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ENERGY GL BAL Autumn 2026

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ENERGY GLOBAL

CONTENTS 03. Guest comment

AUTUMN 2026

28. The global shift to ultra-large modules

04. Building a renewable future in Asia Pacific Sonya Kalnin, Watson Farley & Williams, looks at Asia Pacific's transition from building capacity to building systems.

Arif Aga, Director, SgurrEnergy, questions whether 600 – 700 Wp designs are compromising mechanical reliability in the solar photovoltaics industry.

32. The maintenance bias in operations and maintenance

Kieran Hill-Cousins, Monitoring and Performance Manager, Ethical Power, places a spotlight on the importance of how renewable energy sites are operated, and emphasises how availability should be used as a metric for performance. Sonya Kalnin, Partner, Watson Farley & Williams, looks at Asia Pacific’s transition from building capacity to building systems.

enewable energy markets across Asia Pacific are confronting a paradox. After years building generation capacity, the challenge is now how to integrate that capacity into power systems while maintaining reliability, supporting economic growth, and meeting demand. This challenge is emerging across markets with very different resource bases and stages of development, from Japan’s mature power market to Singapore’s import-led strategy and Indonesia’s resource-driven transition. Despite these differences, convergence is evident. Policymakers, utilities, developers, and investors

are focused on the same issues: procurement, transmission, system flexibility, market design, and reliability. The next phase of renewable development will therefore be defined less by technology deployment, and more by the systems required to support it at scale.

Corporate demand is becoming a defining market driver One of the most significant developments across Asia Pacific is the growing influence of large electricity consumers on renewable energy markets.

ENERGY GLOBAL AUTUMN 2026

he UK solar industry has plenty of reasons to celebrate in 2026. The 800 MW, co-located Springwell solar farm has become the largest solar project approved in the UK to-date, and the wave of utility scale photovoltaics (PV) approvals signals a decisive shift in how the country generates power. Developing and building these projects is impressive and rightly receives healthy press coverage. However, there is one question that rarely makes the front page: once these sites are built, how well are they

10. The heat transition

Raymond C. Decorvet, Global Business Development, Heat Pumps, Everllence, explains mega heat pumps for grid balancing and district heating. 32

14. Fail to prepare; prepare to fail

Megan Barrett, Executive Director, Engineering Tomorrow, rings the alarm on tomorrow's energy labour shortage and argues why it should be addressed at earlier levels of education.

20. From demonstrators to serial production: Industrialising floating wind foundations

Laurent Verdier, Chief Business Development Officer, BW Ideol, outlines how recent production line developments signal to the floating offshore wind industry that a sustainable supply chain is getting ready to serve a multi-gigawatt pipeline.

24. Strengthening solar energy with smarter cybersecurity

As solar becomes increasingly recognised by EU institutions as critical grid infrastructure, its importance to Europe's energy security is coming into sharper focus. Christelle Barnes, General Manager at SolarEdge UK, addresses how photovoltaic installers, developers, EPCs, and system owners can strengthen cybersecurity and better protect both their assets and the wider grid.

ENERGY GLOBAL AUTUMN 2026

36. Beyond dry docking: The future of asset integrity in floating offshore energy Danny Constantins, Executive Chairman, EM&I, Malta, explores how innovation, robotics, and continuous maintenance are reshaping offshore production in Asia Pacific and beyond.

42. Understanding the corrosion challenge Robert Cole, Corrocoat, discusses extending asset life in Energy from Waste facilities through advanced corrosion protection.

48. Global news

ENERGY GL BAL Autumn 2026

Reader enquiries [enquiries@energyglobal.com]

ON THIS ISSUE'S COVER Large scale heat pumps are emerging as a key technology for decarbonising heat supply. A flagship example with high-efficiency compressor technology from Everllence is located in Esbjerg, Denmark. There, the world’s largest CO₂-based seawater heat pump supplies climate-neutral heat to around 25 000 households while helping balance fluctuations in renewable power generation.

Forever pioneers. Forever for the better. Forever excellence.

Copyright © Palladian Publications Ltd 2026. All rights reserved. No part of this publication may be reproduced, stored in a retrieval system, or transmitted in any form or by any means, electronic, mechanical, photocopying, recording or otherwise, without the prior permission of the copyright owner. All views expressed in this journal are those of the respective contributors and are not necessarily the opinions of the publisher, neither do the publishers endorse any of the claims made in the articles or the advertisements.

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COMMENT

Carl Gurney

Director of Renewable Energy, Gallagher UK & Ireland

T MANAGING EDITOR James Little james.little@palladianpublications.com SENIOR EDITOR Elizabeth Corner elizabeth.corner@palladianpublications.com EDITOR Jessica Casey jessica.casey@palladianpublications.com EDITORIAL ASSISTANT Abby Butler abby.butler@palladianpublications.com SALES DIRECTOR Rod Hardy rod.hardy@palladianpublications.com SALES MANAGER Will Powell will.powell@palladianpublications.com PRODUCTION DESIGNER Siroun Dokmejian siroun.dokmejian@palladianpublications.com HEAD OF EVENTS Louise Cameron louise.cameron@palladianpublications.com MARKETING AND DIGITAL EXECUTIVE Sophie Birss sophie.birss@palladianpublications.com DIGITAL EVENTS COORDINATOR Merili Jurivete merili.jurivete@palladianpublications.com DIGITAL CONTENT COORDINATOR Kristian Ilasko kristian.ilasko@palladianpublications.com DIGITAL ADMINISTRATOR Nicole Harman-Smith nicole.harman-smith@palladianpublications.com ADMINISTRATION MANAGER Laura White laura.white@palladianpublications.com SENIOR WEB DEVELOPER Ahmed Syed Jafri ahmed.jafri@palladianpublications.com Editorial/Advertisement Offices: Palladian Publications Ltd 15 South Street, Farnham, Surrey, GU9 7QU, UK +44 (0) 1252 718 999 www.energyglobal.com

he UK’s energy transition is often framed as a future challenge, but considerable progress has already been made: the country has halved its emissions since 1990, while continuing to grow its economy. This represents one of the biggest infrastructure projects of our time and the financial and operational challenges are wide-ranging, making insurance and risk management critical to attracting investment and supporting the delivery of projects. The UK is increasingly relying on renewable energy and emerging technologies as it continues to decarbonise its energy system. A significant milestone was reached in late 2024 with the closure of the country’s last coal-fired power station, ending 142 years of coal-fired electricity generation. This marks an important step away from the most carbon-intensive fossil fuel and towards a more sustainable future. Today, more than 50% of UK electricity generation is powered by renewable sources such as hydropower and solar energy, with 2024 marking the first time that the country reached this milestone. However, for all the progress made, around 80% of the UK’s overall energy demand is still met by fossil fuels, highlighting the scale of the challenge that remains. Decarbonising sectors such as manufacturing still requires much further investment and innovation in electrification. Electrification is transforming transport, heating, and digital infrastructure in the UK and globally, and is a key reason why the country has made such considerable progress in reducing emissions. The growth of electric vehicles has been central to this transition, with heat pumps also expected to play a greater role in the years ahead, having only been installed in a fraction of UK homes to date. However, electrification also brings new challenges as the UK grid system is not currently catered for this change. Upgrade works are already underway in some parts of the country, requiring significant investment

and co-ordination. It undoubtedly represents the biggest change to our energy system for many generations. At the same time, emerging technologies – namely artificial intelligence (AI) – are creating additional demand for electricity, adding further complexity to the equation. The rapid growth of data centres and AI significantly increases the demand for electricity, posing challenges for grid capacity. Research suggests that data centres use around 1.5% of global electricity, but usage varies significantly by country – for example, some suggest that it uses as much as 6% of the nation’s supply in the UK and US. The government’s ambition for the UK to be a leading force on AI requires further investment in data centres, which are energy intensive. The UK’s energy infrastructure will therefore need to evolve to support energy generation and storage. Meeting this demand will require substantial long-term investment, creating an important role for insurers and risk managers in supporting project delivery and resilience. Insurance is essential to enabling new technologies to scale – without it, lenders are unlikely to provide the capital needed to launch or develop projects. But insurers do more than transfer risk, they also help businesses to identify vulnerabilities and advise on decision-making to improve resilience. These are complex, high-value projects and investors and lenders need to be confident that the risks – ranging from supply chain disruption to the protection of assets – have been accurately identified and accounted for. The UK’s energy transition is well underway, but the scale of the challenge ahead should not be underestimated. Expanding renewable energy generation and storage, supporting the development of emerging technologies, and meeting the increased demand for energy required by emerging technologies such as AI all present a sizeable challenge. Insurers and risk managers are therefore not just supporting projects, but are critical to their launch and continued success.

ENERGY GLOBAL AUTUMN 2026

Sonya Kalnin, Partner, Watson Farley & Williams, looks at Asia Pacific’s transition from building capacity to building systems.

Corporate demand is becoming a defining market driver One of the most significant developments across Asia Pacific is the growing influence of large electricity consumers on renewable energy markets.

In Japan, distributed generation and corporate power purchase agreements (PPAs) are driven by technology companies and industrial manufacturers seeking access to renewable electricity. Corporate demand for green power is influencing project development. Similar dynamics are emerging elsewhere in the region. Thailand’s growing demand from data centres, digital infrastructure, and manufacturing is driving renewable procurement structures, including the Utility Green Tariff programme and direct PPA initiatives, with a proposed 2 GW pilot programme for data centres. Vietnam is expanding participation in direct PPAs and allowing negotiated pricing under evolving market frameworks. Indonesia’s National Digital Economy Strategy 2030 and Singapore’s growth in advanced manufacturing, digital infrastructure, and electric transportation is likewise driving rapidly-rising electricity demand and demand for secure and reliable low-carbon electricity. In both markets, access to clean and dependable power is becoming increasingly important for attracting investment in energy-intensive industries and data centres. Across the region, renewable energy procurement is being shaped by commercial demand rather than government support mechanisms alone.

Figure 1. If corporate demand is reshaping the economics of renewable energy, grid infrastructure is shaping its practical limits.

Figure 2. Access to clean and dependable power is becoming increasingly important for attracting investment in energy-intensive industries and data centres.

ENERGY GLOBAL AUTUMN 2026

Grid infrastructure moves to the centre of the energy transition If corporate demand is reshaping the economics of renewable energy, grid infrastructure is shaping its practical limits. Japan provides a particularly clear example. Despite significant renewable deployment, grid modernisation remains a major challenge. Curtailment, connection bottlenecks, and geographical constraints continue to affect project development and are important considerations for policymakers, utilities, and investors. The approximately 480 MW Ukujima mega solar project in Nagasaki Prefecture illustrates both the scale of opportunity and the complexity of integration. Expected to be completed in 2027, the project will be one of Japan’s largest solar facilities and among the largest globally. Located on an island, it requires more than 60 km of undersea high-voltage transmission cable to connect generation to the Kyushu grid, giving it transmission requirements more commonly associated with offshore wind projects. Grid constraints are becoming more visible elsewhere in the region: Thailand has identified grid capacity and connection timelines as material constraints for large scale renewable projects and energy-intensive developments; Vietnam continues to face congestion and curtailment challenges reflecting rapid capacity expansion and grid integration constraints; South Korea’s First Basic Plan for Renewable Energy includes structural reforms to grid access and transmission development moving beyond first-come allocation. Although the specific constraints differ, from curtailment in Japan to congestion in Vietnam and connection bottlenecks in Thailand, the underlying challenge is increasingly the same, ensuring transmission can keep pace with renewable deployment. Singapore’s target to import approximately 6 GW of low-carbon electricity by 2035 highlights the growing importance of regional diversification and interconnection. Indonesia is expected to play a significant role in this evolution, despite tightening supply-demand conditions domestically. Through co-operation between the two countries, Indonesia’s Riau Islands and Sumatra provinces are being positioned as potential sources of low-carbon electricity exports to Singapore via future subsea transmission infrastructure. This emerging Indonesia–Singapore corridor is one of the clearest examples of how the region’s energy transition is evolving beyond national markets. Renewable energy development is increasingly being linked to regional transmission networks, cross-border electricity trade, and broader energy co-operation. Collectively, these developments highlight an important shift. The energy transition is increasingly dependent not only on renewable generation, but also on the infrastructure required to connect renewable resources to demand centres, both within and across national borders.

