to 5,149 GW, according to a new report from the International Renewable Energy Agency (IRENA).
That’s a 15.5% jump in just one year, and renewables made up 85.6% of all new power capacity added globally. Fossil fuels are still around, but they’re clearly losing ground when it comes to new builds.
This surge is happening at a moment when energy security is back in focus. Rising geopolitical tensions, especially in the Middle East, are once again exposing the vulnerability of fossil fuel supply chains to global shocks and price spikes.
Renewables, on the other hand, are local, fast to deploy, and increasingly cheap. That’s making them a key tool for countries looking to stabilize their energy systems and reduce exposure to volatile fuel markets.
IRENA Director-General Francesco La Camera said the trend is hard to ignore: “Countries that invested in the energy transition are weathering this crisis with less economic damage, as they boost energy security, resilience, and competitiveness.”
Solar dominated 2025’s growth, adding 511 GW, or about three-quarters of all new renewable capacity.
Wind followed with 159 GW of new capacity. Together, solar and wind made up 96.8% of all new renewable additions last year.
That’s not a coincidence – these two technologies have seen the steepest cost declines, and they’re now the fastest to scale.
Other technologies are growing, but much more slowly. Bioenergy added 3.4 GW, while hydropower (excluding pumped hydro) added 18.4 GW. Geothermal barely moved the needle, with just 0.3 GW added globally.
Not every region is benefiting equally from the renewables boom.
Asia continues to dominate, accounting for 74.2% of all new renewable capacity in 2025 – a staggering 513.3 GW. The region’s renewable capacity grew by 21.6% year over year.
Africa, while still smaller overall, posted its fastest growth yet, adding 11.3 GW (up 15.9%), led by Ethiopia, South Africa, and Egypt.
The Middle East also saw a surge, with capacity growing 28.9%, driven largely by Saudi Arabia.
But the gap remains wide. Asia now has 2,891 GW of total renewable capacity, compared to Europe’s 934 GW. Central America and the Caribbean lag far behind, with just 21 GW total.
That imbalance matters. Regions with lower renewable shares are more exposed to fossil fuel price swings and supply disruptions – exactly the risks that are in the spotlight right now.
This is the clearest signal yet that the energy transition is accelerating.
When 85% of new global power capacity is renewable, the debate shifts. This isn’t about whether clean energy will take over; it already is, at least when it comes to new builds.
What’s driving it isn’t just climate policy. It’s economics and risk. Solar and wind are now the cheapest, fastest options in most markets, and they don’t come with fuel price volatility or geopolitical baggage.
That last point matters more than ever. Every time tensions spike in the Middle East, fossil fuel markets wobble. Countries that leaned into renewables are now seeing the payoff – more stable energy costs and less exposure to global shocks.
But the report also highlights a growing divide. Asia is sprinting ahead, while regions like Central America and the Caribbean are barely on the board. That’s not just a climate issue; it’s an energy security problem.
Geothermal is generally hard to execute. However, in the UK they are exploring the idea of using abandoned, flooded coal mines as a heat source for geothermal heating. The water in these mines can be 20º C (68º F) or even higher as one in Yorkshire is 45º C at 1 km depth. Water source heat pumps are used to extract the stored heat from the mineshafts. The UK has thousands of abandoned mines and this could be a much less complicated way to reap the benefits of geothermal heat.
The transition is happening fast, but not evenly. And the countries that move fastest will be the ones least exposed when the next energy crisis hits.
Read more: FERC: Renewables made up 88% of new US power generating capacity in 2025
If you’ve ever considered going solar, make it easy by finding a trusted, reliable solar installer near you that offers competitive pricing by checking out EnergySage. It has hundreds of pre-vetted solar installers competing for your business, ensuring you get high-quality solutions and save 20-30% compared to going it alone. Plus, it’s free to use, and you won’t get sales calls until you select an installer and share your phone number with them. 
