Tommy Greer

Arevon Energy has broken ground on the 251 MW Gibson Solar Project, set to be constructed in Gibson County, Ind.

The groundbreaking ceremony was attended by Indiana and Gibson County public officials and leaders, landowners and community members, as well as project partners and the Arevon team. 

The ceremony also recognized Arevon’s partners and collaborators, such as Signal Energy, the project’s EPC contractor. Arevon and Northern Indiana Public Service Company (NIPSCO) executed a commercial contract, which, under the terms of the agreement, NIPSCO will own and operate the project following the conclusion of construction.

“The Gibson Solar Project is a key addition to Arevon’s portfolio, marking the fourth solar project we have under construction in Indiana,” says Tommy Greer, CCO at Arevon. 

“We celebrate not only the start of construction at Gibson Solar but also the transition to clean energy as an opportunity to create jobs and drive economic expansion.”

Arevon recently announced the start of construction for its 192 MW Ratts 1 Solar Project and its 73 MW Heirloom Solar Project. The company also issued announcements on a financing package to build the 228 MW Posey Solar Project and announced Posey Solar’s start of construction.

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The plan, as reported by Energy-Storage.news in July, is based on an initial need determination made by the CPUC, which found that up to 10.6GW of long-lead-time (LLT) clean energy resources should be procured by 2037 in support of California’s 2045 decarbonisation goal.
This would include up to 7.6GW of offshore wind and up to 1GW of geothermal, alongside up to a gigawatt of long-duration energy storage with at least a 12-hour discharge period and up to a gigawatt of LDES with multi-day discharge capability.
The resources were strategically selected for their ability to support California’s greenhouse gas (GHG) emissions reduction goals, scale up the technologies to reduce costs, enhance the diversity of the California resource mix, and enable their more effective integration into the grid.
Solicitations for the geothermal and LDES resources would begin in 2026, for resources to come online between 2031 and 2037, while offshore wind solicitations would begin in 2027 for online dates between 2035 and 2037.
As noted in our July article, several stakeholders responding to a consultation on the strategy were opposed to the inclusion of lithium-ion (Li-ion) battery storage within the scope of eligible LDES technologies.
The California PUC took this into account and selected technologies that energy providers are not procuring in large enough quantities to create scale and lower costs. Pumped hydro energy storage (PHES) resources, on the other hand, are eligible but only for installations of 500MW or under that had already been allocated state funding prior to 1 January 2023.
The regulator wants to establish competition across a broad range of resource categories, encourage competition where possible, and maximise opportunities to reduce costs over time through a series of solicitations.
CPUC, or DWR as the Central Procurement Agency, may decide not to procure certain resources if the cost to ratepayers would be too high. CPUC’s proposed decision including the latest revisions can be seen here.
While the procurement strategy identifies a specific need for LDES resources of 12-hour duration or more, California’s resource mix will likely also see a proliferation of long-duration storage of up to and including 8-hour duration as it nears its 2045 net-zero target date.
The California Energy Commission recently found in a report that in fact the majority of LDES to be deployed in the coming years will likely be 8-hour, from a fleet of energy storage systems (ESS) ranging from 4-hour to 100-hour. This would be highly dependent however on longer-duration systems becoming cost-competitive on a dollars-per-kilowatt basis, as examined in a recent ESN Premium article.

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(Source: Ingeteam)

Ingeteam has supplied its solar PV power conversion systems and controls for two Acciona Energía projects, located in Wharton and Fort Bend counties, Texas. 

The first project, with a 317 MW capacity, consists of 48 transformer stations equipped with 185 Ingeteam central inverters. This is the first large-scale project to be installed and commissioned by Ingeteam for Acciona Energía in the U.S.

The second project has a 458 MW capacity and is equipped with 71 medium voltage full skid-type transformer stations, integrated with 131 INGECON SUN 3Power C Series liquid cooling central inverters. 

The contract signed between the two companies also includes commissioning works and the supply of its power plant controller for both plants.

