Cuyama is connected to the distribution network operated by utility Pacific Gas and Electric (PG&E) and sells power and grid services into the Californian wholesale power market operated by CAISO.

The project is made up entirely of used electric vehicle (EV) batteries from Honda’s Clarity model. That is different to B2U’s flagship 28MWh Sierra facility, also in California, which uses batteries from a range of vehicles including Nissan, Chevy, Tesla and Ford. B2U didn’t reveal the OEM which made the batteries themselves when asked by Energy-Storage.news.

With its two projects among the largest anywhere in the world made of repurposed EV batteries, we asked president Freeman Hall to discuss how it ensured safe and optimal performance of its systems. A Germany-based second life firm Stabl said earlier this year most second life companies “would struggle” with these over time.

“B2U’s EPS technology is architected to only allow batteries to function within conservative guardrails where battery performance data is monitored in real time, along with hazard detection and other alerts. Batteries are automatically disconnected if guardrail settings are exceeded,” Hall said.

“These points are set well inside the battery’s operational limits for voltage, cell temp, etc. B2U achieves all required permits and UL certification. B2U has conducted extensive testing above and beyond that required for permitting in order to exceed the highest standards to ensure safe and reliable operation of our second life battery systems.”

The company’s business model is different to most others focused on repurposing EV batteries into stationary BESS projects in that it owns and operates its own projects (currently only Cuyama and Sierra) whereas others are technology providers, delivering smaller systems to outside customers. Hall discussed why it had gone this route in an interview with us in February this year.

We asked him for an update on this, how long it took to get a return on its systems, and whether it would move to providing systems to outside parties, to which he claimed returns were double that of first-life systems and that it was looking at third party deals too.

“B2U uses its proven EPS technology to deploy second life batteries in plug and play fashion in large scale BESS that cost about half as much to build and operate as new battery systems. B2U’s facilities earn the same revenue as new battery systems selling energy, ancillary services, capacity attributes, etc.”

“So project returns are double that of new battery systems. B2U is in process with partners and 3rd party customers to increase deployments of second life BESS using its EPS technology. B2U will be expanding outside of California to work in other markets and with 3rd party customers quite soon. Stay tuned.”

Energy-Storage.news did a deep-dive into the topic of second life energy storage for an edition of Solar Media’s quarterly journal PV Tech Power last year.

See all Energy-Storage.news coverage of the second life energy storage space here.

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The project will take advantage of long-term contracts with “a major energy commodity firm” and several California electric community choice aggregators (CCAs), the announcement said.

The announcement also claimed the deal made esVolta and Impact Finance among the first partners to structure tax equity for standalone storage, made possible by the Inflation Reduction Act. For large-scale standalone projects it is the seventh that Energy-Storage.news has reported on, following announcements from Aypa Power, Spearmint Energy, Plus Power, SMT Energy and SUSI, Strata Clean Energy and Eolian.

It is the first tax equity transaction for esVolta, which only develops battery storage projects, and was acquired by Generate Capital last year.

Most large-scale BESS in California are four-hour systems in order to get the maximum payment under resource adequacy (RA), grid operator CAISO’s framework to ensure there is capacity to meet demand without centralised capacity market auctions. A two-hour BESS could bid in part of its capacity to meet the four-hour requirement.

Atlantica Sustainable Infrastructure secures PPAs for two BESS totalling 180MWh

In related news, Atlantica Sustainable Infrastructure has entered into two power purchase agreements (PPAs) with “an investment grade utility” for its Coso Batteries 1 and Coso Batteries 2 projects, both co-located with a geothermal plant in California.

The PPAs run for 15 years and will see the assets receive fixed monthly payments adjusted by the financial settlement of CAISO’s day-ahead market.

Coso Batteries 2 is a 20MW/80MWh project in advanced development expected to come online in 2025, while Coso Batteries 1 is a 25/MW100MWh system coming online in 2024. The two projects require investment of US$35-45 million and US$40-50 million respectively.

California is the largest energy storage market in the US with significant renewables penetration, plentiful land and long-term bankable PPAs helping the market take off, with nearly 7GW of BESS online across grid-scale, commercial and residential systems today.

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Infinity Power is a joint venture between Egyptian developer Infinity and UAE-based investment firm Masdar. Masdar also owns UK developer Masdar Arlington Energy.