Storage and system flexibility become increasingly important As renewable penetration increases, system flexibility is becoming an increasingly important component of energy transition planning. Japan offers several notable examples. The Sano-shi mega-solar and battery energy storage system (BESS) project combines utility scale solar generation with co-located battery storage, demonstrating the growing integration of storage with renewable generation. Similarly, the Dohoku wind power cluster combines more than 500 MW of onshore wind capacity with a dedicated 240 MW/720 MWh battery facility designed to alleviate curtailment and improve utilisation of renewable generation. Vietnam is also increasing deployment of BESS to improve grid stability and renewable integration. In Thailand, growing demand from data centres, distributed generation, and electric vehicles is reinforcing the importance of hybrid projects and energy storage for system reliability, with greater deployment expected under the forthcoming Power Development Plan (PDP). Singapore is pursuing system flexibility through storage and market innovation to optimise limited land and system capacity. Sembcorp Industries successfully piloted a battery stacking solution on Jurong Island, increasing storage capacity from 285 MWh to 326 MWh

without requiring additional land. At the same time, the Energy Market Authority is launching a Virtual Power Plant Regulatory Sandbox to test distributed energy resources in providing grid services.

Market frameworks evolve from incentives to implementation As renewable energy markets mature, policymakers are increasingly shifting their focus from incentivising deployment to creating frameworks capable of supporting large scale integration, investment certainty, and market participation. Japan’s transition from Feed-in Tariffs to the Feed-in Premium scheme is occurring alongside the maturation of the Japanese Electric Power Exchange, which is attracting growing participation from traders and financial market participants driven by volatility in spot pricing and imbalance risks. Thailand’s proposed Climate Change Act, Utility Green Tariff programme, and direct PPA initiatives signal a shift from policy ambition to implementation, introducing new procurement pathways for corporate consumers and improving project bankability. Vietnam has undertaken extensive regulatory reform through the revised Power Development Plan VIII, Electricity Law 2024, Resolution 253/2025/QH15, and associated implementing regulations governing renewable

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energy development and direct PPAs. Together, these reforms create a more comprehensive framework for renewable and new energy development and a transition towards market-based electricity mechanisms while also establishing a foundation for technologies such as green hydrogen and green ammonia and supporting private sector participation. Indonesia continues to refine its renewable energy framework through Presidential Regulation 112/2022, which introduced a new tariff and procurement framework supporting more competitive pricing across solar, wind, hydro, and geothermal projects. South Korea’s First Basic Plan for Renewable Energy similarly reflects a move towards more integrated market design through the replacement of the Renewable Portfolio Standard with a government-led, fixed-price auction market supported by competitive technology-specific auctions. Singapore has expanded funding for clean energy deployment, strengthened carbon market initiatives, increased its carbon tax, and supported the development of cross-border Renewable Energy Certificate frameworks and carbon credit markets. Across the region, policy attention is increasingly focused on creating frameworks capable of supporting execution, investment certainty, and system integration rather than simply encouraging renewable deployment.

Technology diversification and energy security As renewable energy markets mature across Asia Pacific, diversification is increasingly being driven by system needs rather than technology preferences. Different markets are pursuing different technology pathways based on resource availability, land constraints, reliability requirements, and energy security priorities. Japan is expanding offshore wind, geothermal, and biomass alongside hydrogen and ammonia initiatives. Indonesia is leveraging one of the world’s largest

Figure 3. In many respects, the first phase of the transition was about installation. The second is about integration and execution at scale.

ENERGY GLOBAL AUTUMN 2026

geothermal resource bases as firm renewable supply while balancing renewable development with LNG to meet rising demand. Vietnam is advancing floating solar, wind, and emerging hydrogen opportunities to diversify supply and reduce reliance on coal. South Korea is combining large scale solar expansion with offshore wind industrialisation, while Singapore is pursuing regional electricity imports and emerging low-carbon technologies including hydrogen, geothermal, and nuclear options to overcome domestic resource constraints. Thailand, meanwhile, is expected to see scaling deployment of hybrid renewable projects, battery storage, and other low-carbon technologies as the next phase of its energy transition takes shape. In Japan, solar remains the largest renewable energy source, although future growth may become increasingly constrained by land availability. Offshore wind is expected to drive future growth, supported by targets of 10 GW by 2030 and 30 – 45 GW by 2040, while onshore wind, geothermal, and biomass continue to advance through projects such as Abukuma, Appi, Waita No. 2, and Sendai Port. Japan’s energy transition increasingly reflects a pragmatic approach that combines renewables, nuclear power, hydrogen, and ammonia. Despite renewable growth, LNG and coal continue to play a significant role in electricity generation, reinforcing the importance of energy security considerations. Indonesia’s position is distinctive. It possesses approximately 40% of global geothermal potential, yet renewables remain a modest share of the generation mix. It also remains the world’s second-largest producer of geothermal electricity by installed capacity, giving it access to a source of firm renewable generation that few markets can replicate. At the same time, Indonesia’s transition continues to follow a twin-track approach, with renewable energy development occurring alongside LNG infrastructure expansion to address demand growth and system constraints. Projects such as Abadi LNG and PLN EPI’s diesel-to-LNG conversion programme illustrate the continuing role of natural gas in supporting supply and shifting LNG towards domestic demand, reinforcing electricity security amid external price volatility. Vietnam is pursuing a broad renewable portfolio encompassing floating solar, onshore wind, offshore wind, biomass, and emerging hydrogen opportunities as part of a transition towards a more reliable and diversified system. The 800 MW floating solar project on the Son La hydropower reservoir and ongoing offshore wind development illustrate this diversity and ongoing capacity expansion. South Korea’s strategy combines rapid capacity expansion in solar deployment, onshore wind reforms, and offshore wind industrialisation. The First Basic Plan for Renewable Energy supports solar expansion through the use of idle and underutilised land while also promoting offshore wind through dedicated installation vessels, port capacity, and shared grid infrastructure.

Thailand’s future technology mix is expected to be shaped by rapidly rising electricity demand from data centres, digital infrastructure, and industrial users. The forthcoming PDP 2026 – 2050 is expected to restore long-term visibility for the deployment of hybrid renewable projects, battery storage, carbon capture and storage, and other low-carbon technologies, translating policy momentum into bankable and scalable projects. Singapore’s approach is shaped by its limited domestic renewable resources. Alongside continued but constrained solar deployment, the country is pursuing regional electricity imports, hydrogen, geothermal opportunities, and potential nuclear deployment as part of a diversified long-term energy strategy. Across the region, countries are pursuing different combinations of renewable and low-carbon technologies that reflect their resource bases and energy priorities.

and capable of supporting long-term economic growth. Strikingly, markets with very different resource bases and regulatory structures are now confronting many of the same questions, from procurement and transmission to system flexibility, storage, and market design. While policy responses continue to differ, the underlying issues are converging. The growing importance of storage, market reform, cross-border trade, and regional interconnection points to a common reality: the transition will be defined not simply by the construction of renewable assets, but by the systems required to support them at scale. Ultimately, success will depend less on how quickly new capacity is built and more on how effectively it is integrated into increasingly sophisticated energy systems. In many respects, the first phase of the transition was about installation; the second is about integration and execution at scale.

From installation to integration

Note

The renewable energy transition in Asia Pacific is often measured in gigawatts of installed capacity, project announcements, and investment commitments, yet developments across the region suggest it is entering a new phase of maturity. The defining challenge is no longer whether renewable energy can be deployed at scale, but how it can be integrated into power systems in ways that are commercially viable, operationally reliable,

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ENERGY GLOBAL AUTUMN 2026

Raymond C. Decorvet, Global Business Development, Heat Pumps, Everllence, explains mega heat pumps for grid balancing and district heating.

ear the UNESCO-listed Wadden Sea in Esbjerg, Denmark, a large scale seawater heat pump supplies 25 000 households with climate-neutral heat. At the same time, it helps stabilise the power grid and balances fluctuations in renewable energy generation. The underlying technology combines two high-performance compressors with a transcritical carbon dioxide (CO2) cycle. Replacing a coal-fired plant, the system avoids 120 000 tpy of CO2 emissions – illustrating a blueprint for the decarbonisation of district heat supply while balancing grids. Globally, around 40% of CO2 emissions are linked to energy production, and roughly half of total energy demand is used for heating and cooling in residential and industrial applications. This highlights a fundamental reality: the energy transition is, to a large extent, a heat transition, and both transitions lead into energy security. Decarbonising heat therefore requires scalable solutions

– and district heating is one of the most effective levers available. According to the latest International Energy Agency report, district heating supplies around 10% of final energy consumption for heat and serves more than 600 million people worldwide. At the same time, however, it remains largely fossil-fuel-based globally, with coal accounting for around half and natural gas contributing about one-third of district heat production. Large scale heat pumps offer a pathway to address this challenge. They make it possible to decarbonise heat supply entirely without compromising security of supply or economic viability – end users will not even notice the difference.

A technology that speaks for itself Heat pumps are widely regarded as a proven, robust, and mature technology with numerous advantages – above all, their high efficiency. They achieve coefficient of performance (COP) values between 3 – 5. For every

kilowatt-hour of electricity they consume, they generate 3 – 5 times that amount of heat – and usable cooling at the same time on top. In comparison, electric boilers typically achieve a COP below 1. Unlike gas, renewable energy is largely independent of geopolitical influences and, aside from natural fluctuations, remains reliably available and price-stable.

Moreover, there are strong indications that costs will continue to decline in the future. In order to deploy a large scale heat pump alongside renewable energy, a suitable heat source is required. Coastal locations can utilise seawater, as in Esbjerg, where the North Sea provides a stable source of thermal energy. Inland, comparable opportunities are offered by rivers, lakes, or industrial sources. However, not all cities have access to natural water resources, which is why wastewater is a particularly attractive option in urban environments. After treatment, it retains a relatively stable temperature, making it a reliable heat source that can be used across multiple facilities within a city. Wastewater has another advantage; while temperature extraction from natural water bodies is limited for environmental reasons, controlled sources allow for greater temperature extraction. This can increase the usable thermal output and improve overall system performance.

Between carbon-neutral heat and grid stability Figure 1. Hot water storage tank, heat pump building, and wood chip plant in the Port of Esbjerg, Denmark, from left to right. Source: DIN Forsyning.

Figure 2. Inside the heat pump hall in Esbjerg, Denmark. Source: Sebastian Vollmert.

The role that large scale heat pumps can play in stabilising power grids is less known, but is becoming increasingly important in a system dominated by renewable energy. The growing integration of weather-dependent sources such as wind and solar introduces fluctuations that often do not align with demand. Especially during periods of low output, bottlenecks can emerge in the grid. This is where large scale heat pumps enter the picture. In addition to providing heating and cooling, they can help balance the fluctuating generation of renewable sources with electricity demand. Due to their grid-stabilising capabilities, large scale heat pumps act as a bridge between the heating and power sectors. Even without storage, their dynamic operating behaviour enables them to respond flexibly to fluctuating electricity prices and provide primary control reserve. When combined with thermal storage tanks, they can absorb excess green electricity from the grid by heating or cooling water for later use. With their flexibility and efficiency, large scale heat pumps provide a compelling answer to today’s energy sector challenges.

The largest CO2-based seawater heat pump

Figure 3. The transcritical compression cycle and its components.

ENERGY GLOBAL AUTUMN 2026

Climate-neutral heat is already a reality in Esbjerg. In November 2024, Everllence (formerly MAN Energy Solutions) commissioned the world’s largest CO2-based seawater heat pump at the city’s port, with a total heating capacity of 70 MWth (two x 35 MWth). Operated by the municipal utility, DIN Forsyning, the plant replaces a decommissioned coal-fired power plant and supplies around 280 000 MWh to the district heating networks of Esbjerg and the neighbouring town of Varde each year. Powered by electricity from a nearby wind farm, the plant provides climate-neutral heat to around 25 000 households and avoids approximately 120 000 tpy of CO2 emissions. It is complemented by a 60 MW woodchip boiler and a 40 MW electric boiler, which serve as peak-load and backup units.

