Energy Global Winter 2021 by PalladianPublications

ENERGY GL BAL WINTER 2021

SHAPING A SUSTAINABLE ENERGY FUTURE WITH RELIABLE WIND POWER shell.com/naturelle WIND POWER IS ON THE RISE 1

Offshore wind is gaining share. By 2025: – annual installations set to quadruple – 21% of new wind installations will be offshore (vs 6.5% in 2020)

2020 was a record year for wind power, despite COVID-19 – 93 GW of new capacity installed – a 53% YoY increase – global cumulative wind power capacity reached 743 GW

BUT THERE IS MORE TO BE DONE

Current capacity avoids over 1.1 billion tonnes of CO2 annually – equivalent to South America’s annual carbon emissions

Wind’s share of the global power mix must increase from 6% today to 30+% by 20501 to achieve Paris Agreement targets

OPERATORS ARE UNDER PRESSURE TO: Protect sensitive ecosystems, both onshore and offshore

Effectively maintain turbines and transformers in remote and harsh conditions

Keep up with rapidly changing standards and regulations

ENVIRONMENTALLY ACCEPTABLE LUBRICANTS (EALS) CAN SUPPORT PRODUCTIVITY & SUSTAINABILITY TARGETS

Ensure efficient, reliable power generation

SHELL NATURELLE DELIVERS: Protection for wildlife and ecosystems Readily biodegradable 3, low aquatic ecotoxicity 4, no bioaccumulation

Equipment performance – Wear and corrosion protection for vital equipment components – Supporting reliable equipment operation

Lower carbon intensity High bioderived content, solar-powered manufacturing 5

Environmental protection – Helping reduce impact of accidental leak or spillage 2 – Ensuring compliance with environmental legislation

More sustainable packaging Containers made with up to 40% PCR help reduce plastic waste 6 Carbon-neutral 7 lubricants By protecting and restoring nature

[1] [2] [3]

[4]

[5]

Global Wind Energy Council, Global Wind Report 2021 (PDF, 30.1 MB) Compared to conventional mineral oils Readily biodegradable in accordance with OECD 301 B, >60% degraded by the end of the 28-day test. Meeting the requirements of OECD common acute toxicity tests for assessing EALs according to US EPA requirements Bern, Switzerland, 90 MWh of electricity generated from solar energy, representing 19% of the plant’s total electricity use and avoiding an estimated 0.004 kt/y of greenhouse gas emissions (2019 data).

[6] [7]

PCR: Post Consumer Resin. Pails at least 25%, IBCs at least 40%. In participating locations “Carbon neutral” indicates that Shell has engaged in a transaction where an amount of CO₂ equivalent to the CO₂e amount associated with the raw material extraction, transport, production, distribution and end-of-life of the product has been avoided as emissions through the protection of natural ecosystems or removed from the atmosphere through a nature-based process. CO₂e (CO₂ equivalent) refers to CO₂, methane and nitrogen oxides.

ENERGY GLOBAL

CONTENTS

WINTER 2021

24. Solar's significant potential

03. Comment

Rodrigo Salim, Head of Renewables & Storage Product Line (France), and Cathy Redson, Global Product Manager for Solar PV Systems (USA), Aggreko.

04. America flies the renewables flag Nikhil Kaitwade, Future Market Insights, India.

28. Powering the energy transition David Reid and Jenny Darnell, NOV, USA.

34. Unlock the power of ocean waves

Nikhil Kaitwade, Future Market Insights, India, examines the consumption of renewable energy in North America, specifically its use in transport, packaging, and agriculture.

Marcus Lehmann, CEO and Co-Founder, Thomas Boerner, CTO and Co-Founder, and Julie Mai, Head of Communications, CalWave Power Technologies, USA.

ith new promises and growth paths ahead, will renewable energy prove to be muchneeded salvation for humanity? The answer to this question is being researched and debated across the globe. As the debate on combatting climate change and saving world resources continues, administrations worldwide are actively encouraging the use of renewable energy across every domain. The renewable energy industry has remained quite resilient through the outbreak of COVID-19. With decreasing costs of resources and rapid technological advancements, the sector has emerged as the new power source application, especially in the automotive and packaging industry. Despite suffering from a decline during 4Q20 from supply chain constraints, the renewable energy industry is expected to witness new tailwinds with the growing adoption of green technology in the automotive industry. When it comes to renewable energy, the US is among one of the largest and most attractive markets across the globe. According to the International Energy Agency (IEA), the US energy sector was valued at US$350 billion in 2018, becoming the second largest in the world. With the US being home to a thriving renewable energy industry, North America is one step ahead when it

ENERGY GLOBAL WINTER 2021

38. Time to invest in innovation

Mark Goalen, Offshore Engineering Director, Houlder, UK.

08. Offshore wind + hydrogen = the future?

44. The goal: hit the sustainability targets Emma Mallinson, Shell Naturelle, UK.

48. An eco approach

Ido Sella, CEO and Co-Founder, ECOncrete, Israel.

Nigel Curson and Neil Service, Penspen, UK.

52. Mapping the heat beneath our feet

14. A boost for green hydrogen

56. See the bigger picture

Andreas Rupieper and Dr. Volker Goeke, ITM Linde Electrolysis, Germany.

20. Strike a balance

Mike Popham, CEO of STRYDE, UK.

Michael Mondanos, PhD, Silixa, UK.

60. Global news

Dr. Peter Ellis, Technology Director, Green Hydrogen, Johnson Matthey, UK.

Reader enquiries [enquiries@energyglobal.com]

ON THIS ISSUE'S COVER

ENERGY GL BAL WINTER 2021

NOV delivers technology-driven solutions to empower the global energy industry. For more than 150 years, NOV has pioneered innovations that enable its customers to safely produce abundant energy while minimising environmental impact. The energy industry depends on NOV’s expertise and technology to continually improve oilfield operations and assist in efforts to advance the energy transition towards a more sustainable future. NOV powers the industry that powers the world. Visit nov.com/energy-transition

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10/12/21 3:24 PM

Clean Ambition: Rediscovering Nuclear Energy As decarbonization efforts ramp up worldwide, nuclear power is receiving renewed attention. What will its role be, and how will it fit into larger decarbonization plans? Download Black & Veatch’s new eBook series on nuclear power and its place within the grid of the future. bv.com/netzeronuclear

COMMENT

T EDITOR Lydia Woellwarth

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ENERGY GL BAL

o summarise 2021 in a few words would be doing the year a disservice. For the entire world, the year has been nothing short of a rollercoaster, a time to rip your calendar up because 99% of the time, plans will have been cancelled or rearranged (thank you pandemic). Over 20 months deep into this drama called COVID-19, I think we are fully aware now that this is life for the foreseeable future, but enough with the doom and gloom, this month is the season of goodwill, fiery festivities, an abundance of smiles, and a deluge of delicacies. This positivity for the upcoming festive period is matched in the renewables sector, which hopes to continue its growth trajectory into the new year, having already been glowing with success for the entire 12 months passed. The daily news from the industry has been of innovative technologies developed, project contracts signed, finances finalised, and strong partnerships formed, to name a smattering of successes. According to Deloitte, the renewable energy industry has remained nothing less than resilient during the year, with renewables becoming increasingly competitive with other available energies as a result of falling costs of renewable energy resources, more durable energy storage, and improvements in technology. The future of renewables is poised to accelerate, largely driven by support from government policies, stricter emissions rules, more ambitious clean energy goals, and support for environmental, sustainability, and governance considerations. The COP26 Climate Change Conference, held this year in Glasgow, Scotland, provided world leaders the opportunity to collaborate, pool ideas, and present creative ways to actively reduce carbon emissions, and the world will see actions taken over the coming years regarding the decisions and declarations formalised at this event.

If we look at the figures – because numbers do not lie – the incredibly promising future for the renewable energy industry is clear as day. The International Energy Agency (IEA) has reported that global renewable electricity capacity is projected to rise by more than 60% by 2026, up from 2020 levels. Specifically, over the coming years, it will be renewable energies that account for approximately 95% of all increases in global power capacity – with solar photovoltaics singularly contributing 50% of this. Whilst China disappointingly refused to join the global pledge at COP26 to phase out its use of coal, instead willing to phase down use of the product, the country actually remains the global leader in the volume of its renewable capacity additions. The IEA has forecast China to reach 1200 GW of wind and solar capacity in 2026, far ahead of its 2030 target. Interestingly, India, another country that also only pledged to phase down its use of coal, will be the global leader in terms of the renewable energy growth rate, with new installations of production doubling when compared with the past five years. In the more imminent year of 2022, it is the next-generation clean energy technologies that we should keep an eye on. Forget the other colours of the spectrum, it is green hydrogen that is displaying its potential, mainly due to the decreasing costs of renewable energy, which is a vital input in the production of green hydrogen. This issue of Energy Global magazine features several articles on green hydrogen and its place in the global energy mix, so read on to learn more. As an interesting 12 months comes to an end, the Energy Global team thanks all our readers for their support and positivity, and we look forward to continuing to provide you with current and informative market news and developments as we move into 2022. We wish you all a healthy and prosperous holiday season.

Nikhil Kaitwade, Future Market Insights, India, examines the consumption of renewable energy in North America, specifically its use in transport, packaging, and agriculture.

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comes to the application of renewable energy. The US has the largest geothermal capacity of any other country with 3.7 GW, and the third largest bioenergy capacity with 14.2 GW. In 2019, the US ranked as the second most attractive country for renewable energy investment, according to Select USA. To capitalise on this trend, leading automotive, packaging, and technology players are lining up to strengthen their presence in North America. According to the Energy Information Administration (EIA), consumption of liquid fuels for bulk terminals in the US reached 16.2 million bpd during 2020, and the oil consumption for the same will rise through 2021. Hence, bulk terminal key players are eyeing the US market to increase their sales. As per a research report by ESOMAR-certified market intelligence, Future Market Insights, on the bulk terminal market, North America will house the world’s second largest number of tank terminal operators across the globe. With the strong presence of industrial automation and automotive giants, the US is expected to be the most attractive market across North America. For instance, Zenith Energy, a leading player in transitioning to a cleaner energy future by pioneering sustainable and renewable energy liquid bulk terminals, has acquired three West Coast terminals.

How is renewable energy transforming the US? In 2020, the consumption of renewable energy in the US grew for the fifth year in a row, reaching a record high of 11.6 quadrillion Btu. Over 12% of total US energy consumption was concentrated in the industrial and transportation sector. When it comes to greenhouse gas (GHG) emissions, industries tend to be blamed at large. However, according to a CDP Carbon Majors Database report, for over 71% of global GHG emissions, around 100 companies are responsible, mostly those US based. With growing sustainability and environmental concerns, every industry is transitioning towards generating clean energy. As the US is home to leading pulp and paper, mineral processing, food processing, automotive, and agriculture industries, switching to renewable energy is more prominent in the country. Renewable energy is increasingly attracting consumers and governments for its potential to curb GHG emissions. Since the aforementioned industries have increasingly opted for renewable energy for production and manufacturing, the use of wind energy, hydroelectric power, solar energy, and geothermal power, collectively grew by 69% in 2019. In 2020, the US was among the top five countries using solar energy in the transportation industry. To reduce emissions, the US Department of Energy announced an initiative of nearly US$200 million to reduce emissions from cars and trucks. With 11 billion t of freight vehicle transport, coupled with US$35 billion worth of goods transported every day in the US, the government is extensively developing the way to use clean and green energy for sustainable transport. As people are becoming more aware of the hazardous effects of carbon emission, the adoption of hybrid and

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electric cars, for example, is growing every day. Driven by this, the US Department of Energy initiated the EEMS programme to improve transportation energy efficiency through low-cost, clean energy, and secure technologies. In the coming years, the US transportation industry is expected to have a new face with its ‘SMART Mobility 2.0’ programme, replacing oil with clean renewable energy and domestic fuels, through bioenergy, hydrogen, and fuel cell technologies. Some of the leading industry players are using renewable energy for improving the performance of container terminals as well. For efficient and sustainable maritime activities, the container terminal industry is under a great deal of pressure for maintaining sustainability. To meet the sustainability demand, bulk container industry players across North America are adopting renewable energy technologies to reduce coal consumption. Port authorities and terminal operators are increasingly becoming aware of the challenge of energy efficiency, and are increasingly being concerned with coal emissions. Hence, the regulation of port areas has become more stringent, mostly due to the emission of sulfur and nitrogen oxides. To cater to the growing demand, bulk terminals across the US are shifting from fossil fuels to renewable energy resources. While some terminals are introducing these technologies voluntarily and have invested in energy-efficient technologies, many port authorities and terminal operators are still lagging regarding the importance of energy-efficient infrastructure. According to Future Market Insights, leading industrial automation giants are leveraging their advanced technologies incorporated in liquid bulk variants, to cater to the growing demand for clean energy liquid bulk variants. With the rapid development of port infrastructure, fleeting coal, oil changes, and inefficiencies in fleet management, the need for liquid bulk containers is surging across the US. These developments will create immense opportunities for renewable energy in the bulk terminals industry.

Rise of floating solar photovoltaics Expansion of solar projects in North America, especially in the US, is a chief trend across wastewater treatment plants, agriculture and fish farms, mining companies, and other sectors. As a clean, green, renewable energy source, floating solar photovoltaics is a pillar when it comes to addressing climate change. Consequently, several industry players within North America are exploring this technology through various projects, emphasising sustainability to reduce emissions through mining and wastewater treatment plans. Considering the developments lined up across diverse end use industries, North America might be the first in preserving natural resources through renewable energy.

Supply chain strategies continue to evolve with advent of renewable energy With the onset of COVID-19, the supply chain industry remained under pressure. The US-China trade tension

created more challenges during 2020. However, as a result of the focus on adopting renewable energy sources in diverse sectors, US renewable energy researchers are likely to face transformation with relaxed domestic measures and ease in shipping methods. Focus on sustainability is expected to rise globally and North America will be a trendsetter in renewable energy adoption. The US, with the shale gas revolution, will be a hotspot of this change within North America. Over the coming years, several solar developers are likely to ramp up their compliance monitoring activity, as they try to mandate the Solar Energy Industries Association’s (SEIA) Solar Supply Chain Traceability Protocol, which comprises stringent regulations intended to trace the origin of solar materials.

Can renewable energy limit food waste? According to the Food and Agriculture Organisation, the agrifood value chain consumes over 30% of the earth’s available energy. The availability of fossil fuels has played a vital role in feeding the world but it also has increased environmental problems. With natural resources being finite and an increasing population, the adoption of renewable energy in the food industry is like a boon. North America has one of the largest agriculture and food industries across the globe. As the adoption of solar-powered irrigation and biogas digesters is increasing, the North American food industry is witnessing an enormous change in its core. In 2021, 56.7 billion lb. of milk was produced in the US, according to the US Department of Agriculture. With the increasing consumption and production of milk, the amount of wasted milk is significant. 3.7 gal. of milk is wasted every day in the US, which negatively affects the economy, environment, and farmers. To curb that waste, the regulatory bodies are investing in developing sustainable energy technologies with which the milk can be restored or cooled with the use of biogas – a renewable energy source. The food processing and aquaculture industries are also focusing on green and clean energy innovation to reduce carbon emissions and reach independence from fuel price fluctuations. For instance, the leading food processing industry giants are investing in the development of solar agro-processing power stations which play a significant role in agricultural production, especially in milking, the emergence of solar mills in rural farms, and by saving manual labour. Hence, with the incorporation of renewable energy in food processing and food manufacturing, key players are trying to reduce the amount of waste. For instance, in 2021, Food Union, the international ice cream and dairy production and distribution group, announced its investments in renewable energy to power ice cream and dairy operations in the Baltics and Norway. Additionally, US Department of Agriculture Secretary Tom Vilsack announced the investment of US$464 million to build or improve renewable energy infrastructure and to help rural

communities, agricultural producers, and businesses lower energy costs in 48 states and in Puerto Rico.

