Techniques developed by researchers at Queen Mary University of London and Imperial College London could help provide raw materials needed for sustainable alternatives to conventional lithium-ion batteries.

A handful of critical chemical elements, including lithium, cobalt and graphite, power rechargeable batteries at the heart of everything from mobile phones to large-scale electricity grid storage.

Demand for these essential materials is set to grow as more countries move away from fossil fuels, and so will the environmental and geopolitical impacts of their mining and disposal.

Dr Maria Crespo, lecturer in Green Energy at Queen Mary, will be exhibiting her team’s work on future batteries research at this year’s Royal Society Summer Science Exhibition, a free public festival of science held at the Society’s central London home from 2 – 7 July.​

“Moving away from fossils fuels is an essential part of any plan to transition to net zero,” Dr Crespo said.​

“However, if we continue to rely on lithium-ion batteries as the only option for fuelling our future, we are swapping one unsustainable, environmentally damaging resource for another.​

“We need to diversify our batteries, so we are not relying on one group of scarce elements for every energy storage task, and we need to think much more carefully about how we reuse our materials when their lifespan is up.”​

A 2023 review^[1] forecast that, by 2040, demand for lithium, cobalt and nickel in electric vehicle batteries would outstrip production, but that improved recycling could meet up to half the raw material demands.

Dr Crespo estimates that for the UK to meet the 2050 energy storage requirements projected by the National Grid with lithium-ion batteries alone, would require lithium equivalent to 14 times the weight of The Shard, London^[2].

But the critical elements used in lithium-ion batteries are relatively scarce. Lithium accounts for just 0.002% of the Earth’s crust and often elements like nickel and cobalt are found in geopolitically insecure regions or vulnerable ecosystems.

Last year, in collaboration with The Tyre Collective, Dr Crespo secured funds to transform particulates captured from vehicle tyres into components of sodium-ion batteries^[3], an alternative to traditional lithium-ion batteries.

To be cost effective, alternative technologies like sodium-ion batteries, which have lower gram-for-gram energy storage potential, would have to be cheaper than lithium-ion to be cost effective.

Another recently patented technique^[4] is looking at how rarely recycled nylon packaging, and other plastics, could be converted into hard carbon battery electrodes at relatively low temperatures, reducing the demand for virgin graphite.

Diversifying our battery chemistry, and the sources of raw materials, can also improve the sustainability and efficiency of lithium batteries, which will remain important for high-energy uses.

Dr Heather Au, Royal Society University Research Fellow at Imperial College London and a member of the exhibit team is researching lithium-sulfur batteries made with waste from the paper industry.

“When we need to use lithium for the large amount of energy it can store, we can replace the critical cathode materials, like cobalt and nickel, with sulfur, a cheap, abundant and non-toxic element,” Dr Au said.

“We can produce these electrodes using lignin, which is a waste product of paper manufacturing that is, currently, mostly burned for heating.

“The advantage of using our technology for lithium-sulfur systems is that they are much lighter than conventional electrodes, which could increase the gram-for-gram energy storage potential.”

Visitors to the Summer Science Exhibition will have a chance to talk to the researchers behind the work and try their hand at making batteries of their own.

1. Maisel et al. 2023 A forecast on future raw material demand and recycling potential of lithium-ion batteries in electric vehicles. Resources, Conservation and Recycling –https://www.sciencedirect.com/science/article/pii/S0921344923000575#
2. For reaching a target of 63 GWh of battery electrical storage in 2046. National Grid Electric System Operator, 2023, FES in Five, p. 10.
3. Material Matters exhibition shows new batteries and pressure sensors developed from tyre wear particles – https://www.sems.qmul.ac.uk/news/6520/material-matters-exhibition-shows-new-batteries-and-pressure-sensors-developed-from-tyre-wear-particles/
4. Upcycling plastic waste into high-capacity sodium-battery anodes – https://imperial.tech/wp-content/uploads/2024/05/11601_upcycling_plastic_waste_anodes_pub_MAY24.pdf

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O-I Glass and GridBeyond plan to implement a groundbreaking battery storage solution at O-I’s Alloa, UK facility. The innovative 8MW battery system and supporting energy management system (EMS) leverages artificial intelligence to significantly enhance energy efficiency, resilience and sustainability.

“Our energy strategy is grounded in resilience, innovation, and transformation, to embrace cutting-edge solutions that are scalable and sustainable,” said Randy Burns, Chief Sustainability and Corporate Affairs Officer for O-I.