Engineering efficiency at scale At the core of the heat pump system is the transcritical compression cycle. Seawater from the North Sea serves as the heat source, while the district heating network acts as the heat sink. Within the closed-loop system, CO2 is used as the refrigerant – a substance that is both environmentally and toxicologically safe. This is particularly important for DIN Forsyning, as the plant is located directly adjacent to the Wadden Sea, a UNESCO World Heritage site with a highly sensitive ecosystem. Particularly during winter operation, the system was required to deliver high load capacity and efficiency. In the transcritical cycle, the compressor compresses the CO2 to a high pressure, causing it to enter a supercritical state in which it can transfer heat with exceptional efficiency. Using CO2 as a refrigerant, combined with preheating via return water, further enhances performance. Initial measurements indicate a COP of 3 in winter, with target values of up to 7 in summer. The plant can generate water at 90˚C for direct feed-in to the network or to a 2500 MWh thermal storage tank for later use. Alternatively, it supplies preheated water at lower intermediate temperatures (>55˚C), which can be further heated by the biomass or electric boilers, or blended at the network outlet via the condenser. This flexibility enables DIN Forsyning to optimise operations efficiently based on demand, electricity prices, and availability. In addition to efficiency, operational robustness was a key design objective. Alongside the flexible interaction with other heat generation units, the compressors play a critical role. At the heart of the system are two oil-free, hermetically sealed HOFIM® motor-compressor units from Everllence. They operate with high-speed motors and active magnetic bearings, eliminating the need for oil and significantly reducing maintenance requirements. Their compact design and high-power density make them ideal for large scale heat pump applications such as Esbjerg. A remote monitoring, data analysis, and diagnostics system ensures efficient control. The heat pump system has also been explicitly designed for high load flexibility in order to deliver grid services. The compressors, which are also used in other applications, are designed to be switched on and off multiple times a day, making them well suited for participation in 15-minute grid-balancing markets, as commonly used in Denmark. On Everllence’s test bench in Zurich, the two large scale compressors now installed on site demonstrated a load change of 7 MW within just 30 secs. for a single unit. Operators can respond flexibly to demand fluctuations and take advantage of electricity volatile electricity prices, generating additional revenue streams.

Thermodynamic suitability of refrigerants The choice of refrigerant is a key consideration in both the design and operation of large scale heat pumps because it directly impacts system efficiency, safety, and regulatory compliance. Broadly, refrigerants can be divided into synthetic and natural substances. While low global warming potential synthetics such as R1234ze are used in

Figure 4. A disassembled HOFIM® compressor, the core component of the heat pump.

Figure 5. The circuits in the supercritical CO2 heat pump.

some applications, natural refrigerants – including CO2, ammonia, and hydrocarbons – are increasingly gaining importance. Unlike synthetic refrigerants, they are free of persistent chemicals. These substances are very long-lasting, accumulate in water, soil, and living organisms, and can have negative health effects. CO2 – as used in the Esbjerg heat pump – for example, is a particularly efficient natural refrigerant. However, this applies only if the return temperatures are relatively low, approximately under 50˚C. This is why there is no single best refrigerant; selecting the appropriate refrigerant requires balancing multiple factors. In addition to performance and cost considerations, sustainability, safety, and environmental compatibility all play a role. Ultimately the system design is determined by three key parameters: the characteristics of the available heat source, the required temperature level of the heat sink, and the return temperature of the district heating network.

A blueprint for other cities While the two heat pumps in Esbjerg have been operated for the second winter seasons now, another heat pump is already under construction in Aalborg, also in Denmark, and will significantly surpass the facility in Esbjerg. With a total capacity of 177 MW (four x 44 MWth), it is expected to cover one-third of the city’s heat demand and save up to 210 000 tpy of CO2 emissions. Other, somewhat smaller, Everllence heat pump projects are currently underway in Germany and the US, for example. Pioneering projects such as those in Esbjerg or Aalborg demonstrate how the decarbonisation of heating networks can succeed. The technology is there, and with the right conditions and a reliable heat source, large scale heat pumps can turn almost any city into a viable blueprint for decarbonised heat.

ENERGY GLOBAL AUTUMN 2026

Megan Barrett, Executive Director, Engineering Tomorrow, rings the alarm on tomorrow’s energy labour shortage, and argues why it should be addressed at earlier levels of education.

he US renewable energy build-out is accelerating on a scale that will test not only manufacturing capacity, project finance, and permitting systems, but also the country’s ability to develop the engineers and technical workers needed to sustain it. The U.S. Energy Information Administration (EIA) reports that developers and operators plan to add a record 86 GW of utility scale generating capacity in 2026. Solar represents 51% of the planned additions, followed by battery storage at 28% and wind at 14%.1 Growth in generation is expected to follow. The EIA also forecasts that the combined share of US electricity supplied by wind and solar will increase from approximately 18% in 2025 to 21% in 2027. Over the same period, utility scale solar generation is projected to rise from 290 billion kWh to 424 billion kWh.2 Every gigawatt requires people: engineers, technicians, skilled trades, construction and commissioning teams,

grid operators, manufacturing specialists, and supply chain professionals. The U.S. Department of Energy’s 2025 U.S. Energy and Employment Report counted approximately 8.5 million American energy workers in 2024, representing 5.4% of US employment. That total included 934 000 workers in electric power generation and 1.46 million in transmission, distribution, and storage.3 Employers are already experiencing difficulty finding the people they need. The Department of Energy’s Energy Workforce Advisory Board reported that 76% of US energy employers experienced some difficulty hiring qualified workers.4 At the same time, the U.S. Bureau of Labor Statistics projects that wind turbine service technicians and solar photovoltaic installers will be the country’s two fastest-growing occupations between 2024 – 2034, with employment expected to increase by 49.9% and 42.1%, respectively.5 These occupations represent only part of the

workforce the sector requires, but their growth illustrates how quickly technical needs are changing. The conventional response is to recruit more aggressively from universities, expand apprenticeships, and retrain workers from adjacent industries. All three are necessary, but none is sufficient if too few young people have chosen an engineering or technical pathway in the first place. By the time employers reach a university career fair or apprenticeship applicant pool, many students have already decided whether engineering fits their abilities, interests, and identities. Collegiate recruiting alone will not close the gap. Meeting this workforce challenge will require the renewable energy industry to engage students well before college, combining hands-on engineering experiences with sustained access to practicing professionals. Through its work with schools and industry partners, Engineering Tomorrow has demonstrated one practical model for that engagement: pairing hands-on, industry-informed engineering laboratories with meaningful interaction between students and practicing engineers.

The pipeline is won or lost early Career and technical education (CTE) helps students connect classroom learning to careers. While 86% of US public high schools offer CTE, students, particularly those from historically underserved backgrounds, do not have equal access to those opportunities.6 Availability also does not guarantee meaningful exposure to engineering. A school may offer technical coursework without opportunities to meet practicing engineers,

Figure 1. Students compare the performance and cost of wind and solar designs, translating classroom science into an engineering optimisation problem.

Key numbers > 330 867 students completed Engineering Tomorrow’s energy-related laboratories in Academic Year 2025 – 2026. > After completing Engineering Tomorrow’s energy-related labs, 43% of students expressed an interest in an engineering career.

ENERGY GLOBAL AUTUMN 2026

understand energy careers, or see how classroom concepts apply to real-world problems. That matters because the energy sector competes with every other technical industry for the same emerging talent. A young person who has never met an engineer may interpret the profession through a narrow cultural lens: an unusually gifted mathematician working alone on machines or code. Research from the National Academy of Engineering recommends presenting engineering as an inherently creative profession concerned with human welfare and capable of providing emotionally satisfying work.7 That framing is more accurate than the familiar stereotype and more likely to help students understand why technical knowledge matters. The need to broaden participation remains clear. Women account for only 16% of the engineering workforce.8 Black workers represented 8% of the overall STEM workforce in 2021, compared with 11% of the total US workforce, while Hispanic workers represented 15% of STEM workers and 18% of the total workforce.9 Racial and socioeconomic barriers persist. The talent required to build and operate the next generation of energy systems exists across geographies and demographic groups. The challenge is ensuring that more students encounter the profession before they conclude that it is inaccessible or not intended for them.

Purpose makes technical difficulty legible Students are often described as avoiding the difficult mathematics and science associated with engineering. Hands-on experience through Engineering Tomorrow’s high school laboratory events suggests a more useful interpretation: students may disengage from technical difficulty when its purpose is invisible. Once a calculation determines whether a wind blade turns efficiently enough to illuminate a structure, whether a solar system produces enough power to race a vehicle, or whether a successful bridge design meets a cost constraint, mathematics becomes a tool rather than an abstract obstacle. A well-designed secondary school laboratory reproduces the logic of professional practice at an accessible scale. In Engineering Tomorrow’s Renewable Energy Lab, students build wind and solar prototypes, collect performance data, compare design alternatives, and work within a defined budget. They analyse a real-world problem, collect and interpret data, carry out test designs, and explain how the engineering process shaped their final solutions. High school laboratories are not intended to train students to design a commercial wind farm. Their value is that they make engineering behaviour visible: define the problem, identify constraints, build, measure, revise, and communicate. These habits apply across engineering disciplines and technical career pathways.

Teachers build foundations; engineers make the profession visible Teachers are central to this work. They understand their students, manage classrooms, assess learning, and connect activities to curriculum standards. Industry engagement should not be designed to replace that expertise. It should

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RENEWING WHAT’S POSSIBLE POWERED BY

supply something schools cannot readily create at scale: sustained access to people who practice engineering. Practicing engineers bring classroom concepts to life by showing students how science, mathematics, and teamwork come together to solve real energy challenges. They also help students understand the societal impact, collaboration, and creativity that define modern engineering careers. Together, these forms of exposure can counter the persistent myth of the engineer working alone. Renewable energy projects are both technical and human systems, requiring teams to integrate design, finance, construction, operations, regulation, community engagement, and supply chains. Students should encounter that collaborative reality and understand that engineering offers many different ways to build a rewarding career while contributing to work that benefits society.

Case study: Engineering Tomorrow’s Renewable Energy Lab at Bechtel A 2025 delivery of Engineering Tomorrow’s Renewable Energy Lab, conducted in partnership with Bechtel Corp., offers a practical illustration of how technical learning and career exposure can be combined. Bechtel welcomed 80 students from high schools across Virginia and Maryland to

its headquarters in Reston, Virginia. Eight Bechtel engineers and an Engineering Tomorrow staff engineer guided students through the laboratory and connected its technical concepts to professional energy-sector work. Through this laboratory, students explored renewable generation, grid scale storage, national supply-and-demand balancing, energy efficiency, and sustainability. They then designed, built, tested, and analysed hybrid wind-and-solar structures intended to illuminate light-emitting diodes. The presence of practicing engineers allowed the technical exercise to become a career conversation. The laboratory could therefore address both content knowledge and the less visible question that often influences career choice: whether a student can imagine themselves doing this work. Longer-term programme data offers an additional indication of the potential value of early exposure. Based on an analysis of National Student Clearinghouse data, Engineering Tomorrow reports that 19% of students who have participated in its programming enroll in an engineering major in college, compared with 5.7% of students nationally, more than three times the national rate. While a single laboratory is not necessarily going to change a student’s college decision, these results support the inclusion of sustained, applied engineering exposure within a broader workforce development strategy if the sector hopes to resolve its talent shortages.

Earlier engagement strengthens today’s workforce as well

Figure 2. Engineering Tomorrow’s Renewable Energy Lab combined generation, storage, and grid-balancing concepts with direct access to practicing engineers.

Placing engineers in schools is usually framed as a long-term recruitment investment. It can also support the workforce already inside an energy company. A 2024 Deloitte survey of 1000 US office professionals found that 87% considered workplace volunteer opportunities important when deciding whether to remain with an employer or pursue a new position. 91% said volunteer opportunities could positively affect their work experience and connection to their employer.10

A practical model for energy employers This model centres on authentic engineering problems, prepares volunteers to communicate their work clearly, and creates repeated opportunities for students to interact with practicing engineers. Energy employers can strengthen this approach by measuring both student outcomes and employee engagement so educational outreach becomes part of a long-term workforce strategy.

Building the human infrastructure

Figure 3. Direct conversation helps students understand the social impact, teamwork, and problem-solving that define modern renewable energy careers.

ENERGY GLOBAL AUTUMN 2026

The renewable energy transition depends as much on people as on infrastructure. Engineers and technicians needed at the end of the decade cannot be recruited at scale if too few students encounter the profession today. Programmes like Engineering Tomorrow’s laboratories give high-school students hands-on experience with real engineering problems and direct access to the professionals who solve them. The most important intervention is not to make engineering appear easy; it is to make the challenge

meaningful. Teachers can develop the knowledge and habits students need to succeed. Practicing engineers can reveal what that knowledge is for, how the work benefits society, and why solving difficult problems can be personally fulfilling. Combining those roles makes high-school classrooms an early and essential part of workforce planning. The US energy sector’s hiring challenge cannot be solved solely at the back end of the talent pipeline. University recruitment, apprenticeships, and worker retraining will remain necessary, but they must be accompanied by meaningful engineering exposure while students are still deciding what they are capable of becoming – combining standards-aligned, hands-on engineering laboratories with direct access to practicing engineers who can explain not only how renewable energy systems work, but also why the work matters. That exposure must reach students in established engineering centres and in communities far removed from them. Whether in rural Tennessee, suburban Virginia, or downtown Houston, students need opportunities to meet engineers, test ideas, learn from unsuccessful designs, and discover that technical careers are developed through practice rather than reserved for those with innate brilliance. The renewable energy workforce will be stronger when more students have built something that works, understood why

it matters, and recognised engineering as a collaborative, purposeful, and personally fulfilling career.

