The project has a power output of 5MW and an energy storage capacity of 10MWh and can be operated at up to 20% overload for short periods. The 4,400 modules are divided into four BESS containers, pictured above.
The four BESS strings are each connected to an inverter and a medium-voltage transformer, and the entire project has a useful life of over ten years. The BESS is partly powered by the plants solar array which totals 9.4MW, and has numerous use cases.
Alwin Schmid, head of electrical engineering at Porsche, said the project was both about the environmental aspect of reusing batteries but also ‘stacking’ revenues and use cases of the BESS in an innovative way.
“Of course, this is about environmental aspects and the core issue of the energy supply. But it was also important to us to take a pioneering role with the storage system.”
“In this unprecedented model project, we were able to combine a number of different goals, including peak load capping, optimisation of self-consumption and simultaneous participation in the energy market.” 
It will be fully integrated into the energy market ‘in very marketable form’ by the end of the year, Porsche added.
The company want to make the Leipzig plant more economical and increase its self-sufficiency, said Jonathan Dietrich, overall project manager for battery storage at Porsche.
“We hope to gain insights from the project in order to be able to equip other Porsche locations with similar systems and capabilities in the future. At the same time, we can utilise batteries from test cars that are no longer suitable for demanding use in the vehicle for a second useful deployment before their final recycling,” he said.
Project is one of the larger second life BESS around
The project is one of the larger BESS projects around deployed using repurposed EV batteries. The largest Energy-Storage.news is aware of are 12MWh and 28MWh systems in California, both deployed by firm B2U.
In Germany, three totalling 25MWh will be built by ABO Wind and Tricera while a 25MW system commissioned two years ago was partially made up of second life batteries.
Second life BESS technology holds promise and will continue to be deployed as the stock of used EV batteries grows, but rapid price falls of new batteries and BESS has reduced the economic benefits of doing it (Premium access article).
One electric vehicle (EV) company executive working on energy storage recently told Energy-Storage.news that the firm had looked at second life BESS in great detail but that the maths behind it no longer added up.

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Postponed projects explain fall, ‘lumpiness’ to continue and international business more profitable than US
CFO Ahmed Pasha explained that the company’s results will continue to be ‘lumpy’ over the four quarters of the year as it works on a relatively lower number of very high-value projects, so project timing has a large effect. Put simply, revenues could differ greatly from quarter to quarter for the foreseeable.
Pasha went on to explain that the fall in Q3 was primarily down to the postponement by a customer of two projects that would have been worth US$100 million, and the signing of certain projects in its backlog were delayed. The reasons for the delay were nothing to do with interconnection issues, however, and more around “site readiness, civil works, permitting and the customer decision process”, Pasha said.
Interestingly, CEO Julian Nebreda confirmed an analyst’s suggestion that the firm’s international activities have a higher average selling price (ASP) and higher margins than the US business, and the higher weighting to international activities in the quarter explained the higher profits. “We have seen a lot of profit in the international markets,” Nebreda said.
The reasons include the fact that the firm’s offering internationally tends to incorporate engineering, procurement and construction (EPC) services as part of a more broader offering. The firm has also been actively selling its storage-as-transmission product, the Ultrastack, in the European market which has a higher ASP.
US cells
Fluence has also revealed that it has secured US-manufactured cells from AESC (Automotive Energy Supply Corporation), a joint venture between Nissan and Tokin Corporation which is building gigafactories in the US. Those cells will enable it to provide BESS that meet the criteria for domestic content tax credit incentives under the Inflation Reduction Act.
Several analysts quizzed Pasha and Nebreda about this. Nebreda said the cell costs were “very competitive” “and that “everybody realises this is the right move, and we’re ahead of everybody”.
In response to an analyst question around whether US cells could cover all its US demand, he also revealed that Fluence has contracted with AESC for two production lines and has the right of first refusal for any additional lines it brings up.
“So we have ample capacity to meet the demand that we see today and our clearly to meet our commitments,” Nebreda said, although not going as far as saying that would be true in future.
Later, he said: “It’s going to be a tight market, but I think that there will be enough to cover demand, though I don’t know about [if it will be as early as] 2026. But over time, we’ll have enough to cover the demand in the U.S. This is very important and it will happen. We will work to meet that demand.”
40% of US demand relates to data centres
Nebreda also said that 40% of its US projects were ‘indirectly’ related to data centres. By this, he meant that 40% of projects were being deployed to support renewable energy power purchase agreements (PPAs) being procured by big tech players to supply their growing data centre demand with clean energy.
SEC investigation and independent law firm enlisted
In February this year, short selling investment firm Blue Orca issued a short note on Fluence alleging numerous financial improprieties and major shareholder AES, and a US affiliate of its other major shareholder Siemens, were both unhappy with the company’s performance – something Fluence immediately denied.
In a 10-Q form filed along with Fluence’s results last week, the company said that, in response to that report, it completed an internal investigation with the help of outside counsel and forensic accountants.
“They looked at every comment and found they had zero merit,” Nebreda said in the call.
The Securities and Exchange Commission (SEC) is however conducting a formal investigation into the company, the 10-Q added.
“Although we cannot predict the timing or the outcome based on the nature of these matters and information requested by the SEC we do not expect it to have a material impact on our financial condition,” Pasha said in the call.
While the markets reacted negatively to the Blue Orca note at the time of its publication, they have reacted positively to the earnings release and discussion last week, trading around 10% higher than before it.