Construction on the BESS will start in early 2024 and is expected to be completed and operational in 2025, and will be among the largest such projects in West Africa. It will provide ancillary services like frequency regulation, reactive power and energy charging and discharging. A CCA is similar to a power purchase agreement (PPA).

Senelec estimates that the BESS will save the grid an estimated US$165 million over its operating life, including by reducing reliance on thermal power plants.

Papa Mademba Biteye, general manager at Senelec said: “Senegal is constantly eyeing opportunities to push ahead its renewable energy agenda by embarking on solutions that speeds up its transition to a low-carbon economy.”

“The capacity charge agreement project with Infinity Power plays a pivotal role across both operational and financial levels through a long-term guaranteed performance to provide increased grid stability, integrate renewable energy into Senelec’s electricity grid and empower Senegal in becoming an independent power producer.”

Senegal has been something of a hotspot for energy storage activity in the West Africa region recently.

Last month, Energy-Storage.news reported on the West African Development Bank (BOAD) approving a US$24 million loan for a solar and storage project with 45MWh BESS while in July a co-located project with a 20MWh BESS claimed to be the first dedicated to frequency regulation in the region was financed.

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While it’s logical for Energy-Storage.news to spend most of its time looking at those large-scale projects and who is building them, who supplies them, who owns them and so on, it would be remiss of us if activity in other regions went unreported.

Here then, are three BESS projects in the Northeast US, which while not of the same individual scale as some of the bigger projects we see, help tell the story of BESS adoption across the country.

New York: BESS as alternative to traditional network upgrades

The story of large-scale front-of-the-meter BESS in New York is a complex one, and as reported by this site over the past year or so, has been characterised by a very slow start to even touching the sides in getting to the state’s ambitious 6GW by 2030 deployment target.

Meanwhile, various distribution level projects have been ongoing, and developer Agilitas Energy said earlier this month that it has brought into commercial operation a non-wires alternative (NWA) BESS project for utility company Con Edison.

NWA or non-wires solution (NWS) projects, as the names suggest, are built in locations where battery storage can serve as a cheaper and quicker way to upgrade electricity delivery networks than conventional infrastructure upgrades that also minimises disruption to their operation while being deployed.

Agilitas won a 2019 Con Edison Request for Proposals (RFP) for a NWS in the utility’s networks in the Queens region of New York City. Con Edison (ConEd) was seeking cost-effective guarantees to lower its peak load on three of its networks and Agilitas’ winning proposal was for its standalone BESS in Long Island City.

The BESS, which is 4.8MW/23.7MWh, enables ConEd to defer investing in its network infrastructure in the area for up to four years. Agilitas Energy has a 10-year contract in place to discharge up to four hours of energy stored in the batteries during the utility’s peak demand period from the beginning of May until the end of September.

In an interview in June for Energy-Storage.news Premium, Agilitas CEO Barrett Bilotta said the focus on the distributed end of the BESS market allowed the developer to minimise downside risk as part of its strategy.

Massachusetts: 18MWh of BESS yields US$10 million in savings

Two battery storage systems will help municipally owned Groton Electric Light Department (GELD) in Middlesex County, Massachusetts, make significant cost savings, reduce its reliance on diesel generators and add emergency backup.

Delorean Power, like Agilitas Energy an developer, owner and operator of distributed scale battery storage projects, announced last week that it will carry out two battery storage projects, each of 2MW/9MWh, for GELD.

Expected operational start date for the pair is mid-2024, and the BESS assets will charge from the grid during off-peak times when energy is cheaper and discharge when demand peaks.

In addition to “actively reducing energy consumption during these critical times,” as Delorean Power put it, they also offer opportunities to lower carbon intensity on GELD’s grid, with off-peak times generally representing the hours when renewable energy production is most abundant.  

Delorean Power co-founder and managing partner Rory Jones claimed the projects will “deliver major financial savings to the community of Groton in the range of ten million dollars” over their lifetime.

One project will be built at an existing GELD utility substation, while the other will be at the premises of a new local school which is under construction. The BESS at the school site will also be usable as an emergency backup power source in the event of outages resulting from natural disasters or other causes. The batteries would replace diesel generators which would otherwise serve the same purpose.

Delorean Power is currently also building a 5MW/22MWh BESS for another Massachusetts municipal utility, Holden Municipal Light Department (HMLD), expected to come online in October next year.