Renewable energy revolutionising the North American packaging industry In 2021, the renewable energy industry has been focusing on keeping pace with rapid technological advancements in the packaging industry. The growing interest in clean energy technologies is compelling packaging industry manufacturers for more investments to capitalise on the ongoing trends. The emergence of intelligent packaging and the integration of clean energy technology is reshaping the packaging industry in North America. With the US being home to the leading major packaging industry, sustainability remains the largest concern for the government as well as consumers. Along with the transportation industry, the US is trying to make amends with the environment by introducing clean energy and sustainable packaging to consumers. The emergence of intelligent packaging through renewable energy, recycling, and incorporation of advanced technologies such as artificial intelligence is expected to be at the heart of the new US economic model. The presence of packaging industry giants such as Henkel, Dow, Emmerson, and Evergreen Packaging, and the use of biomass and other renewable energies is making deeper inroads in the US packaging industry. For instance, Evergreen Packaging uses renewable energy to power its operations and manufacturing production by using efficient cogeneration or combined heat and power (CHP) process. This process helps reduce the electricity and avoid energy losses due to the transmission of electricity. Also, this company claims that approximately 85% of the energy it uses to make paper products comes from a renewable energy source: biomass and lignin. In addition, millennials nowadays are becoming more concerned and aware of the environment and hence are willing to pay more for sustainability. To bank on this trend, leading players such as Emmerson packaging are introducing innovative, recyclable, and biodegradable sustainable packaging by using renewable energy resources. The company is introducing fully recyclable and biodegradable products with very few films. Its sustainable SmartPack packaging uses energy-curing technology to reduce the number of films that are needed to produce a sustainable product, making them one of the leading packaging companies in North America. Based on such aforementioned development in regards to the use of renewable energy for sustainable packaging, North America is expected to be at the forefront of the global renewable energy industry.

Summary The renewable energy industry is booming and innovations hold promise to deliver a clean energy future. In the coming years, more industries across the globe will join the bandwagon to stay ahead of the competition.

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Nigel Curson and Neil Service, Penspen, UK, detail why making informed decisions on whether reusing existing infrastructure or starting afresh to bring green hydrogen onshore could make the greatest economic and environmental sense.

ife – business and personal – has not been without its challenges in recent years. But there is another one facing many organisations as offshore wind becomes the world’s fastest growing renewable energy source. Estimates suggest the sector is forecasted to expand from a generating capacity of approximately 30 GW today, to 190 GW by 2030. But with challenges comes opportunity. Supported by environmental policy targets and falling technology costs, the International Energy Agency has predicted offshore wind will become a US$1 trillion industry over the next two decades. The size of this potential market is encouraging asset owners to weigh up the potential for repurposing existing offshore oil and gas assets for wind – or to consider building new infrastructure. In the UK, the Offshore Wind Industry Council says there is potential for the generation of up to 1000 GW – well above the 75 - 100 GW likely to be needed for UK electricity generation by 2050. This opens up the potential of growing the offshore wind industry beyond local electricity requirements, to the production of green hydrogen as offshore wind costs continue to fall.

Support for hydrogen The international community – including the UK – is committed to the benefits of a hydrogen-based energy economy.

FFAccording to the Global Wind Energy Council, of all renewable energies, offshore wind and wind/solar hybrid projects have the highest potential to improve the economics of green hydrogen projects due to cost competitiveness and scalability.

FFOnshore wind became one of the cheapest new sources of electricity in 2020, while offshore wind has delivered a global levelised cost of electricity (LCOE) reduction of more than 67% over the last eight years.

FFThe Hydrogen Council estimates the market for hydrogen and hydrogen technologies will reach revenues of more than US$2.5 trillion/y and create jobs for more than 30 million people by 2050.

FFOverall demand for hydrogen in the UK is predicted to increase up to 300 TWh, comparable to the nation’s electricity system today.

Environmental benefits of green hydrogen Various colours are used to identify hydrogen production, from blue to green, brown, pink, yellow, white, grey, etc., with carbon neutral green hydrogen produced by electrolysis using a renewable energy power source such as offshore wind. The Offshore Wind Industry Council estimates green hydrogen from offshore wind could cost less than blue hydrogen (produced using natural gas) by 2050. Electrolytic hydrogen production splits water into hydrogen and oxygen. However, electrolysis currently faces several challenges: FFAlkaline electrolysers do not work well with intermittent renewable sources, but alternative technologies such as proton exchange membranes (PEM) are being developed to address this.

FFThe efficiency and lifespans of electrolysers need to be increased to make them more economically viable and scalable, and the development of new electrodes and catalysts will lead to improvements and decreased costs.

FFDespite these challenges, the production of hydrogen at scale using electrolysis is an essential long-term requirement in achieving net zero carbon emissions objectives.

Whether to reuse or build new The significant increases anticipated in demand for both offshore wind and green hydrogen are key components in the energy transition as the global focus shifts from hydrocarbons to renewable sources. However, it creates several important questions for existing offshore oil and gas asset owners, asset developers, technology owners, and integrity engineers to consider. These include: FFCan renewed value be found from redundant assets or infrastructure such as pipelines and platforms by reusing them for green hydrogen?

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FFIs doing this technically feasible or economically viable based on a through-life cost basis compared with a cabled supply?

FFWhat are the economic benefits of deferring abandonment (for example, 20, 30, or 40 years) by repurposing the asset?

FFWould the deferment of abandonment result in cheaper energy? There are several challenges when it comes to examining the reuse of existing infrastructure. However, key considerations include asset safety, the costs of maintenance, asset capacity, and infrastructure compatibility. The most important issue relating to hydrogen and pressure containing equipment compatibility is embrittlement or material degradation through enhanced fatigue and mechanical joint leakage. This can lead to a reduced operational pressure in the pipeline and reduced capacity, a problem when also considering the relatively lower energy value of hydrogen on a volumetric basis. Using wind power to generate energy offshore which is then transported for use onshore will require high voltages and DC to avoid significant losses. A world-first pilot project using wind power to generate hydrogen offshore and transmitting via the use of an existing gas pipeline system – PosHYdon – is being developed off the coast of the Netherlands. Using the Neptune Energyoperated Q13a-A platform 13 km offshore Scheveningen, electricity generated by offshore wind turbines will power the containerised hydrogen plant on the platform, converting seawater into demineralised water and then into hydrogen by electrolysis. The green hydrogen will be mixed with produced natural gas and transported via an existing gas pipeline to the coast. The 1 MW electrolyser will produce a maximum of 400 kg/d of green hydrogen. The aim of PosHYdon is to gain experience of integrating working energy systems at sea and the production of hydrogen offshore. However, the offshore hydrogengenerating process raises several points for consideration relevant to its more widespread adoption in the future. A high degree or purification of water is currently required for electrolysis whether onshore or offshore. Although there are some seawater-capable electrolysers currently in research and development, there are none on the market. The question of how practical and cost-efficient it is to build and maintain a water purification plant offshore, compared to running a pipeline from the shore to the platform, is important. Consideration must also be given to disposal of the high volume of produced solids. Likewise, a thorough assessment of whether an existing platform is suitable for mounting an electrolyser, in terms of the weight and space required, will be critical. When it comes to investment, decisions on the most appropriate method for offshore green hydrogen production will be driven by which solution delivers the most appropriate through-life cost. With existing assets or infrastructure, this must include an assessment of the cost savings in deferred

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abandonment – which may be put off for 20 years or more – compared to how long the asset can be expected to last and what the cost of maintenance would be. The production of hydrogen offshore will be complex and capital-intensive: FFElectrification will require cables, j-tube to protect the cable from the seabed to the topsides and electrical isolation, rectifiers, and controllers.

FFThe hydrogen process requires desalination of the seawater.

FFProduction will require electrolysers, a buffer tank, and a compressor.

FFStatic equipment will include piping, valves, a flare stack or vent stack, metering, and instrumentation.

FFRotating equipment will include a non-centrifugal compressor and power generation – either hydrogenfuelled gas turbines (if powering the platform by hydrogen) or stand-by diesel generators. On top of these aspects, all the existing standard offshore platform components will be required, such as a lay down area, cranes, a heli-deck, accommodation, and life boats.

The condition and integrity of existing pipelines will also have to be assessed. These may not have much operational life left in them as many have been in operation beyond their original design life. In addition, the size of the pipelines and safe operating pressure may limit the energy throughput. When considering the jacket structure, many jackets have been in place longer than they were designed for, thus creating integrity and degradation issues. Furthermore, the jacket will have a limited load bearing capacity. This will ultimately limit what can be installed on the topsides (by weight), which in turn could limit the production output from the electrolysers. Upgrade complexity, asset location, topsides configuration, plot space, and even the insurance implications of using a repurposed asset have to be taken into consideration. Pipes must be piggable so that an inspection tool can be run to check for hydrogen embrittlement and other degradation issues. Hydrogen accelerated fatigue is another limiting factor. Whilst electrolysers may be able to increase or reduce production as renewable energy supply fluctuates, the potential constant cycling of topside plant and the subsea pipelines will need to be addressed. With all the above points taken into consideration, asset owners will be better able to make informed decisions on whether reusing an existing asset or infrastructure vs a new

Figure 1. Solar can play a powerful role in amplifying green hydrogen production.

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build makes the greatest economic and environmental sense.

Meeting the challenge In making such decisions, it is important for asset owners to enlist the support of a partner with solid expertise and a full understanding of hydrogen-related projects. This may include: FFThe design and installation of hydrogen pipelines, storage systems, and production systems.

FFThe maintenance of hydrogen, blended hydrogen, and CO2 networks.

FFRegulatory support. FFTechnical specifications and material selection recommendations.

Starting the process

Figure 2. Green hydrogen has been identified as a key potential route to speed up the transition to a carbon neutral future.

The transition work required to bring green offshore hydrogen onshore is complex and requires detailed preparation. For asset owners, a critical component of this initial work is a feasibility assessment and review of existing onshore assets. As an example, Uniper UK Ltd recently commissioned Penspen to carry out a fitness for continued service assessment, site audit, hydrogen feasibility technical report, and design and integrity review for the Theddlethorpe to Killingholme (KIPS) and Blyborough to Cottam (BCot) pipeline systems. These systems are designed to provide gas to Uniper’s owned and operated power plants at Killingholme and the Cottam Development Centre (CDC) respectively. The CDC is a combined cycle gas turbine plant, with a generating capacity of 400 MW. Uniper is investigating the possibility of blending hydrogen with natural gas at various ratios, up to 100% hydrogen, together with the suitability of the existing BCot and KIPS system assets. The hydrogen percentages in natural gas to be considered are 5%, 10%, 15%, 20%, 30%, 50%, and 100% hydrogen. Uniper requested a study to determine the feasibility and system compatibility with hydrogen. The study incorporated all pipeline system elements, including the pipeline, inlet and outlet points, block valve stations (BVS), above ground installations (AGI), pressure reduction stations (PRS), and off-takes. The services delivered included a site audit and the undertaking of assessments at various levels. These included a collation and review of asset documentation; an equipment inventory audit; system flow assurance and thermal input assessment; hydrogen degradation mechanisms; AGI equipment, pipeline design and integrity reviews; safety assessments, including venting and hazardous area zones; maintenance and inspection changes; a pipeline quantitative

risk assessment (QRA); personnel competency and training, emergency response, and regulatory requirements. The compatibility of equipment and assets with hydrogen at different blend increments was determined through codes and standards requirements, relevant industry and academic research, industry best practices and lessons, as well as engineering assessments. Penspen provided Uniper with a hydrogen feasibility technical report, containing fitness for continued service evaluations of the above ground equipment and pipelines within the two systems. This determined at what percentage of hydrogen the existing system components are suitable and at what point further assessment, modifications, or replacements are required to continue operations. Penspen also produced an extensive list of recommendations, highlighting further work required to ensure the assets are safe and ‘hydrogen ready’ prior to transitioning, plus an implementation plan of the next steps to be taken.

Conclusion Offshore wind has been identified as a rapid growth energy source, and hydrogen as an important energy vector. The combination of the two represents an exciting prospect for the UK’s expansion of renewable energy. It creates significant business growth opportunities, too. To facilitate that growth and to maximise economic returns, asset owners, asset developers, and technology owners/integrity engineers have key decisions to make on whether to reuse existing offshore infrastructure or build anew, a challenge that Penspen is well-equipped to help them rise to, whilst driving positive change for a greener, more sustainable energy future.

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he main target of this year’s 26th UN Climate Change Conference is to secure global net zero by the middle of the century and keep 1.5˚C within reach. Hydrogen (H2) is set to play a key role in the defossilisation of various sectors and industries and in realising climate-friendly mobility options. It is produced by using electricity to electrolyse or split water into hydrogen and oxygen. When the energy is sourced exclusively from renewables, it is called green hydrogen (green H2), which prevents both local and global carbon emissions. While many market players believe that the pathway to cost parity with grey (SMR-based1) or blue (SMR-based, combined with CCS2) hydrogen involves significant CAPEX reduction and efficiency improvement in the electrolysis technology, the truth is that the levelised cost of hydrogen (LCOH) is much more dependent on:

F The right location, where renewable electricity is widely available at an attractive levelised cost of electricity (LCOE) and high load factors.

F The availability of a suitable H2 infrastructure for efficient transport and storage over the next 5 - 10 years.

When considering the example of a 100 MW PEM electrolysis system with a 2021-level project realisation cost and the current technology maturity/efficiency, and comparing both to the 2025 outlook, it can be shown that the

Andreas Rupieper and Dr. Volker Goeke, ITM Linde Electrolysis, Germany, explain how hydrogen can support defossilisation and outline the steps needed to make it happen, providing insights into the enabling technologies and measures, the costs, and success stories.

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efficiency and CAPEX improvement from expected innovation and industrialisation would only reduce the LCOH by approximately 15%. This is not nearly enough for cost parity. Favourable renewable energy conditions on the other hand allow a >40% reduction in LCOH, which is an important and much-needed step to reach the €2/kg hydrogen target. At today’s natural gas prices in Central Europe and without penalties from emissions trading systems, the LCOH for green H2 tends to be up to three times higher than for grey hydrogen, subject to the employed power cost. The LCOH of green H2 can drop to cost parity over the next five years, but only if the renewable LCOE comes down to values between €20 - €30/MWh, and if combined with the expected CAPEX improvement and efficiency increase as result of product maturation and industrialisation. In any case the LCOH is much dependent on the power cost. Under this scenario, the main challenge is how to achieve an acceptable LCOE to reach the targeted LCOH and improve the overall economic viability of green H2. Linde sees three main contributors:

The electrolysers must be located in places with a favourable electricity cost Today’s typical SMR-based hydrogen production is located beside large primary industry consumers, e.g. refineries, and chemicals manufacturers. The molecule is delivered as ‘over-the-fence’ via a short pipeline connection from a central production plant.3 Such plants are often piggy-backed with bulk consumers, where the molecule is transported by trailers to the distributed consumers of the secondary

industry (metals, glass, food, paper, electronics, etc.). So, the central hydrogen production plant is located where the largest single-point consumption occurs, and this can be done because natural gas as the primary feedstock is made available via an unbelievably dense pipeline infrastructure. Unfortunately, when changing hydrogen production from fossil to green (with electricity now becoming the number one feedstock), the business cases typically suffer from high LCOE of >€50/MWh. This inhibits investment and defossilisation. Hydrogen consumers committed to defossilisation now have two alternatives: FFMoving the hydrogen-consuming value chain to areas with a low LCOE, which is costly and difficult in many aspects.