References 1.

2. 3. 4. 5.

7. 8.

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‘New U.S. Electric Generating Capacity Expected to Reach a Record High in 2026’, U.S. Energy Information Administration (EIA), (20 February 2026), www.eia.gov/todayinenergy/detail.php?id=67205 ‘Solar Power Generation Drives Electricity Generation Growth over the Next Two Years’, EIA, (16 January 2026), www.eia.gov/todayinenergy/detail.php?id=67005 ‘2025 U.S. Energy and Employment Report’, U.S. Department of Energy (DOE), (2025), www.energy.gov/policy/2025-us-energy-employment-report-useer ‘21st Century Energy Workforce Advisory Board’, DOE, (9 July 2025), www.energy.gov/policy/21st-century-energy-workforce-advisory-board-ewab ‘Wind Turbine Service Technicians Employment Projected to Grow 49.9 Percent from 2024 to 2034’, U.S. Bureau of Labor Statistics, (13 July 2026), www.bls.gov/opub/ ted/2025/employment-for-wind-turbine-service-technicians-expected-to-increase-499-percent-by-2034.htm ‘Unlocking College and Career Success: How the RELs Are Making a Difference in Access, Enrollment, and Completion’, Institute of Education Sciences citing National Center for Education Statistics data, (8 July 2024), https://ies.ed.gov/learn/blog/ unlocking-college-and-career-success-how-rels-are-making-difference-accessenrollment-and-completion ‘Messaging for Engineering: From Research to Action (2013)’, National Academies Press, (2013), www.nationalacademies.org/read/13463/chapter/5 ‘Science and Engineering Labor Force’, U.S. National Science Foundation | National Science Board and National Center for Science and Engineering Statistics (NCSES), (2019), https://ncses.nsf.gov/pubs/nsb20198 ‘The STEM Labor Force: Scientists, Engineers, and Skilled Technical Workers’, U.S. National Science Foundation | National Science Board and NCSES, (2024), https://ncses.nsf.gov/pubs/nsb20245/data ‘Deloitte Survey: Workplace Volunteer Opportunities Can Unlock a Greater Sense of Connection and a More Positive Work Experience for Employees’, PR Newswire, (4 June 2024), www.prnewswire.com/news-releases/deloitte-survey-workplacevolunteer-opportunities-can-unlock-a-greater-sense-of-connection-and-a-morepositive-work-experience-for-employees-302162157.html

The Future of Offshore Wind Starts Here 12th November | Sunderland | www.offshorewindne.com

Figure 1. Floatgen is a 2 MW floating wind turbine demonstrator installed off the coast of Le Croisic in France. Source: BW Ideol and V. Joncheray.

ENERGY GLOBAL AUTUMN 2026

urope’s energy transition must answer several strategic imperatives: moving away from fossil fuels, guaranteeing security of supply through a diversified energy mix, restoring energy sovereignty, and maintaining competitive electricity prices that allow European industry to thrive. Floating offshore wind addresses all these imperatives. Installed far from the coast, it captures powerful, consistent winds while preserving coastal landscapes. Beyond being a new energy source, it is also a driver of reindustrialisation. Yet, it was needed to build floating foundations not as one-offs, but as industrial products. That is precisely the question BW Ideol has spent the last 15 years answering, after two demos and one pilot project, with its standard product designed for serial

manufacturing out of the Fos3F and Ardersier3F facilities to be located in Fos-sur-Mer (France) and Ardersier (Scotland).

15 years of design for scale BW Ideol was founded in 2010 with a clear thesis that the technology shall be designed for industrialisation, enabling floating offshore wind to follow levelized cost of energy reduction path of bottom fixed projects. The company started from a blank slate, listing the features a cost-competitive and scalable floating foundation should have. The result was the Damping Pool® – a square ring hull with a large central opening that enhances hydrodynamic stability, low draft for load-out at port, and wind turbine generator integration, without the complexity of ballast systems during installation and operation. The design has now been validated through three offshore reference projects: the 2 MW Floatgen demonstrator off Le Croisic has been operating since 2018; the 3.2 MW Hibiki demonstrator off Kitakyushu, Japan, was commissioned the same year with a steel hull; and most recently, in May 2026, the 30 MW Eolmed pilot farm was commissioned 18 km off Gruissan in the Mediterranean Sea. The numbers tell the scalability story. Floatgen’s 2 MW hull measures 36 x 36 m, Eolmed’s 10 MW hull measures 45 x 45 m, and the standardised concrete product designed for 16 MW is 54 x 54 m, with dimensions and structural characteristics optimised for serial production rather than bespoke construction. Rather than growing the design with each turbine generation, BW Ideol has developed a standardised product platform that adapts to wind turbine ratings while maintaining a common manufacturing footprint. That is the logic of a product platform, not a project-by-project approach.

Eight years of learning Among BW Ideol’s three operating reference projects, Floatgen holds a special place. Built in concrete and operated for more than eight years off Le Croisic, the demonstrator has provided a unique dataset on the long-term performance of the Damping Pool technology. The first key learnings are about stability and structural integrity at sea. After nearly a decade in the Atlantic, including winter storms with waves up to 10 m, the concrete hull of Floatgen has held up well. Regular inspections found no degradation beyond

normal design margins. The second learning was accessibility and operational performance. Floatgen also showed that routine maintenance on a Damping Pool floater is straightforward. The deck layout lets technicians reach turbines and balance-of-plant components safely in moderate sea states (up to 2.3 m Hs). Over eight years, availability figures have confirmed the design philosophy: a simple, stable platform that stays accessible when it is needed.

The steel supply chain lesson: What three French projects revealed While Floatgen validated the concrete design, the construction of France’s three pioneering pre-commercial floating wind farms – Provence Grand Large (PGL, 25 MW), Eoliennes Flottantes du Golfe du Lion (EFGL, 30 MW), and Eolmed (30 MW) – revealed a structural limitation in the local supply chain for steel floating foundations. The three projects executed during the COVID-19 pandemic and the Ukrainian Crisis faced schedule pressure, due to limited fabricators, steel price inflation, and logistic road constraints. The experience demonstrated a hard truth, that European shipyard capacity is limited and oriented towards high-value, low-volume work, with limited capacity to serve commercial projects. Alternatively, sourcing to fabrication yards in Asia and sourcing complete or semi-completed structures across the globe, exposes projects to steel price volatility, Suez Canal risks, import tariff uncertainty, and a limited pool of ultra-large carrier vessels.

Why concrete – and why it matters Concrete offers a fundamentally different supply chain logic. The raw materials – cement, aggregates, water, reinforcement steel – are abundant and locally available across Europe. The manufacturing skillset aligns with the existing civil engineering and precast concrete industry, not with shipbuilding. A concrete floating foundation built in Fos-sur-Mer draws on a European supply chain for roughly 85% of its value, consistent with the objectives of the EU Net-Zero Industry Act. It creates local employment – over 1300 direct jobs anticipated at Fos3F – and insulates project economics from the volatility of international steel markets and shipping lanes. Concrete also brings advantages in carbon footprint. Low-carbon concrete mixes, produced on-site with locally-sourced materials, can significantly reduce the embodied carbon of each foundation compared to steel alternatives manufactured overseas and shipped thousands of kilometres.

The gantry slipform approach

Figure 2. Floating foundation Damping Pool® by BW Ideol on the EolMed offshore wind farm in the Mediterranean.

ENERGY GLOBAL AUTUMN 2026

The critical enabling factor for serial concrete production is the manufacturing method itself. Traditional construction of large concrete uses standard form work, dozens of tower cranes, and hundreds of self-propelled modular transporter (SPMT) axle lines. BW Ideol’s ‘3F’ factory adopts a fundamentally different approach: a facility using gantry slipform and skidding lines, similarly to the facilities developed in Asia and Middle East, to build more than 2000 concrete caissons for port extensions and jetties. It was recently demonstrated in Europe during construction of the Princess Elisabeth Energy Island caissons in Belgium. The Damping Pool geometry was designed from the outset to be compatible with gantry slipform construction. Its compact dimensions mean that multiple workstations fit within the available quayside area for complete construction.

The floating foundation progresses through a series of dedicated workstations, each performing specialised activities – reinforcement installation, concrete pouring, curing, post-tensioning, and outfitting – while a moving gantry slipform system enables continuous, standardised operations. The result is a genuine production line for floating foundations. BW Ideol estimates a cadence of approximately one complete floating foundation every 12 days once the line is at full capacity. This rate is essential for serving projects of several hundred megawatts where multiple foundations must be delivered within a single installation campaign window.

Fos3F: The case study The Fos3F factory – officially the Floating Foundation Fabrication Line in Fos-sur-Mer – is designed to occupy approximately 30 ha. at the 4XL terminal of the Grand Port Maritime de Marseille, which has designated the DEOS site as the future hub for floating wind in the Mediterranean. The Fos3F project has already secured up to €74 million from the EU Innovation Fund and €52 million under France’s C3IV scheme – €126 million in total public backing – reflecting both the strategic importance and the maturity of the industrial plan.

Market sizing The Mediterranean floating offshore wind pipeline is taking shape rapidly. France alone has tendered or announced approximately 3.7 GW of floating wind capacity on its Mediterranean coast through the AO6 and AO10 rounds, including the 250 MW Golfe de Fos 2 project (awarded to EDF Renewables, Maple Power, and BW Ideol’s project company) and the 250 MW Narbonnaise 1 project. Across France, Italy, Spain, Greece, and Malta, the total addressable market for Fos3F is estimated at approximately 10 GW of floating wind capacity in the 2030 – 2037 timeframe. This translates to approximately 250 floating foundations, enough to occupy the Fos3F production line for the better part of a decade.

Commercial model and industrial timeline The company commercialises the Fos3F factory’s output through EPC contracts for the supply of complete floating foundations and mooring system. Developers reserve production capacity early through preferred supplier agreements (PSAs). This model – standard among wind turbine OEMs and cable suppliers but new for floating foundations – gives developers predictable pricing and delivery schedules while giving the factory the order book it needs to operate efficiently. The PSA is later converted into a full EPC contract as the project reaches final investment decision (FID). The manufacturing line is designed to deliver foundations free alongside ship at the marshalling port, ready for turbine integration and tow-out, providing a single, integrated contractual interface that simplifies project execution. A recent and decisive development: BW Ideol and NGE have signed an exclusive 50/50 partnership to develop the Fos3F project. NGE is one of France’s leading independent construction groups, with extensive expertise in large scale civil engineering, concrete infrastructure, and industrial construction. Under this partnership, the two companies will jointly hold the Fos3F special-purpose vehicle, combining BW Ideol’s Damping Pool technology with NGE’s

Figure 3. Illustrative projection of a concrete floating foundations production line by BW Ideol.

industrial execution capability in delivering complex concrete structures on a scale. This partnership addresses one of the key requirements for developers and lenders: a credible, experienced EPC partner standing behind the manufacturing commitments.

Competitive position The competitive landscape for floating foundations remains fragmented. While several technology providers have achieved TRL 7 (operational demonstrators), none combine proven technology with dedicated industrial manufacturing capacity and EPC delivery in Europe’s Mediterranean basin. Concrete spar technology is unsuited to Mediterranean water depths. Steel semi-subs technology mostly relies on external fabrication partners, Asian shipyards, and a licensing model. EPC players proposing steel semi-subs bring execution capability, but their proprietary technology is still unproven to date and faces the same supply chain constraints. BW Ideol’s differentiating position is that it offers an integrated value proposition: a TRL 7+ technology validated across three offshore projects, a concrete-based solution, and EPC delivery capability.