A third photovoltaic project, also with Acciona Energía, involving 325 MW of solar power for the state of Ohio, is in the final commissioning phase. Here, Ingeteam supplied 62 full skid transformer stations equipped with 124 central inverters and the PPC control system.

“It is most rewarding to continue to work together with leaders in the U.S. market such as Acciona Energía and help contribute to their plans to electrify a sustainable future,” says Ingeteam’s Nohra Nasr.

“Without a doubt, these projects reaffirm their confidence in our technology and service support as a reliable partner. It also motivates us to continue to do things right which ultimately strengthens our leading position in the United States.”

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Construction on the BESS should start immediately with commercial operations expected to begin in late 2026.
Duncan, VP of BMES said: “The Apache Hill project offers Vitis a unique opportunity to expedite its time to market via an advanced development project located at an advantaged position within the ERCOT system. Our teams worked seamlessly throughout the execution process, and we look forward to seeing the project support Texas’ reliable provision of electricity amidst an era of unprecedented demand growth.”
Stephanie Clarkson, CEO of Vitis Energy added: “With ERCOT’s dynamic landscape, making sure projects are in optimal locations is critical to ensuring grid reliability and the long-term success of a project.”
Vitis Energy is a woman-owned independent power producer (IPP) formed in 2022 while Black Mountain Energy Storage (BMES) was founded in 2021 but has become one of the most active BESS developers in Texas, where the grid operator is Electric Reliability Council of Texas (ERCOT).
The ERCOT market is the second-largest for grid-scale BESS in the US after California but is likely to have nearly 10GW online by October 2024. BESS investors are capitalising off some of the highest price spreads in the world and a huge ancillary services market, with ERCOT’s lack of interconnection with other parts of the US making it effectively an island grid.
In the last two years, BMES sold a 700MW portfolio to banking group UBS, 400MW/600MWh to developer Cypress Creek Renewables and 490MW to Peregrine Energy Solutions, all in ERCOT. In project development news, it secured approval for a 1.4GWh project in Wisconsin a year ago though it suffered a setback for a 240MWh project in Texas in July 2024 after a frosty reception from local stakeholders (Premium access).

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Construction on the BESS should start immediately with commercial operations expected to begin in late 2026.
Duncan, VP of BMES said: “The Apache Hill project offers Vitis a unique opportunity to expedite its time to market via an advanced development project located at an advantaged position within the ERCOT system. Our teams worked seamlessly throughout the execution process, and we look forward to seeing the project support Texas’ reliable provision of electricity amidst an era of unprecedented demand growth.”
Stephanie Clarkson, CEO of Vitis Energy added: “With ERCOT’s dynamic landscape, making sure projects are in optimal locations is critical to ensuring grid reliability and the long-term success of a project.”
Vitis Energy is an independent power producer (IPP) formed in 2022, certified as a women’s business enterprise by the Women’s Business Enterprise National Council in 2022, meaning it is at least 51% owned by one or more women actively involved in management. Most BESS IPPs in the ERCOT market are institutionally owned or male-led.
Black Mountain Energy Storage (BMES) was founded in 2021 but has become one of the most active BESS developers in Texas, where the grid operator is the Electric Reliability Council of Texas (ERCOT).
The ERCOT market is the second-largest for grid-scale BESS in the US after California but is likely to have nearly 10GW online by October 2024. BESS investors are capitalising on some of the highest price spreads in the world and a huge ancillary services market, with ERCOT’s lack of interconnection with other parts of the US making it effectively an island grid.
In the last two years, BMES sold a 700MW portfolio to banking group UBS, 400MW/600MWh to developer Cypress Creek Renewables and 490MW to Peregrine Energy Solutions, all in ERCOT. In project development news, it secured approval for a 1.4GWh project in Wisconsin a year ago though it suffered a setback for a 240MWh project in Texas in July 2024 after a frosty reception from local stakeholders (Premium access).

