The agreement centres on the 50 MW Pizarroso solar plant in Cáceres, which has been operational since 2023. Under the deal, Zelestra will integrate a 160 MWh battery energy storage system into the facility, transforming it from a standalone solar installation into a hybrid asset capable of responding to market fluctuations and supporting grid stability. Unlike greenfield hybrid projects—where solar and storage are designed together—the retrofit model introduces added engineering challenges, including system integration, inverter compatibility, and grid interconnection constraints. Despite this complexity, the model highlights a growing need to enhance the performance of existing renewable assets rather than relying solely on new capacity additions.

Spain’s rapid solar expansion has intensified midday oversupply risks, leading to price cannibalisation and curtailment in certain regions. By incorporating storage, operators can shift energy output to periods of higher demand, improving revenue predictability while reducing strain on the grid during peak production hours. The 160 MWh system suggests a configuration focused on intra-day balancing, aligning with current opportunities in energy arbitrage and ancillary services, although long-term value will depend on how electricity markets evolve to reward flexibility.

EDP’s role as the offtaker reflects a broader shift in power purchase agreement structures, moving away from fixed-volume contracts toward more dynamic arrangements that incorporate storage-enabled optimisation. By embedding storage within the agreement, EDP gains greater control over supply-demand alignment, reducing exposure to negative pricing and improving portfolio balancing. The companies previously collaborated on a project in Trujillo, Extremadura, combining 170 MW of solar with 400 MWh of storage. The progression toward retrofit applications signals a broader expansion of hybridisation strategies, reinforcing the relevance of the Solar Storage Retrofit model across different asset types and development stages.

BKV is evaluating both greenfield development and acquisitions of gas-fired power assets, with the objective of adding roughly 1GW of capacity. The company’s focus remains firmly on Texas, where it already operates two gas-fired facilities via its publicly listed US arm. These assets, secured in 2021 and 2023, each deliver approximately 1.5GW and serve the state’s power market. As demand from AI-driven and cloud-based data centres intensifies, Banpu sees tightening supply conditions as a catalyst for new investments.

“The US power business will be a core earnings driver, supported by sustained demand from data centres and AI,” said Vongkusolkit in an interview. “Valuations have increased, but the long-term growth outlook continues to justify investment.” The Banpu US expansion plan reflects a broader strategic pivot, as the company gradually reduces its reliance on coal and builds a more diversified energy mix anchored in gas and renewables.

While this transition is underway, Banpu continues to benefit from external market dynamics. Supply disruptions in the Middle East have supported coal demand, prompting the company to increase output across its mining operations in China, Indonesia and other regions. Alongside its US ambitions, Banpu maintains a global power portfolio spanning China, Laos, Vietnam and Australia, with a combined generating capacity of 3GW.

To meet this clean power goal, authorities intend to expand renewable energy capacity to 100 gigawatts by 2030, with a focus on scaling up solar and wind power generation. The South Korea renewable energy target comes against the backdrop of renewable sources accounting for 11.4 percent of total power generation last year, underscoring the scale of expansion required over the next decade.

As part of the broader clean power transition strategy, the government will progressively shut down 60 coal-fired power plants by 2040 while accelerating the deployment of cleaner energy alternatives. Alongside capacity expansion, policy support will be directed toward strengthening green industries, including the development of solar modules, wind turbines, and battery energy storage systems.

The plan also extends to industrial decarbonisation. Authorities will assist key sectors in shifting toward environmentally sustainable operations, including backing the steel industry’s ambition to commercialize hydrogen-based reduction iron-making technology by 2037 and supporting the petrochemical sector’s move to electrify naphtha cracking centers. In parallel, the government aims to ensure that 40 percent of new vehicle sales consist of electric or hydrogen-powered models by 2030. “We will swiftly implement the energy transition plan to make sure that South Korea remains resilient to external shocks, such as the ongoing conflict in the Middle East,” Climate Minister Kim Sung-whan said in a press release. The South Korea renewable energy target reflects a broader push to align energy security with industrial transformation goals.

The project introduces the first commercial application of domestically developed 8.6-meter large-aperture parabolic trough collectors. Designed with six hours of molten salt thermal storage, the system enables power generation beyond daylight hours while supporting peak load management. Utilizing heat transfer oil-based technology, the solar field spans 242,000 square meters and incorporates 68 loops, including eight equipped with the newly developed 8.6-meter collectors and 60 with 5.77-meter variants.