Outlook: From prototype to production line The floating offshore wind industry has reached an inflection point. The technology works – Eolmed, WindFloat Atlantic, Hywind Tampen, and others have proven that. The question is no longer if floating wind can be deployed, but how to deploy it at the scale and cost required by national targets and auction prices. The lessons from a decade of French pilot projects are clear: steel shipyard fabrication, whether in Europe or Asia, cannot deliver the volume, cost, and schedule certainty that commercial scale floating wind demands. Concrete, manufactured on a dedicated gantry slipform production line with a local supply chain, can. BW Ideol’s answer – 15 years in the making and validated by eight years of continuous Floatgen operations, three offshore projects, and the hard-won experience of France’s first floating wind pilot farms – is a standardised concrete floating substructure manufactured on a floating foundation factory. With €126 million in public funding secured, an exclusive partnership with NGE in place, and the first commercial projects moving towards FID, Fos3F is well on track to serve the Mediterranean Sea project pipeline.

ENERGY GLOBAL AUTUMN 2026

As solar becomes increasingly recognised by EU institutions as critical grid infrastructure, its importance to Europe’s energy security is coming into sharper focus. Christelle Barnes, General Manager at SolarEdge UK, addresses how photovoltaic installers, developers, EPCs, and system owners can strengthen cybersecurity and better protect both their assets and the wider grid.

ybersecurity has moved rapidly up the solar industry’s agenda, but the roots of the challenge lie in the way Europe’s energy system has evolved. For much of the past century, Europe’s energy grid was centralised and largely analogue, built around a relatively small number of large, heavily-regulated power stations. Security responsibilities were clearly defined, and oversight was concentrated around a limited number of assets. The growth of solar and other renewable technologies has transformed that model. Europe’s energy system is becoming increasingly decentralised and digital, with power now generated across a vast network of smaller sites. Yet, many of these assets do not operate under the same level of cybersecurity scrutiny as traditional power infrastructure.

ENERGY GLOBAL AUTUMN 2026

Large utility scale solar plants above 100 MW are generally subject to more stringent requirements. However, much of Europe’s utility scale solar capacity is now generated by sites below this threshold. According to Wood Mackenzie, half of this capacity, representing more than 120 GW, comes from plants producing less than 25 MW each. In practice, the smaller the installation, the less likely it is to fall within existing cybersecurity regulation. At the same time, solar systems have become far more connected. In residential and most commercial installations, inverters convert the electricity generated by solar panels into usable power and are typically connected to the internet to support remote monitoring, software updates, and fault diagnosis. At the utility scale, connected services are also used

to manage functions such as battery optimisation, production curtailment during periods of grid surplus, and responses to negative electricity pricing. This connectivity delivers clear operational and commercial benefits, but it also expands the potential attack surface. As has happened with many fast-growing technologies, the pace of solar deployment has often moved faster than the development of robust cybersecurity practices. That creates an important opportunity to build greater resilience into systems from the outset. However, many utility scale installations remain accessible through the public internet and still rely on default or weak passwords. In these circumstances, the remote compromise of an unsecured photovoltaic (PV) inverter is not simply a theoretical risk. In some cases, gaining access can be alarmingly easy.

Strengthening cybersecurity through new regulation Growing awareness across the EU has resulted in many developments in regulation and industry action. The European Radio Equipment Directive (RED) Article 3.3 and the UK’s Product Security and Telecommunications Infrastructure (PSTI) Act made a good start in 2024 on improving the security of connected devices, introducing basic standards like unique and complex passwords, and protections for user data. While these rudimentary requirements apply to a broader set of connected devices, and not just solar, they have helped to raise the bar for this industry as well. More robust regulation is on the way. The Cyber Resilience Act has been passed, due to come into effect gradually in the next two years, and will impose stricter security requirements on manufacturers of connected devices than RED or PSTI. The EU’s NIS2 Directive is expected to be fully transposed into national laws across all member states within the next year. While the specifics of implementation will vary, the drafts make clear that it will assign clearer responsibility and liability for cybersecurity risks to asset owners, operators, and critical service providers. In the solar industry, this means the management of EPCs, developers, asset owners, and even investors or insurers, are expected to carry legal accountability for their solar arrays, and any results of a cybersecurity breach, including potential outcomes such as blackouts. Tightening cybersecurity regulations is a positive development for the industry, but tailored measures are still needed to fully safeguard solar infrastructure. For example, oversight remains limited when it comes to how device manufacturers manage communications with installed devices such as inverters. Even greater opportunities for improvement exist in utility scale setups, as there is no regulation on firewall access management for small solar plants, which constitute the majority of solar power generation in Europe. Regulation is catching up, but awareness is growing fast – a strong sign that more targeted policies are coming. The EU Commission has announced the launch of PV risk assessments, and countries like Germany have launched public consultations and industry engagement to develop bespoke regulations for the solar sector. Lithuania has gone a step further, setting severe connectivity limitations on unsecure solar devices

ENERGY GLOBAL AUTUMN 2026

based on cybersecurity considerations – even retroactively. As such, installers, developers, and EPCs should closely monitor regulatory changes which may soon impact them directly.

Taking action ahead of further regulation While the solar industry awaits clearer, more robust regulations, it must take proactive steps now. It is important to understand that regulations may soon assign legal liability over the cybersecurity of asset portfolios to the owners of utility scale solar plants, and the O&M companies which service them. Just as solar plant owners are now required to install fences, security cameras, and fire safety measures, in the near future they will likely be required to invest in both software and hardware cybersecurity solutions beyond a simple firewall and VPN connection. Asset owners are advised to onboard the expertise needed to ensure compliance with developing requirements beyond just NIS 2, and to understand what contractual obligations will be required from O&M providers and EPC partners. Owners must also understand that components such as inverters, battery energy storage systems or the PV monitoring provider may be subject to varying levels of compliance requirements. At minimum, updated inventories of physical components should be maintained.

Building a more resilient solar industry As regulations evolve, every part of the solar value chain has an opportunity to strengthen its cybersecurity readiness. Proactively addressing potential vulnerabilities can help avoid costly retrofits, compliance penalties, or product recalls down the line. Given the long lifetime of solar systems, choosing more secure, future-minded solutions would be wise, as is standard in other areas such as fire safety, electricity safety, or durability, where more durable solar panels are chosen to withstand extreme weather events. At utility scale sites, asset owners and O&M companies must start managing access and control to solar plants of any size as if these were already regulated as critical infrastructure. The priority now is for solar industry professionals to stay ahead of regulation rather than wait for new requirements to force action. Awareness is rising among installers, system owners, and policymakers, and cybersecurity can no longer be treated as an optional expense to be reduced wherever possible. That mindset is becoming as outdated as considering seat belts or airbags unnecessary additions in the automotive sector. Instead, cybersecurity should be viewed as a fundamental part of managing operational risk and limiting liability. Companies that fail to recognise this shift may find themselves unable to meet future regulatory requirements. More seriously, poorly protected systems could become a point of vulnerability within wider national energy infrastructure. Investing in stronger cybersecurity today will help protect the solar industry’s long-term growth, while reducing the likelihood of expensive retrofits, compliance issues, and system replacements in the future. In an increasingly connected energy system, prevention remains far more effective, and far less costly, than responding after a breach has occurred.

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ENERGY GLOBAL AUTUMN 2026

Arif Aga, Director, SgurrEnergy, questions whether 600 – 700 Wp designs are compromising mechanical reliability in the solar photovoltaics industry.

n the rapidly evolving solar photovoltaic (PV) industry, the past few years have witnessed a dramatic transformation in module technologies. Driven by relentless competition and pursuit of lower levelized cost of energy (LCoE), manufacturers have been pushing technological boundaries to deliver increasingly higher power modules. What began as a transition from 400 W modules to the 500 W class has quickly escalated into a race towards modules exceeding 600 W and even 700 W peak power. These advancements have been accompanied with the adoption of larger wafer sizes such as the 210 mm format. Larger wafers allow modules to operate at higher current densities while accommodating advanced interconnection designs such as multi-busbar (MBB) architectures. When combined with next-generation cell technologies like TOPCon and HJT, these innovations significantly boost power output per module. At the same time, module dimensions have expanded considerably, producing ultra-large panels designed to maximise energy density per installation area.

These innovations, combined with expanded module dimensions, promise reduced balance-of-system (BoS) costs and enhanced project economics. Yet, as the industry embraces these ultra-large formats, a critical question emerges: are the short-term gains in power density worth the long-term mechanical risks?

The drive towards larger wafers and higher power The shift towards oversized modules is largely driven by economies of scale. Larger cells allow manufacturers to pack greater energy density into each module while increasing production costs only marginally. As a result, developers can deploy fewer modules to achieve the same megawatt capacity. This reduction in module count offers multiple advantages for large scale solar installations. Fewer modules mean fewer mounting components, fewer electrical connections, and shorter installation timelines. For utility scale projects, where thousands or even millions of modules are deployed, these incremental efficiencies can translate into substantial savings. Higher power modules also increase string output, allowing designers to optimise inverter loading and reduce the complexity of electrical infrastructure. Combined with lower labour requirements during installation, these benefits make

high-wattage modules an attractive option for developers seeking to maximise project efficiency. The market dynamics further accelerate this trend. The solar industry operates in a highly competitive environment where manufacturers constantly strive to reduce cost per watt-peak. Even small improvements in module efficiency or power output can provide a competitive advantage in procurement and tendering processes. At the same time, developers face pressure to minimise CAPEX while maximising energy yield. In such a landscape, ultra-large modules appear to offer a compelling solution delivering higher power ratings while promising lower BoS costs. In a volatile market plagued by fluctuating prices and supply chain disruptions, ultra-large modules appear as a timely solution. Manufacturers are shaving every cent per watt-peak to stay competitive, while developers demand higher-wattage options to secure edges in tenders. The result? A paradigm where bigger is not just better, it is essential for cost reduction and efficiency gains.

Mechanical challenges in the era of giant modules The rapid escalation in module dimensions significantly alters the mechanical behaviour of PV panels. Modern large-format modules frequently exceed 2.4 m2 in area and weigh more than 33 kg. This increase in size and weight introduces additional stresses on the module structure, particularly on the glass laminate and aluminium frame. As module dimensions grow, the bending moment experienced under wind or snow loads increases substantially. Larger surface areas act similarly to aerodynamic sails, making them more susceptible to deflection under environmental loading. Even relatively modest wind pressures can generate amplified stresses across the module surface.

Deflection and flex under load

Figure 1. Expansive solar installation supporting clean energy generation.

Due to large surface area of the module, even a marginal increase in the wind or snow load is amplified. These in turn cause stress on the solder joints, lead to the expansion of micro cracks, and produce localised damages. Larger spans cause strain especially in the central region of the module. This stress can induce cracks and residual stress which may evolve during the thermal cycles in the operational period.

Handling and logistics hurdles A module weighing over 35 kg exceeds the logistical limit and handling norms. As an impact of the higher module weight, higher breakage rates due to risk of corner impact during transportation and handling would be the result. Increased weight and size often requires two or more people handling the module, which increases labour demand.

Mounting and tracker compatibility Figure 2. Solar panels deployed across a utility scale renewable energy site.

ENERGY GLOBAL AUTUMN 2026

Increased wind loads result in higher foundational loads and tracker torque. As module length increases, dynamic wind effects – particularly torsional galloping –

become more noticeable. Non-uniform stress distribution may be introduced by torque tube stiffness, tracker backtracking angles, and wind-induced torsion.

Limitations of standard testing protocols Current IEC mechanical load tests provide a baseline for qualification, assessing static loads of 5400 Pa front-side and 2400 Pa rear-side, alongside dynamic loads and hail impact simulations. However, these standards fall short of replicating the full spectrum of stresses over a 25 – 30 year lifespan. They overlook thousands of dynamic wind cycles, oscillatory loads, and varying torsion that large modules endure in the field. Such repeated stresses can lead to fatigue in components, crack propagation, and solder joint failure issues not fully captured in lab settings. Consequently, the safety margins for ultra-large modules are narrower than for their predecessors, demanding tighter tolerances and robust system integration.

Weighing long-term value against incremental gains Pushing beyond 700 Wp often yields diminishing returns: marginal energy gains are offset by heightened complexities in logistics, handling, and installation. Reinforcements like structural enhancements or advanced trackers may erode anticipated BoS savings. The core debate is not whether these modules function – it is whether they deliver sustained value in utility scale deployments.

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To navigate this transition responsibly, the industry must prioritise several key principles: > Lifecycle reliability over wattage: Durability over the full project lifetime should outweigh marginal increases in module power. > Field data-driven decisions: Real-world performance data should guide module selection rather than relying solely on nominal power ratings. > System-level optimisation: Overall system efficiency must take precedence over maximising the performance of individual components. > Risk-adjusted evaluation metrics: Technology-specific risks should be incorporated into project decision-making frameworks.