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Solar PV manufacturer Trina Solar will provide the lithium iron phosphate (LFP) battery energy storage system (BESS) units from its storage arm Trina Storage, while H&MV Engineering will construct the project. Trina’s BESS product Elementa uses in-house manufactured battery cells.
Strübbel is in the onshore wind area between Hamburg and St. Peter-Ording, which Aquila said creates ideal conditions for balancing out intermittent renewable energy generation.
Schleswig-Holstein is in northern Germany, where most renewable energy generation is, while most demand centres are in the south. That imbalance creates a need for energy storage, to balance regional differences in supply and demand but also for storage-as-transmission projects, covered most recently here.
System integrator Fluence’s senior manager for policy and market development said on LinkedIn this week that revenues for BESS in Germany have soared this summer, to around €308,000 per MW on an annualised basis, six times higher than in the UK. It’s been a volatile time however, with BESS owner-operator Gore Street revealing that revenues there for the year to March 2024 had fallen by 47% to around €95,000 per MW.
Andrew Wojtek, CEO of Aquila Clean Energy EMEA, said: “Battery storage systems contribute significantly to system stability in an electricity mix with a high share of renewable energies and are therefore a crucial factor for the achievement of our objective of making affordable, clean electricity available to market participants.”
Aquila Clean Energy, part of Aquila Capital, is a renewable and energy storage developer active across Europe and Australia. In energy storage, it was an early mover in Belgium, and is also actively developing projects in Italy, Poland, Australia and elsewhere.

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Alongside that desynchronisation, Kuhi touched on what the firm is hoping to achieve with its first project, the drivers behind Estonia’s grid-scale energy storage market, and more.
Grid-scale energy storage projects are being deployed in other Baltic nations Lithuania and Latvia. Latvia’s transmission system operator (TSO) AST selected Rolls-Royce Solutions for 80MW/160MWh of projects while Fluence has already deployed 200MW/200MWh of storage-as-transmission BESS for Lithuania’s TSO Litgrid.
Energy-Storage.news: What changes in the electricity sector in Estonia are driving the need for energy storage?
Kristjan Kuhi: Estonia and the whole Baltic region is currently rapidly increasing its renewable energy production. The more production of non-dispatchable renewable energy we have on the market, the more the electricity system will need storage to keep prices stable.
So ideally, the development of renewable energy production and energy storage development should go hand in hand.
In addition, the transition to a 15-minute balancing period and the desynchronisation of the Baltic electricity system from the Russian grid will increase the need for storage.
Can you provide an update on the decoupling from Russia and synchronising with the European system?
The desynchronisation from BRELL network is planned for February 2025. The Baltic TSO’s can give a more detailed overview of this plan.
In this project, Eesti Energia is definitely a key player with our dispatchable production capacities which can help to maintain the stability of the Baltic electricity system.
Can you explain your 25MW/50MWh BESS project: why it was launched and what it will be used for?
Eesti Energia will build the company’s first large-scale storage system at the Auvere industrial complex later this year to balance the fluctuations in electricity prices caused by the growth in renewable energy production and to support the stability of the electrical system. This is a pilot project to make sure the solution is suitable both in Estonia and the company’s other retail markets.
Estonia and the Baltics is scheduled to be decoupled from the Russian electricity system in 2025, after which the Baltic electricity grids will have to manage their own frequencies. Storage solutions will help to ensure that the electricity system is operational, i.e. that the balance between consumption and generation and frequency is guaranteed.
As batteries are able to react very quickly to changes in the electricity system, they are ideal assets for ensuring such ‘system services’.
Why did the initial procurement fail to secure a supplier, and how was the second structured differently to be successful?
Since it is our first storage project, we initially mis-evaluated some of the requirements in the first procurement. However, thanks to the feedback from the market, we were quickly able to make adjustments.
Why was LG chosen and when will the project come online?
LG’s proposed project was most suitable for Eesti Energia regarding the technology and its cost.
Can we have an update on your pumped hydro energy storage project?
The pumped hydroelectric power plant project is currently at the pre-study stage, where work continues to develop a commercially viable and technically feasible solution.
What other BESS projects are we likely to see in Estonia in the near future?
The 25MW/50MWh BESS project is a pilot project, which means that we want to convince ourselves that it is possible to design similar storage facilities outside Estonia, i.e. in Eesti Energia’s other home markets in Latvia, Lithuania and Poland.
Future storage plans will depend primarily on the outcome of this large-scale energy storage system, but as things stand, the announced storage device will not be the last.