Annual electricity generation is projected at approximately 719 million kilowatt-hours. The facility is expected to reduce coal consumption by about 216,900 tons and lower carbon dioxide emissions by roughly 652,300 tons. Over its lifecycle, the project is anticipated to contribute around 774 million yuan ($110.57 million) in local tax revenue. To date, it has generated over 2,000 local jobs and delivered more than 5.2 million yuan in income through labor and equipment utilization, the company stated.

According to Lin Boqiang, director of the China Center for Energy Economics Research at Xiamen University, China’s expansion into ultra-high-altitude CSP highlights both the region’s strong solar resources and advancing technological maturity. He noted that deploying projects above 4,500 meters remains technically demanding, yet China is currently leading in translating such capabilities into commercial-scale execution. The high-altitude CSP plant initiative aligns with broader national efforts to scale renewables, storage, and electrification to reduce reliance on oil and mitigate risks linked to global energy supply disruptions.

Industry data from the China Solar Thermal Alliance indicates that around 25 CSP projects were under active construction by the end of 2025, totaling approximately 3,000 megawatts in capacity. China’s long-term target aims to expand installed CSP capacity to about 15,000 megawatts by 2030, implying the addition of roughly 6,000 megawatts over the next five years, based on guidance from the National Development and Reform Commission.

Global Model Reveals Uneven UV Exposure Risks

Engineers from UNSW have developed a high-precision global model that quantifies ultraviolet radiation exposure on solar panels based on geography, atmospheric conditions, and mounting configurations. The model delivers the first global-scale comparison between fixed-tilt and tracking PV systems, enabling developers and asset owners to better anticipate performance outcomes across regions.

The findings indicate that UV radiation varies significantly across climates, with arid and tropical regions experiencing the highest exposure levels. As outlined in the IEEE study , UV irradiance can exceed 80 W/m² in arid zones, compared to less than 30 W/m² in high-latitude regions, highlighting substantial geographic variability.

This variability directly translates into differences in degradation behaviour, even for identical module technologies installed under similar configurations.

Tracker Systems Face Elevated Degradation Exposure

The study highlights that system design plays a decisive role in UV exposure. Solar panels mounted on single-axis or dual-axis tracking systems receive significantly higher UV radiation compared to fixed-tilt installations.

• Tracking systems can receive up to 1.5 times more UV radiation
• Annual UV-driven degradation can reach 0.35% per year
• Fixed-tilt systems typically see around 0.25% per year

Over a standard 20-year operational lifecycle, this differential compounds into measurable performance loss. The IEEE analysis further notes that tracking systems can experience approximately twice the degradation rates in arid and semi-arid regions compared to fixed-tilt systems .

While trackers improve energy yield, the findings introduce a trade-off between generation efficiency and long-term asset durability.

UV Degradation Impacts Asset Lifespan

A key conclusion of the research is that UV degradation alone can account for a substantial share of total module performance loss in solar PV systems.

In high-irradiance environments:

• UV-related degradation may contribute nearly 25% of total annual degradation
  System lifespan could be reduced by 7–10 years
• This challenges the commonly assumed linear degradation rates of around 0.5% annually used in financial and performance modelling.

As observed by Power Info Today, this non-linear degradation profile introduces uncertainty in long-term yield forecasts and levelised cost of energy (LCOE) calculations, particularly for utility-scale solar projects in high-UV regions.

Testing Standards Underestimate Real-World Conditions

The study raises concerns over existing international testing frameworks. Current standards, such as UV preconditioning requirements of 15 kWh/m², fall significantly short of real-world exposure.

In regions like Alice Springs, Australia, this threshold can be reached in just over a month, compared to decades of expected operational exposure.

According to the IEEE findings :

• Standard test exposure levels represent only a fraction of lifetime UV dose
  Even enhanced protocols fail to replicate 25–30 years of field conditions
• This mismatch suggests that modules passing certification may still face accelerated degradation in operational environments.

Technology Shift Increases UV Sensitivity

The transition toward high-efficiency PV technologies is further amplifying the issue. Advanced cell architectures such as TOPCon, heterojunction (HJT), and PERC are designed to capture a broader solar spectrum, including UV wavelengths.

