Sunlight Group’s facility in North Carolina, US. Image: Sunlight Group.

Greece-based battery manufacturer Sunlight Group has received €275 million (US$290 million) in loan financing to expand production and research.

The firm has received the funding in the form of seven-year loans issued by a collection of Greek banks, and goes towards funding Sunlight’s five-year business plan which requires €560 million in total. €125 million is being provided by Eurobank and Alpha Bank and €150m from the National Bank of Greece.

Sunlight will upgrade its current production and assembly lines in its facilities in Xanthi (Greece), Verona (Italy), and North Carolina (US) to produce lithium-ion and lead-acid batteries and energy storage systems.

The company also has plans to develop a lithium-ion battery gigafactory in Europe and conduct R&D into battery recycling, to contribute to the development of Europe’s battery supply chain.

Funds will also support further international growth, partly through M&A, as well as R&D into its lithium-based products via the “European Battery Innovation” (EuBatIn) project. EuBatIn is an Important Project of Common European Interest (IPCEI), a transnational state-funded project launched to increase the competitiveness of European industry. Sunlight’s project gained the special status back in 2020.

According to its website, Sunlight Group’s main products are batteries for motive power (machinery), reserve power and advanced technology applications including submarines and torpedos. By the end of 2021, its annualised production capacity reached 3.6 million motive power cells and 150,000 energy storage cells. Total sales increased 54% in 2021 to €271.9 million, while EBITDA reached €24.1 million, up 25%.

The company recently moved to acquire a German battery distributor, Nonnweiler-Primstal-based A. Müller GmbH, according to a filing dated 31 May on the website of competition watchdog the Bundeskartellamt. A. Müller sells small batteries for applications including a variety of internal combustion engine (ICE) vehicles, camping, backup power and other small stationary storage solutions.

Lampros Bisalas, CEO of Sunlight Group, said: “We are heavily investing across our facilities in Greece, Europe and the US to increase our overall production capacity, as demand for lithium-ion batteries in particular continues to outstrip supply.”

“These additional funds will give us the necessary support to address global challenges to lithium supply, as well as the continued R&D required to make lithium-ion batteries the most energy-efficient, cost-effective, and viable green energy solution on the international market.”

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Rendering of CS Energy’s 200MWh Chincilla BESS project, announced by the state-owned group earlier this year. Image: CS Energy.

Queensland, Australia, needs energy storage and the state government has identified batteries as the fastest way to add it to the electricity network.

The government said on Friday that it is funding the rollout of 13 separate large-scale battery storage projects. A state minister described as a “battery blitz” which will create up to 336 local construction-related jobs.

Out of those, 12 will be sized at up to 8MWh capacity each, but state-owned companies will also build a 400MWh battery energy storage system (BESS) that will be Queensland’s largest to date.

While Queensland’s state budget, announced last week, includes support for two large-scale pumped hydro plants, battery storage can be deployed much more quickly, Minister for Energy, Renewables and Hydrogen Mick de Brenni said.

Greenbank, the 400MWh project, “will be a game-changer in the way we operate the grid and will be critical for soaking up our sunshine and wind to feed into the system when Queenslanders need it,” according to deBrenni.

It will be built by transmission system operator Powerlink and utility CS Energy, both owned by the government. The project will be sited at the 275kV Greenbank transmission substation which opened in 2006 about 42km from Brisbane.

Powerlink said the BESS will be 200MW output alongside its 400MWh capacity, with construction expected to begin next year and take about a year and a half to complete.

Earlier this year, CS Energy also committed to the deployment of a 100MW/200MWh BESS near Chinchilla, a town in Queensland’s Western Downs region. That project will be part of a green energy hub at the site of CS Energy’s Kogan Creek coal mine and coal power plant alongside a green hydrogen demonstration facility.  

“Adding firm, fast-start generation assets to our portfolio will enable us to more effectively respond to changing demand in the National Electricity Market,” CS Energy CEO Andrew Bills said.

A feasibility study is also being conducted for the possibility of a 300MWh BESS project at CS Energy’s Stanwell coal plant, Energy-Storage.news reported last June.

The 12 other projects mentioned in a joint statement from ministers will be built by another state-owned entity, Energy Queensland, which is involved in electricity distribution, retail and energy services. The group has already completed five other battery storage projects

At a recent national Energy Ministers Meeting, the consensus among the forum was that the delivery of more renewables and storage will be the best way to mitigate the impacts of global energy market challenges on Australia’s own market, de Brenni said.