Maryland: Pilot helps utility overcome capacity constraints  

BGE, a utility headquartered in Baltimore, Maryland, will benefit from Fairhaven, a newly completed 2.5MW/9.74MWh BESS in the town of Chesapeake Beach.

As with another BESS installed and brought online towards the beginning of this year by the utility, which is a subsidiary of energy holding company Exelon, the system has been developed as a result of a Maryland state pilot programme.

In the pilot, utilities have been tasked with deploying battery storage systems that provide a range of applications, and more significantly will be under a variety of different ownership models. For example, in December last year utility Potomac Edison brought online a BESS paired with EV charging infrastructure.

BGE did not mention which companies provided the BESS technology or carried out the installation in a release sent to media including Energy-Storage.news, but it did note that the utility will own and operate the project, and when not being used to help BGE alleviate capacity constraints on its grid, will be able to play into PJM Interconnection wholesale market opportunities.

BGE said the two BESS projects will enhance reliability of service for 9,000 of its customers, while also allowing the utility to defer investment into undergrounding 10 miles of electric distribution equipment, which would be much more expensive.

Two other Exelon-owned energy suppliers in Maryland, Pepco and Delmarva Power, are also building BESS pilot projects under the Maryland Energy Storage Pilot Project Act of 2019, with the state figuring out the best way forward to hit its target of deploying 3,000MW of energy storage by 2033.   

BGE itself is targeting net zero emissions status by 2050 and aims to reduce operational emissions 50% by 2030.

“Now operational, the Fairhaven battery storage facility is providing nearby communities with improved service resiliency in advance of the coldest days of winter while supporting Maryland’s ambitious clean energy goals,” BGE VP of regulatory policy and strategy Mark Case said.

The new Fairhaven project came online on 10 November, BGE said.

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In total, the BESS units would be spread across nine sites, four of them peakers and the remining five baseload power plants, including four 20MW output storage systems, three 50MW systems and two 100MW systems.

Although neither PREB or Genera PR responded to requests from Energy-Storage.news for confirmation and further information on the approvals ahead of publication, a proposal document from Genera PR submitted to the authority on 27 October was made available on PREB’s website.

Additionally, PJ Wilson, president of the Solar + Energy Storage Association of Puerto Rico (SESA), told Energy-Storage.news the move was a positive one, that would assist LUMA, the entity tasked with coordinating the rebuild and redesign of Puerto Rico’s transmission and distribution (T&D) grid together with FEMA, to manage flows on the network.

“More storage is always a good thing,” Wilson said.

“Deployment of large amounts of large-scale storage should help alleviate potential ‘hosting capacity’ concerns, as well as become an important tool in the toolkit available to LUMA to help avoid blackouts on the island.”

Federal funding sought for BESS buildout

Puerto Rico’s energy sector was already in dire straits due for financial reasons with the Puerto Rico Electric Power Authority (PREPA) declaring bankruptcy in 2017, just a couple of months before hurricanes and then a 2020 earthquake damaged or destroyed as much as 80% of the grid’s infrastructure.

Genera PR – a subsidiary of liquefied natural gas (LNG) company New Fortress Energy – was appointed early this year as manager of the island’s power fleet. Selected by PREPA and the Puerto Rico Public-Private Partnership Authority (P3 Authority) to modernise the fleet over 10 years, the move effectively took the sector into privatisation.

It is at these PREPA legacy facilities that Genera PR proposed building its battery systems, using their existing points of interconnection (POI) to the grid. Genera PR said the intention is to “maximise the electrical injection capacity available without overloading existing grid capabilities”.

As has been seen in many other territories at scale, including the US and more recently the Philippines, batteries can improve the operational and economic efficiencies of thermal power plants, reducing the cost of fuel and maintenance. Reducing the amount of fuel burned can also be of environmental benefit.

Genera PR also posted to its own website a comment from its VP of regulatory affairs Katiuska Bolaños to the effect that the company is working with FEMA and the Central Office of Recovery, Reconstruction and Resiliency (COR3) to get the 430MW buildout federally funded.

Bolaños quoted the estimated cost of the project at US$650 million, and said that after getting PREB approval, Genera PR would begin competitive solicitations for the BESS equipment and for construction services.

“The company’s goal is to begin this process as soon as possible, due to the challenges in manufacturing and delivery time in a project of this magnitude,” Bolaños said.