However, these designs may increase vulnerability to UV-induced material degradation. The IEEE paper notes that modern architectures often use UV-transparent materials and modified passivation layers, which can heighten sensitivity to UV exposure and accelerate performance decline .

Strategic Implications for Solar Project Development

The introduction of a global UV modelling framework provides actionable insights for developers, manufacturers, and asset owners.

Key applications include:

• Site-specific module selection based on UV exposure profiles
• Improved accelerated stress testing prior to deployment
• Optimisation of mounting configurations for lifecycle performance
• Enhanced financial modelling incorporating non-linear degradation

Power Info Today notes that the findings reinforce the need for climate-specific engineering approaches in solar deployment, particularly in high-radiation geographies where performance risks are most pronounced.

Towards Climate-Specific Reliability Standards

The study underscores the necessity of revising industry standards to reflect real-world environmental stressors. Climate-specific testing, higher UV exposure thresholds, and regionally adaptive reliability benchmarks are identified as critical next steps.

Ultimately, the research positions UV degradation as a central variable in solar PV systems’ performance, requiring greater integration into design, testing, and investment decision-making frameworks across the energy sector.

Under the planned France offshore wind tender, authorities will allocate a total of 10 gigawatts of capacity, split evenly between turbines fixed to the seabed and floating wind installations. The projects will be distributed across seven designated zones spanning the English Channel, Atlantic Ocean and Mediterranean Sea. In a move aimed at strengthening regional supply chains, the tender will include provisions requiring developers to rely on domestic and European manufacturing, reducing dependence on Chinese components.

The timing of the auction reflects mounting pressure within the sector. Developers have been contending with higher equipment costs, tighter financing conditions, and ongoing construction challenges. Industry sentiment has also been affected by project cancellations in the US linked to decisions by Donald Trump. Against this backdrop, the French government is attempting to provide stability while maintaining its long-term climate commitments, including achieving carbon neutrality by mid-century.

Despite parallel investments in nuclear energy, the government’s renewable push has faced criticism from opposition groups such as Marine Le Pen’s National Rally ahead of the upcoming presidential election. France has also scaled back earlier expansion targets for solar and onshore wind, increasing the strategic importance of offshore deployment.

Energy minister delegate Maud Bregeon stated the tender would help “consolidate our industry for bottom-fixed wind, and to become the leader of the floating wind industry.” She added that up to four of nine strategic turbine components and as much as 50% of permanent magnets may still be sourced from China. Developers selected under the France offshore wind tender are expected to receive a guaranteed power price of below €100 ($115) per megawatt hour.

Recent project dynamics highlight both opportunity and risk. The government awarded a 1.5-gigawatt offshore project to TotalEnergies SE last year after limited bidding interest. Meanwhile, Electricite de France SA has encountered construction delays and sought to renegotiate support for projects off Normandy. Currently, France operates nearly 2 gigawatts of offshore wind capacity, with 5.6 gigawatts under construction or development. The country aims to reach 15 gigawatts by 2035 and 45 gigawatts by 2050, meeting roughly 20% of national electricity demand.

The new entity is designed to streamline the development, construction, ownership and operation of solar, wind, and battery storage assets. By pooling capital resources and technical expertise, the JV deal partners intend to accelerate deployment and strengthen their competitive position across high-growth markets. Upon completion, the platform will act as the exclusive vehicle for both companies’ onshore renewable energy activities in the region. The venture will include 3GW of operational assets alongside an additional 6GW of projects currently in advanced stages, with commissioning targeted by 2030.

Commenting on the agreement, Masdar CEO Mohamed Jameel Al Ramahi said: “This joint venture reinforces Abu Dhabi’s status as a global center for energy leadership, combining the expertise of Masdar and TotalEnergies to drive renewable energy deployment across Asia. For Masdar, this JV strengthens and diversifies our portfolio, unlocking new opportunities in attractive, high-growth markets, while bringing in a like-minded partner to accelerate growth and deliver additional value in our existing markets.” Both partners will contribute assets of comparable value to the venture, ensuring balance in ownership and operational input.