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Michelle Lewis is a writer and editor on Electrek and an editor on DroneDJ, 9to5Mac, and 9to5Google. She lives in White River Junction, Vermont. She has previously worked for Fast Company, the Guardian, News Deeply, Time, and others. Message Michelle on Twitter or at michelle@9to5mac.com. Check out her personal blog.
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Australian solar and thermal energy storage company RayGen says it has achieved a major international milestone with the commissioning of a 1 MW concentrated solar plant in Brazil.
Image: RayGen
RayGen has installed a 1 MW concentrated solar system in Brazil with local power company Axia Energia, formerly known as Eletrobras, investigating the technology’s potential to help power ‘AI factories.’
RayGen Chief Executive Officer Richard Payne said the new facility is now fully operational, showcasing the Melbourne-based company’s concentrated solar technology in one of the world’s fastest-evolving energy markets.
“This is a proud moment for RayGen and for Australian innovation and advanced manufacturing,” Payne said in a Linkedin post. “Our unique technology, which generates clean electricity and thermal energy, is being rolled out internationally.”
RayGen’s PV Ultra technology uses an array of mirrors, or heliostats, to concentrate sunlight onto PV modules located in a central receiver. The solar generation system is traditionally coupled with a thermal water-based energy storage system but the Brazilian project has so far been limited to the concentrated solar element.
The new 1 MW facility, deployed at Axia’s Petrolina site in Brazil’s northeast, features a standalone PV Ultra system, comprising a heliostat field, receiver tower, PV Ultra modules and plant control system.
Axia, responsible for 17% of the Brazil’s power generation capacity and 37% of the total transmission lines in the national interconnected system, said the Petrolina site will be used to test the technology under local conditions prior to their potential deployment at scale.
Axia Executive Vice President Technology and Innovation Juliano Dantas said pioneering RayGen’s technology opens up alternatives to combine renewable energy, energy storage, and inertia.
“It is about enabling solar generation driven by demand, with power quality, which is very much aligned with Axia Energy’s philosophy of serving the market,” he said, adding that the company “intends to further investigate how this system can help power AI factories.”
RayGen’s integrated solar electricity generation and long-duration energy storage technology has been on show at a test facility at Newbridge in Victoria since 2015. The company also operates a commercial facility at Carwarp in the state’s northwest. That facility, that came online in 2023, consists of 4 MW solar and 3 MW / 50 MWh storage, capable of delivering 17 hours of continuous power to the electricity grid.
The Carwarp facility is under an offtake agreement with AGL which has also acquired the rights for an approved utility-scale project planned for Yadnarie, on South Australia’s Eyre Peninsula.
The Yadnarie project would include 200 MW of solar generation and thermal storage of 115 MW capable of running at full capacity for just over 10 hours (1,200 MWh.
Updated April 1 to clarify the project does not include energy storage element.
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Danish independent power producer (IPP) European Energy has secured approval for its 1.1GW Upper Calliope solar project in Queensland near Gladstone, Australia. 
According to the firm, the project is underpinned by a 25-year power purchase agreement (PPA) with mining and materials group Rio Tinto. Power generated will supply Rio Tinto’s Queensland operations, including aluminium smelting and alumina refining facilities in the Gladstone region.
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The site benefits from proximity to existing transmission infrastructure and a well-established industrial demand base, the company said. 
“Securing planning approval materially advances the Upper Calliope project and reduces execution risk,” said Thorvald Spanggaard, executive vice president and head of project development at European Energy. 
“Together with the long-term contracted offtake, the project now represents a permitted, utility-scale solar asset with defined revenue characteristics – one of the largest of its kind.” 
The firm will now move the project into advanced development, including finalising grid connection, procurement and investment. 
In October 2025, the company partially divested a solar and storage project in Latvia to Sampension, one of Denmark’s largest pension funds. The IPP sold 50% of its 111MW Saldus project, pairing 65MW of PV and a 46MW BESS, to the pension fund. European Energy said the divestment would enable it to recycle capital into its pipeline of new projects. 
Additionally, European Energy commissioned a 90MW hybrid solar-wind park in Sweden, marking its first hybrid project. Located in Kronoberg county, the Skaramala project combines 39.3MWp of solar PV with 49.6MW of wind capacity. 