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Alongside that desynchronisation, Kuhi touched on what the firm is hoping to achieve with its first project, the drivers behind Estonia’s grid-scale energy storage market, and more.
Grid-scale energy storage projects are being deployed in other Baltic nations Lithuania and Latvia. Latvia’s transmission system operator (TSO) AST selected Rolls-Royce Solutions for 80MW/160MWh of projects while Fluence has already deployed 200MW/200MWh of storage-as-transmission BESS for Lithuania’s TSO Litgrid.
Energy-Storage.news: What changes in the electricity sector in Estonia are driving the need for energy storage?
Kristjan Kuhi: Estonia and the whole Baltic region is currently rapidly increasing its renewable energy production. The more production of non-dispatchable renewable energy we have on the market, the more the electricity system will need storage to keep prices stable.
So ideally, the development of renewable energy production and energy storage development should go hand in hand.
In addition, the transition to a 15-minute balancing period and the desynchronisation of the Baltic electricity system from the Russian grid will increase the need for storage.
Can you provide an update on the decoupling from Russia and synchronising with the European system?
The desynchronisation from BRELL network is planned for February 2025. The Baltic TSO’s can give a more detailed overview of this plan.
In this project, Eesti Energia is definitely a key player with our dispatchable production capacities which can help to maintain the stability of the Baltic electricity system.
Can you explain your 25MW/50MWh BESS project: why it was launched and what it will be used for?
Eesti Energia will build the company’s first large-scale storage system at the Auvere industrial complex later this year to balance the fluctuations in electricity prices caused by the growth in renewable energy production and to support the stability of the electrical system. This is a pilot project to make sure the solution is suitable both in Estonia and the company’s other retail markets.
Estonia and the Baltics is scheduled to be decoupled from the Russian electricity system in 2025, after which the Baltic electricity grids will have to manage their own frequencies. Storage solutions will help to ensure that the electricity system is operational, i.e. that the balance between consumption and generation and frequency is guaranteed.
As batteries are able to react very quickly to changes in the electricity system, they are ideal assets for ensuring such ‘system services’.
Why did the initial procurement fail to secure a supplier, and how was the second structured differently to be successful?
Since it is our first storage project, we initially mis-evaluated some of the requirements in the first procurement. However, thanks to the feedback from the market, we were quickly able to make adjustments.
Why was LG chosen and when will the project come online?
LG’s proposed project was most suitable for Eesti Energia regarding the technology and its cost.
Can we have an update on your pumped hydro energy storage project?
The pumped hydroelectric power plant project is currently at the pre-study stage, where work continues to develop a commercially viable and technically feasible solution.
What other BESS projects are we likely to see in Estonia in the near future?
The 25MW/50MWh BESS project is a pilot project, which means that we want to convince ourselves that it is possible to design similar storage facilities outside Estonia, i.e. in Eesti Energia’s other home markets in Latvia, Lithuania and Poland.
Future storage plans will depend primarily on the outcome of this large-scale energy storage system, but as things stand, the announced storage device will not be the last.