The headquarters of the joint venture will be located within Abu Dhabi Global Market, with a workforce of approximately 200 employees drawn from both organisations. The agreement remains subject to regulatory clearances and customary closing conditions. Patrick Pouyanné, chairman and CEO of TotalEnergies, stated: “We are delighted with the signing of this agreement with Masdar, which brings together two major renewable players to build a renewable champion in Asia. It will allow us to combine the strengths of our two companies to secure significant positions in these markets and create more value than if we were acting alone. This agreement is fully in line with the renewable energy strategy of our Integrated Power business. We are also pleased to further deepen, in this area, the long-standing relationship between the United Arab Emirates and TotalEnergies.”

The African Energy Chamber (AEC), representing industry stakeholders, welcomed the development, emphasizing the importance of stronger intergovernmental and institutional linkages. Increased coordination between Petrosen and NNPC is expected to facilitate knowledge transfer, enhance institutional frameworks and accelerate project execution across upstream, refining and gas commercialization segments. Senegal Nigeria energy ties also aligns with ongoing efforts to operationalize the Africa Energy Bank, with Senegal already contributing capital and positioning itself within the financing structure for future energy projects.

“This is exactly the kind of collaboration Africa needs. When countries like Senegal and Nigeria work together – sharing knowledge, building infrastructure, strengthening NOCs and improving policies – we create an environment where investment can thrive and where Africa can take control of its energy future. Strong partnerships between African nations will be the foundation of energy security, industrialization and economic growth across the continent,” states NJ Ayuk, Executive Chairman, AEC.

Momentum around Senegal Nigeria energy ties comes as both countries scale their oil and gas ambitions. Senegal continues to build on recent production milestones, including operations at the Sangomar oilfield and the Greater Tortue Ahmeyim (GTA) LNG project. Output at Sangomar has stabilized at approximately 100,000 bpd, while GTA has recorded 24 LNG cargo exports between February 2025 and February 2026, alongside 1.6 million barrels of condensate marketed internationally. The country is also advancing the Yakaar-Teranga offshore project and pursuing a $100 million onshore exploration campaign aimed at unlocking new reserves through seismic acquisition and exploratory drilling.

Nigeria, Africa’s largest oil producer, is simultaneously targeting production levels of around 2 million bpd while expanding its refining and gas sectors. A 2025 licensing round offering 50 frontier and one deepwater block is expected to attract $10 billion in investment, complemented by renewed engagement with international oil companies including Chevron, ExxonMobil and Shell. The NNPC is targeting $30 billion in upstream investments by 2030.

On the downstream side, plans are underway to expand the Dangote Refinery’s capacity to 1.4 million bpd, while recent gas flare commercialization initiatives are set to unlock $2 billion in investments. The growing alignment between Senegal and Nigeria reflects a wider continental shift toward cooperative frameworks aimed at strengthening energy security, infrastructure development and long-term market integration.

Key Announcements and Strategic Milestones

A historic milestone was recorded on June 15, 2025, when Nepal began exporting 40 MW of electricity to Bangladesh through India’s transmission network. This tripartite framework established the first operational cross-border electricity commerce beyond simple bilateral deals in South Asia. In addition to this, Bhutan has recently commissioned the 1,020 MW Punatsangchhu-II hydroelectric project and its first large-scale 22.38 MW Sephu solar plant, signaling a move toward a more diversified renewable portfolio.

Meanwhile, India’s Central Electricity Authority (CEA) has outlined a massive grid expansion plan to support a peak demand projected to reach 459 GW by 2035-36. This roadmap introduces operational measures such as Solar Hour and Non-Solar Hour concepts to optimize the use of existing transmission lines for wind and battery storage during low-solar periods.

Investments and Financial Frameworks

The scale of the regional clean energy transition requires unprecedented capital mobilization. India’s transmission roadmap alone proposes the addition of 137,500 circuit kilometers of lines at an estimated cost of nearly ₹7,93,300 crore. Bangladesh’s draft Energy and Power Sector Master Plan (EPSMP) 2026-2050 estimates a requirement of $107.4 billion for the electricity sector and up to $85 billion for primary energy.

In Pakistan, the people-led solar revolution has already demonstrated significant fiscal impact, helping the country avoid approximately $12 billion in oil and gas imports as of February 2026. Furthermore, the Asian Development Bank (ADB) has remained a critical financier, with $20.54 billion cumulatively invested in 86 projects across the subregion as of December 2023.