Skaramala is the first of three hybrid projects planned in Sweden. A second project, Grevekulla, is under construction and will pair 38MW of solar PV with the existing 36MW Grevekulla wind farm, with commissioning expected in 2026. 

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Solar generation rose 20.4% YoY to 41.2 BU in Q4 2025
February 5, 2026
Follow Mercom India on WhatsApp for exclusive updates on clean energy news and insights
Solar power generation in India rose nearly 22% year-over-year (YoY) to 164.5 billion units (BU) in 2025, up from 133.7 BU, according to data published by the Central Electricity Authority (CEA).
Solar power generation growth in Q4 2025 was driven by the commissioning of multiple projects delayed from 2021 and 2022 due to uncertainties linked to the Great Indian Bustard (GIB) conservation case. These projects were implemented under the Central Public Sector Undertaking (CPSU), IREDA-backed, and other central government programs. Execution momentum picked up after the Supreme Court’s verdict eased blanket restrictions on renewable energy development in designated priority zones, providing regulatory clarity and allowing construction and transmission activities to resume.
Parallelly, developers accelerated execution and grid connectivity ahead of the expiry of the interstate transmission system (ISTS) charges waiver in June 2025, pushing several projects toward early or partial commissioning to retain transmission cost exemptions. Projects that achieved partial commissioning before the deadline were granted full ISTS charge exemptions for the entire approved capacity, further encouraging faster execution.
The combined impact of regulatory clarity on GIB-related constraints and the approaching ISTS waiver deadline led to a marked increase in commissioned capacity in Q4 2025, supporting higher solar power generation.

Q4 2025
Solar power generation during the fourth quarter (Q4) of 2025 reached 41.2 BU, up 8% from 38.2 BU in Q3 and 20.4% YoY from 34.2 BU in Q4 2024. The increase was driven by solar installations, which rose 8.8% quarter over quarter and 39.6% year over year, supporting generation growth.
The northern region generated the highest solar power during the quarter, with 15.6 BU, accounting for 38%. The southern and western regions followed with 13.2 BU and 11.7 BU, accounting for 32.2% and 28.5%, respectively. The eastern and northeastern regions generated 409.5 MU and 95.8 MU, accounting for 1% and 0.2%, respectively.

 
Rajasthan remained India’s leading solar power-producing state, generating 13.5 BU, followed by Gujarat and Karnataka, which generated 6.1 BU and 4.6 BU, respectively.
Solar generation in Rajasthan decreased by 5.5%, while in Gujarat and Karnataka it rose by 26.5% and 14.8% QoQ, respectively.
In Q4 2025,  Rajasthan continued to experience curtailment, peaking at 51.5% between 10:30 am and 2:30 pm across around 4.3 GW of capacity, due to nearly 18 months of delays in Phase II transmission lines, including the Khetri–Narela corridor. This curtailment sharply reduced peak-hour solar generation, with about 8.1 GW of renewable energy zone output stranded due to limited general network access capacity of about 14 GW, compared with 22.5 GW of approved projects.
India’s renewable energy capacity, including large hydroelectric projects, reached 258.3 GW by the end of Q4 2025, accounting for 50.2% of the country’s total installed power capacity, based on data from the CEA, the Ministry of New and Renewable Energy, and Mercom’s India Solar Project Tracker.
Mercom’s India Solar Project Tracker provides access to the most comprehensive database of large-scale solar projects covering commissioned and under-development projects.
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© 2026 by Mercom Capital Group, LLC. All Rights Reserved.

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Climate Tech is Making Europe More Resilient to Energy Shocks  Bloomberg.com
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Pakistan’s solar boom blunts energy crisis  CNN
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Premier Energies powers up 5.6-GW TOPCon solar module factory in India  renewablesnow.com
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A ₹760 million stabilization fund will support pay-ins and pay-outs
April 1, 2026
Follow Mercom India on WhatsApp for exclusive updates on clean energy news and insights
The Ministry of New and Renewable Energy (MNRE) has approved a pilot Contracts for Difference (CfD) program for renewable energy, with the Solar Energy Corporation of India (SECI) designated as the nodal agency.