By strategically charging and discharging the battery based on grid conditions, GridBeyond’s AI-powered system helps to stabilise the local electricity grid during peak periods, increases O-I’s resilience against brownouts, and improves the grid’s efficiency and sustainability. It allows charging during times of high renewable energy availability and discharging energy to the site at peak hours of demand. With this approach, O-I is projected to conserve up to 240 tons of CO₂ emissions annually at the Alloa facility once the project is operational.

The sophisticated battery management algorithm also helps to maintain a smaller overall footprint of the grid as it smooths out the load during peak hours.

In addition, the battery system will increase power resiliency at the Alloa plant by balancing voltage dips on site and helping to prevent production equipment from tripping out.

“We are supporting O-I’s global sustainability strategy by leveraging localized product and process innovations to transform our operations,” said Jim Rankine, O-I’s UK Managing Director. “From our use of second-generation biofuels, derived entirely from renewable waste materials to leveraging AI to maximise energy efficiency, we are taking a holistic approach to achieving balance across our stakeholder ecosystem.”

“Through its AI platform, GridBeyond is a key player in supporting businesses’ energy transition and helping to deliver net zero. We are extremely proud of working with O-I and use our expertise to support the company to deliver a sustainable future,” commented Michael Phelan, CEO at GridBeyond.

As part of O-I’s vision to be the most sustainable, and chosen, supplier of brand-building packaging, the company aims to reduce GHG emissions by 25% by 2030. To learn more about O-I’s sustainable packaging for wine and its global vision for sustainability, visit the company’s website.

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GridBeyond will be delivering BESS solutions to Keppel DC Dublin 1 and 2, which are located at City West and Ballycoolin, Ireland respectively. The two data centres are owned by Keppel DC REIT, a Singapore listed pure-play data centre REIT.

The BESS at the two data centres will provide additional flexible capacity to the power system. By adding this flexible capacity, the BESS will help integrate more renewable energy sources into the energy mix and support the grid in times of stress for the benefit of all consumers. This will also add 8MW of flexible capacity to the grid ahead of the winter peak demand period.

The project includes the installation and management of a 2 x 2MW/2.2MWh battery at the Citywest site and a 4MW/6.1MWh battery at the Ballycoolin site. GridBeyond will manage the flexibility of the sites by connecting the batteries to its AI-powered energy technology platform, GridBeyond Point. Power from the batteries will be discharged in response to instructions from the grid operator to provide green power during times of grid stress. Historically, during times of grid stress, generation facilities, often carbon-intensive, are brought online to balance the grid. By capturing excess renewable energy from renewable sources that would otherwise be wasted the BESS will be able to provide lower carbon flexibility to the system when required.

It is also estimated that the installation of the two batteries at the two data centres will deliver a reduction of 240,000kg of CO₂ per year, further advancing the two companies’ net zero agenda.

GridBeyond Regional Director for Ireland Denver Blemings said, “This project shows how data centres can play a bigger role in the energy transition. It’s great to see companies, like Keppel DC REIT, use demand response programmes to support the grid and use renewable energies in the delivery of their activities”.

Gary Watson, Country Manager (Ireland) of Keppel DC REIT, said, “Leveraging this partnership with GridBeyond, Keppel DC REIT’s is able to take another step towards our 2030 net zero targets. We will also explore other ways to increase the use of renewable energy, such as installing on-site solar, to bolster our efforts to decarbonise our operations.”

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Railpen, formerly known as RPMI, runs the railways’ pensions schemes on behalf of its parent, the Railways Pension Trustee Company Limited. It manages £34 billion of assets on behalf of over 350,000 members.

Its investment will support AGR in achieving its target of putting over 500MW of high quality renewable assets into operation by 2029.

Railpen has committed to invest in AGR’s near-term UK solar, battery energy storage system (BESS), and greenhouse projects.    Its backing will enable construction before 2026 of 160MWp of solar arrays, of 150MW in BESS, as well as AGR’s second sustainable greenhouse.

London-based AGR was co-founded in 2011 by Oliver Breidt.

Besides bringing forward onshore wind projects in the UK and northern Ireland under the Feed-in Tariff, plus solar farms across southern England & Ireland, it is known for one of Britain’s biggest and most technologically advanced greenhouses, the Fenland Greenhouse near Ely, Cambridgeshire, pictured above.

The project spans 22 hectares and produces over 2.5 million vegetables every week at peak output. The complex is powered through a combination of water-sourced heat pumps and CHP gas engines, coupled with a back-up boiler. Fenland I greenhouse spans 60Ha and produces over 2.5 million cucumbers per week. The project was initiated in 2021 as a standalone greenfield development and delivered to Greencoat Capital, part of Schroder’s Capital, in 2022.