FFConnecting the point of hydrogen consumption with the areas of industrial use with a dedicated hydrogen pipeline. The second option requires the political will by governments, e.g. in Europe, to set up a Europe-wide hydrogen pipeline infrastructure to connect attractive renewable energy locations for central green H2 production with the areas of industrial use. Instead of the electrons, the molecule is transported. This has a number of advantages: FFHydrogen pipelines represent the most cost-effective option for long-distance and high-volume transport, with costs ranging from €0.11 - €0.21 per 1000 km per 1 kg of hydrogen; the existing natural gas pipeline grid can be converted to pure H2 use in acceptable time frames.4

FFExtra power grid congestion is prevented: the non-avoidable energy loss of electrolysis (today approximately 25% of gross power consumption), resulting in waste/off-heat, does not need to be transported via the power grid.

FFWith a dedicated hydrogen pipeline grid, today’s large scale industry consumers, as well as future consumers (e.g. steel sector for direct reduction of iron) can be efficiently procured. Figure 1. Levelised cost of hydrogen – 100 MW central plant in 2021 vs 2025.

FFRoad transportation of molecules to procure distributed secondary consumers can be significantly reduced.

The electrolysers must be flexible for the intermittency of the renewable power

Figure 2. Electrolysis as a solution provider when taking the upstream optimisation and the byproducts valorisation into account.

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Designing an optimally configured electrolyser under renewable energy conditions is challenging since renewable energy does not flow 24/7 at peak power like natural gas, and power costs are not constant if engaged in the spot market. Accordingly, the sizing of an electrolyser must consider both gas demand and renewable power availability: FFOn the supply side, customers typically specify the renewable energy via an annual power profile, using an hourly or 15 min. time resolution.

FFAlso, the gas demand side may be more discontinuous than experienced, since new green H2 applications such as H2 mobility specify highly fluctuating refuelling patterns, both from a weekly and seasonal point of view. Hence, choosing the configuration leading to an optimum LCOH is not straightforward, but rather the result of a dedicated optimisation run. Linde has developed a software product called Clean Hydrogen Business Modeller (CHBM), which does exactly this job. For better balancing of the demand-supply equation, two storage options, electrochemical batteries and compressed hydrogen tanks, are considered – variable in size. Besides renewable energy pricing and gas demand profiles, the tool considers further basic financial assumptions as specified by the user and of course including downstream requirement such as H2 pressure. CHBM features a results page, where the improvement in LCOH reduction is broken down into single contributions, such as LCOE or optimum load point operation of the electrolyser. The tool is currently being extended to cover the upcoming electrolyser technology for XXL plants, and provision to give expert users more flexibility in specifying inputs, boundary conditions, and cost optimised production of green H2 based chemicals, such as green ammonia.

The electrolysis is beyond hydrogen supply When extending the revenue streams of an electrolysis by operational flexibility towards grid services or when optimising the LCOE by curtailed power management and arbitrage, the whole value chain and electrolysis operation must be adjusted accordingly. Linde uses its CHBM to analyse and optimise the overall plant configuration, starting with the green power profiles to match the demand of the green gases. The modeller factors in volatility in the power price and availability, and the customer’s molecule demand. For byproduct valorisation, converting waste heat to off-heat use not only improves the overall efficiency, but can also help to close the growing gap in district heating when coal-fired power plants are shut down in Central Europe.

Alternatively, the heat can be exported to greenhouse farming. Also, (green) oxygen as a byproduct can be used as an additional revenue stream in different applications such as oxyfuel (pure oxyfuel or combustion air enrichment) or wastewater treatment or sustainable fish farming (when the electrolysis plant is in coastal regions).

Green hydrogen – a success story Linde has been systematically investing in hydrogen technologies and advancing them to market maturity for more than four decades. The company is a leading provider along the entire hydrogen value chain – from production to the application. All discussions about a greener future powered by hydrogen come down to one core technology – the electrolyser. Linde decided in 2015 to partner with the British company ITM Power, a leader in the area of proton exchange membrane (PEM) technology. In 2019, the two companies set up the joint venture ITM Linde Electrolysis (ILE) to bundle the complementary core competencies. Through this joint venture, Linde can deliver end-to-end green hydrogen solutions, covering every step in the project lifecycle from concept engineering and feasibility studies through EPC proposals and cost estimates to engineering services and turnkey handover to the operator. Linde can point to several flagship projects that clearly illustrate the fact that green H2 is on a growth path. Establishing a broader production base for green hydrogen is the aim of one reference project based at the Leuna chemicals complex in Germany. This is where the world’s largest PEM electrolyser operated by Linde is set to commence operations in the second half of 2022. Linde Engineering together with ILE are building the plant to supply industry customers with green H2. Leuna’s current capacity for hydrogen produced by electrolysis is 4500 m3/h. When the PEM electrolyser, which will initially operate using certified eco-power, switches to renewable energy generated locally mid-2022, the plant will be able to produce up to 3200 tpy of green H2. This would be enough to fuel approximately 600 fuel-cell buses, allowing them to travel 40 million km while reducing carbon dioxide emissions by up to 40 000 tpy. More sucess stories can be found on Linde Engineering’s website.

Notes

Figure 3. Clean Hydrogen Business Modeller (CHBM) stage 1: Key system components and configuration.

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1. Steam methane reforming (SMR) is where CO2 emissions are typically approximately 10 t of CO2 per tonne of hydrogen. 2. Steam methane reforming with carbon capture and storage (SMR with CCS) where the CO2 emissions from the SMR process are captured at a rate of between 55% and 95% and sequestered in safe geological formations for permanent storage of the CO2. 3. Industrial scale = 20 - 100 000 Nm3/h hydrogen production capacity. 4. According to a recent study by the European Hydrogen Backbone (EHB), Gas for Climate press release, 13 April 2021, ‘European Hydrogen Backbone grows to 40 000 km, covering 11 new countries.’

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Dr. Peter Ellis, Technology Director, Green Hydrogen, Johnson Matthey, UK, discusses the decarbonisation of the hydrogen industry and the technological trade-offs and decisions that must be considered to achieve this goal.

he challenge presented to achieve net zero emissions is real and countries around the world must do absolutely everything in their collective power to hit this target. Policy makers globally have begun communicating their strategies and roadmaps for achieving net zero by 2050, with low carbon hydrogen having a major part to play. Why is this? It is a recognition of the role sustainable hydrogen can have in decarbonising end uses where, for example, direct electrification is not successful, where hydrogen is used as a chemical, where energy needs to be stored for more than a few hours, or moved from where it is generated to where it is used.

A growing market Demand for hydrogen has grown more than threefold since the 1970s and continues to rise. The International Energy Agency reports that the demand for hydrogen in its pure form is approximately 70 million tpy. Currently this hydrogen is almost entirely supplied from fossil fuels, with 6% of global natural gas and 2% of global coal going to hydrogen production. Consequently, the production of hydrogen is responsible for approximately 830 million tpy of carbon dioxide (CO2) emissions, over twice the CO2 emissions of the UK. In energy terms, total annual hydrogen demand

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worldwide is approximately 330 million t of oil equivalent, larger than the primary energy supply of Germany. Changing the way in which hydrogen is produced can prevent a huge portion of today’s CO2 emissions and enable the hydrogen market to grow without exerting an additional burden on the environment for future generations. This can be achieved by building new or retrofitting existing fossil fuelpowered hydrogen plants with carbon capture and storage systems (CCS), more commonly referred to as blue hydrogen, or extracting hydrogen from water molecules through electrolysis powered by renewables, known as renewable hydrogen or green hydrogen. The growth and optimisation of these low-carbon hydrogen technologies will enable the decarbonisation of the existing hydrogen market and other hard-to-abate sectors where electrification is not an attractive option, whilst also ensuring that new applications for low-carbon hydrogen can evolve. New applications could include hydrogen as a transport fuel, replacing natural gas for heating, and using hydrogen as an energy vector to store and move renewable energy. There are so many diverse opportunities for lowcarbon hydrogen that it is difficult to predict how far it can ultimately go.

Options for green hydrogen production Green hydrogen is produced using energy from renewables, such as wind and solar, to split water into hydrogen and oxygen gases in a device known as an electrolyser. There are several different electrolyser technologies available but the two most frequently used now are alkaline water electrolysis (AWE) and proton exchange membrane (PEM) electrolysis. PEM electrolysers use platinum group metal (pgm) catalysts applied in ultra-thin layers to a polymer membrane to achieve the key reactions producing high-purity hydrogen. They have a smaller relative footprint than alternatives and are flexible in operation, hence their ability to harness the intermittency of renewable energy effectively. Alkaline electrolysers use an aqueous electrolyte solution such as potassium hydroxide or sodium hydroxide in a cell to produce hydrogen. This is a mature and well-understood

Figure 1. Focusing on delivering high-quality, catalyst coated membranes.

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technology with a lower capital cost today, but typically produces lower purity hydrogen than PEM, generally with a larger footprint and less flexible operation. Other slightly less mature technologies include anion exchange membrane (AEM) electrolysis, which has the potential to offer many of the same benefits as PEM electrolysis without using pgms as catalysts or in other parts of the system, and solid oxide electrolysis (SOEC) technology which uses solid ceramic material as the electrolyte operating at temperatures in excess of 600˚C, making it well suited to applications where heat is available, such as in combination with nuclear power.

Considerations for system optimisation At the heart of every PEM electrolyser is a catalyst coated membrane (CCM) which is responsible for the conversion of water into hydrogen and oxygen. CCMs consist of a bespoke polymer membrane and precisely engineered layers of structured platinum and iridium oxide catalysts. The catalysts are applied to the membrane which uses electrical energy in the most efficient way. The key to achieving an optimal system is not just combining the most advanced individual components but optimising each component and the way the CCM is assembled based on the end use operating requirements, balancing the trade-offs and design choices that exist for electrolyser owners and operators.

End use What is meant by end use operating requirements? Consider two very different uses of hydrogen. Firstly, a hydrogen refuelling station with an electrolyser in situ will need very high purity hydrogen so as not to damage the fuel cells, and the system may not need to run 100% of the time if storage is available, but ultimately it will need to be flexible and produce low-cost hydrogen for consumers. Compare this to a large ammonia production facility where the electrolyser may need to run 100% of the time to keep up with in-production demand and prevent outages. In this case, the primary requirements could be a robust and durable system to prevent unscheduled and expensive maintenance stoppages. When considering CCM design, these operating requirements must be balanced with multiple trade-offs and design choices including: efficiency, durability, CAPEX, and OPEX. Efficiency in this case means how much power is needed to make a unit of hydrogen and directly influences the cost of the hydrogen that is produced. The efficiency of the electrolyser system is impacted by various properties of the CCM, including membrane thickness, membrane additives, and catalyst effectiveness. Johnson Matthey (JM) can tailor membranes to its customers’ needs, offering reinforcements, recombination catalyst layers, radical scavengers, and a range of thicknesses to suit multiple applications.

The durability of the CCM can be improved through increasing the thickness of the membrane or increasing the catalyst loading. However, both of these activities will increase the CAPEX of the system and should therefore be carefully considered. JM uses membrane additives to increase the durability of its CCMs, and the company is developing next-generation catalysts which will be more stable under operating conditions, helping lower overall system costs.

Electrolyser design Another area sometimes overlooked, and one that adds to the CAPEX, is electrolyser design. It is important that electrolyser engineering designs take into account CCM production methods, facilitate efficient manufacture, easy reproducibility, and low in-production waste. For example, producing a circular electrolyser offers benefits in highpressure operation from an engineering perspective but this can create significant CCM production waste (more so than square or rectangular designs), which increases the overall cost of the CCMs. It is therefore key for electrolyser producers to work with the supply chain, including the CCM supplier, to ensure that the right balance of performance is achieved in the chosen application. JM works with electrolyser producers and, in some cases, its customers to ensure that this balance is achieved. Once the balance of trade-offs has been set, it is also very important that circular economy principles are incorporated into the system design, working together across the supply chain to enable recycling and the ability to reuse as much of

the electrolyser as possible. In this way, the carbon footprint created by the manufacture of electrolysers themselves can be minimised.

Conclusion There are still many challenges to overcome. To be successful means addressing the trade-offs that exist today and facilitating the growth of tomorrow. On the hydrogen production side, the levelised cost of low-carbon hydrogen must be reduced significantly (ideally to approximately US$1/kg or lower), using new technology approaches for CCMs and their components, and next-generation manufacturing techniques which unlock new products and use the raw materials ever more efficiently. Electrolyser system developers and end users must be supported in achieving their goals, whether they are for grid balancing, chemicals production, or heating and fuelling applications. The time for action is now, working together to achieve the energy transition goals globally. Balancing customer needs and the trade-offs faced in green hydrogen production must be discussed openly to ensure that scale-up and costdown can happen quickly. JM has a vision, for a world that is cleaner and healthier, for today and future generations. The science and engineering the company deploys cuts across numerous parts of the hydrogen value chain, including hydrogen production catalysts, components for hydrogen fuel cells and electrolysers, and new technologies for low carbon hydrogen production, including both blue and green routes.

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lobal energy markets are changing, and no industry or sector has been left untouched by the call to action to tackle climate change. At this year’s COP26 Summit, the Global Energy Alliance for People and Planet (GAEPP) was launched to accelerate investment in green energy transitions and renewable power, demonstrating the crucial role renewable energies, such as solar, have in reducing emissions. However, switching fossil fuels off to turn cleaner energy on presents challenges that are being felt acutely by industries around the world, especially those operating off grid. In the absence of a grid connection, which is often the case for sectors such as mining and oil and gas, power generation is a fundamental decision for operators. Moving away from diesel generation to gas is an initial step, but the imperative to integrate renewable energy systems in response to a global call for action on climate change has become a priority, especially for those operating in energy intensive industries. Given that solar power by its very nature produces energy on a highly variable basis, it has not previously been a viable solution for many of these hard-to-abate sectors. This combined with the short-to-medium-term nature of these projects has minimised its adoption in the industry, where solar simply has not been considered. Recent cost reductions in solar photovoltaic (PV) equipment driven by global competition and economies of scale, along with a robust global appetite for investment in renewable energy projects, have inspired break-through innovations in solar power, batteries, and hybrid system controls technology. This has opened up the possibility for traditionally carbon intensive industries to incorporate renewables into their energy mix. Looking at the mining industry as an example. It is estimated that the industry uses 6.2% of total global energy consumption. Integrating solar power into the energy mix throughout the lifecycle of the mining project from the construction phase all the way through to day-to-day

Figure 1. Optimised photovoltaic (PV) system design is key to maximising production and cost savings.

Rodrigo Salim, Head of Renewables & Storage Product Line (France), and Cathy Redson, Global Product Manager for Solar PV Systems (USA), Aggreko, discuss the potential of solar to support off grid decarbonisation.

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mining operation, can have a significant impact. However, this requires a partner with experience, especially when considering the reliability, cost, and flexible nature of these complex solutions.