Under the approved framework, SECI will issue a tender for 500 MW of renewable energy capacity to supply 1,500 MWh of power during three non-solar hours each day. The specific hours may be defined within a designated time band by SECI, allowing developers operational flexibility.
The projects will be implemented on a build-own-operate basis, with a contract tenure of 12 years.
Developers will be selected through a competitive reverse bidding process, with a cap of 125 MW per bidder to ensure broader participation.
The CfD mechanism will enable renewable energy generators to sell electricity on power exchanges, while SECI will settle the difference between a competitively discovered strike price and the prevailing market clearing price. This structure is designed to provide revenue certainty to developers while retaining market-based price discovery.
Settlements will be benchmarked to zonal day-ahead market (DAM) prices, and the bidding sequence will follow a structured order beginning with the Green Day-Ahead Market (GDAM), followed by DAM, and subsequently the Real-Time Market (RTM).
To support the settlement framework, the government has created a ₹760 million (~$8.12 million) stabilization fund for pay-ins and pay-outs. The profits and losses will be shared daily between the renewable energy generator and the CfD pool in a 30:70 ratio, with monthly reconciliation.
If the pool turns zero or negative at any point during the 12-year tenure, SECI must replenish it from its own resources, while the Government of India’s outgo under the framework will remain limited to ₹760 million (~$8.12 million).
Revenue from the sale of renewable energy certificates tied to power sold in DAM or RTM must also be deposited into the CfD pool. SECI may retain up to 25% of profits credited to the pool, after deduction of the generator’s share, to meet operational expenses, although a two-year moratorium will apply before such withdrawals begin.
Upon completion of the 12-year contract period, developers may continue to sell power in the open market without CfD support, or enter into power purchase agreements or bilateral arrangements, subject to applicable regulations.
The pilot aims to test the financial, operational, and regulatory viability of CfDs in India’s evolving power market, providing a potential pathway for scaling market-based renewable energy procurement mechanisms in the future.
Recently, SECI invited quotations from scheduled commercial banks to invest ₹4.5 billion (~$49.603 million) in term/fixed deposits.
Subscribe to Mercom’s India Solar Tender Tracker to stay on top of real-time tender activity.
Arjun Joshi
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Spanish renewable energy developer Ecoener has secured 15-year power purchase agreements (PPAs) to build two solar PV projects totalling 200 MWp in Guatemala. 
The portfolio comprises the 140 MWp Cocales and 60 MWp La Hulera solar PV projects, marking a significant milestone as the first in Guatemala to integrate battery energy storage systems (BESS).  
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Cocales will feature a BESS with 20 MW/80 MWh of storage capacity, while La Hulera will include a 10 MW/40 MWh system, enhancing grid flexibility and supporting renewable integration. Both plants are slated to commence operations in early 2028. 
The contracts were secured through Guatemala’s largest power auction, awarded via an international tender that received 51 technical bids for around 4.7 GW of capacity under the government’s Power Generation Expansion Plan to meet burgeoning domestic energy demand. 
“This contract award reaffirms the strength of Ecoener’s international position and our capacity to compete successfully in highly competitive environments. It is also a relevant stage in the incorporation of storage solutions that deliver greater operational efficiency and long-term value to the company, as well as stability to the electricity system,” Luis de Valdivia, chairman of Ecoener, said. 
With the commissioning of the Cocales and La Hulera projects, Ecoener will bring its operational capacity in Guatemala to 362MW. The company is entering an expansion phase after its largest single-year increase in 2025, when 253MW came online, taking its total capacity to 680 MW. Including the projects currently under construction, Ecoener’s total installed capacity globally will reach 815MW. 
Beyond Guatemala, Ecoener has a presence in 13 other markets across the Americas – including Colombia, the Dominican Republic, Honduras, and Panama – as well as in Europe, including its home market of Spain and Greece, and in Asia. 