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The PHES plant comprises 10 fixed-speed units and two variable-speed units, all 12 of which have a power rating of 300MW. The variable-speed units are the first in China, and enhance the flexibility of the PHES to adapt to grid load and stability requirements.
It was reported two years ago that the project with all 12 units had been completed but updates since appear to contradict that.
For example, Austria-headquartered technology provider Andritz provided a variable speed unit for the plant and gave the following timeline:

15 March 2023: Stator lifted into pit
4 July 2023: Rotor lifted into pit
Mid-October 2023: The main installation work completed
Early November 2023: Dry commissioning completed
10 November 2023: Wet commissioning officially commenced
27 November 2023: First run of the unit
10 December 2023: First synchronisation test in turbine mode completed

Andritz said that the project saw it take a much greater role in whole power plant equipment commissioning than it had ever done previously. The company is working on several other projects in China too, as well as as in Turkey, Brazil and Scotland (with the Cruachan plant, covered by our sister site Solar Power Portal).
At 3.6GW the Fengning plant is larger than what is widely reported to be the largest existing PHES plant in the world, the Bath County plant in Virginia, US, which has a power rating of 3,003MW.
Larger projects are underway elsewhere, including the 5GW Pioneer-Burdekin project in Queensland, Australia. The Queensland government just announced that 5 kilometres of core samples have been collected and solid granite will now be confirmed structurally through the site.
China brought 6.7GW of hydropower capacity into service last year according to the International Hydropower Association, of which 6.2GW was PHES. It intends to reach 80GW of PHES by 2027 and a total hydropower capacity of up to 120GW by 2030.

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That’s a silly question, of course; there are plenty of components without which an energy storage asset, whether batteries, batteries in hybrid with generation, or using non-battery technology, can’t function.
But if you asked energy storage technology providers what the most overlooked component is in terms of its importance, the energy management system (EMS) might be a common response.
The EMS, sometimes also called the power plant controller (PPC), is essentially the software-based operating system and controls platform which simultaneously monitors, coordinates and optimises the asset during its lifetime.
Wärtsilä Energy Storage & Optimisation (Wärtsilä ES&O) has been in the game longer than most. Its GEMS Digital Energy Platform was originally developed by Silicon Valley energy storage startup Greensmith Energy back in the 2010s before Wärtsilä ES&O acquired the software-specialised system integrator and launched its own energy storage business.
Wärtsilä’s GEMS suite is now on its seventh iteration, as reported earlier this week by Energy-Storage.news as the platform was launched.
Its new features and updates are designed to enable effective control and dispatch in an industry of ever-larger battery energy storage system (BESS) projects, “multi-gigawatt-hour” projects in fact, while helping respond even faster to grid signals.
Combined value
A lot of the value that comes from energy storage is driven by the software and the EMS, says Wärtsilä ES&O’s head of software product management, Ruchira Shah.
“Storage, unlike a solar or wind plant or gas plant, doesn’t have intrinsic value in the same way, because it’s not a generator of energy. It is, at its heart, an arbitrage device, which means that it really matters when you charge and when you discharge and how you make those decisions,” Shah says.
“That’s all software.”
For example, the EMS can be the difference between responding in time to meet market requirements and not; a good EMS can “easily enable” operators to adapt to changing grid codes or when new market opportunities open up.
That doesn’t just apply to standalone energy storage projects; GEMS is an EMS from which any type of energy asset can be controlled, including the gas-fired engine power plants which Wärtsilä’s legacy business divisions manufacture and sell around the world.
It can also mean the coordinated control of, say, solar and energy storage within the same portfolio, or even the same power plant or microgrid. That, again can mean economic value as well as operational efficiency, and in the case of renewables, making low-carbon energy dispatchable.