Queensland wants to maximise use of renewable energy

Queensland has historically been the highest emissions-producing Australian state and has lagged on climate policies but is targeting 50% renewable energy by 2030, coupled with a 30% reduction in emissions against 2005 levels by that time. It has already surpassed the 20% renewable energy mark.

The state has some of the highest levels of rooftop solar uptake in the world, Treasurer Cameron Dick said, and large-scale battery projects like Greenbank “allow us to capture the energy generated by Queenslanders, and best use it for Queenslanders,” Dick said.

In 2021 however, the state only accounted for just 8% of Australia’s total battery storage market including all segments from residential to grid-scale, while it placed third for utility-scale battery storage installed capacity among states as of the end of last year, according to research from solar market consultancy SunWiz.

In other developments from Queensland, a proposal for a fossil fuel peaker plant filed by Quinbrook Asset Management was radically altered from a planned 1,000MW of gas turbines to instead couple just 150MW of turbines with battery storage. That revision earned the project the development approval green light from Queensland’s Planning and Environment Court (P&E Court) in April.

The state government also said earlier this month that it is putting A$48 million (US$33.2 million) into feasibility studies and other development assistance to progress two potential new pumped hydro energy storage (PHES) plants, including one at Borumba Dam reservoir, water treatment and irrigation facility.

This would be in addition to Kidston Stage 2, a PHES plant currently under construction by developer Genex Power – which incidentally is also building a 100MWh BESS facility as well as large-scale solar and wind in the state – Australia’s first new PHES since the early 1980s.

The last one built before that, Wivenhoe pumped storage plant, is also in Queensland. A recent report from the Australian Energy Market Operator (AEMO) found that due to extreme electricity price volatility, Wivenhoe’s utilisation in Q1 2022 was 551% increased from the same period last year, helping drive record quarterly high spot market revenues for Australia’s fleet of PHES plants.

“This week’s budget backs nation-building, game-changing pumped hydro storage projects in Kidston and Borumba, but batteries are the form of storage we can get into the network the fastest,” Minister de Brenni said, highlighting that the 400MWh Greenbank BESS brings the government’s commitment to investing in batteries up to more than 720MW of projects.

Queensland’s government, led by premier Anastasia Palaszczuk and the Queensland Australian Labor Party, announced its 2022-2023 state budget on 21 June, including provisions for progressive coal royalties, committing power plant operators to pay higher fees back to the state for periods of increased profits.

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Mammoth Solar

Bank of America has signed a 15-year, 160 MW agreement with Constellation Energy Corp.to purchase power and project-specific renewable energy certificates (REC). This agreement will help Bank of America power approximately 17% of its global electricity consumption with clean, renewable energy from a portion of the Mammoth Central project, the third and final phase of the broader Mammoth Solar project, which is currently being developed by Doral Renewables LLC in Starke and Pulaski counties in Indiana.

Bank of America will receive renewable energy and RECs from Mammoth Central as part of its retail electricity supply contract with Constellation, which covers locations in Delaware, Pennsylvania and Virginia. By powering its facilities in these locations with solar energy, Bank of America is expected to reduce greenhouse gas emissions (GHG) associated with its energy use by more than 95,000 metric tons annually.

The agreement will begin when the project construction has been completed and the project becomes operational, which is expected in late 2024. By purchasing the RECs, Bank of America is also helping to facilitate the development of this project, which will provide renewable energy to the broader electric grid.

“Supporting utility-scale solar energy projects like this one demonstrates our strong commitment to net zero before 2050,” says Alex Liftman, global environmental executive at Bank of America. “This initiative will enable us to reduce our operational impact on the environment and help drive more renewable energy development in our local communities. It is critical that we accelerate the low-carbon transition by developing and deploying more low-carbon solutions, including a sustainable electric grid.”

Additionally, as part of the bank’s agreement, Doral will establish a pollinator habitat at the solar energy facility. This will enable nature-based benefits in the local community, including enhanced perennial vegetation that facilitates increased environmental benefits and other healthy habitats for pollinators. Bank of America required pollinator habitat specifications when selecting project partners. A pollinator scorecard is used to ensure the habitat meets the standards outlined by environmental nonprofit organizations. Some of the scorecard metrics include how much of the site is covered by wildflowers and native plants, bloom time, the presence of a site management plan, insecticide use, and outreach to the community.