For Railpen, its AGR investment reflects its commitment to investing in infrastructure, including directing £500m to UK energy projects since 2019. The company will be represented on the AGR board by Lewis Vanstone and Cristiana Dochioiu. AGR’s co-founder Oliver Breidt will remain as group director.

Breidt said: “I’m incredibly pleased to announce our partnership with Railpen in what is a landmark move for us. Railpen’s investment and reputation will help propel AGR into new territories and technologies, including our 1GW pipeline in Italy, and see us expanding our presence in Germany and into further agricultural assets.

“I’m very pleased to be working with Lewis and Cristiana who bring with them a wealth of experience. This will be a transformative chapter for AGR and our mission.”

Dochioiu, investment manager at Railpen added: “AGR’s approach to sustainable infrastructure development and investment matches Railpen’s ethos for sustainability and providing essential infrastructure to the UK.

“We are excited to work with the AGR team and Oliver to further develop the pipeline at AGR and drive positive change through our investment portfolio, building the critical infrastructure needed to support the UK’s transition to net zero. Railpen’s scale and long-term approach makes us an ideal partner for AGR’s ambitions to enhance energy and food security in the UK and Europe.”

Railpen were advised by parties including CMS for legal services, Grant Thornton on financial and tax and Willis Towers Watson on insurance. AGR were advised by lawyers Eversheds Sutherland.

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The £300 million funding round was led by the UK Infrastructure Bank (UKIB) and multinational energy leviathan Centrica, supported by investors including Rio Tinto, Goldman Sachs, KIRKBI and Mosaic Capital.

The investment will enable the construction of one of the world’s largest long duration energy storage (LDES) facilities in Carrington, Manchester, using Highview’s proprietary LAES technology.

Once complete, Carrington – otherwise known as the location for Manchester United’s training complex – will have a capacity of 300MWh and an output power of 50MW per hour for six hours.

Construction begins on the site now.  Full operation is scheduled for early 2026. Over 700 jobs will be supported during construction and in the plant’s supply chain.

UKIB’s investment reflects its ambition to direct private finance to help new technologies reach commercial scale, as they aid Britain’s transition to Net Zero.

With its £70 million investment, Centrica comes on board as Highview Power’s strategic partner, supporting both Carrington & an accelerated roll-out of the firm’s technology elsewhere in the UK.

Highview believes its programme sets the bar for storage energy systems around the world, raising Britain to global leadership in energy storage and managing grid flexibility.

Highview Power is now at work planning four even bigger LAES plants elsewhere in Britain. The 2.5 GWh facilities, funded with an anticipated future £3 billion, will ensure a fast roll-out of the technology to align with the nation’s LDES (long duration energy storage) goals enabling the ESO’s Future Energy Scenario plans.

Highview Power has developed its LAES technology over 17 years. The technology can store renewable electricity for as much as several weeks, longer than electro-chemical batteries. The company says it is ready to be rolled out at scale, at key grid chokepoints.

Stability services to the National Grid including system balancing, feature among Highview’s business offers, speeding the redundancy of despatchable fossil fuelled power to manage demand volatility.

More manageable storage curbs curtailment costs, too. Last year British bill payers were caught on a £800 million hook, as stilled wind farms claimed compensation simply because the NG was too full to accept their low carbon output.

Highview Power seeks completion by 2035 of its larger UK installations, timed to meet one National Grid scenario of 2GW needed from LAES. That figure would represent nearly 20% of Britain’s energy storage for longer than two hours.

“There is no energy transition without storage” declared Richard Butland, pictured, Highview’s co-founder & CEO.

 “The UK’s investment in world-leading offshore wind & renewables requires a national long-duration storage programme to capture excess wind and support the grid’s transformation.

“UKIB, Centrica and our other partners are backing Highview’s ambitions to bring renewable energy storage into Britain’s economy at scale, liberating the potential of what is both the greenest and by far our cheapest energy source.

Centrica group chief executive Chris O’Shea enthused: “The energy transition is an opportunity that could transform lives. But with the UK’s changing energy mix, and more intermittency from renewables, we have to explore new, innovative ways to store energy so our customers have electricity available when the wind doesn’t blow and the sun doesn’t shine”.

Greater Manchester’s mayor Andy Burnham weighed in too. “My vision is for Greater Manchester to be a leader in the green transition. Highview Power’s decision to build one of the world’s largest long duration energy storage facilities at Carrington is a huge boost for the region.