According to Genera PR, the battery systems would provide a broad range of applications and services for the grid, including grid support ancillary services like fast-spinning reserve, load-levelling, voltage control and frequency regulation.

Batteries can provide many of these services more efficiently than thermal power plants due to the ability of BESS to respond to signals from the grid in microseconds, and inject or absorb power much more quickly, while not requiring time to warm up before going into action.

The BESS would be charged daily during prime solar PV generation hours in the morning to early afternoon.   

How a BESS and peaker co-location project has been planned.

Schematic of the BESS facilities’ locations at power plant sites.

The batteries will charge during the hours of abundant solar generation. Images from Genera PR submission to PREB.

Genera PR noted in its presentation to PREB that 95 load-shedding events have occurred in the territory since October last year, which the systems would help mitigate.

While US and island authorities have sought to bolster the rebuilt grid with renewable energy and battery storage facilities – to some extent even designing the rebuild around those technologies – this has largely been focused on residential and commercial and industrial (C&I) systems, with some success, as this article by our colleagues at PV Tech analysed (Premium Access required). The region sits among the top US markets for residential batteries, according to Wood Mackenzie Power & Renewables.

In July, the US Department of Energy (DOE) said it would allocate just over US$450 million for a rollout of residential solar PV and battery storage in Puerto Rico, representing the first tranche of funding in a billion dollar resiliency programme.

Last week the DOE selected three solar and power equipment leasing and installation companies: Sunrun, Sunnova and Generac, to carry out those installations. They will begin in Spring 2024 and systems will be installed at low-income and vulnerable households, such as those that experience the most frequent outages and those with medical conditions that make them more dependent on electricity.

SESA president PJ Wilson told Energy-Storage.news that the association applauded the DOE’s “approach, development and administration” in disbursing that first set of funds.

“[The] DOE realised that, by far, leases have been and are the most effective financing tool on the island for residential solar and storage systems. By focusing on making already-existing, already-successful lease programs more widely accessible to Very Low Income residents, we anticipate that the programme will achieve its intended result of causing up to 40,000 homes that otherwise wouldn’t have been able to install solar-plus-storage, to be able to do so.”

Wilson also said that while the DOE anticipates the 40,000 home installations to take about five years to carry out, SESA estimates they could all be completed within about 18-24 months, “if administered smoothly”.

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Aaron August

AutoGrid has expanded its partnership with Puget Sound Energy (PSE), Washington state’s largest utility, on a virtual power plant (VPP) solution built on the AutoGrid Flex platform.

PSE and AutoGrid began working together on a VPP in 2021 to provide a centralized application for enrolling, dispatching and assessing the performance of individual and combined programs across PSE’s portfolio. The partnership is now expanding to provide aggregation monitoring, reporting and customer management for all participating programs, empowering PSE to enhance grid reliability and achieve its goals of decarbonization.

The complexity of managing the energy grid through the clean energy transition involves balancing renewables with reliability and ensuring a stable energy supply even in the face of varying conditions.

The AutoGrid Flex platform manages over 8 GW of virtual power plants in nine countries. With the advanced demand response and DER management capabilities provided by AutoGrid Flex and its network of OEM partners and aggregators, PSE will be able to dispatch sufficient capacity to mitigate system peaks in both summer and winter seasons.

PSE’s VPP aims at reducing costs while maintaining reliable energy supply to its more than 1 million residential and business customers. Additionally, the VPP solution allows participating customers to receive monetary incentives for sharing assets with the grid and/or curtailing usage, helping the utility efficiently manage increasing electricity demand.

“This is an exciting partnership for PSE as we work toward our renewable energy goals while maintaining safe, reliable energy for our customers,” says PSE’s Aaron August. “With AutoGrid, we’ll be able to engage our customers like never before to use energy as efficiently as possible, because the cleanest form of energy is the energy you don’t use.”

“AutoGrid is honored to join forces with PSE to demonstrate the power of harnessing distributed energy resources to create a clean, more resilient, and cost-effective grid,” adds AutoGrid CEO Ruben Llanes. “Our partnership will not only help PSE achieve its goals but set a standard to collectively accelerate progress toward a sustainable energy future.”

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The developer claimed it is the largest approved energy storage project to-date in Europe, exceeding the current largest facility in Europe by 50%, implying the current largest facility is around 183MWh.