“Through this purchase, Bank of America is demonstrating its commitment to addressing the climate crisis by directly supporting the development of a new-build renewable energy asset,” comments Jim McHugh, chief commercial officer at Constellation. “We’re focused on expanding our suite of sustainable power options, which will soon include an hourly carbon-free solution, to help our customers reach their net zero emissions goals.”

Bank of America will use the Constellation Offsite Renewables (CORe) retail power product to facilitate its renewable energy transaction.

“We are proud that Constellation and Bank of America chose Mammoth to advance their environmental, social and governance goals,” states Nick Cohen, president and CEO of Doral. “Investors all over the world are rewarding clean energy efforts and some of the biggest winners are communities that are being revitalized. Even the bees and butterflies are winners as the deal includes special provisions for a pollinator habitat. This commitment from Constellation and Bank of America is further validation to the economic development efforts of Indiana and the community leadership in Starke and Pulaski counties.”

The Mammoth Solar facilities will be built in three phases. Recently Doral Renewables secured tax equity financing from Bank of America for the first phase, Mammoth North. That financing will enable 400 MW of new solar power upon completion.

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QuickBOLT’s QB2 with 3” Microflashing has officially received Miami-Dade County acceptance, enabling easier permitting processes, greater permit approval coverage and savings on solar installation projects.

QB2 received state approval in Florida in January 2021, meeting state requirements and improving the permitting prospects of installers across the state, but Miami-Dade NOA significantly improves the permitting position of QB2.

Miami-Dade has one of the strictest approval processes in the country due to its high-velocity hurricane zones (HVHZ). All new projects must meet a set of requirements to ensure products are secure when tested against these extreme weather conditions. The Miami-Dade County NOA requires going through a series of rigorous product evaluations, including both structural engineering and water ingress protection.

Having Miami-Dade NOA for both tests in one – as QB2 has – allows installers to skip project-specific stamped engineering and save on permitting costs. This speeds up the permitting process and saves money on each job, in addition to the time savings installers will receive from mounting with QB2, which saves an average of 1.5-2 hours per 7kW system.

QB2 mounts over asphalt shingle and can be installed on flat roofs with rolled asphalt, EPDM or TPO. Mounting over the shingle with QB2’s Microflashing, rather than lifting shingles to install sheet metal flashing, protects the integrity of the roof by maintaining the existing roof protections. Top mounting is made possible by patented BoltSeal mechanical-compression technology and the company’s over 30 years of experience developing wood fasteners with Quickscrews International, parent company of QuickBOLT.

QB2 comes in stainless steel (part #17662) and black (part #17862) for customers that want an all-black solar array. In addition to purchasing direct through QuickBOLT, QB2 can be found at many Miami-Dade County distributors.

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Industria Power’s installed BESS system

The City of San Diego via Gridscape Solutions has awarded Industria Power a construction contract for eight microgrids, saving an estimated $6 million over 25 years in avoided energy costs. Construction is moving out of engineering into mobilization and is set to conclude in December 2022.

Industria Power is the general contractor for this multifaceted microgrid project. As the project developer, Gridscape Solutions was awarded a California Energy Commission (CEC) Advanced Emergency Microgrid grant.  Gridscape then brought in Industria Power to complete the construction of the project. Shell New Energies US will be the asset owner and operator for 25 years.

“Industria Power and Gridscape Solutions continue to work together to develop and construct more than 18 Complex Solar Microgrids at multiple locations throughout California,” said Ralph Ciarlanti III CEO & President of Industria Power.

The City of San Diego prioritized eight building sites, including three recreation centers, two fire stations and three police stations. The facility microgrids include 930 kW of solar photovoltaic systems, 2175 MWh of battery storage and multiple electric vehicle (EV) charging stations.

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Jennifer Logan

The U.S. Department of Energy’s (DOE’s) National Renewable Energy Laboratory (NREL) has named Jennifer Logan as CFO. She joins NREL from the Thomas Jefferson National Accelerator Facility (Jefferson Lab) in Newport News, Va., where she has served as CFO and business/finance director.

“Jennifer brings extensive experience to the laboratory from her career in the national laboratory system, as well other roles in the federal government, and we are excited to welcome her to NREL’s leadership team,” states Martin Keller, NREL’s laboratory director. “As the laboratory continues to grow, Jennifer’s leadership will play a critical role in financial planning and ensure that we have the resources we need to accomplish our mission toward a clean energy future.” 