Policy and Regulatory Shifts

Nations are introducing market-oriented reforms to attract private participation. Pakistan has launched the Competitive Trading Bilateral Contract Market (CTBCM) to move away from a single-buyer model toward a competitive structure where generators and large consumers negotiate directly. Similarly, Sri Lanka has enacted amendments to the Electricity Act to unbundle the Ceylon Electricity Board (CEB) into separate state-owned enterprises for generation, transmission, and distribution.

India has notified a long-term trajectory for Energy Storage Obligations (ESO), which will increase to 4% by FY 2029-30, requiring that at least 85% of stored energy be procured from renewable sources. From an industry standpoint, Power Info Today believes these regulatory frameworks are being structured to support the management of intermittency associated with large-scale non-fossil capacity deployment.

Operational Impact and Technology Deployment

The operational focus has shifted to grid stability and high-voltage transfer. India is implementing 1150 kV AC transmission systems to carry large volumes of electricity from renewable-rich states like Rajasthan and Gujarat to industrial hubs. In the battery energy storage system (BESS) sector, battery prices have dropped 65% since 2021, making co-located solar-plus-storage systems cheaper than new thermal plants in many contexts.

Nepal’s performance in the first five months of FY 2025/26 underscores the operational success of regional trade, with the country earning Rs. 18.26 billion from power sales to India and Bangladesh. However, analysts warn that Pakistan’s rapid 5 GW rooftop solar surge is creating revenue erosion for distribution companies, highlighting the need for urgent grid modernization and tariff restructuring.

Market and Strategic Relevance

The regional energy landscape is now defined by the necessity of decoupling growth from volatile fossil fuel imports. While fossil fuels still account for roughly 69.99% of South Asia’s primary energy mix, the non-fossil capacity is outpacing fossil growth. India reached a historic milestone in July 2025, where renewable generation met 51.5% of the country’s total daily electricity demand. As the war in Iran continues to threaten global trade routes, the push for an integrated South Asian grid connecting the hydropower of the Himalayas with the solar-rich plains of India and the coastal wind potential of Sri Lanka has transitioned from a developmental goal to a matter of regional energy security.

Power Info Today observes that the growing emphasis on cross-border electricity trade, grid expansion, and storage integration reflects a broader alignment of regional energy systems with evolving security and supply stability priorities.

Under the terms of the MOU, the companies will explore cooperation across a range of technical domains linked to the SMR rollout, including fuel qualification and testing, plant life management, hot cell technology, core design and operational modelling, as well as regulatory licensing support. The arrangement allows Rolls-Royce SMR to assess Studsvik’s facilities and technical capabilities, while identifying areas where these services can support the deployment of its ‘factory-built’ NPPs. Chris Cholerton, Rolls-Royce SMR CEO, said: This agreement expands our relationship with Studsvik and strengthens our European supply chain, bringing together worldclass expertise to support the rollout of Rolls-Royce SMR technology. Studsvik’s long-standing capabilities in nuclear services make them an ideal partner as we accelerate towards deploying our SMRs across global markets.

Studsvik President & CEO Karl Thedéen also pointed to the timing of the agreement as aligned with increasing momentum in nuclear investment. He said: Governments and customers around the world have taken decisions on important investments in nuclear power, creating long-term opportunities. We are convinced that working closer together, both organisations will benefit from the acceleration of Rolls-Royce SMR business activities in the Nordics, UK and Europe, supporting stable, clean, and reliable energy. The Rolls-Royce SMR design features a three loop PWR delivering 470 MWe derived from 1,358 MWt, built around modularisation principles that prioritise factory-based assembly using standardised components alongside advanced manufacturing techniques.

Progress on deployment continues following the outcome of a multi-year competition managed by Great British Nuclear (now Great British Energy – Nuclear), where Rolls-Royce was selected as the primary technology partner and preferred bidder in June 2025, with a Final Investment Decision (FID) anticipated in 2029. The UK Government identified Wylfa on the island of Anglesey, North Wales, in November 2025 as the site for three Rolls-Royce SMRs, with potential expansion to eight units. In parallel, the company has been selected by Czech utility ČEZ to deliver up to 3 GWe of new nuclear capacity in the Czech Republic and remains among the final two contenders in Vattenfall’s technology selection process in Sweden for potential SMR construction at the Ringhals NPP site. Studsvik continues to support the global nuclear sector with specialised services spanning fuel and materials testing, plant life-extension, and operational efficiency, backed by more than 75 years of experience in nuclear technology and radiological services.