Power without compromise One of the key challenges with using renewables is the intermittency of solar PV and wind systems which rely on certain environmental conditions. There are technologies available, however, that when combined with proper design, installation, operations, and maintenance can eliminate the impact of variable generation and actually improve reliability. At Aggreko, the company’s modelling tools help to properly size and design a bespoke hybrid system, considering both technical and economic project goals. Battery storage has become a lynch pin to the energy transition and is a driver of greater adoption of renewable hybrid power systems. Hybrids enable the integration of renewables without compromising on reliability, making the solution particularly beneficial for areas with limited or no access to permanent power. The instantaneous response of battery energy storage systems can smooth the intermittency of solar PV power or sudden start or stop of large loads such as motors and heat. In addition, excess renewable generation can be stored and shifted for use at night to increase overall renewable energy penetration. Putting innovation into action, Aggreko is currently deploying a hybrid power solution for the Salares Norte mine,

based in the Chilean Andes. This remote site faces additional challenges in ensuring reliable energy as it sits at an altitude of 4500 m in the mountain range, 190 km from the nearest town. Aggreko’s solution pairs a high-altitude performance diesel genset with a solar PV system designed and built to meet the air density and extreme weather conditions experienced at the site. Cloud cameras capture images in 30 sec. intervals to help predict and react to cloud events, increasing reliability and maximising fuel savings. In addition, the gensets incorporate spinning reserve and cold reserve units to efficiently manage peaks in demand and deliver a reliable power supply across all five of the mine’s distribution points.

Greater affordability Power generation represents a significant proportion of off grid operating costs. With this in mind, it is easy to understand why getting the right fuel type or fuel mix to optimise fuel costs and maintain competitiveness is top of a decision maker’s priority list. The rise of green financing in the form of assets, bonds, and funds demonstrates how investors are putting monetary importance on the energy transition. In 2012, the sustainable debt market was worth approximately US$10 billion, but has since risen to nearly US$750 billion.1 Renewable energy has emerged as one of the major recipients of green bonds that form a key link between capital providers and renewable energy projects. This is significant as it signals a major transformation in the renewable energy market and provides an alternative pathway for large industrial

Figure 2. Single-axis trackers increase energy yield by following the sun from East to West.

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energy consumers to meet their environmental, social, and governance (ESG) goals. These types of options, plus new platforms for peer-to-peer energy trading and energy co-operatives, are shaping a new project financing landscape as an impetus for industries around the world to more easily pursue renewable solutions. For the Granny Smith mine in Western Australia, Aggreko was asked to replace the diesel generators with gas units to take advantage of the recent gas line extensions to the otherwise hard to reach area. Following discussions about how and if renewables could be incorporated into their power package, Aggreko integrated over 20 000 solar panels, equating to almost 8 MW of solar power generation and 2 MW/1 MWh battery storage with the existing thermal gas supply as a hybrid power station – under one contract and with no capital outlay. In total, the solar, thermal, and battery storage assets will produce approximately 18 GWh/y of energy, with carbon emissions at the mine expected to be reduced by approximately 9500 t CO2e – the equivalent of taking 2000 cars from the road.

Figure 3. Aggreko’s hybrid solar-gas solution at the Granny Smith gold mine in Western Australia.

Solutions with flex The initial investment combined with questions around reliability and inaccessibility challenges for remote projects has to date limited the uptake of solar solutions for off grid application. Aggreko has also seen some reticence to making large scale investments into a particular energy source, given how quickly the energy sector is moving and the likelihood that today’s technology will very quickly be outdated. This has led to concerns around stranded assets Figure 4. Over 2000 solar panels were integrated with the existing gas power and tied up capital which is ultimately slowing the pace of station to produce approximately 18 GWh/y. incorporating renewable energies into the sector. Industries without grid access and the need for power solar and other renewable power, encouraged by greater only for the duration of a particular project, such as a mine or efficiency and improved access to technology. A proven track oilfield, are also reluctant to install permanent solutions such record of off grid hybrid systems are easing previous concerns as a solar field. More flexible solutions are needed to enable around the use of renewable energies in islanded grids, and an effective solution to these legitimate concerns. Aggreko’s by the use of battery energy storage systems, such as the one turnkey, energy-as-a-service (EaaS) business model eliminates deployed at the Granny Smith mine, it is possible to obtain these risks, keeping energy costs as an operating expense even greater reliability, by smoothing the intermittency of solar through either short-term rental options or medium- and PV power and managing its peaks in demand. Innovations long-term contracts. By increasing the flexibility of the solution, in the financing of renewable projects have also opened up Aggreko is expanding the potential for more renewable power alternative energies for large industrial energy consumers. As for large industrial sites, in locations that previously seemed one of the biggest recipients of green bonds, a key link has out of scope. developed between capital providers and renewable energy projects, helping industries, including mining, meet their ESG Embracing the sun goals. With COP26 putting a much-needed global spotlight on the Aggreko sees it as its job to open doors for those hard-toneed for better solutions to the climate catastrophe, there is abate sectors that face even greater challenges when it comes a huge opportunity for energy intensive industries, including to responding to the energy transition. It is Aggreko’s intention mining, to review their energy mix. that, with continued innovation and collaboration with its With innovations in both the technology and financing customers and suppliers, the company will see further uptake required for solar projects, industries without grid access are of solar solutions in these industries to help realise a lower better able to add alternative energies into their operations. carbon future. Aggreko’s turnkey, EeaS business keeps power cost as an operational expense, eliminating the requirement for large initial investments. By making solutions more flexible, Refererences 1. https://www.bloomberg.com/news/articles/2021-01-14/the-sustainable-debt-market-is-all-grown-up previously out of scope locations are now able to embrace

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David Reid and Jenny Darnell, NOV, USA, explain how the company is learning from the past to forge the way for the future energy industry.

hile oil and gas will remain critical to powering the global economy, the transition to cleaner, carbon-neutral energy sources is an opportunity to improve the economic competitiveness and affordability of renewable energy. As an industry leader, NOV was inspired to help move toward a more sustainable future. NOV faced that challenge head-on by evolving to include renewable energy initiatives such as wind, solar, geothermal, carbon capture, and more. NOV’s goal is simple: rejuvenate and improve upon what the company already has, repurpose technology and equipment traditionally used in oil and gas operations, and reposition its skills and knowledge in oil and gas into the renewable space – all in the name of a more sustainable future. “We enable energy for life,” said Clay C. Williams, NOV’s Chairman, President, and CEO. “Making energy accessible, affordable, attainable, and sustainable is only one part of our story. We are a diverse company with people who are personally invested in the outcomes of our environment and communities because we live here, too.” Whether from traditional oil and gas or renewable sources, NOV facilitates access to reliable, affordable, and clean energy around the world.

Innovating with a purpose Purposeful innovation shapes the culture at NOV. Every role, project, and product begins and ends with a purpose and an idea. As the energy industry has evolved, NOV has shifted its focus to develop what its customers need to be successful. It has

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never been about the fuel source, but about the process that delivered the products and services the world needed at the time. NOV’s goal has always been to help its customers make energy more efficient, affordable, and accessible so that in the end, the people win. “We have a decades-long history of adapting to a rapidly changing world, but we are very familiar with being the change ourselves,” said Rium Johnson, NOV’s Chief Health, Safety, Security, and Environmental Officer. “That’s why we are not only focusing on designing products that help make a better world, but on the sustainability of how we build them.” From decades of innovation and success in oil and gas operations, to major developments in the offshore wind market, to the development of a fit-for-purpose, postcombustion carbon capture system design, to groundbreaking drill bits and motors shattering geothermal records, NOV is an expert in energy – no matter the source.

Rejuvenating the global energy industry with purpose-built technologies NOV has always been at the forefront of solving the complex challenges of the energy industry. The industry depends on the company’s expertise and technology to continually improve oilfield operations and assist in efforts to advance the energy transition toward a more sustainable future. NOV technologies ushered in the shale revolution much like they are paving the way for the energy transition. “The truth is that there is a moral case for fossil fuels, and a moral case for alternative energies,” said David Reid, NOV’s Chief Marketing Officer and Chief Technology Officer. “There is an assumption by some people that those who are pro-energy transition are anti-oil and anti-gas. But the truth is: we are all interested in changing the world and making it a better place.” A good example of purpose-built technology is NOV’s Ideal™ eFrac fleet which has augmented the environmental outlook of hydraulic fracturing operations. By shifting from diesel-powered to electric-powered, the Ideal eFrac system is designed to reduce emissions and significantly increase power density. Fewer pumps are needed onsite to reach the same

operational goals, reducing road traffic and contributing to an overall lower carbon emission for the operation. The company also knows that you do not have to catch what you do not release. NOV’s engineering teams study the utility of each of their designs to minimise connections and potential leak points, reducing emissions on equipment in even the most remote locations. In the future, NOV will have the tools to collect data to predict and mitigate these types of emissions even further.

Repurposing core competencies to support the energy transition As the energy industry evolves, many are ready to shift to strictly clean, carbon-neutral energy – a step the industry is not ready for based on available infrastructure, supply chain challenges, and technological constraints. NOV is here to help move that transition along by repurposing existing technology to support renewable energies, while also maintaining its position as a leading supplier of technical solutions to the oilfield. “The reality is that the world has low-cost energy that some applications and people must have in the meantime,” said Reid. “NOV is helping make that energy and its infrastructure even more affordable and accessible. At the same time, we are reaching for renewable energy – helping to generate it more efficiently, affordably, safely, and sustainably – as soon as possible.” The transferability of NOV’s technology to support renewable energies is almost unmatched and supports innovation, service, and creativity across the company. NOV jack-up rigs have been used for oil exploration and production for decades, and the company is supporting the offshore wind market with proven and new designs for wind turbine installation vessels. Drill pipe, drilling motors, and drill bits used in oil and gas wells are capable of boring holes for geothermal operations. Pumps and grinders designed for processing hydrocarbons and sewage work just as well for biogas applications. NOV is seeing, in real-time, how many of its products, services, and technologies can easily be repurposed for use in the renewable space.

Addressing the challenges of an evolving industry

Figure 1. Ideal™ eFrac.

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Industry partners and customers actively involved in the energy transition often report hesitations associated with the cost and unpredictable timelines of renewable energy projects. NOV is able to guide its partners through renewable projects with confidence. The company builds massive structures and drilling rigs that operate with precision in some of the world’s most remote and extreme environments. NOV is working better to eliminate the complexity with integrated supply that significantly reduces execution risk. The company supports its customers’ transition to renewable energy in many ways: wind; carbon capture, utilisation, and storage (CCUS); and geothermal, among others.

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Offshore wind – fixed and floating Globally, a considerable portion of the world’s installed offshore wind power has been constructed with vessels and equipment designed by BLM and GustoMSC, two groups within the NOV Rig Technologies segment. Since 2002, GustoMSC jack-ups with integrated jacking systems and cranes have installed more than 4000 turbines and foundations, providing the company with the necessary operational intelligence to further optimise its solutions for the wind turbine installation market. NOV’s solutions are designed to meet the tailored demands of each unique wind farm, accounting for varying water depths, budgets, and logistics. NOV is a market leader in providing offshore wind installation technologies, with purchase orders in hand for two GustoMSC NG-20000X self-propelled wind turbine installation jack-up vessels – adaptations of its jack-up vessels used in offshore oil and gas rigs. Each holds five sets of 20+ W turbines and are modifiable for operation with LNG or ammonia fuels.

Carbon capture, utilisation, and storage NOV has recently announced the availability of a carbon capture system, engineered, designed, and fully executed by NOV. The post-combustion facility design combines the proven amine-based technology with the process expertise gleaned

Figure 2. Phoenix™ series drill bits for geothermal applications.

over three decades from NOV’s teams after completing 400 gas processing projects worldwide. The company has also established partnerships with critical technology partners to provide flexibility to match the needs of any emitting facility. In addition to its carbon capture technology, NOV’s fibre glass pipe has been used in CO2 injection lines, high-pressure and low-pressure pipelines, ductwork, and other challenging carbon capture and transportation applications for more than 70 years. TK Coatings™ have successfully been used in the storage and transportation of corrosive carbon emissions, preventing corrosion and extending tubular life. Beyond its expansive drilling capabilities, NOV offers offshore offloading and injection with CO2 static and dynamic high-pressure flexible pipe and turret mooring systems.

Geothermal solutions NOV leverages its experience in the oil and gas industry to offer customers the entire geothermal package. With decades of experience in the geothermal space, the company has helped customers complete geothermal wells efficiently and cost-effectively through its complete portfolio of geothermal offerings, including Phoenix™ series PDC drill bits, drilling motors, TK™ Corrosion Control, liner hanger systems, dozens of land drilling rigs, and more. In an industry historically dominated by roller cone (RC) drill bits, NOV’s ReedHycalog is striving to lead the way in fixed cutter polycrystalline diamond compact (PDC) bits, specifically designed for geothermal applications. Where previous legacy fixed cutter PDC bits could not survive or compete in the harsh environments of geothermal drilling, ReedHycalog’s new Phoenix series PDC drill bits are custom designed to enhance drilling efficiency in hard rock formations. To date, ReedHycalog™ drill bits have drilled some of the longest and fastest intervals in geothermal wells around the world, and at the lowest cost per foot drilled. NOV’s Vector™ motors have displayed extreme durability drilling through hard, abrasive, and fractured basalt in Iceland and withstood and succeeded in the hottest wells of Central Europe, outperforming other failed motors on the market. Since 2003, Tuboscope’s proven line of TK Corrosion Control products have been used in a variety of geothermal projects throughout the Netherlands, Germany, and France. In addition to remarkable corrosion protection, Tube-Kote™ coatings prevent deposit mitigation and improve laminar flow efficiency. TK-Liner and TK-Ring II systems have successfully been deployed into geothermal producers in the Netherlands – the world’s first application for these types of products in geothermal production wells. NOV’s engineered system is proven to prevent corrosion, reduce heat loss, and minimise friction.

Repositioning today’s technology for tomorrow’s growth Figure 3. Vector™ series drilling motors for geothermal applications.

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While innovation is central to NOV and occurs at each of the company’s locations, its dedicated research and

development facilities are meant to inspire collaboration and ideation. Just outside of Houston, in Navasota, Texas, US, is the Springett Technology Centre, where a dedicated renewables team works to assist pockets of teams across NOV with rapid prototyping and creative problem solving. Using 3D printers and leveraging a wide range of tools in their maker space, the renewables team supports democratising technology development across NOV. Similarly, at the Flotta Environmental and Low Carbon Laboratory, located on Orkney Island in Scotland, NOV’s teams prioritise research and development toward its carbon capture initiatives and other technologies to support the energy transition. While NOV’s areas of research and development are vast, a few include:

Figure 4. Tri-floater is a triangular, semi-submersible floating wind turbine foundation.

Biogas NOV’s range of solids handling, pumping, and mixing solutions, along with its composite piping, is already in use in biogas projects covering all kinds of waste including wastewater, landfill, and animal waste. The company’s current product development efforts and strategic partnerships in this space aim to solve recurring plant efficiency issues, high operational costs, and fragmented supply chains. Furthermore, NOV helps food and manufacturing companies leverage its expertise to proactively solve their waste compliance issues with growing regulations around disposals, circularity, and overall carbon footprint.

Hydrogen/ammonia Designed for oil or condensates, NOV’s subsea storage units (SSUs) are simple, flexible-bag structures that rest on the seafloor, each with a protective dome. This eliminates problems with the emulsion layer and bacteria growth — yet saves on capital and operating costs. These are being repurposed for safe, easy subsea storage of hydrogen as ammonia. NOV also offers its fibre glass system (FGS) competitive, lightweight, corrosion-resistant vessels as an alternative to austenitic stainless steel pressure vessels often used in traditional seawater applications. They are rated up to 290 psi (20 bar) and certified for transportation of ammonia.