Wärtsilä GridSolve battery storage hardware at a large-scale project in Ruien, Belgium. Image: Wärtsilä
“Solar is not a schedulable asset, it’s going to produce when it produces, and as an operator you can curtail it, but you can’t make it produce more,” Shah says.
“The interesting thing is that when you combine different assets, like when you combine solar and storage, all of a sudden you can now support, say, a power purchase agreement (PPA) requirement that is looking for firm output in, say, a specific time period that with solar alone, you can’t meet.”
“We support a range of different asset classes, including solar, wind, storage and engine power plants and then we support a range of different markets. I think the challenge for any software player is to be able to understand how those asset classes intersect with that market and also what opportunities you can have when you combine different assets.”
Multi-GWh scale projects
In a 2022 interview with this site, Wärtsilä ES&O head Andy Tang spoke about how average customer product sizes had moved from single-digit megawatt-hours of capacity to double digits and were already at around 100MW/200MWh.
This had been especially true in the US and Australia, two of the markets where the company is most active. Since that interview, the trend has continued, to the point that the GEMS 7 platform is designed to be suitable for projects that go into the multiple gigawatt-hour scale.
“Things are moving so fast in the industry that it’s tough to predict with certainty what projects are going look like in two to three years,” Shah says, but in the case of the rapid evolution of project sizes, the message from customers and the market was clear.
“This was a little bit easier, in the sense that we could see larger projects in our pipeline, and it takes a while for these projects to reach the contract stage, then once they’ve reached the contract stage, there’s often a couple of years before they actually commission them,” Shah says.
“There’s a fairly long lead time. So, in this case, it was a lot clearer where we had to go to. Looking at the pipeline, you had a sense that this is where we need the software to go in the future.”
From a technical perspective, delivering an EMS fit for very large projects is all about the “huge volume” of data that needs to be collected and actioned upon, Shah says, with data coming from metering systems, inverters and power conversion system (PCS) hardware, and of batteries, down to the module level.
That meant designing software and an architecture that could support that volume of data. At the same time, the new platform comes with new visualisations for large sites on the monitoring portal.
It enables users to “zoom out and see a full picture of the site, and then be able to zoom in to particular sections of the site within the user interface (UI),” Shah says.
Market needs faster response times
Wärtsilä claimed GEMS 7 comes with a number of other new enhancements, from upgrades to alarm and monitoring systems to features that enable automated cell balancing and state of charge (SoC) calibration.

GEMS rack at a BESS site in the UK. Image: Wärtsilä
Alongside those, the EMS is also designed to offer lower latency in responding to grid signals, in other words boosting an already split-second response times, which Ruchira Shah says is going to be vital for asset owners looking to participate in increasingly sophisticated classes of ancillary and system stability services applications.
There is generally in the global market a move towards faster response times and decreased latency, Shah says.
She offers the example of Australia’s National Electricity Market (NEM), where 60-second and 5-minute markets are now joined by the 2-second very fast frequency response (FFR) Frequency Control Ancillary Services (FCAS) markets and associated revenue streams.
“As you increase the number of renewables on the grid, and you decrease the number of spinning turbines which provide natural inertia to the grid, you need to replace that somehow,” Shah says.
“You need to be able to have batteries respond to frequency events faster and faster, and so I think that is why globally we’re seeing requests for shorter response times and markets created for assets that can respond faster and faster to the needs of the grid.
So that’s an important piece, a huge part of the core of GEMS, to be able to meet these new market needs and to be able to meet these new types of requirements in terms of reduced latency.”