“This new plant will deliver renewable energy to homes and business across our region and bring world-leading technology, jobs, skills and investment to Greater Manchester. I’m delighted to welcome Highview Power”, Burnham declared.

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To delve into the current state and future prospects of this dynamic market, in this article GridBeyond’s Head of Origination, Neil Garland sheds light on the remarkable growth and evolution of corporate PPAs, the driving forces behind their adoption, and the emerging trends shaping the future of renewable energy agreements. He discusses the intricacies of the regulatory environment, the various models in use, and the innovative technologies that are revolutionising the sector.

Q: Can you provide an overview of the current state of corporate PPAs in Great Britain and Ireland? How have these markets evolved in recent years?

A: The PPA market in UK and Ireland is going from strength to strength. Not only has the number of deals significantly increased, but there has also been a shift in terms of who is doing them. In 2023, c~80% of all deals done (at the larger end) were by corporates with utility suppliers well in the minority. But as the market continues to mature, terms and conditions are becoming more standardised (although no truly standard CPPA exists as of yet), which means that the time taken to negotiate such contracts is gradually reducing.

Q: What is the future outlook for corporate PPAs in GB and Ireland? Are there any emerging trends or technologies that could significantly impact this market?

A: If the contracting process continues to simplify, I predict that we’ll not only see the number of CPPAs being secured increase exponentially, we’ll also see the contracted volume (i.e. in MWh) in CPPAs reduce. If the barriers to entry ease, this should make getting a CPPA more viable to smaller generators and corporate buyers.

As the cost of battery energy storage systems (BESS) continues to fall, we’re seeing an increasing number of collocated projects and hybrid CPPA’s (e.g. solar PV and BESS). Not only can BESS open doors to an wider range of revenue sources (e.g. Capacity Market, Firm Frequency Response and Balancing Reserve), but it can also be used to provide a more tailored export profile to a corporate buyer, by storing excess generation and discharging it when needed.

Q: What are the primary drivers behind the increasing adoption of corporate PPAs in GB and Ireland? Are there specific industry sectors leading this trend?

A: More and more businesses are coming to understand the inherent value of CPPAs. Whilst the majority will be using them as a tool attempt to deliver their net zero strategies, a significant number see value in being able to fix a proportion of their energy volume.

Energy costs can be highly volatile, influenced by fluctuating fossil fuel prices and geopolitical uncertainties. By entering into CPPAs, companies can lock in a portion of their energy costs at a fixed rate for the medium to long term, providing financial predictability and shielding themselves from market volatility. This stability is particularly appealing to large energy consumers who seek to manage their operational costs more effectively.

Additionally, corporate reputation and brand image are influential factors. Consumers and clients are increasingly favouring businesses that demonstrate a commitment to environmental stewardship. Companies that lead in renewable energy adoption can enhance their brand value and differentiate themselves in a competitive market.

In terms of industry sectors driving this trend, technology companies, financial services, and retailers are at the forefront. Technology firms, such as data centres and cloud service providers, are major energy consumers with a vested interest in sustainable practices to offset their significant carbon footprints. Financial services companies are also prominent, often driven by investor expectations and corporate social responsibility mandates. Retailers, meanwhile, are motivated by both customer expectations and the substantial energy demands of their operations, including logistics and large physical store networks.

Q: What are the most common types of PPAs being utilised in GB and Ireland (e.g., physical vs. virtual PPAs)? What factors influence the choice between these options?

A: The virtual/financial CPPA model is most prevalent in Ireland, whilst there is a more even split between virtual and physical sleeved CPPAs in GB.

In my opinion, the key factor businesses need to consider when deciding which model best suits them, is they are happy to commit to the additional reporting obligations that financial derivative contracts require.

Q: Can you discuss the typical pricing structures and contract terms seen in corporate PPAs in GB and Ireland? How do these compare to other regions?

A: Pricing structures and terms in GB and Ireland are broadly similar to other deregulated markets across the globe (including US and EU states). These structures and terms are broadly designed to balance the financial and operational needs of both energy producers and corporate buyers, while also promoting the adoption of renewable energy.

Typically new-build assets will require a long-term contract (i.e. 10 year plus) with a guaranteed price for generation and any associated benefits. Existing assets may be more open to shorter-term contracts and/or variable prices on account of having already made their return on investment.

Q: How do companies manage the risks associated with long-term PPAs, such as price volatility and counterparty risk? Are there specific strategies or tools commonly used?