Last year, the firm secured a US$43.1 million loan from Proparco, the French Development Agency-backed financier, to fund its 60 MW Payita 1 solar PV project in the Dominican Republic’s María Trinidad Sánchez province. 

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LAFAYETTE, IN — Large-scale solar projects in Tippecanoe County would be a lot smaller than previously proposed, according to new language introduced in the county’s solar ordinance amendment.
During Wednesday’s Area Plan Commission Ordinance Committee meeting, Tippecanoe County commissioners Tracy Brown, David Byers and Tom Murtaugh all said they support a project cap of 400 acres.
Conversations around large-scale solar developments began in early 2025 after a 1,700-acre development dubbed the Rainbow Trout Solar project was proposed for the northwestern side of Tippecanoe County.
After the Rainbow Trout Solar project was halted in August following a 4-3 vote to deny by the Tippecanoe County Board of Zoning Appeals in August, Geenex and RWE Energy, the companies behind Rainbow Trout Solar, filed a civil lawsuit to reverse the decision. In December, Circuit Court Judge Sean Persin ruled that a group of 11 neighbors who fought the proposed solar development will be allowed to intervene in the company’s lawsuit.
After a March 4 APC ordinance committee meeting, preliminary language in the ordinance limited the total for large-scale solar projects at 6,000 acres across the entire county but offered no caps on individual projects. It also allowed large-scale solar projects in agricultural, agricultural-wooded or office research zones while removing land zoned AA, or prime agriculture land, qualifying for special exception for large-scale solar.
Brown said 1,700 acres, the proposed size for Rainbow Trout Solar, was a “big chunk” of land, but he noted the next large-scale solar project could be even more.
“It may not take long to get to 6,000 acres total,” Brown said. “It makes sense to cap a project at 400 acres. Not only cap it, but also put a distance between projects so that you have a buffer.”
Brown said he also would propose a one-mile distance between projects so that developers don’t attempt to piggy-back off previous project sites.
Byers said that while reading reports from committee members tasked with crafting language for the ordinance, he was disheartened by the lack of concern for the type of farm ground projects would encompass.
“From the get-go, I have been against it, but I am willing to work with it,” Byers said. “Who knows? We’ve heard 400 acres will kill a project; no one will do it. Panels change, panels may get better, they may be able to absorb four times the power. So a 400-acre facility might equal a 1,000-acre facility down the road.”
Commissioners also requested additional setbacks from property lines, including 50 feet from a public right-of-way, 500 feet from a non-participating property with one side touching the project, 700 feet from a non-participating property with the project touching on two sides, 1,000 feet from a non-participating property with three sides touching the development, and 1,500 feet from a non-participating property with all four sides touching the development.
Kenny McCleary, a member of the Solar Study Committee organized to help craft and negotiate language for the county’s proposed ordinance, said he is disappointed, discouraged and frustrated by the ordinance’s proposed decommissioning plan.
“What you have in front of you is a piece of Swiss cheese,” McCleary said. “The decommissioning document you have in front of you is a hollow shell of what the community team put together to be a very thorough, comprehensive, full life cycle effort to ensure that the county, that property owners, that adjacent property owners, that the environment and our county infrastructure are not put at risk by this type of project throughout its entire life cycle and through the restoration and recovery into whatever mixed purpose that ground is going to have when this thing is pulled out.”
The plan initially proposed by the committee was drawn from the experiences of neighboring counties in their solar developments, McCleary said. What is currently included in the proposed ordinance requires the project owner manage panel removal, soil restoration after removal and inspection requirements throughout the decommissioning process.
Lindsey Payne, member of the West Lafayette Go Greener Commission, was also on the Solar Study Committee. She said she is in favor of large-scale solar developments.
Throughout the committee’s nine meetings between September and February, which lasted two to three hours each session, Payne said she found herself with concerns about language in the proposed ordinance that may not be an outright ban but could have that effect on large-scale solar projects.