Prior to joining Jefferson Lab, Logan served for 18 years in various federal contracting and acquisition roles within the U.S. Department of Defense in Virginia. She is a veteran of the United States Armed Forces, beginning her career as an officer in the Air Force.

“It takes a strong support network of financial systems to accomplish critical goals toward the transformation of our energy systems here in the United States and around the world,” Logan says. “I’m looking forward to joining the talented team at NREL and bringing leadership toward positioning the laboratory to fulfill its mission with the best financial tools and processes that are necessary to meet those essential objectives for our energy future.”

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A completed project Harmony Energy worked on in the UK, using Tesla Megapacks. Image: Harmony Energy.

Harmony Energy Income Trust plc has secured a £60 million (US$73.8 million) debt facility from major UK retail and commercial banking group NatWest to support the acquisition of the first project in the developer’s new pipeline.

The 99MW/198MWh battery energy storage project is located in Buckinghamshire, England, and known as Bumpers. Harmony has the discretion to allocate the funds to alternative pipeline projects if desirable.

NatWest has provided the five-year facility with an initial margin of 300 basis points (bps) over SONIA interest rates, which will then rise to 375bps after five years. It is set to be interest-only for the first three years and also provides for an uncommitted accordion that could see the total amount borrowed increase to £130 million over time.

Harmony raised £186.5 million through the placing and offer for subscription of its Initial Public Offering in November 2021. This is helping it expand its battery storage portfolio in the UK, including the company securing a lease for its 100MW Creyke Beck project in February.

NatWest meanwhile has expanded its role in the battery energy storage sector, including providing a £380 million funding package to Gresham House Energy Storage Fund in November 2021, closing the funding round for Fotowatio Renewable Ventures’s 7.5MW/15MWh Holes Bay battery project in October 2021 and completing a financing deal with Statera Energy to support eight new projects in March 2021.

It is also an established lender for the UK solar sector.

To read the full version of this story visit Solar Power Portal.

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Ambri’s liquid metal battery cells are housed in stainless steel casings and then integrated into containerised systems. Image: Ambri.

Early concept rendering of the Vametco mini-grid project. Image: Abengoa.

US startup Ambri has received a customer order in South Africa for a 300MW/1,400MWh energy storage system based on its proprietary liquid metal battery technology.

The company touts its battery as being low-cost, durable and safe as well as suitable for large-scale and long-duration energy storage applications.

Ambri has signed the deal with South African renewable energy power producer and retailer, Earth & Wind to deploy the tech at a combined wind and solar PV generation plant in the country’s Eastern Cape region.

Earth & Wind is yet to begin generating and selling power – the company is developing a large portfolio of wind, solar, hydropower and biomass, with partnership deals and land agreements in place over five provinces in South Africa for more than 15GW of power.

Of that pipeline 2GW of wind and solar has passed the environmental approval stage and the company is preparing to break ground on its first 19MW solar plant this year.

The grid in South Africa suffers frequent outages and network operator Eskom carries out load shedding events regularly to try and manage the system.

Solutions to the issues have included targeted procurements of dispatchable energy, including a large Eskom tender in which solar-plus-storage projects were eligible and won – alongside gas power plants.

This need, coupled with the nation’s climate and renewable energy policy goals will be continuing drivers for energy storage technologies, Ambri said of the customer’s order.

Ambri’s battery cells use liquid calcium alloy anodes with a molten salt electrolyte and solid antimony particles in the cathodes. These are arranged into stainless steel containers and integrated as DC-coupled containerised battery energy storage systems (BESS).

While the batteries operate at a temperature of 500°C, they are safe to operate and are not subject to some of the same safety or technical issues with lithium-ion batteries that can be caused by thermal runaway, electrolyte decomposition and off-gassing, the company claims.

This week, on 21 June, Ambri’s founder and now chief scientific advisor Prof Donald Sadoway won a European Inventor Award for his work on the batteries. The company was spun out of lab work from MIT, where Sadoway is still a professor of materials chemistry at its Department of Materials Science and Engineering.

Sadoway won in an international category at the awards, hosted by the European Patent Office.

“When I look at all the patented technologies that are represented at this event I see an abundance of excellence, all of them solutions to pressing problems. I wonder if the judges are assessing not only degrees of excellence but degrees of urgency,” Sadoway said on accepting the award.