Charting a sustainable path forward The global pivot to ultra-large modules is irreversible, with value chains standardising to accommodate them. Yet, as power densities soar, the industry must establish rigorous validation frameworks to mitigate mechanical risks. Future PV advancements should be gauged not by wattage milestones, but by resilience and efficiency in addressing durability challenges. Ultra-large panels symbolise progress, but true innovation lies in ensuring that scale enhances rather than compromises long-term performance. By balancing ambition with prudence, the solar sector can harness these technologies for a more reliable, cost-effective energy future.

ENERGY GLOBAL AUTUMN 2026

actually being operated? It is a question that should be at the heart of every investment into renewables.

Framing it any other way is a misrepresentation of what is actually at stake.

Availability is profitability

The bathtub curve

The dominating metric on most operations and maintenance (O&M) websites is megawatts under management. It is a headline number, and it is the wrong one. What actually determines the return on investment for an asset owner is not installed capacity, it is availability. A site that is poorly maintained and running at 80% availability is decreasing value every single day, regardless of how impressive it looked at energisation. This distinction matters especially for the 1300+ utility scale solar PV sites that sit below the threshold for Critical Government Infrastructure classification in the UK. These sites do not attract the same scrutiny as an 800 MW project, but their collective contribution to energy supply, and the financial exposure of their owners, is just as real. Over a multi-decade operational life, the quality of O&M on five 20 MW sites is every bit as consequential as on a single 100 MW one. The industry mindset needs to shift. O&M is not a cost of maintenance to be minimised – it is revenue protection.

During the early stages of any project, it is easy to assume that component failure should not be something that is seen as a high priority. With fresh warranties and installation, immediate replacement of assets, especially modules and inverters, is usually not expected. However, failure rates within projects tend to fall within a bathtub curve with an increased level of ‘infant failure’, caused by immediate manufacturing defects. SCADA systems provide real-time data insights to a string level, but may not necessarily highlight module-level faults, leading to a loss of generation that could go undetected until the annual thermography or onsite inspection. Even with fault identification, the procurement and maintenance of a correct spares stock is vital, with lead times from manufacturers honouring warranties sometimes taking over a month, potentially causing a significant loss of generation during that time. And while the loss of a singular panel will not impact generation in a significant way at utility scale, repeated failures of modules can potentially indicate on-site faults, caused by batch-level faults, poor installation, or poor system design. Understanding, tracking, and ultimately resolving this is critical throughout the entire life cycle of a plant. Effective corrective maintenance does not just require a responsive, qualified engineering team, but a level of data management and procurement built to minimise the inevitable loss of availability.

Maintenance is not a tick-box exercise

Figure 1. Engineer working on site.

Figure 2. The bathtub curve.

ENERGY GLOBAL AUTUMN 2026

The Heathrow substation failure in early 2025 is a stark illustration of what happens when preventative maintenance becomes a compliance exercise rather than a risk management discipline. Teams flagged elevated moisture content in a bushing, but no mitigating action was taken. The result was a catastrophic failure with consequences that extended far beyond the asset itself. The same risk exists across utility scale solar. When preventative maintenance results identify an emerging issue, the correct response is a controlled, planned intervention: downtime scheduled to minimise generation impact, parts and engineering expertise in place, and risk eliminated before it becomes a crisis. That requires an O&M partner with the technical depth to interpret results, not just record them. Both corrective and preventative maintenance remain critical across the full operational life of a site. Assets a decade or older are now commonly showing generation losses of around 30% from poorly maintained equipment, a figure compounded by the

increasing obsolescence of electronic components, which typically fall out of manufacturer support within a few years of production.

Repowering: Plan for it before you need it The conversation about repowering feels premature at the commissioning stage. It should not. There has been a marked improvement in the technology used on utility scale solar over the past few years. String inverters are being installed with around 2.3 times the volume of those installed in 2016, while their power output has also increased by nearly six times in the same period. Component obsolescence, accumulated generation losses, and the commercial case for upgraded technology all converge, typically sooner than asset owners anticipate. The optimal position is to have an O&M partner execute the repowering programme. They already hold the site’s history, understand the current underperformance, and can minimise generation loss during the transition. Bringing in a third party at that stage means starting from scratch with knowledge that should have been building for years.

Figure 3. Data integrity in practice.

The construction-to-operations disconnect Even a technically excellent O&M team can be hampered from day one by a poor handover from construction. The priorities during construction, completing acceptance certificates, hitting milestones, Figure 4. On-site engineers checking metering data during a maintenance visit. and signing off provisional acceptance certificate (PAC), are legitimately different from the long-term focus on availability and performance. That difference parts procurement risk. And throughout all of this, there is in mindset, left unchecked, creates gaps: outstanding constant commercial pressure to reduce operating costs. works that are not clearly documented, O&M manuals Some O&M providers have responded to that pressure that do not reflect the as-built asset, and an O&M by quietly reducing service quality to meet contractual provider starting on the back foot. response times on paper while compromising actual A seamless transition requires deliberate effort from output. Asset owners who choose a provider on cost alone both sides. Clear documentation of outstanding works at are often the last to know. PAC, a comprehensive and accurate O&M manual, and The only answer to increasing complexity is investment a structured feedback loop from operations back into in the right O&M partner. This is not just an engineer project design all reduce the impact of that initial bathtub with a spanner, but a need continuous monitoring curve of faults and improve the quality and reliability of infrastructure, portfolio-level data intelligence, and future assets. the operational flexibility to respond at scale without sacrificing quality. Standards must increase with The renewable energy industry has spent the past complexity decade proving that solar works. The next decade will be The challenges facing O&M providers are not getting defined by how well it is operated. simpler. Connection point scarcity is driving development To do that, how O&M providers are evaluated needs patterns that create geographically dispersed portfolios, to change. Megawatts under management is a great with widely distributed assets that still require the same marketing metric, but availability is the only number that level of responsiveness. Co-located solar and battery reveals whether an investment is performing or not. The energy storage system sites are adding technical best O&M providers understand that distinction and build complexity. Global supply chain instability is creating their operation around it.

ENERGY GLOBAL AUTUMN 2026

Danny Constantins, Executive Chairman, EM&I, Malta, explores how innovation, robotics, and continuous maintenance are reshaping offshore production in Asia Pacific and beyond.

he offshore energy sector is entering one of the most significant periods of transformation in its history. For decades, the industry’s operating model was shaped by predictable cycles. New assets replaced ageing ones. Offshore inspections followed established schedules. Maintenance strategies were built around periodic shutdowns and dry-docking campaigns. Diving operations, while inherently challenging, remained a standard part of lifecycle asset management. Today, many of those assumptions are changing. Geopolitical uncertainty, energy security concerns, ageing infrastructure, rising capital costs, and the accelerating energy transition are combining to create a new operating environment. At the same time, advances in robotics, remote inspection systems, digital technologies, and

artificial intelligence (AI) are redefining what is possible in asset integrity management. Nowhere is this more evident than in the Asia Pacific region. Home to some of the world’s largest concentrations of floating production assets, major LNG export facilities, rapidly growing gas import infrastructure, and emerging floating offshore wind developments, Asia Pacific has become a proving ground for the next generation of inspection, repair, and maintenance strategies. For owners, operators, investors, insurers, and regulators, the challenge is no longer simply maintaining assets safely. The challenge is ensuring that critical offshore infrastructure remains productive, economically viable, and resilient throughout increasingly extended operating lives.

The organisations that succeed will be those that recognise a fundamental shift is underway: asset integrity is no longer a maintenance issue; it is a strategic business issue.

Energy security is driving a new asset reality The global energy transition is often discussed in terms of replacement – renewables replacing hydrocarbons and new technologies replacing old ones. The reality is considerably more complex. While renewable energy continues to grow rapidly, global demand for reliable and affordable energy continues to increase. Governments across Asia Pacific are balancing decarbonisation commitments with energy security requirements, economic growth objectives, and industrial competitiveness. The result is a more diverse offshore energy landscape than many anticipated. Oil and gas production remains critical. LNG continues to play an increasingly important role as a transition fuel. FSRUs are expanding into new markets. Floating LNG (FLNG) facilities are opening access to previously stranded resources. At the same time, floating offshore wind is emerging as a major opportunity in regions where deep-water conditions make fixed-bottom installations impractical.

Figure 1. LIMPET on a coamingless sea chest inlet.

These developments have one characteristic in common: they all depend on the long-term integrity of high-value floating assets. For many operators, replacing assets is no longer the preferred option. The economics increasingly favour extending the operational life of existing assets through carefully managed inspection, maintenance, and repair programmes. Drillships that might previously have been retired are now undergoing extensive life-extension programmes. FPSOs continue operating far beyond original design expectations. Gas infrastructure assets are being positioned for decades of additional service. This trend is creating a fundamental change in how the industry thinks about asset integrity.

The end of the dry docking mindset For generations, major maintenance activities were built around periodic dry-docking cycles. While effective, dry docking creates significant operational challenges. Assets must leave station, production is interrupted, logistics become complex, costs escalate rapidly, and specialist facilities may be located thousands of miles from operating regions. In today’s environment, those constraints are increasingly difficult to justify. Production interruptions directly impact revenue. Energy markets demand reliability, investors expect stronger returns on capital, regulators require higher levels of assurance, and insurers seek greater confidence in risk management. As a result, operators are increasingly pursuing continuous maintenance strategies that allow assets to remain productive while integrity management activities are undertaken. This is particularly relevant for floating gas infrastructure. Historically, floating storage assets often relied heavily on periodic dry-docking campaigns to address hull integrity, sea valves, cathodic protection systems, and underwater structures. The future is likely to look very different. Instead of major maintenance events every five years, operators are moving towards a model of continuous asset integrity management in which inspection, maintenance, and repair activities are integrated into normal operations. This approach reduces operational disruption, improves visibility of asset condition, and provides greater flexibility in responding to emerging issues. Most importantly, it aligns integrity management with business objectives.

Technology is breaking traditional constraints

Figure 2. Remotely operated vehicle pilot onshore.

ENERGY GLOBAL AUTUMN 2026

A significant driver behind this transformation is technology. Historically, inspection and maintenance programmes were constrained by three factors: access, weather, and human safety. Today, all three are being challenged. Advances in remotely operated systems have enabled inspections that were once considered impossible without divers. Improvements in robotics have expanded operating envelopes and reduced weather limitations. Enhanced imaging, data processing, and remote communications have improved the quality and availability of integrity information.

The result is a fundamental shift in how offshore work is performed. Instead of mobilising diving spreads, operators increasingly deploy remotely operated vehicles (ROVs) capable of undertaking underwater inspections while reducing personnel exposure. These ROVs are now being piloted from onshore bases often hundreds of kilometres away. Instead of waiting for ideal environmental conditions, new generations of inspection technologies are being designed to operate effectively in more challenging metocean environments. Instead of sending personnel into confined spaces, robotic systems are gathering inspection data remotely. These developments are not simply technological improvements. They represent a new philosophy of asset integrity management – one that seeks to remove people from hazardous environments wherever practical while simultaneously improving data quality and operational efficiency.

Figure 3. KING CRAB, under development.

Safety as a strategic driver The offshore industry has always prioritised safety, but expectations continue to evolve. Today, there is growing recognition that the safest intervention is often the one that does not require human exposure in the first place. This principle is becoming increasingly influential in inspection and maintenance planning. Traditional underwater inspections involve divers operating in dynamic and often unpredictable conditions. Confined space inspections expose personnel to atmospheric hazards, restricted access, and complex rescue requirements. Working at height introduces additional risks that must be carefully managed. While these activities can be performed safely, they remain risk-intensive. Consequently, many operators are asking a different question; rather than asking how risks can be managed, they are asking whether those risks can be removed altogether. This shift is driving increased adoption of diverless inspection systems, robotic maintenance technologies, remote operations, and automated data collection methods. The implications extend beyond safety performance alone. Reducing personnel exposure can lower logistical complexity, decrease offshore accommodation requirements, simplify operational planning, and reduce overall project costs. For executive leadership teams, these benefits increasingly align safety objectives with commercial objectives.