Continue reading

Alongside that desynchronisation, Kuhi touched on what the firm is hoping to achieve with its first project, the drivers behind Estonia’s grid-scale energy storage market, and more.
Grid-scale energy storage projects are being deployed in other Baltic nations Lithuania and Latvia. Latvia’s transmission system operator (TSO) AST selected Rolls-Royce Solutions for 80MW/160MWh of projects while Fluence has already deployed 200MW/200MWh of storage-as-transmission BESS for Lithuania’s TSO Litgrid.
Energy-Storage.news: What changes in the electricity sector in Estonia are driving the need for energy storage?
Kristjan Kuhi: Estonia and the whole Baltic region is currently rapidly increasing its renewable energy production. The more production of non-dispatchable renewable energy we have on the market, the more the electricity system will need storage to keep prices stable.
So ideally, the development of renewable energy production and energy storage development should go hand in hand.
In addition, the transition to a 15-minute balancing period and the desynchronisation of the Baltic electricity system from the Russian grid will increase the need for storage.
Can you provide an update on the decoupling from Russia and synchronising with the European system?
The desynchronisation from BRELL network is planned for February 2025. The Baltic TSO’s can give a more detailed overview of this plan.
In this project, Eesti Energia is definitely a key player with our dispatchable production capacities which can help to maintain the stability of the Baltic electricity system.
Can you explain your 25MW/50MWh BESS project: why it was launched and what it will be used for?
Eesti Energia will build the company’s first large-scale storage system at the Auvere industrial complex later this year to balance the fluctuations in electricity prices caused by the growth in renewable energy production and to support the stability of the electrical system. This is a pilot project to make sure the solution is suitable both in Estonia and the company’s other retail markets.
Estonia and the Baltics is scheduled to be decoupled from the Russian electricity system in 2025, after which the Baltic electricity grids will have to manage their own frequencies. Storage solutions will help to ensure that the electricity system is operational, i.e. that the balance between consumption and generation and frequency is guaranteed.
As batteries are able to react very quickly to changes in the electricity system, they are ideal assets for ensuring such ‘system services’.
Why did the initial procurement fail to secure a supplier, and how was the second structured differently to be successful?
Since it is our first storage project, we initially mis-evaluated some of the requirements in the first procurement. However, thanks to the feedback from the market, we were quickly able to make adjustments.
Why was LG chosen and when will the project come online?
LG’s proposed project was most suitable for Eesti Energia regarding the technology and its cost.
Can we have an update on your pumped hydro energy storage project?
The pumped hydroelectric power plant project is currently at the pre-study stage, where work continues to develop a commercially viable and technically feasible solution.
What other BESS projects are we likely to see in Estonia in the near future?
The 25MW/50MWh BESS project is a pilot project, which means that we want to convince ourselves that it is possible to design similar storage facilities outside Estonia, i.e. in Eesti Energia’s other home markets in Latvia, Lithuania and Poland.
Future storage plans will depend primarily on the outcome of this large-scale energy storage system, but as things stand, the announced storage device will not be the last.

Continue reading

The company, founded in 2005, required “significant” equity investment to enable its plans, including the construction of a factory in Queensland, to scale up manufacturing and develop its newest generation of hybrid flow batteries.
Despite receiving commitments from state and federal governments in Australia to support the plans, it was unable to match that investment as required, leading to it entering administration and appointing Richard Hughes and David Orr from consultancy Deloitte as Voluntary Administrators.
In an interview with Energy-Storage.news Premium, to be published later this week, Richard Hughes, a licensed liquidator, said that although he was only appointed to the case last Friday, he is “pretty encouraged by the early interest we’ve had.”
“We’ve got quite a number of parties that approached us, unsolicited, already and we’re only on about business day four. I’m encouraged by the early interest for sure, and we think that there definitely could be parties that come through and do something,” Hughes said.
Trading in the company’s shares remains suspended on the Australian Securities Exchange (ASX), while the administration process effectively protects Redflow and its subsidiaries from creditors.
The Deloitte administrators’ aim is to get concrete proposals for a deed of company arrangement, which is “essentially a contract between the company and its creditors to resolve how those [creditors’] claims will be dealt with in a restructured Redflow.”
Hughes and Orr hope to be able to take a suitable deed of company arrangement to creditors in around a month’s time, with creditors then set to vote to approve it, or not.
“At the moment, I’m calling for people who are interested in essentially leading a proposal like that, or sponsoring a proposal like that, to come forward and have a look and let us know what they would like to do,” Hughes said.
All options could be considered, from investment that injects capital into the company in return for equity, to potential new ownership that could set a new management direction for Redflow, the administrator said, under Australian administration rules, which according to the Deloitte consultant are fairly flexible.  

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