“The liquid metal battery addresses an existential threat to the health of our atmosphere which is related to climate change.”

Founded in 2010, Ambri’s commercialisation activities have gathered pace in the last couple of years. Last year it secured US$144 million in a Series A funding round, at the same time securing a long-term supply deal for the antimony used in its cathode.

Earlier this month, Energy-Storage.news reported that the company will be tripling the footprint of its manufacturing facility in Massachusetts as well as adding an innovation centre to the complex. Ambri said yesterday it will begin shipping batteries to the Earth & Wire project in 2024 and anticipates commissioning of the project in 2026.

South Africa vanadium producer Bushveld could put 180MWh of storage at its own facilities

In related news, vanadium producer Bushveld Minerals has secured financing for a hybrid mini-grid project at its mine in the North West province of South Africa.

The project, at Bushveld’s Vametco Alloy mine, will pair 3.5MW of solar PV with a 1MW/4MWh vanadium redox flow battery (VRFB) system.

It will meet around 10.7% of the mine’s energy needs as well as serving as a demonstration and trial of the technology’s suitability for mining applications.

In late 2020, it was announced that Spain’s Abengoa had been appointed for EPC duties. However, Abengoa is now not associated with the project, a source close to the matter told Energy-Storage.news.

The flow battery system will be provided by CellCube, a manufacturer in which Bushveld owns a 25.25% stake and vanadium for use in the electrolyte is already being taken from the Vametco facility.

Regular readers of this site and our journal PV Tech Power will know that Bushveld is targeting a high level of vertical integration within the VRFB industry: in addition to investing in manufacturers, the company is building an electrolyte processing plant and has launched a subsidiary, Bushveld Energy, which is actively advancing VRFB projects including the Vametco hybrid mini-grid project.

It’s expected to cost about ZAR113 million (US$7.1 million) and Bushveld Energy has provided 40% of the equity, alongside South African investment firm NESA Investment Holdings, which put in the other 60%. Bushveld and NESA have formed a special purpose vehicle (SPV) company for it.

Banking group ABSA has also approved a ZAR64 million loan towards construction. A 25-year power purchase agreement (PPA) is in place.

Bushveld Energy noted that it will log ZAR5.6 million in its own revenues from the project, while its parent company’s mining and processing facilities could potentially host a total 120MW of solar and 180MWh of battery storage.

“This VRFB mini-grid project is a useful proof-of-concept of the greater technological qualities of long-duration VRFB systems when used in conjunction with renewable energy,” Bushveld Minerals Group CEO Fortune Mojapelo said.

“At a fundamental level the project also perfectly demonstrates the sustainable uses for vanadium and positions it as a key metal in the green energy transition.”

Preparation of the site for the mini-grid’s construction began in the first quarter of this year and with the project now full funded, it is expected to be completed during the first half of next year.

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Ground mount solar photovoltaic (PV) modules at the Hickory Park site in Mitchell County, Georgia. Image: RWE.

RWE has begun the operation of its Hickory Park project, a power plant combining 195.5MW of solar PV with 40MW/80MWh of battery storage in Georgia, US.

It is the European utility and power generation group’s largest solar-plus-storage project in the US and energy from it will be sold to utility Georgia Power through a 30-year power purchase agreement (PPA) signed in November 2019.

Construction began in late 2020, as reported by Energy-Storage.news at the time, on the site in Mitchell County.

RWE will operate and manage the 1,800-acre facility, selling energy as well as Renewable Energy Credits (RECs) to Georgia Power. The project had originally been scheduled for completion in late 2021.

The solar PV is directly integrated with the DC-coupled lithium-ion battery energy storage system (BESS), which was supplied by technology provider and energy storage system integrator Wärtsilä.

Wärtsilä has previously said the DC coupling makes Hickory Park a true hybrid resource – leveraging the battery storage to make the solar generation dispatchable and easier to integrate onto the local grid.

While it marks RWE’s biggest solar-plus-storage project in the US to date and its first solar plant in the state of Georgia, the group’s biggest battery project to date by nameplate output is a 60MW standalone BESS it has just brought online in Ireland.

Elsewhere in Europe, the company is currently constructing three much smaller solar-plus-storage projects in its home country, Germany that add up to about 45MW of PV and 20MWh of BESS, all sited at lignite coal mines RWE owns.