A: Having two parties willing to agree a fixed price for the full term of the CPPA. This fixed pricing mechanism provides insulation against market fluctuations, ensuring that the costs remain predictable for the volume supplied under the agreement.

There are several tools commonly employed for the purposes of managing counter-party risk, these include conducting thorough credit checks, provision of an Investment-grade Letter of Credit (LOC), Parent Company Guarantee (PCG), holding collateral in a bank account or securing credit insurance or a surety bond. By employing these strategies and tools, companies can effectively manage the risks associated with long-term PPAs, ensuring financial stability and minimising exposure to potential market and counterparty uncertainties.

Q: Which renewable energy sources (e.g. wind, solar) are most commonly featured in corporate PPAs in GB and Ireland? What drives the preference for certain types of renewable energy?

A: CPPAs allow businesses to lower their overall emissions by arranging long-term supply agreements directly from renewable or low-carbon energy sources and increases the proportion of renewable power in an organisation’s energy mix. This supports corporate social responsibility and sustainability goals, reduces the need to purchase carbon permits and can also result in a commercial and reputational advantage.

The most common type of renewable energy featured in CPPAs secured in UK and Ireland is solar, followed closely by onshore wind. There is a strong preference for some buyers to secure electricity from what they consider to be “true green” sources. This is over other forms of certifiably renewable power such as anaerobic digestion, biomass and energy-from-waste.

Q: What are the main challenges and barriers that companies face when negotiating and implementing PPAs in GB and Ireland? How can these be overcome?

A: Credit, term and price.

When it comes to credit, not all buyers are able to satisfy the “investment grade” credit rating requirement (usually least “BBB+” or higher from S&P/Fitch or Baa1 or above from Moody’s.). Whilst there may be some flexibility offered by renewable electricity developers, an alternative solution for buyers is to contract with smaller and/or existing assets where the credit requirements may be less stringent.

Some companies are not comfortable with contracting for a 5/10/15 year term, although this is often a requirement when attempting to source from new build (‘additional’) assets. A solution for buyers is to contract with smaller and/or existing assets where a shorter-term deal may be possible.

Agreeing a satisfactory price for both parties can make or break a negotiation. If the developer of a new build asset doesn’t secure the minimum price he/she needs to meet their investment requirement, the project may not go ahead. Whilst the project should be priced on it’s own merits (technology, scale, additionality, profile and term), it still needs to be competitive versus the wholesale electricity market in order to attract buyers. CPPAs are often inflation-linked (e.g. CPI), meaningly that the developer can recover additional value throughout the term of the contract, even if they have to accept a lower power price initially.

Neil has worked in the energy industry for 16 years, including holding senior energy procurement positions at Hovis, JLR and Aggregate Industries, and as a retailer/consultant with time at e.on, ENER-G, Mitie, and most recently as Origination Manager at Good Energy.

At GridBeyond, Neil provides a link between renewables generators and energy buyers, supporting our clients in navigating the PPA market, identifying the most appropriate counterparties and ensuring that they receive the best revenues and savings from their agreements.

Q: How does the regulatory landscape in GB and Ireland impact the structuring and execution of corporate PPAs? Are there significant differences between the two regions?

A: Whilst the UK and Irish electricity markets have a lot of common due to their shared history, there are some still challenges that exist, particularly concerning Northern Ireland. Renewable generation plants in NI are eligible, like the rest of the UK, to receive Renewable Energy Guarantees of Origin (REGOs) for the power that they produce. Unlike plants in England, Scotland and Wales though, they are not connected to the National Grid and instead they are connected to Ireland’s Single Electricity Market (I-SEM). Ultimately, this makes the process of contracting (and sharing the benefits) between generators in NI and buyers in the rest of the UK or ROI more complicated.

You can download GridBeyond’s White Paper entitled Introduction to Corporate Power Purchase Agreements here. 

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The Danes today confirmed their investment go-ahead to co-locate the 300MW/600MWh storage system, among Europe’s largest, on the Norfolk site.  No cash value was disclosed.

Commissioning the devices is timetabled for late 2026. Co-locating both facilities will minimise disruption during construction and later during operations.

At 600MWh, the Tesla-built battery will host clean wind power in quantities enough to power a nominal 80,000 homes.

Ørsted sees gargantuan coulomb crèches like Swardeston as natural partners for its 12 wind farms now generating in British waters.

The company has 660MW/1,850MWh of batteries either under construction or already in service across the UK and US.  Over 2GW of further amp hotels are in various stages of development in the same regions, plus Ireland.