The claim may be true of continental Europe but, as Energy-Storage.news wrote last week, several larger projects in the UK have been granted approval to begin construction too, including a 640MWh project from SSE Renewables, an 800MWh one from Innova and a 2GWh one from Carlton Power. Going off public reports SSE’s is the only one to have moved past final investment decision (FID) stage, however.

The largest operational BESS facilities in Europe are both in the UK, both owned by developer-operator Harmony Energy totalling 99MW/198MWh each.

The Alfeld project is Kyon’s second large-scale BESS project approval in the space of a few weeks, after a 58MW/116MWh system was given the green light by regulators at the end of October.

It will be built near an existing substation and will help integrate Germany’s growing renewable energy generation resources. Kyon now has permits for almost half a gigawatt of energy storage capacity in Germany.

Grid fee exemption for storage extended to projects coming online by 2029

The project announcement comes a few days after the German parliament voted on the reform of Germany’s energy law (Energiewirtschaftsrecht – EnWG) in a move which spells good news for BESS developers, as system integrator Fluence’s Lars Stephan explained in a LinkedIn post on the day of the vote last week (10 November).

Current legislation exempts energy storage assets from grid fees if they go online before August 2026, but the amendments extend that deadline by three years to August 2029, the company’s senior manager for policy and market development said.

Since developing, permitting and building projects takes “easily three years” the change is significant, he said.

“Investors, get your pipelines ready, the German energy storage market just removed a huge hurdle to large scale investments into Germany.”

Stephan said the change “…enables developers and investors a proper timeframe to not just build single projects, but entire pipelines into a booming German market. And it gives the German regulator a sufficient time frame to reform the antiquated German grid fee structure.”

Grid fees refers to treating energy storage resources as both consumers and producers of electricity, charging them for both importing and exporting electricity to the grid. The removal of this so-called “double-charging” has been called for in other European markets like the Netherlands.

Another positive aspect of the update law is that it now provides a robust mandate that regulator’s actions have to consider system flexibility including the use of energy storage as guiding targets, Stephan added.

“Given the traditionally negative view of the regulator on energy storage, including pretty bold disregard for recent legislation, including an introduction of a storage definition in the EnWG, this is an important guardrail, that will be difficult to ignore.”

Energy-Storage.news’ publisher Solar Media will host the 9th annual Energy Storage Summit EU in London, 21-22 February 2024. This year it is moving to a larger venue, bringing together Europe’s leading investors, policymakers, developers, utilities, energy buyers and service providers all in one place. Visit the official site for more info.

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The BESS, for which the MWh capacity wasn’t revealed, will provide grid-supporting ancillary services as well as “store and distribute sustainably generated energy”, the announcement said. Stockholm Exergi will operate the BESS.

ADS-TEC claimed the project is the most powerful modular large-scale storage solution in Sweden, though the announcement didn’t specifically say it had entered commercial operation. There would typically be a gap of a few months between physical installation of BESS units and full commercial operation to allow for testing and commissioning.

Energy-Storage.news has asked the company to comment and will update this article if and when a response is received.

A larger, 40MW project that system integrator Nidec ASI is building for international independent power producer (IPP) Neoen should be coming online soon, with the start of construction announced in January 2023.

That was the first of a flurry of large-scale projects announced over the course of 2023 so far in Sweden, some of which are early-stage (like two from developer SENS in October and September) or set to come online next year.

Developers and operators are looking to capitalise on high prices in ancillary service markets across the Nordic energy market, something pan-Nordic optimiser Capalo AI recently discussed with Energy-Storage.news.

Energy-Storage.news’ publisher Solar Media will host the 9th annual Energy Storage Summit EU in London, 21-22 February 2024. This year it is moving to a larger venue, bringing together Europe’s leading investors, policymakers, developers, utilities, energy buyers and service providers all in one place. Visit the official site for more info.

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The five battery energy storage system (BESS) projects are all in the southern region of Apulia, where solar PV will be the dominant renewable energy source going forward making load shifting a significant part of the business case for energy storage.

The portfolio’s combined 410MW power and 3,280MWh energy storage capacity indicates a discharge duration of 8 hours, the highest duration typically seen for large-scale lithium-ion systems. Several 8-hour projects in California, US, have gone ahead.