Disruptive innovation to break those constraints EM&I has pioneered a suite of innovative technologies that enable safer, more efficient, and cost-effective asset integrity management without the need for divers, dry-docking, or confined space entry. Its proven ODIN® system provides diverless inspection of critical sea valves and sea chests, with more than 400 installations worldwide. Advanced ROVs deliver underwater inspections (UWILDs) with reduced personnel

Figure 4. Mechanical JAWS anode, newly installed.

on board, mitigating safety risk and bringing efficiencies to asset operators. CLAMTM cofferdam technology facilitates diverless hull structural repairs, and LIMPETTM enables sea chests to be safely blanked using specialised ROVs deployed directly from the asset. Complementing these solutions, JAWSTM allows sacrificial anodes to be replaced on both external and internal hull structures without exposing personnel to the risks associated with diving, working at height, or confined space entry. Together, these technologies enhance safety, minimise operational disruption, reduce costs, and support continuous asset integrity management while assets remain on station and productive.

Floating renewables face the same integrity challenge Although much discussion surrounding asset integrity focuses on oil and gas assets, the lessons are equally relevant to floating renewable energy developments. Floating offshore wind is expected to become a major component of future energy systems, particularly throughout Asia Pacific. Countries including Japan, South Korea, Taiwan, Australia, and several Southeast Asian nations possess

ENERGY GLOBAL AUTUMN 2026

extensive deep-water resources that favour floating wind technology. However, floating wind introduces many of the same integrity challenges faced by the offshore oil and gas sector. Hull structures require monitoring, mooring systems require inspection, corrosion protection systems require maintenance, and underwater structures remain exposed to harsh marine environments throughout their operational lives. The economics of floating wind make efficient maintenance particularly important. Operators must minimise intervention costs while maximising energy production and availability. As a result, many of the technologies being developed for floating production units are likely to become equally important for floating renewable assets. Remote inspection systems, autonomous underwater vehicles, robotic maintenance solutions, and condition-based integrity management strategies will become essential components of future offshore wind operations. The energy transition is not reducing the importance of asset integrity; in many respects, it is increasing it.

Collaboration is becoming more important than competition One of the most encouraging developments in the offshore sector is the growing emphasis on collaborative innovation. Many of the industry’s most significant challenges are shared challenges. Corrosion affects all operators; access limitations affect all operators; ageing infrastructure affects all operators; and safety risks associated with confined space entry, underwater operations, and working at height affect all operators. Consequently, collaborative industry initiatives are becoming increasingly valuable. A notable example is the progression from the Hull Inspection Techniques and Strategy (HITS) joint industry project to the broader Hull Structural Integrity (HSI) initiative operating under the Floating Energy Research Forum. The evolution itself is revealing. The industry’s focus has expanded beyond inspection alone to encompass integrity, maintenance, and repair as interconnected elements of a comprehensive asset integrity management strategy. Importantly, participation increasingly includes not only operators, but also drilling contractors, classification societies, regulators, researchers, and technology providers. This reflects a growing understanding that future challenges require collective solutions. Industry feedback consistently identifies three priority concerns: > Safe and efficient access to critical structures. > Inspection and maintenance of cargo oil tank bottom plating. > Management and mitigation of corrosion. Each of these challenges has implications extending well beyond individual assets. They affect safety performance, operating costs, environmental risk, asset valuations, and regulatory confidence. Collaborative research provides a pathway towards solutions that benefit the industry as a whole.

Figure 5. ODIN access port external view.

Figure 6. CLAM cofferdam installed.

ENERGY GLOBAL AUTUMN 2026

The rise of continuous integrity Perhaps the most important trend shaping the future is the movement towards continuous asset integrity management. Historically, asset condition was often assessed through periodic inspections conducted at fixed intervals. Increasingly, operators are seeking a more dynamic understanding of asset health. Continuous integrity management combines inspection technologies, digital data collection, predictive analytics, and risk-based maintenance planning to provide a more complete picture of asset condition over time. Rather than relying solely on periodic snapshots, operators can identify degradation trends, prioritise interventions, and allocate resources more effectively. This approach supports better decision-making at every level: > Operational teams gain greater visibility of emerging issues.

> Management teams gain greater confidence in maintenance planning and capital allocation. > Investors gain greater assurance regarding asset longevity. > Insurers gain stronger evidence of risk management effectiveness. > Regulators gain confidence that safety and environmental performance standards are being maintained. In an industry where a single asset may represent billions of dollars in capital investment, that confidence has significant value.

A new definition of asset integrity The offshore industry’s understanding of asset integrity is evolving. Traditionally, integrity management was viewed primarily as a technical discipline focused on inspection schedules, maintenance activities, and regulatory compliance. Today, it is becoming something much broader. Asset integrity now sits at the intersection of safety, operational performance, sustainability, economics, and corporate reputation. It influences production efficiency, energy security, environmental performance, and investment outcomes. The organisations that thrive in the coming decades will be those that embrace this broader perspective. They will:

> Invest in technologies that reduce human exposure to risk.

> Adopt maintenance strategies that keep assets productive while preserving long-term integrity.

> Leverage robotics, remote operations, and digital systems to improve decision-making.

> Collaborate across industry boundaries to solve common challenges. Most importantly, they will recognise that inspection, repair, and maintenance are no longer simply operational activities; they are strategic enablers of long-term value creation.

Where will this lead? As Asia Pacific continues to expand its role as a global offshore energy powerhouse – across oil, gas, and floating renewables alike – the future will belong to operators that can maintain asset integrity without compromising safety, productivity, or sustainability. The destination is clear: fewer shutdowns, fewer people exposed to risk, greater operational resilience, and longer asset lives. The technologies are already emerging. The question for industry leaders is no longer whether this transformation will occur; it is how quickly they choose to lead it.

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ENERGY GLOBAL AUTUMN 2026

Robert Cole, Corrocoat, discusses extending asset life in Energy from Waste facilities through advanced corrosion protection.

s Energy from Waste (EfW) facilities continue to play an increasingly important role in supporting energy security, reducing landfill dependency, and contributing to circular economy objectives, operators face growing pressure to maximise plant availability, optimise maintenance budgets, and extend the service life of critical assets. While significant attention is often focused on combustion efficiency, emissions reduction technologies, and energy recovery systems, the long-term performance of an EfW facility ultimately depends on the condition of the infrastructure that supports these processes. Corrosion, erosion, and chemical attack remain among the most persistent threats to operational reliability across the sector. For operators seeking to reduce downtime and improve whole-life asset performance, effective corrosion management has become a critical component of modern asset integrity strategies.

Getting to grips with corrosion EfW facilities operate in some of the most demanding environments within the power generation industry. Throughout the process, assets are routinely exposed to elevated temperatures, moisture, aggressive chemicals, and abrasive materials that can accelerate degradation.

Combustion gases often contain chlorides, sulfur compounds, and acidic condensates capable of attacking exposed metal surfaces. Equipment such as ductwork, stacks, flue gas treatment systems, tanks, pipework, and pumps may be subjected to continuous exposure to corrosive process streams, creating conditions that can rapidly deteriorate unprotected substrates. In addition to corrosion, many assets experience significant abrasion. Ash handling systems, material transfer equipment, and process vessels frequently encounter abrasive particulates that can wear away protective surfaces and expose underlying metal to further attack. Temperature cycling presents an additional challenge as repeated heating and cooling can create stresses within protective systems, encouraging cracking, moisture ingress, and coating breakdown if protection is compromised. Over time, these mechanisms can result in wall loss, leaks, structural deterioration, unplanned outages, and costly repairs. While corrosion is often viewed as an unavoidable consequence of operation, its impact extends far beyond maintenance expenditure. Asset degradation can directly affect plant availability, operational efficiency, and overall lifecycle costs.

The shift towards proactive asset preservation Historically, maintenance programmes have often focused on repairing assets once visible deterioration has occurred. While reactive maintenance remains necessary in certain circumstances, many EfW operators are increasingly adopting a more proactive approach centred on asset preservation and lifecycle management. The objective is straightforward: prevent degradation before it reaches the point where major repairs, refurbishment, or replacement become necessary. This shift reflects a broader industry focus on whole-life cost management. Rather than assessing assets purely on their initial capital cost, operators are increasingly evaluating the long-term financial impact of maintenance interventions, downtime, replacement costs, and lost production. For EfW facilities, where operational continuity is essential, extending maintenance intervals and reducing the frequency of major shutdown activities can deliver significant commercial benefits. A proactive asset preservation strategy can also support sustainability objectives. Extending the life of existing infrastructure reduces the consumption of raw materials, limits waste generation, and minimises the environmental impact associated with manufacturing and transporting replacement equipment.

Why protective coatings remain critical

Figure 1. Energy from Waste (EfW) combined heat and power facility where corrosion protection works were undertaken.

Protective coatings continue to represent one of the most effective methods of preventing corrosion across industrial infrastructure. When correctly specified and applied, advanced coating systems create a barrier between aggressive operating environments and the underlying substrate, helping to prevent moisture ingress, chemical attack, and corrosion. However, not all coating technologies perform equally under the demanding conditions found within EfW facilities. As operating environments become increasingly challenging, coating performance is being evaluated not simply on initial appearance or short-term protection, but on its ability to deliver long-term resistance to permeation, chemical attack, and thermal stress. This is where Glassflake reinforced coating technologies have established a strong reputation across multiple industrial sectors.

The science behind the technology

Figure 2. Internal ductwork exposed to aggressive flue gas conditions prior to protective coating application.

ENERGY GLOBAL AUTUMN 2026

Glassflake reinforced coatings utilise engineered Glassflakes dispersed throughout the coating matrix to create a highly effective barrier against the penetration of water, oxygen, and corrosive species. Unlike conventional coating systems, where moisture and contaminants can follow relatively direct pathways through the coating film, the overlapping Glassflake structure creates a significantly longer and more complex route for permeation. This mechanism, often described as a ‘tortuous path’, forces moisture and corrosive agents to travel a much

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greater distance before reaching the substrate. By slowing the movement of these corrosive elements, the coating’s barrier performance is significantly enhanced. The result is improved resistance to moisture ingress, chemical attack, and long-term degradation, helping to extend coating service life and reduce maintenance requirements. For EfW operators, where assets may be exposed to aggressive flue gases, acidic condensates, elevated temperatures, and high humidity, reducing permeation can play a critical role in protecting infrastructure and maintaining operational reliability.

Benefits for EfW facilities The demanding operating conditions found throughout EfW facilities require protective systems capable of withstanding far more than atmospheric corrosion. Glassflake reinforced coatings offer several characteristics that make them particularly well suited to these environments. The enhanced barrier properties help protect substrates from moisture and chemical ingress, particularly in areas exposed to acidic condensates and corrosive process streams. The coatings also demonstrate strong adhesion to correctly-prepared substrates and provide durable protection across a wide range of industrial environments.

These characteristics make Glassflake systems suitable for protecting critical assets including: > Ductwork and stacks. > Flue gas treatment systems. > Process tanks and vessels. > Pipework and pumps. > Ash handling equipment. > Ancillary plant infrastructure. Importantly, many systems can be applied as part of refurbishment programmes, enabling operators to restore and protect existing assets rather than undertake costly replacement projects. As organisations continue to focus on both operational efficiency and sustainability, the ability to extend the service life of existing infrastructure is becoming increasingly valuable.

Protecting critical assets at an EfW facility

The practical benefits of advanced corrosion protection can be demonstrated through a recent project undertaken at a UK EfW combined heat and power facility, which involved processing approximately 245 000 tpy of household, commercial, and industrial residual waste. The facility’s flue gas handling system included critical duct and stack assets operating in challenging conditions, with temperatures reaching up to 160˚C at the inlet and 120˚C at the outlet. Continuous exposure to aggressive gaseous emissions and elevated temperatures had resulted in corrosion affecting key areas of the system, creating concerns around long-term asset integrity and reliability. The operator required a corrosion protection solution capable of delivering long-term performance, while minimising disruption to plant operations during installation. Following a detailed inspection, Corrocoat recommended the application of Corrothane XT, a Glassflake reinforced coating system designed for elevated-temperature, non-immersed service environments. To maximise coating performance and longevity, the Figure 3. Critical duct and stack assets operating within an EfW facility. project involved comprehensive surface preparation, including abrasive blast cleaning to Sa 2.5 standard, followed by the application of Corrothane XT using airless spray techniques. Critical wall-to-floor interfaces within the duct and stack system were reinforced using multi-axial glass fabric and laminating resin to enhance durability in vulnerable areas. Full inspection, coating thickness testing, and spark testing were undertaken to verify system integrity. To minimise downtime, multiple coating teams were mobilised and shift working was implemented throughout the project, helping Figure 4. Glassflake reinforced coating systems create a tortuous path that reduces vapour to accelerate completion while permeation and enhances long-term corrosion protection. maintaining quality standards.