The departing Sunak administration intended to multiply the nation’s present offshore generation capacity fourfold by 2030, reaching 50GW.  In their manifesto due tomorrow, Labour are expected honour that target.

Duncan Clark, Ørsted’s boss in UK & Ireland, said: “The Swardeston battery will help ensure renewable energy is used in the best possible way by storing it when demand is lower and then releasing it back into the system when really needed. This maximises the potential of renewable energy whilst providing increased energy security and value to consumers. “

Mike Snyder, Megapack senior director at battery providers Tesla, said: “We are excited to be part of this industry-leading project with an exceptional partner. This project demonstrates the value and flexibility of Tesla’s best-in-class power electronics, providing enhanced grid stability and enabling more renewables on the grid.”

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As the number of electric vehicles and battery-powered devices increases, the partnership brings together Enva’s nationwide collection infrastructure and extensive relationships with car dealerships, along with Altilium’s expertise in the recycling of old EV batteries and recovery of critical materials, including lithium.

Altilium’s proprietary EcoCathode process converts end-of-life EV batteries and manufacturing scrap into sustainable battery precursors, cathode active materials (CAM) and cathode precursor (pCAM) for direct reuse in new batteries.

Across its 38 sites in Britain & Ireland, Enva deploys latest technologies to recover as many valuable secondary materials as possible from industrial scrap.

Under the agreement, Enva and Altilium will work together to explore initiatives including the safe collection of EV batteries from across the UK for recycling using the EcoCathode process.

Using advanced hydrometallurgical recycling processes, Altilium can recover over 95% of the battery metals, in a format that can be directly reused in the production of new batteries.

The arrangement benefits Altilium by removing the need to set up its own collections, and in supplying relationships with waste producers and automotive OEMs.

The partnership will also provide feed Altilium’s intended Teesside refinery. Coded as ACT 4, Teesside is planned as Britain’s only depot refining lithium ion to battery-ready Cathode Active Materials (CAM), of high enough quality for direct re-use in making new batteries. Teesside will be big enough to recycle batteries from 150,000 EVs every year, producing 30,000 tonnes of CAM, enough to meet 20% of Britain’s expected demand as this decade ends.

Michael Sneath, head of Enva’s batteries division, commented: “Expert handling and storage of this potentially hazardous material is paramount.

“This collaboration will solve an emerging problem for our customers, enhancing the UK’s recycling capabilities and contributing to the circular economy by transforming used batteries into valuable raw materials for new batteries.”

His counterpart at Altilium, Rod Savage responded: “By leveraging Enva’s collection network and our processing expertise, we aim to set a new standard in battery recycling, ensuring maximum recovery of materials and supporting the growth of the EV market in an environmentally responsible way.”

Before the early 2030s, over 100 million EV batteries worldwide are expected to end their working lives.  By recycling Britain’s share within our borders, Altilium & Enva intend that valuable resources remain in the UK supply chain.

Altilium is the UK’s only company in upcycling old EV material to produce high nickel CAM for direct re-use in new powerpacks. Its proprietary EcoCathode process results in a 60% reduction in carbon emissions and 20% lower costs compared to virgin materials.

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Believed to be the biggest deal of its kind in the world, the contract will connect just over 50% of GRID’s large-scale batteries to Octopus’ technology platform Kraken.   Kraken’s unique AI and machine learning optimisation will charge GRID’s batteries at times of renewable energy glut and discharge them when Britain’s National Grid is under stress.

Such intelligent flexibility reduces wasteful instances of ‘curtailment’ or jettisoning cheap clean power when too much electricity – both low carbon & thermal – swamps Britain’s  transmission  & distribution networks.

‘Curtailment’ left UK energy bill payers with a staggering £800 million of costs in 2022.

Launched in 2018, Gresham House is the largest battery investment fund in the UK, owning around one-fifth of UK utility-scale storage. Octopus will take over half of GRID’s British-based large-scale battery fleet for the next two years.

Those 14 large-scale amp hotels & coulomb crèches can store in excess of 900MWh of electricity  – enough to power 1 million homes for an hour, or a city the size of Birmingham.

Its deal with Gresham House follows hot on the heels of Octopus reaching 1GW worth of shiftable load – the largest virtual power plant in the UK – through its electric vehicle (EV) tariff, Intelligent Octopus Go.

The supplier’s head of flexibility Kieron Stopforth said: “Every year the UK loses hundreds of gigawatt-hours of clean energy because our system isn’t flexible enough to keep it – PLUS have to pay for this senseless waste.