Offshore floating wind NOV partnered with the University of Maine to design and build the first US offshore floating wind composites prototypes. This market is currently in the precommercial development phase, but there is growth opportunity over the next decade, with rapid growth likely through 2030. The company is also developing an efficient, highly automated fabrication process that employs the existing shipbuilding and offshore supply chain. This will lower costs and increase the scalability of commercial-size floating wind farms.

Improved crane technology on installation vessels will increase lifting capacity to 1764 t at a 131 ft (40 m) radius, with a 522 ft (159 m) main hook height above the main deck, allowing for the installation of the larger, new-generation wind turbines scheduled to be delivered in 2024 and beyond. Floating wind turbines are key to unlocking the massive energy potential in global offshore deep water, where there are strong winds, and bottom-founded structures are not economically feasible. Other industry players are partnering with NOV to develop technologies to mitigate project execution risk for these structures. For example, a tri-floater semi-submersible floating wind foundation is designed to require less steel and lower total project CAPEX but retains full quayside construction. Going deeper and larger than ever before, NOV’s tri-floater design is ready for full scale offshore application and commercialisation where it can unlock massive energy potential. The tri-floater design provides the wind turbine foundation and is based on a proven semi-submersible technology developed for the offshore oil and gas industry.

Onshore wind NOV is developing fit-for-purpose onshore wind tower erection equipment with a unique mobility system to provide superior lifting at taller heights and significantly improve the safety, reliability, and efficiency of tall wind tower installation.

Summary When it comes to the energy transition, NOV is working closely with its customers to rejuvenate the resources the company already has, repurpose traditional oil and gas technologies, and reposition its skills and expertise to better serve today’s industry and make renewable sources of energy more accessible and affordable for everyone. As NOV learns from the past to shape the way forward, the company continues to power the industry that powers the world.

ENERGY GLOBAL WINTER 2021

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alWave, a California, US-based developer of clean energy technologies, is working to unlock the power of the world’s oceans. The company is tapping into wave energy, the largest unused renewable resource and the third-largest after wind and solar, to support increasing global energy demands while decarbonising the industry through proprietary innovation. The concept of using man-made devices to convert the kinetic and potential energy of ocean waves into electricity is nothing new. In fact, such innovations have appeared around the world dating back as early as 1799. However, fundamental challenges associated with efficiency and cost have long-held the industry back from achieving the same level of success as others in the energy space. Now, CalWave is proposing a feasible solution that addresses these key technical and financial barriers to provide clean, reliable, and affordable electricity to coastal communities worldwide.

Harnessing wave energy for power CalWave’s xWave™ wave energy converter (WEC) device is built on the game-changing industry advancements in which the company was awarded for through the US Department of Energy’s Wave Energy Prize. No other wave energy technology has high efficiency and wave load mitigation united in one architecture. The xWave achieves high efficiency by operating fully autonomously and fully submerged which allows for protection from aggressive swells and storms, while also permitting energy capture from multiple degrees of freedom. “From a technical standpoint, what makes our device special is that we have integrated a novel wave load mechanism into the design similar to pitch and yaw control in wind energy,” stated Thomas Boerner, CalWave’s CTO. “Contrary to a set as-is geometry once the device is manufactured, we can actively change the geometry of the wave absorber body to not only operate efficiently in small waves – but also to continue operation in severe sea states encompassing very large waves.” These landmark features enable for high performance at lowest cost, which should lead to affordable energy prices once available to the market.

Marcus Lehmann, CEO and Co-Founder, Thomas Boerner, CTO and Co-Founder, and Julie Mai, Head of Communications, CalWave Power Technologies, USA, highlight how ocean-based solutions are creating ripples as the world enters the greatest energy transition period in modern history.

Additionally, the xWave encapsulates other critical aspects that bode well with the needs of varied end users. Scalable in both design and functionality, energy farms that utilise the technology can supply coastal communities with anywhere from 5 MW to over 500 MW of local power. Further, the xWave

achieves a minimum 40% capacity factor alone. Studies show that when co-located with offshore wind, over 80% capacity factor can potentially be reached. The device is projected to be able to withstand over 20 years of use in open-ocean and has been designed to survive 100-year storm events. With operation and maintenance processes occurring on the surface via hot-swap capabilities, incurred costs are also predicted to be lower than that of offshore wind. The technology has also been deemed to have an acceptable environmental impact according to the latest State of the Science report.

Testing in California and the US

Figure 1. CalWave’s x1™ wave energy converter pilot unit was manufactured in-house in Alameda, California, US, with final assembly occurring onsite in San Diego, California.

Figure 2. CalWave’s x1 pilot unit during in-water testing prior to deployment.

In September 2021, CalWave successfully deployed an xWave pilot unit off the Scripps Institute of Oceanography research pier in San Diego, California. For the next six months, the x1™ WEC device, a scaled representation of CalWave’s x100™ architecture, will transform the motion of ocean waves into electricity before being transported back to the shore via an umbilical cable. This x1 device, as it is named, is securely anchored approximately 1800 ft from shore at a depth of 30 m. Before hitting the water, the x1 device was designed and manufactured in-house at CalWave’s warehouse space in Alameda, California. After the device arrived at the marina in San Diego, the CalWave team completed the final assembly before the first in-water test and deployment to site. This event marks California’s first at-sea, long-duration wave energy pilot operating fully submerged. The x1 is currently being tested with the goal of validating the performance and reliability of CalWave’s system in open-ocean. For this trial, CalWave is also collaborating with Pacific Northwest National Laboratory & Integral Consulting, Inc. to monitor marine ecosystem acceptability of the WEC using three different tools: a noise spotter buoy, a drifting hydrophone, and three longterm, bottom-mounted hydrophones. So far, the global State of the Science report has not raised any red flags for marine renewables, but continued monitoring is needed. Following the San Diego pilot, CalWave plans to prepare for deployment of the x100 unit, ranking 100 kW of power, at PacWave – the first federally-approved, commercial scale, utility grid connected wave energy site in the US, expected to start operating in 2023.

Scaling wave energy solutions to meet global needs

Figure 3. CalWave successfully commissioned the x1 unit in California’s first long-term, open-ocean wave energy pilot in September 2021.

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Looking forward, growing bodies of research project that wave energy has the potential to satisfy 20 - 30% of global energy demand. The US Department of Energy alone reports that wave power has the technical feasible resource potential to meet 30% of the US’ electricity demand, equalling US$120 billion in the total addressable market – yet, it is completely underutilised at the moment. CalWave currently views isolated coastal and island communities as the greatest potential benefactors of wave energy development. Islands communities – some of the most adversely affected by the changing planet and roughly 11% of the global population – remain largely dependent on fossil fuel. CalWave aims to power microgrids on islands and in other isolated areas with its x100, 100 kW device. In addition, the x100

Figure 4. CalWave’s x1 pilot unit was deployed approximately 1800 ft from the Scripps Institution of Oceanography research pier in California.

can be utilised for powering data centres, eco-resorts, and military bases. Similar to wind turbines, the xWave architecture is scalable in size. CalWave plans to offer a utility scale version in the coming years called the x800™, an 800 kW model. The x800 device has the capacity to support standalone wave farms operating fully submerged. This offers great benefits especially in areas where offshore wind is facing obstacles due to visual impact. Next to standalone farms, the x800 can also be co-located with offshore wind farms utilising the same and existing electrical export infrastructure and grid connection as well as other synergies such as offshore installation and maintenance.

Powering the blue economy Now as the US Department of Energy’s Water Power Technologies Office works towards understanding the power requirements of emerging coastal and maritime markets, advancing technologies that could integrate marine energy to relieve power constraints, and enabling sustainable growth of the blue economy through its Powering the Blue Economy™ initiative, CalWave has an additional opportunity to make a significant contribution. Based on the x1 technology currently being tested, CalWave is offering a solution to enable the Ocean Internet of Things by rolling out the production of the xNode™ series in 2022. xNode devices, which are uncabled and can be moored at any depth, utilise the xWave’s generator drivetrain and proprietary SCADA platform to provide offshore power and data as a service. These devices offer continuous power of approximately 1 kW and have onboard energy storage capacity of 1 - 10 kWh. The xNode features secure 5G connectivity and satellite data links. Applications that can be served include long-term monitoring using onboard sensors, AUV charging, and data compression and export with the onboard data centre.

Why wave power and why now? The advancement of wave energy technologies is coming at a pivotal time when dependency on fossil fuels nears the planet’s limit and dependency on existing resources is not enough. Main factors to consider when welcoming wave power into the energy field are that it is more consistent, predictable, energydense, and clean compared to other renewables, making it an exceptional complement to what is available now. FFBecause ocean waves are always in motion, energy can be harnessed day and night, throughout every season – which addresses key challenges seen in solar and wind.

FFWave power is predictable and can be forecasted two weeks in advance. When complemented with other renewables, wave power can provide a reliable energy supply for coastal communities year-round.

FFAs the embodiment of solar and wind energy in condensed form, wave power is approximately 30 - 60% more energydense than its counterparts.

FFWave power is clean with one of the lowest lifecycle emissions, and forecasts project that it has the ability to displace up to 1.38 - 1.9 Gt CO2 emissions equivalent annually. Humanity is on the brink of unlocking ocean waves as a stable, abundant, and clean resource for power. It is time that these bold and tested ideas are stood behind and adoption is accelerated for the benefit of people everywhere. CalWave’s mission is to provide clean, reliable, and affordable electricity and freshwater to coastal communities worldwide. The company envisions a healthier, safer, more equitable, and prosperous world – one that unlocks the power of ocean waves to supply 20 - 30% of global energy demand in upcoming decades.

ENERGY GLOBAL WINTER 2021

Mark Goalen, Offshore Engineering Director, Houlder, UK, explains how continued innovation is crucial to ensure offshore floating wind will maximise its role in future offshore energy provision.

n projects as complex as floating offshore wind installations, there are many interfaces and interactions required. Most developers are opting for EPIC contracts to avoid fronting and managing the risks associated with multi-contract management. This EPIC approach reduces developers’ flexibility and potential to deliver cost reductions through innovative processes. This, combined with a lack of available resources from the main turbine manufacturers whose resource is heavily focussed on fixed wind projects in turn, is stifling opportunities for SMEs and therefore stifling innovation at a time when floating foundation designs should be continuing to evolve. Based on its strong track record in supplying marine equipment and engineering expertise to a range of clients in the offshore fixed wind sector globally, including Van Ord, Jan De Nul, Saipem, Eon, MPI Offshore, GeoSea, Boskalis, Siemens Gamesa, Seajacks, and Seaway 7, Houlder now has a focus on helping progress innovation that reduces cost and environmental impact for the floating sector.

Dynamic modelling of site selection Choosing the right floating foundation with the least risk and greatest overall cost benefits requires in-depth project analysis carried out by experts that can model the manufacture, fabrication, assembly, installation, and operation and maintenance (O&M) logistics. This dynamic modelling process should compare options and provide results based on what is most important to the developer including cost, risk, carbon emission, or schedule. The same modelling should also include contingency factors such as installation weather

38 ENERGY GLOBAL WINTER 2021

Time in

e to invest innovation 39

limitations, unexpected schedule delays, and their knock-on consequences. The output from the model could also establish the available budget to develop the O&M vessels that would be required to conduct repairs on location as well as the bespoke tooling that will need to be designed. The optimal technology choice for a new wind farm can be established by following an iterative, cyclical process of evaluation. Limiting criteria will become apparent when comparing options and help clarify the best solution for a given site.

Pragmatic approach to floating foundation choice To deliver the best levelised cost of energy (LCOE) for floating offshore wind projects, the decision on the most suitable floating foundation technology should be based on assessment of available port infrastructure and supply chains as much as water depth and environmental conditions. Without a pragmatic approach, a development could spend significantly more in the OPEX phase of the project than saved during the CAPEX phase. As much as economies of scale based on consistency and repeatability are appealing, the choice of foundation type should not be made before the site analysis. The physical attributes of foundations will influence where they can be fabricated and the ease with which they can be towed and moored. Detailed motion response should be compared on a case-by-case basis for any specific location. A foundation

perfectly suited to the Mediterranean may not be viable in the Pacific. There are currently four main types to choose from, with multiple options for each type, and several more innovative concepts are under development. Spar buoys are typically cylindrical in shape and very stable given their deep draft with ballast creating a low centre of gravity. They require a deepwater area for fabrication and also for maintenance if towed to shore. They can be made from steel or concrete and are conventionally catenary moored. Another option is semi-submersible platforms which typically consist of three connected vertical columns. Considered suitable for most locations given that relatively shallow water is required at the fabrication site, they are also stable for tow during installation and O&M. Their biggest disadvantage is being prone to heave motion which is difficult to prevent without increased fabrication complexity. They are generally fabricated from steel (though concrete is an option) and conventionally catenary moored. Tension leg platforms typically have a central column and arms connected to tensioned tendons. They can be assembled onshore or in a dry dock, but they can be harder to keep stable during transport and installation than other concepts. Their biggest advantage is that the taut mooring lines significantly reduce the length of mooring lines for deepwater locations in comparison to a catenary moored structure. Damping pool structures have a square barge structure which contains a damping pool that has been tuned to

Figure 1. Illustration of different types of floating wind foundations. Image courtesy of ORE Catapult.

40 ENERGY GLOBAL WINTER 2021

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Figure 2. Floating wind turbine (Floatgen). Image courtesy of BW Ideol V. Joncheray.

counteract the foundation motion. They can be made from concrete or steel – a factor that can increase the flexibility of the fabrication location. To add to the complexity of these four main choices, there is contradiction in the messaging coming from different parts of the industry. Some are gearing up for multi-port strategy, while others believe there will only be a select few ports in Europe that produce foundations at the quantity required for a growing industry.

Logistics critical to success It is critical to understand the installation methodology and to define the development’s O&M strategy up front to determine which solutions are feasible and where the challenges lie. Initial findings from UK Offshore Renewable Energy Catapult (ORE) for a select set of scenarios suggest that it is cheaper to tow turbines to shore where crane operations are simpler and there is ready access to onshore services and personnel. However, offshore wind developments can be remote from good port facilities, and there are risks associated with disconnecting and reconnecting the units and towing them to shore. As the Floating Wind Joint Industry Project recently concluded in its Phase III report, one of the main challenges for the tow to port option is the safe detachment and wet storage of cables and mooring connections. Conversely, for in-situ maintenance, there are challenges with the limitations of heavy lift vessels: many of the existing heavy lift vessels are unable to lift to the required hub height with the required reach for larger turbines. Therefore, project logistics can be assumed to be global in scope and complex, and to understand and establish the logistics involved for a particular location, there are a few key parameters that must be defined. The proximity of the wind farm to shore, the wind turbine generator details, the floating foundation design, how many units must be installed within a given time frame, and the O&M strategy. With this information all other unknowns should be able to be established and a cost-effective plan developed.

Research pays dividends Several types of floating foundations have now been proven in full scale trials, and installation at commercial scale has

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been achieved, as evidenced by the completion of the world’s largest floating offshore wind farm to date, the 48 MW Kincardine Offshore Wind in Scotland. Experience so far has demonstrated that some of the most developed technologies have encountered issues or have features that increase fabrication complexity. These will likely be phased out as the designs evolve, and it is important that developers recognise this in their financial models. Some think now is the time to focus in on a select few foundation types with the highest technology readiness level, while others continue working on innovations for the next generation of floating foundation, so operational efficiency and technology options will likely continue to evolve over time. The challenge for developers is to remain open to innovation and look for continued improvement without impeding progress. To make the right decisions requires in-depth analysis of a multitude of influencing factors: a serious undertaking in terms of analysis and research but one that has the potential to pay dividends.