The announcement said the five projects totalled 3,787MWh of energy storage capacity, implying over 9 hours of duration, but a spokesperson for Matrix told Energy-Storage.news the correct figure was 3,280MWh. The discrepancy may relate to the overbuild to account for DC-AC energy conversion or degradation over the project’s lifetime.

They added that the projects are expected to reach ready-to-build (RTB) stage in early 2025.

Developers Energy-Storage.news interviewed for a recent feature on Italy’s burgeoning grid-scale energy storage market for Solar Media’s quarterly journal PV Tech Power suggested durations would be around 4-5 hours, potentially up to 8.

Transmission system operator (Terna) wants an average duration across energy storage resources on the grid to be 8 hours but this is weighted between BESS and pumped hydro energy storage (PHES), which would typically be 10-20 hours.

Yumin Liu, CEO of Emeren Group, commented: “We are not only reinforcing our leadership in the European storage pipeline development, but we are also setting new industry benchmarks, particularly in Italy. We are also extremely glad that the partnership with Matrix is flourishing, bringing mutual success and expansion opportunities to both entities in this rapidly evolving sector.”

See all Energy-Storage.news coverage of the market in Italy here.

Energy-Storage.news’ publisher Solar Media will host the 9th annual Energy Storage Summit EU in London, 21-22 February 2024. This year it is moving to a larger venue, bringing together Europe’s leading investors, policymakers, developers, utilities, energy buyers and service providers all in one place. Visit the official site for more info.

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The project was one of a total eight projects representing 343MW/1,440MWh of battery storage resources selected by Eskom through a competitive tender in mid-2022, along with 60MW of solar PV, aimed at increasing the utility’s available capacity as outlined in its 2019 integrated resource plan (IRP).

The buildout of that portfolio is happening in two phases, with the Hex project among a total 199MW/833MWh of BESS and 2MW of solar PV plants being constructed in Phase 1.

Figures provided by Eskom and reported by Energy-Storage.news in December last year as the 8MW/32MWh Elanskop BESS, another Phase 1 project, began construction, put the total cost of the two phases at about ZAR11 billion (US$630 million). Funders include the African Development Bank, World Bank, New Development Bank and multilateral climate investing platform Clean Technology Fund (CTF). 

Eskom’s application for a generation license for the facility was approved by the National Energy Regulator of South Africa (NERSA) in September 2022. Eskom will own the asset but project developers will carry out operations and maintenance (O&M) duties for a fixed period of five years.

It is understood that in addition to the lithium-ion battery technology which is used at the Hex project, redox flow batteries were also considered as an alternative, according to an environmental and social impact assessment report seen by Energy-Storage.news.

Two BESS technology providers were selected for Phase 1, South Korea’s Hyosung Heavy Industries and China’s Pinggao Group. Both Hex and Elandskap are Hyosung Heavy Industries projects, while among 250 people to have worked on Hex were various local subcontractors, Eskom said in an announcement on business networking site LinkedIn.

Batteries to aid utility and grid operator’s challenging situation

South Africa’s electricity system faces difficult circumstances, with frequent load-shedding events leaving homes and business without power. At the time the 2019 IRP was filed, Eskom’s aim in deploying the batteries was to replace the capacity of retiring thermal generators, but since then it has faced maintenance issues and disruption to the operation of its existing fleet.

A report published earlier this year by the International Institute for Sustainable Development (IISD) recommended that concerted efforts should be made at national and municipal level to promote grid-scale energy storage to help counter those problems, alongside the deployment of renewables.

Eskom’s problems have worsened still since it held the 1,440MWh procurement, with a rash of recent and ongoing, unplanned outages at fossil fuel plants. In April Cape Town’s Mayor said the city would look to deploy a large-scale solar-plus-storage plant in order to reduce its reliance on Eskom’s networks.

Shortly after that announcement the utility itself instructed a rural electricity supplier that it could use battery storage to mitigate the impacts of frequent load-shedding in the town of Frankfort – although the supplier, Rural Free State, was told by Eskom that it would be “unacceptable” for the town to generate its own power using solar PV as part of those measures.

Another procurement for 513MW/2,000MWh of battery storage is also underway to improve Eskom’s situation, launched by the Department of Mineral Resources and Energy earlier this year. The bidding window for that procurement closed in July.

Read more of Energy-Storage.news’ coverage of Eskom here.

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