“Batteries unlock the clean and cheap energy system, storing green energy when it’s plentiful and providing it back to the grid when energy is expensive – and work even better with brilliant tech to manage that optimisation,

“Through this landmark deal with Gresham House Energy Storage Fund, we’re not only increasing the size of our virtual power plant to over 1.5GW, we’re also unlocking the power of flexibility, aiming to drive down grid costs.”

Ben Guest, fund manager of Gresham House Energy Storage Fund plc & MD of Gresham House New Energy, said: “These new contracts with Octopus Energy secure revenues which are above those currently being achieved in the national market, demonstrating the value batteries can provide in balancing supply and demand for retail and wholesale market players.”

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The introduction of this larger European fleet of small, mid- and large-size BESS forms part of Aggreko’s Greener Upgrades initiative, which is aimed at supporting customers move to greener solutions. In 2023, Aggreko Europe invested over $140m in its Greener Upgrades portfolio, increasing its fleet of new steam boilers, Stage V generators, battery storage, oil free air compressors and chillers.

As companies look to reduce their emissions in line with net zero targets and strategies, the ability to draw on temporary solutions that enable them to navigate the energy transition, balancing the need for resilience with economic viability. Being able to adopt this technology will enable the organisations to balance their power use and improve flexibility as they introduce more renewable power provision to their sites.

Rodrigo Salim, Head of Product Line – Battery & Energy Storage at Aggreko said, “Many industries are making their transition to renewable power, and within that must balance intermittency and the skills gap. By consulting closely with customers and providing greener solutions like BESS in a rental capacity, we can help unlock opportunities for our customers so they can scale up their own decarbonisation efforts.”

Whether using a battery solution in a hybrid set-up or on their own, Aggreko says the enhanced BESS fleet will help in reducing emissions, lower NOx fuel consumption and help to solve capacity constraints and provide off-grid power resilience as part of a decentralised energy solution.

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The DNO says its latest tender offers a broader mandate and a more streamlined process for participation compared to the previous tender.

Highlights include:

• 486MW of flexibility sought across 29 locations in Greater Manchester, Cumbria & Lancashire
• access to a combined revenue of more than £7 million over a four year period

The tender is now available on both ElectronConnect and Piclo Max, providing multiple avenues to participate and greater visibility.

Flexibility services, which offer a smarter, more efficient alternative to traditional network reinforcements, are set to play a crucial role in managing energy demand and supply effectively across the North West.

“Our spring flexibility tender reflects our commitment to a more inclusive and accessible flexibility market,” said Ben Grunfeld, strategy and growth director at Electricity North West.

“We are seeking significant capacity from across the North West, and we are making it easier for flexibility providers to participate through industry-leading platforms like ElectronConnect and Piclo Max.”

Building on the foundation set through previous tenders, this latest call for flexibility services marks a pivotal step in adapting to the changing dynamics of energy consumption, generation, and trading.

Full details on the spring tender, including the interactive flexibility map showcasing our latest requirements and the ability to book a one-on-one discussion, can be found Electricity North West’s website: Latest Requirement – Flexible Services.

In 2022, ENW appointed Gillian Williamson as its chief technical officer, one of the first women to hold a senior engineering role in regional distribution.

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Chemicals-to-energy combine Worley and advanced battery technologists Nano One are teaming up to boost deployment of the latter’s One-Pot process.  It makes high-quality materials for cathodes, while claiming a lower environmental impact than prevailing alternatives.

Crucially, say the partners, One-Pot eliminates wastewater contaminated with sodium sulphate, a major challenge in current processes for making cathodes, the electron-emitting terminals of most batteries.

Sodium sulphates are commodities used in much industrial chemistry, including as a filler for dry detergents and in bulking up wood pulp to make paper.

The strategic alliance could be instrumental in accelerating the development and deployment of a new generation of battery cathode material plants sold and licensed to operators globally.

Nano One and Worley, a multinational with Australian origins, will integrate the One-Pot process into a design package, enabling customers to create competitive CAM production facilities to meet growing market demand.

The initial focus will be on lithium ferro phosphate (LFP) cathode chemistries. Other varieties will be addressed in time.

Worley Chemetics will design and fabricate the process reactors, incorporating metal alloys specifically designed for corrosive environments. Additionally, Nano One and Worley will continue to innovate process and plant designs to create a design-once-build-many growth strategy.

Nano One’s CEO Dan Blondal commented: “We expect this partnership to add value and significantly de-risk the One-Pot process, using Worley Chemetics’ patented metal alloys, reactor design and fabrication capability, and the technical and delivery capability of the broader Worley organisation”.