Innovation is crucial The global floating offshore wind industry is expected to grow from 70 MW at the start of 2021 to 70 GW by 2040. As well as powering electricity grids around the world, it will help decarbonise offshore oil and gas production and play a critical role in green hydrogen production. Innovation can take the industry from proven commercial scale to full utility scale development. There is no shortage of companies prepared to invest in the innovation required.

Innovative solutions available Most recently, Houlder is supporting Subsea Micropiles, a foundations company leading the adaption of land-based micropiling technology to create superior marine foundation and anchor solutions. Houlder is providing marine operations and engineering support to accelerate market development and the deployment of Subsea Micropiles’ technology which uses a new robotic seabed drilling system to install and grout micropile anchor foundations. Mimicking the root piles of trees, the design is capable of withstanding significant axial and horizontal loads, providing a stable and consistent connection point for floating structures. Subsea Micropiles can provide a single connection point on even the most complex of seabeds, even if the geotechnical profile changes considerably across the development site. The benefit is that a consistent, more integrated design interface between anchors, mooring system, and substructure can speed up installation and major repair operations for floating offshore wind farms. This is essential as the offshore wind industry expands and tackles increasingly difficult seabed conditions.

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The goal: hit the sustaina 44 ENERGY GLOBAL WINTER 2021

Emma Mallinson, Shell Naturelle, UK, explains why the world needs an effective and environmentally sensitive wind power industry, and how lubricants can assist on this journey.

ith every passing year, the need for more sustainable sources of power becomes clearer. Roughly two-thirds of global greenhouse gas (GHG) emissions were associated with heating, electricity, transport, and industry energy production in 2016, reports the European Environment Agency. Since then, considerable steps have been taken to decarbonise the energy supply chain with renewables leading the way in reducing emissions. In 2020, CO2 emissions in the power sector dropped by 3.3% – the greatest reduction on record, according to the International Energy Agency (IEA). Although there has been less demand due to the COVID-19 pandemic, the increased use of renewable sources was the driving factor behind the drop in emissions.1

ability targets 45

Renewables supplied 29% of global electricity in 2020 while increasing their contribution to emission reduction in the power sector by 50%, according to the IEA. Across Europe, renewables exceeded fossil fuels as the main power source for the first time in 2020, reported Euractiv. This transformation is mirrored by the advances in wind power over the last 12 months. Despite the global pandemic, 2020 was a record-breaking year for the wind industry as it saw the installation of 93 GW of new capacity – a 53% y/y increase on 2019, reported the Global Wind Energy Council. Wood Mackenzie explained how this growth was largely driven by the US and China, which accounted for close to three-quarters of new installations. This means there is now 743 GW of wind power capacity globally.2 In real terms, wind power is helping to avoid over 1.1 billion t of CO2 emissions around the world, which is equal to the annual carbon emissions across the whole of South America. As new turbines are installed, and older models repowered, those working within the sector are faced with the daunting task of maintaining and optimising this record capacity. And this sits alongside the priority of ensuring that wind power continues to be as sustainable as it is reliable.

The continued growth of offshore wind Within this boom, offshore wind is making rapid progress. Annual installations are set to quadruple by 2025, meaning 21% of new capacity will be offshore compared to just 6.5% in 2020.2 In fact, by the end of 2020, there was a total of 35 GW of offshore wind across the world, which is 14 times higher than just 10 years ago.3 This remarkable pace is only set to accelerate further as countries and companies alike search for a wider pool of renewable energy projects. Interestingly, when this optimistic projection of offshore wind’s future is broken down into greater detail, it becomes clear that the sector is extremely diverse. For example, DNV – an independent assurance and risk management provider – suggests in its 2021 Energy Transition Outlook that, by 2050, 9% of global hydrogen produced for energy purposes will come from fixed offshore wind farms.

Figure 1. Biodegradable lubricants by Shell Naturelle.

46 ENERGY GLOBAL WINTER 2021

Alongside this, there is floating offshore wind. Though dependent on more complex infrastructure than its fixed counterparts, including everything from dynamic electric inter-array cables to single point anchorage (SPAR) buoys, floating offshore turbines have a huge potential upside. This is because approximately 80% of the world’s offshore wind resources are located in waters deeper than 50 m – waters that only floating offshore wind can reliably access.4 However, this growth outlook underlines a wider issue. With an increase in demand for wind turbines comes a rise in the need for the operations that manage the end-to-end lifecycle of a facility, including installation, maintenance, and decommissioning. Achieving these efficiently is vital when one considers that logistics alone can account for up to 17% of the annual operational budget for offshore wind farms, while maintenance and servicing costs can reach 19%.5,6 But this cannot happen at the expense of the local environments these facilities operate in, especially when it comes to managing the impact that fossil-fuel-based lubricant products can have on ecosystems should a leakage occur. Operators face two critical challenges in this area: improving the impact of their marine installation and maintenance operations while working to create a sustainable supply chain for the maintenance of internal turbine components.

Challenge 1: Navigating rough regulatory seas for installation and maintenance Around offshore facilities, much of the focus tends to be on the turbines themselves: how many there are and how much power they can generate. However, it is also important for operators to have a clear grasp on the full lifecycle of their new and existing wind farms. Within this, the installation, external maintenance, and – where needed – decommissioning of facilities are key elements. Each of these require the extensive use of heavyduty marine equipment, from the vessels themselves to the cranes that carry out the actual installation of large and complex components. Building and maintaining offshore wind facilities at scale is a significant challenge, even with the ideal weather conditions in place. It requires specialised vessels and machinery that regularly comes into contact with the sea water. This is why marine operations are heavily regulated, making the protection of local ecosystems a high priority for operators working to create new wind capacity or maintain the output of existing facilities. For example, the Vessel General Permit (VGP) requires vessels longer than 79 ft that travel through US waters to

use lubricants that are biodegradable while having low ecotoxicity and no bioaccumulation in their oil-to-water interfaces. Many other regulations globally have their own criteria for the standards that operators must work to when installing, maintaining, or decommissioning an offshore wind farm. The complexity of this is why many countries and regions have ecolabels in place (such as the EU’s Ecolabel and Japan’s Eco Mark) to guarantee that lubricants with those labels meet the specific standards in each regulatory jurisdiction. Ultimately, operators need to demonstrate that they can protect the sensitive ecosystems that exist around their installations. Providing net zero emissions energy is a critical target to hit but, if it is achieved at the expense of the local environment, companies will suffer significant reputational damage and risk harming their license to operate.

Challenge 2: More turbines mean more internal maintenance Once a wind farm is in place, operators need to be sure that it is running as smoothly as possible. They are under pressure to provide efficient and reliable power – with little room for error as demand increases. And this makes the maintenance of the components inside each turbine a critical element in avoiding downtime and maximising power generation. To put this challenge into context, Wood Mackenize reports how 2019 saw global onshore wind operations and maintenance (O&M) costs reach nearly US$15 billion, more than half of which (US$8.5 billion) was spent on unplanned repairs and correctives caused by component failure. Of these component failures, it is generally estimated that 1200 each year are related to gearbox failures – a costly problem to fix when the gearbox accounts for roughly 13% of the overall cost of the turbine itself.7 Fortunately, this is where the right lubrication can help. When faced with access issues and equipment strain that are part and parcel of wind turbine maintenance, operators cannot afford to deploy an ineffective lubricant that may lead to unplanned downtime. Alternatively, an effective lubricant can: extend oil and grease life; prolong equipment lifetime; and improve system efficiency and energy yields. In turn, these benefits can contribute to increased uptime and optimal turbine performance. And, as the size, power, and capacity factor of turbines increases, the role of lubrication becomes magnified. Most often the lubricants used in wind turbines today are fossil-fuel based and in use for at least 10 years, if not for the lifetime of a turbine. Although the risk of leaks in this area are low, there is a solution available to help OEMs and operators further mitigate risks to their license to operate and improve the sustainability of their supply chains.

How environmentally acceptable lubricants can support performance and sustainability targets Biodegradable lubricants offer an effective way for operators to ensure compliance with environmental

regulations and standards and meet their sustainability targets, whether onshore or offshore. To be certified as an environmentally acceptable lubricant (EAL), products must comply with strict environmental criteria and meet minimum technical performance standards. These requirements are set out by key regulation and approvals bodies within each respective region. In line with this, Shell Naturelle products are readily biodegradable (in accordance with OECD 301 B, >60% degraded by the end of the 28-day test) while featuring low aquatic ecotoxicity (meeting the requirements of OECD common acute toxicity tests for assessing EALs according to US Environmental Protection Agency requirements) and no bioaccumulation, thereby reducing the impact should an accidental leak or spillage occur – avoiding harm to wildlife and ecosystems (compared to conventional mineral oils). How it is made can also have an effect on the sustainability of the EAL itself. For instance, the use of solar power in the Shell Naturelle production process in Bern, Switzerland, where 90 MWh of electricity is generated from solar energy, representing 19% of the plant’s total electricity use and avoiding an estimated 0.004 ktpy of GHG emissions (2019 data) – lowers the carbon intensity of its manufacture.8 Additionally, the combination of reductions in plastic waste and use of carbon-neutral products enables operators to further reduce their environmental impact. In participating locations, carbon neutral indicates that Shell has engaged in a transaction where an amount of CO2 equivalent to the CO2e amount associated with the raw material extraction, transport, production, distribution, use, and end-of-life of the product has been avoided as emissions through the protection of natural ecosystems or removed from the atmosphere through a nature-based process. CO2e refers to carbon dioxide, methane, and nitrogen oxides. As operators experience a growing pressure to deliver more, while contributing to a more sustainable future, EALs can help them to strengthen their license to operate and reach the ambitious net zero targets that the industry is racing to achieve. Making the switch to EAL usage can help a business adapt to this rapidly changing industry landscape, by meeting changing standards and regulations confidently without needing to compromise on performance – an outcome that will become increasingly important if global projections for wind power growth continue to be met.

References 1.

2. 3. 4. 5.

6. 7. 8.

World Economic Forum, ‘These 3 charts show what COVID-19 has done to global energy demand’, August 2020. Global Wind Energy Council, ‘Global Wind Report 2021’, March 2021. Global Wind Energy Council, ‘Global Offshore Wind Report 2021’, September 2021. ETIPWind, ‘Floating offshore wind: delivering climate neutrality’, 2020. MDPI, ‘The Role of Logistics in Practical Levelized Cost of Energy Reduction Implementation and Government Sponsored Cost Reduction Studies: Day and Night in Offshore Wind Operations and Maintenance Logistics’, April 2017. Catapult Offshore Renewable Energy, ‘Wind farm costs’, 2019. FireTrace International, ‘Top three types of wind turbine failure‘, May 2020. Shell, ‘Shell uses solar energy to help power lubricant plants in Europe and Asia’, August 2019.

ENERGY GLOBAL WINTER 2021

Ido Sella, CEO and Co-Founder, ECOncrete, Israel, describes how ecological

t has never been more widely recognised that the global climate crisis requires urgent action. This was highlighted by the recent COP26 event in Glasgow, Scotland, where climate pledges were agreed to keep the world’s rising temperatures to within 1.8˚C of pre-industrialised levels. The most significant part of these pledges was the commitment from global governments to cut carbon emissions, to become net zero and slash the worrying global heating predictions. So, where do we go from here? To start, it is acknowledged that there clearly needs to be a fundamental shift away from traditional, carbon-emitting energy production, towards clean sustainable energy, while still meeting the demand of an increasingly technologically

engineering can be leveraged to ensure the sustainability of offshore wind.

developed planet and growing population. Therefore, renewable energy resources such as hydropower, geothermal, solar, wind, and wave energy have become even more popular. Offshore wind is a rapidly maturing renewable energy technology that is poised to play an important role in future energy systems. With the first offshore wind farm erected in 1991 off the coast of the town of Vindeby on the Danish island of Lolland, European countries such as Denmark, Germany, and the UK have taken the lead for years in the technology’s development. However, the efficiency of offshore wind has meant that the industry has already seen significant expansion over recent years, with the market growing nearly 30% per year between 2010 and 2018, benefitting from rapid technology improvements and

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approximately 150 new offshore wind projects are in active development around the world. The technology opens up sites with high wind resources. Sites can be built quickly, at gigawatt scale, close to key markets, making offshore wind an important addition to the technology portfolio to costeffectively decarbonise the energy sector. Furthermore, this goes alongside increasingly sophisticated development of the infrastructure, with turbines growing in size and in terms of the power capacity they can provide, which in turn is delivering major performance and cost improvements for offshore wind farms. In 2018, offshore wind provided a tiny fraction of global electricity supply. However, it is clear that it is set to expand strongly in the coming decades into a US$1 trillion business.

Environmental considerations Those across the environmental advocacy space are strong supporters of offshore wind due to the energy’s systems strong carbon credentials. However, despite offshore wind being a positive development in the race towards net zero, due attention needs to be given in order to limit the potential disruption to marine habitats and ocean ecosystems. This is because offshore wind turbines require massive concrete foundations to anchor them in place, at depths of up to 60 m. Substrate degradation and changes to hydrodynamic flow regimes due to poorly designed foundations can lead to local ecosystem destruction and the proliferation of invasive and nuisance species. This can be significantly damaging to marine life, not only on general biodiversity but also on local fishing industries. If offshore wind energy is to be truly sustainable in the long run, the use of ecological materials and nature-inspired design should become the standard.

Floating wind farms In response to the potential environmental issues caused by traditional offshore wind farms, many have marvelled at the potential for floating wind farms. Whilst most offshore wind turbines are anchored to the ocean floor on fixed foundations, limiting them to depths of approximately 165 ft, floating turbines are tethered to the seabed by mooring lines. These enormous structures are assembled on land and pulled out to sea by boats. Such turbines enable wider possibilities for offshore wind to be utilised in deeper waters, as they are not limited by water depth. Although the novel anchoring technologies utilise less cement than traditional gravity anchors and clump weights, remote deep-sea wind farms demand much more cable to be laid on the fragile seabed and more substations to be erected. Furthermore, the required tethering creates numerous artificial surfaces that may support invasive species and ecological disruption. In addition, although floating wind farms do not require the same surface area of concrete as classic base structures, the concrete avoided is expected to be utilised many-fold by complex maintenance and protection requirements. For example, extensive scour protection for numerous cable current-abrasion prop-ups, as well as mounds and anchors will be required. Jacking up cable intersections using grout bags, foundation grouting, and repair clamp grouting will all require vast amounts of cement. Thus, it is clear that neither approach adequately addresses the environmental issues. If the offshore wind industry is to expand in this way, seas will become more crowded with turbines, the seabed will be razed, food webs will be destroyed, blue carbon stores will be squandered, and foraging and flight paths will be disrupted. Species extinction is a real risk if the world does not adopt an approach to planning, consenting, and grid development that prioritises zero carbon power and nature recovery over other uses of the sea.

A sustainable approach

Figure 1. ECOncrete’s ecological concrete solutions are designed to improve the environmental and structural performance of marine projects.