ENERGY GLOBAL AUTUMN 2026

The completed coating system now provides long-term protection for assets operating within a challenging EfW environment characterised by elevated temperatures, corrosive gases, and demanding process conditions. Through a combination of specialist coating technology, detailed planning, and efficient project execution, the facility was able to strengthen asset protection while reducing the risk of future corrosion-related maintenance interventions.

Repair, refurbish, or replace? One of the most important decisions facing maintenance teams is whether degraded assets should be repaired, refurbished, or replaced. Complete asset replacement often involves substantial CAPEX, extended procurement periods, engineering challenges, and operational disruption. However, advances in repair materials and protective coating technologies mean that refurbishment can frequently provide a practical and cost-effective alternative. Experience across multiple industrial sectors has shown that many assets affected by corrosion, erosion, and chemical attack can be restored and returned to service through carefully planned repair and protection programmes. When undertaken during planned maintenance outages, refurbishment projects can minimise operational disruption

while delivering significant cost savings compared with full replacement. Beyond financial benefits, refurbishment also supports broader sustainability goals by reducing material consumption, minimising waste generation, and extending the useful life of existing infrastructure.

Looking ahead As the EfW sector continues to expand, the importance of asset reliability, operational efficiency, and sustainable lifecycle management will only increase. Corrosion and wear remain significant challenges throughout EfW facilities, affecting a wide range of critical infrastructure. However, through proactive maintenance strategies, effective inspection programmes, and the application of advanced protective technologies, operators can significantly reduce their impact. By focusing on asset preservation rather than asset replacement, EfW operators can improve reliability, reduce maintenance costs, minimise downtime, and support wider sustainability objectives. In an industry where operational continuity is paramount, long-term corrosion protection is increasingly being recognised not simply as a maintenance requirement, but as a strategic investment in asset performance and plant resilience.

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SOLAR

GLOBAL NEWS President of Comoros inaugurates UAE-financed solar plants

hree solar power plants in the Union of the Comoros have been inaugurated. The plants were financed by Abu Dhabi Fund for Development (ADFD), implemented by Abu Dhabi Future Energy Company PJSC – Masdar, and managed by Global South Utilities (GSU). The project was inaugurated by Azali Assoumani, President of the Union of the Comoros, in the presence of Jumaa Rashid Alromaithi, Ambassador of the UAE to the Union of the Comoros; Ahmed Khamis Alkalbani, Representative of ADFD; Dr Mohamed Alzarooni, Head of Projects at Masdar; Ali Abdulla Alshimmari, Managing Director and CEO of GSU; and a number of senior officials from both countries. The project, financed by ADFD at approximately AED84.4 million, comprises three solar photovoltaic plants with a total installed capacity of approximately 20 MW: 12.86 MW on Grande Comore, 4.05 MW on Anjouan, and 3.1 MW on Mohéli. It also includes battery energy storage systems with a capacity of 16 MWh and a power output of 8 MW across Grande Comore and Anjouan, as well as approximately 30 km of 20-kV medium-voltage overhead transmission lines. Technical studies indicate that the three plants will generate approximately 33.75 GWh/y of clean electricity, equivalent to meeting the needs of around 17 500 households and avoiding approximately 20 900 tpy of carbon dioxide emissions.

Bungaban Solar continues to progress

he Bungaban Solar project continues to progress, with a number of important development milestones achieved as the project moves through its next stage. Bungaban Solar is being developed through a 50:50 joint venture between Windlab and Squadron Energy, bringing together the experience, resources, and capabilities of both organisations to progress the project. Western Downs Regional Council approved the project’s development application in June 2025, marking an important milestone in the project’s development. The joint venture has since submitted a referral under the Environment Protection and Biodiversity Conservation Act, an important step in progressing the project’s environmental approvals. The project team has also secured key land agreements and completed a grid connection enquiry with Powerlink, supporting the project’s ongoing development and assessment of its connection requirements. Market engagement with potential suppliers and contractors is also underway, helping the project team better understand the local and regional supply chain and the opportunities that may be available as the project progresses. These activities represent steady progress for Bungaban Solar as the joint venture continues to work through the approvals, technical, and commercial requirements needed to advance the project.

Yellow Door Energy and Nedbank CIB achieve financial close on South African solar park

ellow Door Energy and Nedbank Corporate and Investment Banking (Nedbank CIB) have achieved financial close on 49 MWp Lion Thorn solar park in Leeudoringstad, North West. Nedbank CIB is financing the utility scale solar project, enabling construction to proceed. The utility scale solar project has secured long-term power purchase agreements with PPC and POWERX, a NERSA-licensed private electricity trader. Once operational, it is expected to generate approximately 115 GWh of renewable electricity in its first year and avoid an estimated 104 190 tpy of carbon emissions. The transaction comes as private investment in

48 ENERGY GLOBAL AUTUMN 2026

South Africa’s electricity sector continues to grow and supports the development of new renewable generation capacity while contributing to South Africa’s energy transition, long-term energy security, and economic growth. Construction is scheduled to begin in September 2026, with commissioning anticipated in 2028. The project is also expected to create employment and economic opportunities during construction and operations. Once commissioned, Lion Thorn solar park will add new renewable generation capacity to South Africa’s electricity system, which will help diversify the country’s energy supply and support growing demand for reliable electricity.

BIOENERGY

GLOBAL NEWS Bio Capital enters partnership with Durham County Council

Zenith Energy acquires Italian biogas plant

io Capital has been awarded a new partnership with Durham County Council, strengthening the North East’s role in turning household food waste into renewable energy, low-carbon fuel, and biofertilizer for farmland. Bio Capital, the UK’s largest producer of renewable electricity and biomethane gas from food waste, has announced a new partnership with Durham County Council, as one of two providers processing household food waste from around 250 000 homes. The partnership follows Bio Capital’s recently announced agreement with nearby Darlington Borough Council, which will see food waste from more than 54 000 homes across the borough processed. Together, the two partnerships represent a growing shift in the North East. Food waste collected from households in Durham will be transported to Bio Capital’s Warrens Emerald biogas facility in Newton Aycliffe, County Durham, where it will be processed through anaerobic digestion. The process breaks down food waste without oxygen to create biogas, which can then be used to generate renewable electricity and biomethane gas for homes and businesses. The same process also produces nutrient-rich biofertilizer, which is returned to farmland to support food production.

enith Energy Ltd has entered into a binding letter of intent and exclusivity for the acquisition of 100% of the issued share capital of an Italian biogas development company, which owns the rights to develop a fully permitted and engineered biogas production facility in Italy, subject to completion of the proposed acquisition. The project is fully permitted, fully engineered, and construction-ready, with all material permits, licences, and engineering approvals already obtained. Once operational, the project will produce approximately 3 million m3/y of methane gas, for injection into the Italian gas network, sold at Italian gas prices and benefiting from 15-year government incentives. A long-term feedstock supply contract with a major Italian regional authority, comprising approximately 50% municipal waste and 50% agro-industrial waste, mitigates what is widely regarded as the principal operational risk associated with biogas projects. This provides the project with a stable and secure long-term feedstock supply, supporting predictable operations, and facilitating access to project financing. The project’s projected annual revenues at full operational capacity are estimated at approximately €5 million. The projected annual EBITDA is estimated at approximately €2.5 million.

Diary dates Solar & Storage Live UK 2026 22 – 24 September 2026 Birmingham, UK

Solar & Storage Live Paris 2026 14 – 15 October 2026 Paris, France

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WindEnergy Hamburg 2026 22 – 25 September 2026 Hamburg, Germany

Offshore Wind North East Conference & Exhibition 2026 12 November 2026 Sunderland, UK

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Energy Storage Summit Central and Eastern Europe 06 – 07 October 2026 Warsaw, Poland

SolarPLUS Central and Eastern Europe 24 – 25 November 2026 Warsaw, Poland

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Solar & Storage Live Italia 2026 07 – 08 October 2026 Verona, Italy

Energy Storage Summit 2027 23 – 25 February 2027 London, UK

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ENERGY GLOBAL AUTUMN 2026

ENERGY STORAGE

GLOBAL NEWS BW ESS acquires Valencian energy storage project totalling 126 MW

W ESS, the global energy storage owner-operator, has acquired two utility scale standalone battery energy storage system (BESS) projects in Spain totalling 126 MW/up to 675 MWh from Spanish renewable energy and storage developer, Navacant. The acquisition expands BW ESS’s presence in the Spanish energy storage market, where the company has been active since 2025. Located in the Valencia region, the projects have a capacity of 99 MW and 27 MW, respectively. The projects have been in development for around 18 months and are expected to reach Ready-to-Build (RtB) status in 2027, with commercial operations targeted for 2028. BW ESS intends to own and operate the assets over the long term. CST Energy, one of Navacant’s partners, will continue to lead the projects through the remaining development phase to the RtB stage. Once RtB, BW ESS will lead the delivery of the assets through construction and into their operational phase.

Equinor brings its largest energy storage project online in the US

ast Point Energy, a wholly owned Equinor company, has completed construction and started operations at Citrus Flatts, a 100 MW/200 MWh energy storage facility in Harlingen, Texas, US. With this, Equinor has put five battery storage facilities into commercial production in four years. Citrus Flatts is East Point’s second operational project, following the start-up of the 10 MW/20 MWh Sunset Ridge facility in 2025. These projects represent a key step in building a competitive, scalable position in onshore power for Equinor. They also mark East Point’s progression from developer to independent power producer, in line with Equinor’s strategy to capture value across the value chain. Combined, Citrus Flatts and Sunset Ridge can supply enough electricity to power around 30 000 homes for up to two hours within Texas’ ERCOT power market. Both projects will operate on a fully merchant basis in ERCOT and benefit from Equinor’s integrated approach to power markets, where close collaboration with Danske Commodities helps strengthen operational capabilities, asset management, and portfolio optimisation.

50 ENERGY GLOBAL AUTUMN 2026

Energy Vault acquires land for BESS project

nergy Vault Holdings, Inc., a global energy infrastructure company supporting grid reliability and next-generation artificial intelligence and high-performance computing infrastructure, has completed the acquisition of the underlying project land for the 125 MW/1 GWh Stoney Creek battery energy storage system (BESS) in Northern New South Wales, Australia. The land, which was previously secured under an agreement for lease, is now owned by Energy Vault following receipt of the required Foreign Investment Review Board approval. The transaction represents an important development milestone for Stoney Creek, securing long-term site control and further de-risking the project as it advances towards construction. Construction of the Stoney Creek BESS is expected to commence in 1Q27, with commercial operations targeted for 1H28, subject to final approvals.

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WAVE

GLOBAL NEWS

Eco Wave Power signs agreement with AI engineering GmbH

DOE announces testing facility to accelerate marine energy

co Wave Power Global AB, has announced that its wholly owned US subsidiary, Eco Wave Power U.S. Inc., has entered into an agreement with AI engineering GmbH to develop a physics and data-driven digital twin platform for Eco Wave Power’s proprietary wave energy technology. The collaboration advances Eco Wave Power’s strategy to integrate artificial intelligence, physics-based simulation, machine learning, and digital twin technology into the design, monitoring, and optimisation of its wave energy systems. The initial phase will focus on digitally modelling how ocean waves interact with Eco Wave Power’s proprietary floaters. Using AI engineering’s PAMICS simulation technology, the companies will evaluate floater behaviour, structural loads, and theoretical energy input under different sea conditions. The companies also plan to compare simulated results with real-world sensor measurements and begin developing machine learning capabilities for forecasting energy yield and system loads. A key objective is to determine how the digital twin can be adapted to different project locations.

acWave South, the first fully operational, pre-permitted, and grid-connected wave energy test facility in the continental US, is now open for business. A ribbon cutting ceremony on 27 August 2026 celebrated the culmination of nearly 15 years of planning, permitting, design, construction, and close collaboration between the U.S. Department of Energy’s Hydropower and Hydrokinetic Office, the facility’s operator, Oregon State University, and other partners. Thanks to its pre-permitted status, PacWave South allows wave energy developers to test devices without regulatory delays that can add to testing budgets and timelines. Facility operators have already begun to work with marine energy developers in preparation for the inaugural tests. Bonneville Power Administration signed a power purchase agreement with the PacWave facility in 2025 to offtake the power generated from the wave energy devices undergoing testing. The Central Lincoln People’s Utility District will distribute the affordable, reliable, and secure power to local homes and businesses as soon as tests begin.

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Energy Global - Autumn 2026