Laura Leonard, Worley’s group president for technology, fourth from left in the image above, remarked: “Nano One’s innovative One-Pot process is a game-changer for the production and performance of battery materials. Combining Nano One’s technology with our expertise and scale in battery materials will advance Worley’s growth strategy while accelerating the deployment of this important technology.”

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The public welcomes the prospect of zero-emissions aviation technologies, despite unfamiliarity and even some concerns over their viability.

Researchers for the Jet Zero Council, a partnership between the UK government, industry and academia focused on reducing aviation emissions, quizzed 2,000 travellers about their attitude to kerosene-bereft flying.

They found British adults need thorough reassurance that any new aviation technologies are rigorously tested to ensure their safety before they are introduced commercially.

On average, they believe zero-emissions aviation – i.e. battery- and hydrogen-powered aircraft – to be around 15 years off commercial use.

Despite concerns about range and weight, 37% said they would fly on a battery powered aircraft, and a further 40% said they’d consider it. The public is more confident about hydrogen-powered aircraft, with 35% saying they would take a flight powered by hydrogen, and a further 47% said they’d be open to it.

Emma Gilthorpe, CEO of the Jet Zero Council, says, “It’s great to see how confident the general public are about zero-emissions aviation technologies. Battery- and hydrogen-powered aircraft are a crucial part of decarbonising the future of flight, and it is important that industry makes it as easy as possible for the public to embrace these technologies as they enter service”.

Rachel Gardner-Poole, Chair of the Jet Zero Council Zero Emission Flight Delivery Group, says, “It is really helpful to see the views of the general public on these important topics.  Battery electric aircraft are already being used on a daily basis by some UK-based private flying schools, and will expand significantly to urban and rural settings in the near future, with regional flight also anticipated. Meanwhile, emerging hydrogen propulsion will be capable of domestic flights, and in the longer term, international routes will be flown using hydrogen. Jet Zero Council members are at the forefront of this work and it’s very exciting to see that some of these technologies are projected to enter the commercial market before the end of the decade.”

“It’s important to recognise that aviation is already on the journey to net zero. Commercial flights are using Sustainable Aviation Fuel right now, which are a key part of aviations sustainable future, alongside the zero-emissions aviation technologies of the future”.

“As an industry, we need to clearly communicate the safety and performance of these new technologies and I look forward to the day when transatlantic flight has zero impact on the environment.“

To find out more about the Jet Zero Council, visit https://www.gov.uk/government/groups/jet-zero-council.

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Work at the facility of trial partner Sibelco – illustrated – will start in coming weeks, with commissioning scheduled for September, the hydro engineer said today.

Low-carbon electricity made by RheEnergise’s 500kW HD Hydro demonstrator will support Sibelco’s operations at times of high power demand. The Cornwood mine produces kaolin, mainly for sanitary ware, ceramics, tiles and industrial applications.

Funding the proof-of-concept trial are the government’s Longer Duration Energy Storage (LODES) Demonstration Programme. Devon County Council’s planners also permitted the project.

RheEnergise says its high-density R-19 fluid, two and a half-times heavier than water, is more potent in generating clean electricity when released from lesser heights & in smaller amounts than from conventional dams.

Low-rise hills, not mountains, are thus the sites RheEnergise sees as fitting its intended grid-scale provision of 4 to 16 hours of storage in the 10MW to 100MW power range. It calculates Europe alone has around 115,000 suitable spots, lending themselves to grid connections.

Founder Stephen Crosher says the firm has received enquiries from 30 countries about its technology. In February the firm raised £335,000 from the Low Carbon Innovation Fund.

RheEnergise says its offering is among the few methods of utility-scale power storage which can be scaled up quickly and globally.  One forecast foresees the world’s long duration energy storage (LDES) market growing to US $4trillion by the late 2030s.

Ben Uphill, director operations at its partner Sibelco said “We are looking at new ways to manage and secure our future energy needs, so we’re excited about the potential contribution that RheEnergise’s world-first hydro storage project can make to our operations. ”

Crosher said the firm intends to have its  first 10MW grid-scale project in operation within two years.

“We are hugely appreciative of the support and assistance given to us by Sibelco, the Department for Energy Security & Net Zero and Devon County Council”, he commented.

“Our scheme will help Sibelco’s energy security at Cornwood and show the long-term contribution it can make to the company’s Net Zero ambitions.”

RheEnergise will be exhibiting at the Innovation Zero event at London’s Olympia on April 30 and May 1.

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