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In light of such issues, forward-thinking engineers and regulators continue to work hard to re-evaluate how concrete and steel are being used in marine environments, both at the structural and chemical levels. By seriously addressing the way marine flora and fauna interact with the foundations’ surfaces, they aim to cultivate the growth of strong ecosystems from day one. At the leading

edge of ecological engineering are positive feedback solutions created between concrete that enhances biological processes, which in turn protect and strengthen the concrete itself. By incorporating ecological concrete, instead of ordinary concrete, for all anchoring and maintenance procedures, the renewables industry can significantly reduce its overall environmental impact. ECOncrete is a pioneering start-up delivering highperformance ecological concrete technologies. With solutions which can be applied to any concrete marine infrastructure, such as breakwaters, ports, and offshore structures, to increase strength and durability whilst transforming it into the base for a thriving marine ecosystem and active carbon sink. The company has already provided its technology to a range of coastal projects across the globe. For instance, in 2021 ECOncrete provided solutions to stabilise shorelines at the Port of Vigo, Spain, and the Port of San Diego, US. Furthermore, the company has also been developing its technology to fit offshore infrastructure, as exemplified by its recent partnership with LafargeHolcim in the US, where both companies joined forces to design and produce an ecologically beneficial concrete scour protection unit for offshore wind turbine foundations. The protection developed by this partnership was the first and currently only structural solution to address the ecological impacts of offshore wind turbines on the marine

environment, enabling a more sustainable industry and healthier oceans. The goal will be to design and manufacture a fullystructural concrete scour protection unit that facilitates the growth of marine organisms, whilst meeting all industry standards for stabilising the seabed. The R&D collaboration includes a large scale pilot project to evaluate the ecological performance of the innovative units in an offshore environment before implementation in full scale installations.

Conclusion Overall, renewable energies are key players with regard to world energy supply security and the reduction of fossil fuel dependency. As governments across the globe shift their energy production away from carbon-emitting energies, it is clear that the offshore wind industry will grow exponentially. With offshore wind farms requiring long-lived concrete base structures, nature-inclusive design must become the new paradigm. Whilst there is no one definitive way to calculate the costs of wind and other renewable energy sources, it is important to look at the return on investment over time and determine how they fit into a company’s overall sustainability goals and infrastructure. By using ecological concrete, carbon footprint penalties will be avoided, stable marine ecosystems can be established, and maintenance costs due to sea current erosion (scouring) can be reduced.

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Mike Popham, CEO of STRYDE, UK, describes the evolution of seismic imaging technology and how these advancements are already opening up opportunities for the geothermal sector.

or decades, seismic imaging has unlocked the subsurface for exploration and generated ever-clearer pictures of what lies beneath the ground to inform drilling and extraction strategies. However, it has traditionally been an expensive and complex undertaking that carries health, safety, and environmental (HSE) risks and can have damaging environmental consequences for survey sites. There have been limitations, too, on where seismic acquisition can be conducted because the cumbersome nature of traditional equipment has meant that it has been difficult to conduct surveys in built-up areas, areas with dense vegetation, or in rugged terrain. Yet, advances in technology are changing that. Nodes – no heavier or larger than a smart phone – and their compact infrastructure, pioneered by seismic technology providers such as STRYDE, are increasingly replacing traditional survey methods, such as the use of cables. Critically, as explored in this article, this latest generation of nodal technology is making seismic imaging far more affordable, which is opening up the benefits of the technology to other industries. For emerging, clean industries of the future such as geothermal, the benefits of high-density seismic could be game-changing.

What is seismic imaging? Seismic acquisition involves injecting energetic vibrations into the earth from a source, for example, a vibroseis truck. The seismic waves generated are reflected and recorded by sensors on the surface. This data is then processed and interpreted to determine the properties of the Earth’s subsurface, such as imaging the different layers in the subsurface or understanding the properties of the rocks at different depths. Until very recently, carrying out seismic surveys was expensive. Traditionally, long lines of cables with arrays of sensors were laid out to detect seismic waves, which often meant clearing large swathes of land during the early stages of a survey. It was a labourand machine-intensive process, costly to the organisations requiring the surveys, risky for individuals in the field, and in many cases, damaging to the environment.

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So, while seismic acquisition has been – and continues to be – one of the very best ways to understand the properties of the ground below, its expense and complexity means that it has been reserved almost exclusively for the oil and gas industry.

Advances in seismic imaging technology In recent years, seismic technology has evolved, with the industry switching to using nodes for seismic imaging. Nodes are rugged, self-contained units, typically comprising a sensor, a power source, and electronics, enabling the recording of seismic data. Nodes reduce the equipment needed in the field, improve efficiency, and in most cases, allow improved seismic imaging. However, even today, most nodes remain too heavy and too expensive to enable high-density imaging of the subsurface without a sizeable budget. Furthermore, the weight of most nodes means vehicle-based deployment is still required. The newest generation of nodal technology removes these constraints, unlocking the potential for lower cost, higher quality seismic imaging whilst also improving safety and significantly reducing the environmental footprint of acquiring land seismic. STRYDE’s nodes are small and lightweight, at just

150 g per unit. The equipment needed to handle a large node inventory is also extremely compact, making mobilisation of a seismic survey easier, faster, and lower cost. In the field, efficiencies continue to be evident; one person can carry 90 nodes and deploy them across a survey area on foot. This removes the need for heavy vehicles to transport equipment alongside the crew, allowing seismic contractors to work without necessitating road closures, clearing vegetation, and minimising the carbon footprint of a project. It also broadens the types of terrain where seismic acquisition projects can be deployed – for instance nodes are far easier to deploy in built-up urban environments or in mountainous terrain since recording equipment can be moved on foot. The size and weight of nodes not only facilitates faster deployment, it also allows higher numbers of nodes to be deployed. It is this potential for higher trace density and finer spatial sampling that increases the quality of a subsurface image. But for high trace density deployment to be cost-effective, nodes need to be affordable, and that is where STRYDE really comes into its own. Its nodes achieve everything necessary to deliver a low-cost, high-quality subsurface image, without being overloaded with other unnecessary and costly features. It is this principle – achieved through advances in technology – that presents a great opportunity for seismic imaging to play a crucial role in driving the energy transition. Nodal technology has made high trace density seismic imaging more accessible and affordable than ever.

Opportunities for geothermal

Figure 1. One of STRYDE’s nodes during a seismic survey in Europe.

Geothermal energy is still an emerging form of renewable energy in Europe, with approximately 3 GW of geothermal capacity expected to be installed in the region over the next decade to decarbonise energy and provide heating. To rapidly scale-up geothermal capacity – and for geothermal to play a central role in the energy mix – new sites must be found beyond the known heat vents and hot springs, requiring subsurface images to identify the best locations for well placement. Producing geothermal energy means drilling wells that are sometimes over 1 mile deep into underground reservoirs. Knowing where faults and stress fields lie helps a developer decide where to tap into the rock’s natural permeability and to optimise well trajectory. It therefore comes with some of the same challenges associated with oil and gas extraction. Like fracking, areas around existing geothermal power plants have experienced tremors. This means understanding the structural geology and stratigraphy of the subsurface is critical to the success of geothermal projects. It is here that seismic imaging can play a big role.

Challenges in using seismic for geothermal projects Figure 2. Nodes of this size are making seismic more environmentally friendly.

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While obtaining high-definition images of the subsurface is clearly a huge benefit to developers of geothermal power plants, the cost of using traditional means of obtaining the data required to process these images is prohibitive.

Geothermal developments are typically located in urban or industrial areas. This introduces additional seismic acquisition challenges, which are particularly prevalent if attempting to use traditional cabled systems or bulky nodes. For example, seismic crews have limited access in urban environments due to buildings and infrastructure. Road closures or traffic delays needed to move bulky equipment by vehicle are frustrating for the local population. Finally, receiver equipment is vulnerable to vandalism or theft if it is clearly visible. These challenges mean that developers have to compromise on survey geometry, and ultimately seismic image quality, by acquiring sparser surveys. However, using the latest generation of smaller nodes simplifies these issues. Smaller nodes can easily be buried or hidden from view and the lack of a requirement for a fleet of large vehicles to move bulky equipment avoids traffic delays. Put simply, by allowing the seismic industry to move to Figure 3. Seismic has a key role to play in the energy transition, particularly in geothermal projects. significantly smaller and lower cost nodes, STRYDE has redefined the practicalities of acquiring land Owing to the flexibility of the nodal system and speed at seismic. Productivity increases significantly, with no downtime which data can be processed once the nodes are harvested, due to unreliable equipment. The overall cost of acquiring GTG and realtimeseismic were able to shoot a city-based 3D seismic is minimised, through a combination of reduced study in just one month, in contrast to the six to 10 months it equipment costs, streamlined crews with fewer people and would have once taken with traditional cabled systems. vehicles, and accelerated project delivery. The size and weight also enabled GTG and realtimeseismic Surveys are also safer and more environmentally friendly. to complete surveys during COVID-19, when restrictions limited Vehicle use is typically reduced by over 50%, decreasing project the number of people who could be sent onsite. emissions and HSE exposure. Small teams can deploy a node These projects in Belgium, France, and Switzerland every 15 sec. on foot, with individuals carrying up to 90 nodes demonstrated that, through the use of high trace density each, meaning line clearing is eliminated. In short, this acquisition and modern data analytics, seismic imaging could technology widely used in other industries can help to unlock be used effectively in a city to not only generate an image of the opportunity of geothermal at more sites across Europe and the subsurface, but also to help reveal the true geology of the the world. subsurface. The low cost of the STRYDE nodes has also made it As the energy transition continues, and as governments practical for geothermal operators to continuously collect and business seek to end reliance on fossil fuels, ensuring passive seismic data once a plant is in operation, meaning that there is a good mix of green renewable energy sources able to if small tremors begin to occur, an operator already has access power the planet is essential. to the data that will inform themselves and regulators as to Seismic technology – which has been so important to what caused this event and how to prevent it in future. the oil and gas industry for so long – can help investors and developers unlock geothermal energy, through safer, faster, higher-density surveys that will inform operations teams where Technology in practice faults and stress fields lie, and optimise well trajectory, as this STRYDE’s nodal system enabled companies GTG and source of energy becomes more prominent in cities and realtimeseismic to successfully conduct a variety of complex towns. geothermal projects in Europe using their nodal system.

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Michael Mondanos, PhD, Silixa, UK, describes how fibre optic sensing technology can be used to monitor geothermal operations and provide the necessary data to assist with key project decisions.

eothermal energy can be divided into two distinct groups in the form of lowtemperature geothermal (<150˚C), typically used in direct-use applications, and high-temperature geothermal (>150˚C). The latter is suitable for power generation by circulating the fluid throughout the reservoir, transporting heat to the surface where electricity can be generated. Geothermal power plants produce electricity consistently, with highly predictable and stable power output, facilitating energy planning with remarkable accuracy. There are three critical elements in geothermal energy: heat, fluid, and permeability at depth. An enhanced geothermal system (EGS) is an artificial reservoir created where there is hot rock but insufficient or little natural permeability or fluid saturation. In an EGS, fluid is injected into the subsurface under carefully controlled conditions that cause pre-existing fractures to re-open, creating permeability. During EGS reservoir creation and stimulation, rocks may slip along pre-existing fractures and produce microseismic or induced seismicity events. Induced seismicity data allows better subsurface characterisation but can cause public concern.

The challenges of geothermal wells Geothermal reservoirs offer unique characterisation challenges due to the harsh environment that downhole tools are subjected to and the discrete and spatially discontinuous hydrothermal features that make up the reservoir. EGS offers great potential for dramatically expanding the use of geothermal energy by allowing the development of traditionally inaccessible thermal resources; thus, offering the possibility to reduce carbon emissions to combat anthropogenically induced

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climate change significantly. However, EGS development provides an additional set of challenges as reservoir engineers have the burden of characterising the existing reservoir and dynamically guiding reservoir enhancement in heterogeneous media with an acceptable degree of resolution and accuracy. Developing EGS resources will require highly advanced and novel characterisation and monitoring methods and technologies. The efficiency of a low-temperature geothermal system depends on the thermal properties of the reservoir.

Hydrothermal and enhanced geothermal A challenge in operating traditional hydrothermal power plants is maintaining production flow rates at high temperatures over many years of operation. Reservoir characterisation and continuous monitoring can help guide power plant operations to optimise the use of the geothermal reservoir. A challenge in developing enhanced geothermal systems is predicting the hydraulic connectivity, geomechanical properties, and permeability of fracture networks. For EGS to serve as an effective subsurface heat exchanger, the flowing fracture network must be monitored during the evolution of the reservoir. Continuous monitoring can be utilised to target new injection and production wells, plan stimulation activities, and guide the completion of existing wells to optimise thermal recovery. Observational challenges for EGS microseismic measurements are further compounded by the intrinsic difficulty of borehole instrumentation at reservoir depths in EGS sites; the

Figure 1. Silixa’s distributed acoustic sensing (DAS) interrogators. Left: the intelligent DAS. Right: the Carina Sensing System interrogator. Light is emitted from the interrogator and the back scattered light from the fibre is recorded.

high temperatures (>150˚C) result in a hostile environment and correspondingly short lifetime for most conventional sensors. The traditional solution to monitoring the system operation is to utilise conventional gauges and geophones. These have some limitations because of the high-temperature environment; they can hardly withstand temperatures that can reach 300˚C. In addition, they are expensive, challenging to install permanently, require power, and do not offer the spatial coverage required. If any seismic acquisition is required, they must intervene with the well, stop production, lower the geophones into the well, and then undertake the surveys, wasting both time and money. If this activity occurs on the surface, they must lay several seismic nodes, as it is challenging to achieve the required spatial coverage.

A new approach to geothermal Distributed fibre optic sensing is a rapidly advancing class of technology ideally suited to geothermal monitoring. Optical time domain reflectometry (OTDR) is one of the underlying principles enabling distributed sensing, in which an incident pulse of light is coupled into an optical fibre and the backscattered light is sampled. As the incident pulse travels along the fibre, a small amount of light is scattered and recaptured by the fibre waveguide in the return direction. Through analysis of the backscattered signal and round trip transit time from the launching end to the point of interest, dynamic profiles of the state of the optical fibre at all locations can be developed. Geothermally relevant measurements include distributed temperature sensing (DTS), distributed strain sensing (DSS), and, most recently, distributed acoustic sensing (DAS) for microseismic, seismic, and slow strain investigations. Silixa’s monitoring solution is based on an integrated fibre optic distributed sensing monitoring system that can be combined with hydraulic tests to better constrain the zones with permeable fractures, and an array of automated surface seismic sources to constrain each phase of fracture evolution and behaviour at the geothermal site. By using hightemperature engineered cables and interrogators capable of simultaneous DAS, DTS, and DSS measurements, the system can effectively map initial zones of mechanical stimulation using DAS microseismic monitoring; spatially-resolve elastic compliance estimates of the fractured zones using scattering, and velocity perturbations measured using time lapse VSP imaging and permanent surface seismic sources; and identify zones of flowing fractures using hydraulic tomography with low-frequency DAS strain as the detection modality. These solutions create value for geothermal projects by offering high-quality monitoring data that can be used to optimise the geothermal system design during the exploratory and characterisation phases. Later during the production phase, it also provides a robust and cost-efficient, long-term integrated monitoring system to assist operation decisions and verify operation sustainability and safety.

Geothermal monitoring in action Figure 2. A recording of an M3.3 earthquake with distributed fibre optic sensing; the time of P-wave and S-wave arrivals are indicated.