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However, with grid infrastructure often taking five to fifteen years to plan and permit, in comparison to one to five years for new renewables projects, the current speed of grid build-out is nowhere near fast enough to manage an effective energy transition. 
We certainly still need new poles and wires but transmission-connected batteries can be part of the solution, offering a game-changing solution for grid stability and decarbonisation.  
Transmission-connected batteries are large-scale energy storage systems directly linked to the high-voltage transmission network. Unlike behind-the-meter batteries serving individual buildings, these powerhouses operate at a national level, providing crucial balancing services to the entire grid. 
Energy Superhub Oxford: the first transmission-connected battery project
An innovative model, with a transmission-connected battery at the heart, is Energy Superhub Oxford (ESO) – a project that provides an example for cities looking to expand green transportation, energy, and heating simultaneously, without overburdening the grid. 
Spearheaded by EDF Renewables UK, ESO installed the UK’s first transmission-connected battery, coupled with one of Europe’s most powerful EV charging networks – supporting Oxford’s ambition to reach net zero by 2040. 
ESO’s battery is a unique asset in several ways: it was the first battery in the UK to be connected to the National Grid transmission network and it is the first hybrid battery of its type anywhere in the world, with both a lithium-ion and vanadium flow battery playing a part in the project. 
The 52MW hybrid transmission-connected battery provides balancing services such as frequency response to National Grid, enabling improved flexibility and ultimately greater amounts of distributed renewable generation on the grid of the future. 
ESO has also become a key piece of the puzzle in scaling up green transport in Oxford, with a 7km private cable network offering 10MW of power directly from the UK’s overhead electrical network. This has allowed companies like Oxford Bus Company to bring a brand-new fleet of 104 electric buses to the city– a major win for air quality for Oxford residents. 
This is groundbreaking territory for the battery storage industry, opening up the transmission network to other battery storage developers, who have since been applying to National Grid for similar connections. 
Their role in the market 
At the outset of ESO, it was expected that the transmission-connected battery would spend most of its time trading in the energy markets, and this would deliver most of the revenues, with a smaller contribution from ancillary services like Firm Frequency Response (FFR).  
In reality, however, frequency response services have provided the majority of the project’s revenues. This was primarily due to the introduction of new services, particularly dynamic containment (DC), that resulted in a new market for these batteries.  
Additionally, since ESO’s inception, the energy crisis has resulted in very high prices for the provision of non-battery assets, as well as high price volatility. In this environment, the battery has provided both back up in significant grid stress events, and reactive power.  
In recent years, concern has been raised by the industry that BESS was being consistently overlooked in the Balancing Mechanism (BM), with skip rates for large-scale batteries at 80% on average between November 2022 and May 2023. Since the Electricity System Operator launched the Bulk Dispatch tool in January of this year, there has been significant improvement in weekly dispatch volume for batteries in the BM. Though Bulk Dispatch has certainly improved things for batteries, the Electricity System Operator has some way to go, with the introduction of the 30-minute dispatch rule in the BM and Fast Dispatch set to further improve battery uptake in the BM. 
Change is needed to achieve targets 
The future of a decarbonised UK demands a smarter and more flexible grid. Transmission-connected batteries are not just a supporting act – they are a vital technology that can help accelerate the UK to a net zero future.  
However, the UK cannot fully realise its net zero potential without action from the top. ESO highlighted that in order to ensure successful integration of transmission-connected batteries, we must create an agile and responsive market structure. This demands a regulatory environment that fosters innovation and empowers stakeholders to adapt to the evolving needs of the electricity system – paving the way for more efficient and effective grid management.  
Transmission capacity needs to be vastly expanded, and Ofgem empowered to enable anticipatory grid investment. With delays in getting projects online becoming longer, National Grid and DNOs need to be held to promised timelines.  
The connections queue now stands at 701GW with estimates this could rise to 800GW by the end of 2024. We welcome the work that is currently underway to reform the transmission connections process (with implications for both transmission and distribution connected projects), with the aim of reducing the existing queue and reforming the process for new applicants.
However, a great deal of uncertainty remains surrounding the infrastructure needed to deliver connections and the specifics of the reformed connections process currently under development and its implications for developers of BESS. 
Only with a regulatory environment that supports the growth of renewables can we deliver a smarter and greener grid. 

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The BESS is central to the government’s plans to transition the site, which is about 22km from the nearest city, Rockhampton, to clean energy resources. The government-owned company intends to transform the power station into the Stanwell Clean Energy Hub.