“I think large-scale solar is a very viable energy option, but I think it needs to be done thoughtfully,” Payne said Wednesday. “I think we really do need to be thoughtful with how we address public health and safety, but that’s deeply wrapped up in non-renewable impacts.”
Although the newly proposed language would tightly restrict the size of solar developments in Tippecanoe County, Payne said she still believes large-scale solar is a viable energy option.
“I appreciate the time that Tom Murtaugh and the APC staff put into making this committee happen and seeing it come together so we could talk about these things; it was a noble effort,” Payne said. “We need to engage in this kind of discourse in order to address these kinds of challenges in our community.”
The proposed ordinance will move to the April 15 Area Plan Commission meeting at 6 p.m. in the Tippecanoe County Building at 20 N. APC members will vote to recommend to approve or deny the proposed amendment, which will then be sent to the commissioners.
Jillian Ellison is a reporter for the Journal & Courier. She can be reached via email at jellison@usatodayco.com.

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NextGen Nano to launch USD-400m agrivoltaics roll-out  Renewables Now
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NTPC Green Energy Partners With PTC India To Boost Renewable Power Sales In India  SolarQuarter
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India's reliance on crude oil imports heavily influences its current account deficit, making up about 30% of its merchandise imports and costing $130 billion annually. The nation sees its energy transition, including reaching peak oil consumption, as a key route to economic independence. This transition is supported by rapid solar capacity growth, aiming for 136 GW by the end of 2025, and increasing electric vehicle (EV) sales, which now represent 5% of new car purchases. Although strong services exports in FY25 generated a surplus of $189 billion, helping the trade balance, the substantial cost of oil imports—estimated at $116.4 billion in FY25—continues to strain the economy.
India is building an "electrotech fast track" — a development path quite unlike the fossil-fuel-heavy industrialization taken by the U.S. and China. Even at similar income levels, India's per capita coal power generation is less than 40% of China's 2012 rate, and its per capita oil use for roads is half. Solar power capacity has grown dramatically, increasing 3,450% since 2014 to reach 136 GW by end-2025, with 37.9 GW added just in 2025. Domestic solar panel manufacturing capacity has also surged to 144 GW by year-end 2025, nearly meeting demand. The electric vehicle (EV) market is growing fast, with electric cars making up 5% of total sales and electric three-wheelers accounting for about 60% of their category, contributing to over 2.36 million EV sales in 2025. The recent passage of the SHANTI bill, opening the nuclear sector, adds potential for reliable base power. Globally, renewable energy investment hit $2.2 trillion in 2025, with India drawing significant foreign funding, though its borrowing costs for large-scale renewables are higher than in developed nations.
Despite clear technological progress and government ambition, achieving India's energy independence goals faces significant challenges. Bureaucratic delays and poor execution often slow down even well-meaning initiatives like the PM Surya Ghar and PM E-DRIVE programs. Efforts to boost domestic oil production, crucial for reducing import dependence, are hindered by a complex regulatory system that makes local output economically difficult. The biggest risk, however, is ensuring policy consistency. Long-term energy transition plans are susceptible to political changes, as a lack of broad political consensus and stable safeguards discourages the long-term private investment needed. Although India's EV car sales reached 4.3% in 2025, this is slightly below the 5% average among leading countries and China's earlier progress. Moreover, the nation's heavy reliance on imported energy makes it vulnerable to oil price swings and supply issues. UBS recently highlighted this, downgrading Indian stocks to Neutral because of a strong link between oil prices and Indian equity performance.
Forecasts that India could achieve a current account surplus before 2035 seem realistic, supported by ongoing growth in its services exports and the potential reduction of oil import costs through its domestic energy transition. The renewable energy sector is a major attraction for foreign direct investment, drawing $23.04 billion between 2000 and mid-2025. Globally, renewable sources are expected to exceed coal in electricity generation by late 2025 or early 2026, a shift India is part of. This progress relies on India's capacity to tackle bureaucratic red tape, simplify regulations, and create stable, long-term policies that encourage the sustained investment required for its energy goals and economic independence.

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