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A hydrothermal deployment at the Brady Hot Springs Field in Western Nevada, US, provided Silixa with the opportunity

to try and test its technology. A multi-disciplinary team led by the University of Wisconsin-Madison with partners from academia and industry developed and deployed a highly complex geothermal reservoir monitoring system including distributed fibre optic sensing as part of the US Department of Energy-funded PoroTomo project. Optical fibre cables were deployed in a shallow surface trench and an observation well. The project developed a monitoring methodology to characterise the geothermal reservoir of combined seismology, geodesy, and hydrology parameters at a depth that could be scaled to deployments for monitoring greater reservoir depths and subsequent volumes. The integrated technology developed as part of PoroTomo can be utilised at other hydrothermal and EGS sites to enhance reservoir understanding by estimating subsurface formation parameters and their uncertainties to improve operations at existing facilities and guide new development efforts. The solution consisted of deploying iDAS and ULTIMA DTS over 9 km of fibre optic cable in a trenched seismic and temperature surface array and 400 m of fibre optic cable resistant to high temperatures in a downhole array. Fibre optic sensing technology was utilised for the capability to provide dense seismic and temperature measurements with extremely fine resolution over the entire deployed fibre optic cable array. iDAS was selected for its high-performance seismic measurement capabilities including a wide dynamic sensing range and instrument stability, while ULTIMA DTS measurements allowed for fine resolution of temperature changes in the reservoir. Both technologies also have the capacity to be deployed in the harsh conditions experienced

in geothermal reservoirs. iDAS was combined with an active seismic source to carry out a time lapse seismic survey. Temperature measurements from the ULTIMA DTS were combined with pressure measurements from multiple observation wells. Data was collected during four time intervals, each representative of distinct hydraulic conditions due to alterations in the flow field from manipulation in pumping and injection. Collecting time series data under varying hydraulic conditions allowed the data set to be utilised to characterise the hydraulics of the geothermal reservoir through analyses of the poroelastic response. Both the surface and downhole fibre optic cable installations were completed successfully in late winter 2016. iDAS and ULTIMA DTS data were recorded 24 hours a day over the entire 9400 m of cable for 15 days directly following installation. Analysis of the active and passive seismic data, temperature data, and other data collected is ongoing.

Summary Because geothermal projects have high investment and operational costs, coupled with policy uncertainty and design challenges, there is a greater need for cost-effective and innovative monitoring technologies. This is where distributed fibre optic sensing can generate value for geothermal projects by offering high-quality monitoring data that can be used to optimise the geothermal system design during the exploratory and characterisation phases. Later during the production phase, it also provides a robust and cost-efficient long-term integrated monitoring system to assist operation decisions and verify operation sustainability and safety.

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SOLAR

GLOBAL NEWS

GE and UK Export Finance agree to support Turkish solar project

Biggest solar park in Germany without state funding inaugurated

GE and UK Export Finance (UKEF), UK’s export credit agency, have announced that an agreement has been reached to finance Kalyon Enerji’s 1.35 GW Karapinar solar project located in the Konya Karapinar province, Turkey. The solar power plant is the country’s largest solar facility, approximately 11 km long and 3 km wide, equivalent to over 4600 football pitches. GE Energy Financial Services worked with UKEF, who is set to guarantee a US$291 million (£217 million) Buyer Credit Facility, subject to financial close. This will enable GE to deploy its first FLEXINVERTER solar technology outside the US, supporting Turkey’s clean energy goals and facilitating trade for UK suppliers. Financing for the project will be structured on a project finance basis and raised through J.P. Morgan as acting lead arranger and lender supported by the UKEF guarantee. The integration of the FLEXINVERTER solar technology and the assembly of the solar power station will occur in the UK, supporting approximately 100 UK jobs directly and indirectly in the supply chain. As part of the localisation requirements, GE’s Grid Solutions site in Gebze, Turkey will be producing transformers for integration in the solar inverter system. In addition to GE’s solar technology, the export contract also covers design, engineering, project management, site management, and commissioning. GE Renewable Energy has already completed the commissioning of the FLEXINVERTER solar power station technology for Kalyon Enerji’s 267 MW Karapinar phase I solar plant. Upon full completion, expected by late 2022, the facility will deliver clean electricity to approximately 2 million Turkish households.

Almost one year ago, the first kWh flowed out of WeesowWillmersdorf and now the solar park has been formally inaugurated. With the construction of the solar park approximately 30 km east of Berlin, Germany, EnBW has opened a new chapter in the story of photovoltaics (PV) in Germany. Its 187 MW can supply up to 50 000 households each year with eco-friendly electricity. This is currently the biggest open-field solar power plant in Germany. Furthermore, EnBW built the solar park with no funding through the Renewable Energies Act (EEG). This is a new way of ramping up the use of solar energy in Germany, as EnBW board member Georg Stamatelopoulos explained at the official inauguration ceremony. “We must be faster and more digital in order to increase the pace of expansion for renewable energies. Processes must be streamlined and legally sound. The relevant authorities also need additional staff,” he said. Given the German government’s aim of raising the level of gross energy consumption met by renewable energies to 65% by 2030, there would have to be an annual increase in PV capacity of 10 000 MW – twice as high as the figure to date. Annual generation of approximately 180 million kWh of power will cut carbon emissions by approximately 129 000 tpy. EnBW itself has set a target of achieving net zero emissions by 2035. Between 2021 and 2025, the company invested approximately €4 billion in renewable energies. It is currently building another two major PV projects, each with a capacity of 150 MW, not far from Weesow-Willmersdorf solar park, thereby creating a unique solar cluster in Brandenburg made up of three large solar power plants.

MYTILINEOS announces financial close for Australian solar projects MYTILINEOS S.A. has reached financial close on the non-recourse financing of the Corowa, Junee, and Wagga solar farms in New South Wales, Australia, with lenders ANZ, Societe Generale, and Westpac. This 120 MWp portfolio (40 MWp each project) was acquired in 2019 as part of MYTILINEOS’ strategic entry to the Australian market, one of the most demanding and competitive markets in the world, where access to clean energy is still in demand for many large companies. These solar parks will produce 220 GWh/y to power Australia’s electricity system, reducing 180 000 tpy of

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carbon dioxide emissions. The majority of the power produced and the large scale generated certificates from the three projects are sold under a 10 year green Power Purchase Agreement (PPA) with Coles, a major Australian food and grocery retailer. Despite the adversities and difficulties imposed by the COVID-19 pandemic, project construction was successfully executed by MYTILINEOS’ Renewables and Storage Development (RSD) Business Unit and was completed in 1H21, proving the company’s ability to carry out demanding projects.

WIND

GLOBAL NEWS Approval in Principle awarded to HHI’s floating wind foundation

RWE receives environmental permit for its Polish offshore project

Bureau Veritas (BV) has delivered an Approval in Principle (AiP) to Hyundai Heavy Industries Co. Ltd (HHI) for its design and development of Hi-Float, a floating offshore wind turbine foundation. The certificate was delivered to Seon Mook Lim, Executive Vice President of HHI, by Christophe Capitant, Chief Country Executive of BV Korea. Based on HHI’s vast experience with offshore projects, the offshore floating wind substructure Hi-Float is designed to support a 10 MW wind turbine with proven semi-submersible and mooring technology. A passive ballast system ensures that risk is kept to a minimum during offshore operations. The good performance of Hi-Float in an offshore environment was verified through numerical analysis and wave basin model testing. There has been an increase in the number of floating wind projects emerging worldwide. Market projections show that, as new regional markets emerge, offshore wind growth will continue apace and it is also going to diversify. While to date the majority of offshore wind installations are bottom-fixed, in the coming decades the industry will witness an increase in floating wind capacity. While many technologies are still under development, floating wind has the potential to complement bottom-fixed technologies by enabling feasibility and competitiveness in deepwater zones. Currently, however, the share of floating installations in the offshore wind market remains limited. In 2019, out of Europe’s total offshore wind capacity of 22 GW, the largest regional capacity worldwide, floating wind still only represented 0.2% (45 MW) compared to bottom-fixed installations.

RWE Renewables has moved a major step closer to the realisation of its first offshore wind farm in Poland. Via its Polish subsidiary Baltic Trade & Invest Sp. z o.o., the company received a positive decision by the regional Director for Environmental Protection in Szczecin. This decision specifies the environmental conditions for the realisation of the F.E.W. Baltic II offshore wind farm, which will be located in the Polish Baltic Sea, near the city of Ustka, and has a planned capacity of 350 MW. It was the first Environmental Impact Assessment for a Polish offshore wind project, which has been assessed under a cross-border procedure (ESPOO convention), with participation of Danish and Swedish stakeholders. The whole Environmental Impact Assessment campaign for the offshore wind farm site took two years and was conducted with strong contributions from Polish scientific institutes and companies: among others the University of Gdansk, the Naval Academy, the Polish Geological Institute, the Institute of Oceanology of Polish Academy of Sciences, as well as the research services 3Bird and Tringa. Receiving the environmental permit is a significant milestone in the development of RWE’s first offshore project off the Polish coast. Subject to the Final Investment Decision, construction works could commence as early as 2024. Once fully operational, the wind farm would be capable of producing enough green electricity to supply the equivalent needs of approximately 350 000 Polish households. Through the F.E.W. Baltic II project, RWE will contribute significantly to the local economy as well as to the green energy transition in Poland.

Equinor and EWP collaborate on Korean offshore wind Equinor has signed a Memorandum of Understanding (MoU) with Korean East-West Power (EWP) to co-operate on 3 GW of offshore wind projects in South Korea. Together the partners will contribute significantly to the country’s ongoing energy transition and development of an offshore wind industry in Korea. The Korean Government has set out an ambition to grow renewables by approximately 60 GW to 2034, of which 12 GW is targeted for offshore wind by 2030. Equinor’s partnership with EWP, one of Korea’s stateowned power generation companies (Gencos), provides a strong basis for the offshore wind major to take a leading

role in developing a pipeline of offshore wind projects needed. The MoU between Equinor and EWP confirms Equinor’s strategy of accelerating profitable growth in renewables by creating value from early access at scale in attractive markets, in collaboration with partners that share its vision and goals. Given the Korean coastal water depths, floating solutions are required to realise the South Korean Government’s renewables ambitions. Equinor will bring its decades of floating wind experience and offshore technology to the partnership, including O&M expertise.

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BIOFUELS

GLOBAL NEWS Gasum and Metsä Fibre co-operate on biogas project Gasum and Metsä Fibre, part of Metsä Group, have agreed to co-operate on biogas processing at the biogas part of Metsä Fibre’s Äänekoski bioproduct mill. Metsä Fibre will be responsible for the plant’s overall operations, whereas Gasum will be responsible for the daily remote operation and maintenance of biogas processing. Gasum will buy the biogas produced at Metsä Fibre’s plant for use as a road transport fuel in the company’s filling station network. The Äänekoski biogas plant will use wood-based sludge from the bioproduct mill to produce biogas and biopellets. The biopellets will be used in energy production at Metsä Fibre’s power plant. Gasum will process the biogas from the plant, manage the plant’s operation and maintenance, and sell the biogas for road transport through its filling station network. “Our biogas plant further processes the sludge originating in pulp production into products of higher added value. Together with Gasum, we will be able to process biogas produced at the plant into a transport fuel, says Kaija PehuLehtonen, Senior Vice President at Metsä Fibre.

Bioenergy Devco secures funding for bioenergy project Bioenergy Devco, a developer of anaerobic digestion facilities that transform organic waste into renewable energy and healthy soil products, has secured US$100 million in financing from funds managed by Irradiant Partners, LP. This new capital will support the development of multiple anaerobic digestion facilities to drive sustainable organic waste recycling and reduce greenhouse gas emissions in North America. Irradiant joins Bioenergy Devco’s existing investor base that includes Newlight Partners LP and Sagewind Capital LLC. Bioenergy Devco has constructed more than 240 anaerobic digesters and currently manages 140 facilities worldwide. Since launching in the US in 2019, the company has over 20 anaerobic digesters in development, including two under construction in Delaware and Maryland. Slated to be one of the largest and the first industrial scale food waste digesters in the US, the facility at the Maryland Food Centre Authority will have the capacity to accept more than 115 000 tpy of organic material, offering the same carbon sequestration impact as a forested area 40 times the size of Central Park in New York.

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ARENA releases bioenergy roadmap Bioenergy could play a significant role in reducing emissions, stimulating the Australian economy and creating jobs in regional areas, according to the Australian Renewable Energy Agency’s (ARENA) Bioenergy Roadmap. The Roadmap lays out a vision for a sustainable bioenergy industry that can help lower emissions, increase fuel security, enhance waste recovery, and deliver economic benefits. The Roadmap reveals that the bioenergy sector could contribute approximately AUS$10 billion/y to Australia’s GDP and create 26 200 new jobs, reduce emissions by approximately 9%, divert an extra 6% of waste from landfill, and enhance fuel security. To support the implementation of the Bioenergy Roadmap, ARENA has received AUS$33.5 million in additional funding from the Government to further support and advance Australia’s bioenergy sector through co-funding additional research, development and deployment of advanced sustainable aviation, and marine biofuels. Over the past eight years, ARENA has provided over AUS$131 million in funding towards bioenergy projects across Australia. ARENA’s investments to date span electricity and biogas production, biofuels, efficient feedstock harvesting technology, and projects that aim to capture energy from a range of waste materials.

THE RENEWABLES REWIND > Sustainable Marine tidal project on track > UK battery storage facility acquired by TagEnergy >>Strohm and Siemens Gamesa to develop green hydrogen transfer solutions Follow our website and social media pages for more updates, industry news, and technical articles.

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HYDROPOWER

GLOBAL NEWS

ANDRITZ receives order for Indian hydropower project

GE awarded contract for hydroelectric power plant

ANDRITZ has received an order from the Assam state government-owned utility Assam Power Generation Corp. Ltd (APGCL) to supply the complete electro-mechanical equipment for the Lower Kopili hydropower plant located on the Kopili river in central Assam, India. The start of commercial operation is scheduled for the end of 2024. ANDRITZ’s scope of supply consists of plant design and engineering, manufacture, supply, erection, testing, and commissioning of the complete electro-mechanical equipment, including all five turbine-generator units, for the Lower Kopili hydroelectric project. As the river has a very high acid content at the location of the Lower Kopili hydropower plant, most underwater parts will be made of stainless steel. Once completed, the hydropower plant will have a total installed capacity of approximately 120 MW, based on two main units and three environmental flow units and provide 456 GWh/y of electricity. The project will provide strong support in covering the growing demand for electricity in Assam. This contract will be the fifth project for ANDRITZ from the north-eastern region of India following the contract for rehabilitation work at the Kopili hydroelectric project awarded earlier in 2021.

GE Renewable Energy’s Hydro Solutions has signed a contract to provide full operation and maintenance (O&M) for the Igarapava hydroelectric power plant, located in Rio Grande in the Paraná River Basin, Brazil. The Igarapava hydroelectric power plant was a pioneer in Brazil in the use of the ‘Bulb’ turbogenerator group, which optimises electricity generation from dams with fast running water and extremely low heads of less than 20 m from the top to the bottom of the dam. GE Renewable Energy was one of the project’s main suppliers during Igarapava’s construction and installation. Now, under the new contract, the company is responsible for the O&M of all five hydroelectric generating units, each of which can provide 42 MW, for a total of 210 MW of installed capacity. This amount of energy is sufficient to meet the demand for electricity of 225 000 people. To execute the contracted scope, GE Renewable Energy will operate the plant 24 hours a day, seven days a week. In addition to the day-to-day operation, GE’s team is also responsible for defining and executing the entire plant maintenance plan, from routine activities to predictive and preventive actions, as well as unplanned maintenance.

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ENERGY GL BAL

Energy Global Winter 2021

Articles inside

Global news

Mapping the heat beneath our feet

See the bigger picture

An eco approach

Strike a balance

America flies the renewables flag

Offshore wind + hydrogen = the future?

Powering the energy transition

Unlock the power of ocean waves

The goal: hit the sustainability targets

A boost for green hydrogen

Solar's significant potential