Construction of the Stanwell BESS. Image: Stanwell.
In May 2024, Energy-Storage.news reported that around AU$448 million of the project’s funding will come via a direct investment from the Queensland government via the Queensland Renewable Energy and Hydrogen Job Fund, which was established in 2022 with AU$4.5 billion by Queensland premier Steven Miles’ predecessor Annastacia Palaszczuk.
Mick de Brenni, the Queensland minister for energy and clean economy jobs, said the project would deliver 80 jobs across its construction period and emphasised the potential of state-owned batteries, stating it means “Queenslanders themselves benefit, not overseas shareholders”.
“This battery project is the largest of its kind in Queensland and will create around 80 jobs in construction. What batteries deliver to the Queensland SuperGrid is reliable power. We want to ensure we maintain downward pressure on power bills for all Queenslanders by building more renewable energy and storage,” Mick de Brenni said.
Construction on 600MWh Tarong BESS reaches halfway point
Stanwell also confirmed that its 300MW/600MWh Tarong BESS had reached the halfway mark on its construction timeline. The AU$514 million system will be an addition to the Tarong Clean Energy Hub.
Construction on the standalone battery storage asset being built at the Tarong Power Station site started in August 2023, with hopes to be fully operational mid-2025. Like the Stanwell BESS, it will use Tesla Megapack 2XL battery units, 164 in total.
Work is now underway to connect the battery units to the transformers.
Michael O’Rourke, CEO of Stanwell, said dispatchable energy assets like its Stanwell and Tarong battery projects are “critical as we transform our energy system”.
“The big batteries will play a crucial role in the energy transformation by stabilising energy supply from clean renewable sources, meaning they’ll be able to be charged by sources like wind and solar and pumped back into the grid during periods of high demand,” O’Rourke said.
“This will ensure affordable and reliable electricity for our commercial and industrial customers in Queensland and the Eastern Seaboard. They are a key piece of our commitment to achieving 5GW of energy storage by 2035 and highlights Stanwell’s vision for a sustainable and innovative energy future.”
The Queensland government has been supporting upstream battery manufacturing and materials refining plans within Queensland, in particular seeking to leverage its advantages as a holder of vast natural vanadium resources, the key ingredient in electrolyte for vanadium redox flow batteries (VRFBs) via its Energy and Jobs Plan, an AU$62 billion overhaul and injection of stimulus into the energy sector and local economy.   

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The Valley Clean Infrastructure Plan aims to repurpose up to 130,000 acres of drainage-impaired or water-challenged lands in the Westlands Water District in Fresno County. The District is the largest agricultural water district in the US at 614,000 acres, or 2,400 square kilometres, and serves the agricultural sector.
At full buildout, the plan would include up to 20GW of solar and 20GW of energy storage, which, if achieved, would cover one-sixth of California’s electricity requirements in 2035, MCE said.
In the nearer term, MCE and GCSE have entered a memorandum of understanding (MOU) for 200-400MW of solar and BESS. The 200-400MW BESS would be a 4-hour or 8-hour system. That project would help MCE meet existing mid-term and long-term procurement needs, and the utility is aiming for a commercial operation date (COD) in 2028-2030.
GCSE’s Valley Clean Infrastructure Plan would enable family farms to lease land for clean energy projects and increase water efficiency of the overall region, by concentrating water resources on more productive farmland, it said. Land use, and the perceived threat to farmable land that clean energy projects pose, are huge topics in the industry.
MCE will be the first customer in the programme. It could build the project itself or purchase the resources through power purchase agreements (PPAs). The Inflation Reduction Act (IRA) has made direct ownership of clean energy projects more attractive for non-profit co-operative utilities and aggregators like MCE, because they can benefit from tax credits via direct payments from the IRS.
Fresno County, central California, has been the site of numerous large-scale BESS projects. A year ago RWE connected a 548MWh BESS to an existing solar project there, while last month EDP Renewables did the same (albeit at a smaller scale). Last month we also brought you an exclusive update into a 3GW BESS being developed in Fresno County by NextEra Energy Resources (Premium access).