These were awarded government contracts for fixed payment alongside merchant fees they can earn on the market, in a so-called Innovation Tender scheme run by Germany’s federal utilities regulator, the Bundesneztagentur.

RWE has other big US solar-plus-storage projects in development including Big Star in Texas which is co-locating 200MW of solar PV with 80MW/120MWh of BESS.

In September last year, the group signed a 200MW/800MWh BESS supply deal with manufacturer LG Energy Solution for its US solar-plus-storage projects, which will be integrated with RWE’s own in-house developed energy management system (EMS).

For Georgia, a major centre for new lithium-ion battery production capacity largely aimed at the electric vehicle (EV) sector, it marks another step forward in battery storage deployment.

In a 2019 integrated resource plan (IRP) – the long-term strategy and planning documents that utilities present to regulators in US markets – Georgia Power requested the state Public Service Commission’s permission to own and operate 80MW of standalone BESS.

This was unanimously approved and the first 60MW/260MWh project in that portfolio then granted approval to proceed in 2020 from the Commission. Wärtsilä was awarded the EPC contract for that project, called Mossy Branch Battery Facility.

The utility issued a 1GW request for proposals (RfP) for renewables or renewables-plus-storage projects in November 2021, and then earlier this year request approval to own and operate 1GW of energy storage in its next IRP filing.

Georgia Power wants to retire all of its coal assets by 2035, including 12 generating units totalling more than 3,500MW of capacity by 2028 along the way.

The utility is seeking to replace that capacity with a mix of resources including 6,000MW of new renewable energy in addition to about 5,500MW of existing renewables capacity and signing 2,356MW of PPAs for natural gas over the next six years.  

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GE’s Red Lake Falls wind and solar farm (Credit: GE Renewable Energy)

GE and its regional solution partner Inogen have selected by Sertavul to build one of the first hybrid wind and solar projects in Turkey. The plant is composed of a 32 MW wind farm commissioned in 2020 that will be integrated with a 30 MW solar plant. Adding solar to the wind farm will enable an overall higher capacity factor and availability for the plant while delivering dispatchable renewable energy into the grid, since the sun shines during the day and the wind often blows strongly at night.

“This project is another stepping-stone for the growth of hybrid power plants in Turkey,” says Prakash Chandra, Renewable Hybrids CEO at GE. “The project will help accelerate Turkey’s energy transition by optimizing scarce infrastructure and improving capacity factor of an existing plant, enabling intelligent dispatch of power and supporting our customer Sertavul to deliver more renewable energy.”

“We are proud to have implemented the first hybrid project in Turkey with the cooperation of Sertavul, GE and Inogen,” states Kemal TAŞ, Sertavul’s chairman of the board. “In recent years, investments in renewable energy sources for clean energy have increased worldwide. With this project, we aim to contribute to our country by using renewable energy sources to increase energy efficiency and reduce air pollution. We plan to increase our energy production with the support we receive from our partners.”

“We are very pleased to be a solution partner in one of the most important projects of our country and the world under the leadership of GE,” comments Ali Murat Soydan, CEO of Inogen. “We believe that there is a great hybrid potential in our country. Here, our most important feature is our ability to implement projects very quickly with local production. We are currently constructing and commissioning more than 4 MW solar power plants per day under the GE structure. It is a great financial advantage to our partners that we work with in these projects.”

Inogen will perform site activities and deliver the sun tracking systems that will help increase the total energy production of the power plant.

For the solar plant, GE will deliver seven FLEXINVERTER solar power conversion units. This project is the first installation of GE’s 4.7 MW solar solution worldwide. GE already delivered 1.3 GW of its FLEXINVERTER technology in Turkey.

GE’s FLEXINVERTER is an integrated containerized solution that combines a solar inverter, medium voltage power transformer and an optional MV Ring Main Unit, all integrated in a standard 20-feet ISO high cube container. The technology is a smart solution that helps deliver a reliable, cost-effective, plug and play, factory-integrated power conversion platform for utility scale solar and storage applications. It helps reduce capital and operation costs and ensure a more reliable plant performance.

The FLEXINVERTER is a key component of GE’s Renewable Hybrids FLEX portfolio that includes the FLEXRESERVOIR and the FLEXIQ technologies. The FLEXRESERVOIR is a systems integrated battery energy storage and power electronics solution for multiple configurations and market applications. FLEXIQ is a digital platform that provides design, operation, and fleet management solutions to enable grid compliance and maximize lifetime customer value.

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