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Organised by Solar Media, the publisher of Energy-Storage.News and the host of the Energy Storage Summit series, the awards aim to recognise the innovation, dedication, and pioneering spirit that drive the industry forward. 
Since its inception in 2014, Energy-Storage.News has been at the forefront of documenting and supporting the rapid growth of the energy storage sector. The awards offer a platform to acknowledge the significant advancements made and inspire further progress toward a cleaner, more efficient, and smarter energy system.  The awards currently have over 20 categories and are set to attract over 500 attendees, including the most influential figures in energy storage. 
The winners will be celebrated at a prestigious ceremony on 21 November 2024, at the Hilton London Bankside, where industry leaders will gather to honour the exceptional achievements of their peers. 
This extended deadline is your opportunity to apply for one of the 20+ categories and ensure that your hard work and contributions to the energy storage industry receive the recognition they deserve. Whether you are a seasoned veteran or a newcomer, this is your chance to shine and be acknowledged as a leader in the field. 
You can submit your entry here, before the deadline of Friday, 16 August at 23:59 BST. 

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The project is set to be developed on an area of approximately 1,200 hectares consisting of mostly cleared grazing land, about 20km southeast of Dunedoo, in the NSW Central-West Orana region, the location of one of the Renewable Energy Zones (REZ) being developed in the state. The REZ recently transitioned into the delivery phase, as reported by our sister site PV Tech.
Acen Australia said the BESS will enable excess electricity generated by the PV facilities to be captured and released during periods of high demand. The system will also provide grid stability services and backup capacity to ensure the security of supply.
According to documents observed on the EPBC website, the project will look to install approximately one million solar PV modules and associated mounting infrastructure. The site will also include an on-site substation with a connection voltage of up to 500kV.
Construction of the project, which will have an average workforce of 360 throughout the development phase, will last 28 months, with the construction of the BESS expected to take around 16 months. Throughout operations, a workforce of up to 20 people will be required.
It is worth noting that the Birriwa solar-plus-storage project will be located next to two other solar projects developed by Acen Australia, as seen in the image above. These are the 400MW Stubbo solar PV project, at which construction began in November 2022, and the 320MW Narragamba solar project. These projects will connect to new transmission infrastructure developed by the Energy Corporation of NSW (EnergyCo) as part of the Central-West Orana REZ.
Once the Birriwa solar project receives approval, it will be able to transition into the construction phase. It will connect to the Merotherie Energy Hub and the transmission line proposed by EnergyCo NSW.
This article first appeared on our sister site PV Tech.

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CS Energy worked with Tesla and Downer to deliver the Chinchilla BESS, the first operational project in the Kogan Clean Energy Hub.
CS Energy’s Chinchilla BESS comprises 80 Tesla Megapack 2 systems. The Megapack is based on Tesla’s integrated solution, which includes lithium-ion (Li-ion) batteries, power conversion system (PCS), thermal management and controls.
Alongside the Chinchilla BESS, the Kogan Clean Energy Hub includes the Kogan Renewable Hydrogen Demonstration Plant. The hydrogen plant includes the co-location of a 2MW solar farm, a 2MW/4MWh battery, a hydrogen electrolyser, a hydrogen fuel cell, hydrogen storage, and an out-loading facility.
The demonstration plant will have an on-site hydrogen storage capacity of about 750kg. Through an offtake deal with Sojitz Corporation, hydrogen produced at the plant will be exported to the Republic of Palau.
CS Energy CEO Darren Busine emphasised the potential the project could have for the Western Downs community, sharing that CS Energy is “here for the long-term”.
“Getting the Chinchilla Battery ready for commercial operation has taken a large effort from many people and teams across our entire business, from the team at the site who will operate and maintain the asset to our traders in Brisbane who will dispatch its output into the grid,”  Busine said.
“This project, along with our other projects planned for the Kogan Clean Energy Hub, shows that CS Energy is here for the long-term in the Western Downs community.”
Tesla Megapack’s influence in the Queensland BESS market
It should be noted that Tesla’s Megapack system is being utilised across a number of sites in Australia, including RWE’s 50MW/400MWh Limondale BESS in New South Wales.
Indeed, just last week (8 August) energy storage developer Akaysha Energy said it had started construction of its 205MW/410MWh Brendale BESS, also located in Queensland. The project will incorporate Tesla Megapack technology, with Consolidated Power Projects Australia Pty Ltd (CPP) set to deliver the Balance of Plant.

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