The news follows the 2021 cancellation of ENGIE’s Puako project in Hawaii, also contracted to NHOA. Image: ENGIE.

ENGIE has pulled out of a large-scale solar-plus-storage project contract in the Western Pacific US island territory of Guam.

The French multinational energy group had in 2019 won contracts to deliver 50MWp of solar PV with 300MWh of battery storage in a renewable energy tender hosted by state electric utility Guam Power Authority.

However, according to NHOA, the system integrator contracted to supply the battery energy storage system (BESS), Guam Power Authority has decided to cancel the tender after ENGIE said the project would not be viable if built in today’s market conditions under the contract prices agreed three years ago.

ENGIE notified NHOA of the Guam Power Authority’s action on 21 July, NHOA said in a presentation of its H1 2022 audited financial results, released on 28 July.   

ENGIE had submitted the lowest bid in the third round of the Micronesian Island’s competitive renewable tender programme to earn the right to a 20-year power purchase agreement (PPA).

It had appointed its storage subsidiary, ENGIE EPS, to supply the turnkey BESS which would be equipped with Samsung SDI batteries.

As regular readers of the site might know, ENGIE EPS then changed hands as Taiwan Cement Corporation (TCC) became the majority shareholder of the company, changing its name to NHOA.

NHOA said its energy storage business line achieved EBITDA breakeven in the first half this this year, reporting €1.8 million positive EBITDA. CEO Carlalberto Guglielminotti said in a webcast that this beat the company’s target of breaking even by the end of the year.

“I am not aware of any other pure player in energy storage that has reached breakeven in history and worldwide. But certainly, analysts and investors that joined the call can correct me if I’m wrong,”   

As mentioned in Energy-Storage.news’ coverage when the unaudited figures were released, energy storage accounted for €72.7 million (US$74.51 million) of the company’s global revenue and income total of €82.2 million for the half-year.

The Guam project had however accounted for nearly all of NHOA’s contracts secured in its energy storage business. NHOA said that as a result, from the next reported period, it will no longer disclose ‘Contracts Secured’ or consider it a performance metric.

NHOA also contracted to ENGIE’s cancelled Hawaii project

Regular readers of this site will also know it’s not the first time ENGIE has pulled out of a large-scale island renewables-plus-storage project with NHOA.

Last October ENGIE dropped a project in Hawaii, which again it had won a tender for with the local utility. Poised to sign a 25-year PPA with Hawaiian Electric (HECO) for Puako, a 60MWp solar PV plant with 240MWh BESS, ENGIE cancelled it.

NHOA would have supplied the BESS and said at the time it was “disappointed” with its former parent company’s decision, with ENGIE citing solar industry headwinds and high grid connection costs among its reasons.

The dropping of the Guam project might come as a bigger surprise however, because ENGIE had fought a battle to keep it: in 2020 after the tender win was announced developer GlidePath, an unsuccessful bidder in the process, had lodged an appeal with bodies including the regulatory Guam Public Utilities Commission (GPUC).

GlidePath’s complaints included an alleged non-compliance with the solicitation’s technical requirements in ENGIE’s bid. COVID19 then delayed that whole appeals process before eventually rulings were made in ENGIE’s favour in court in January this year.

Meanwhile, NHOA’s presentation last week mostly reiterated aspects of the company’s performance already covered in its unaudited results release, but NHOA also offered revenue guidance in the range of €140 million to E€160 million for FY2022 across its three business lines: energy storage, e-mobility and EV fast charging infrastructure.

This was up from previous guidance of €100 million to €150 million.

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Paul Gaynor

Longroad Energy Holdings LLC has received a $500 million equity investment by MEAG, acting as asset management arm for entities of Munich Re, alongside two of the company’s existing investors, the NZ Super Fund and Infratil, a listed entity managed by Morrison & Co. The investment will support Longroad’s strategic shift from a primarily “develop to sell” business model to one that is more oriented towards ownership. It will accelerate the expansion of its current 1.5 GW portfolio of owned assets, to 8.5 GW of wind, solar and storage projects over the next five years.

“This important infusion provides Longroad with the capital to rapidly transition to a strategy biased to asset ownership. It also will fuel our acquisition goals and continue to support our investments in adjacent sectors, as we did recently with Valta Energy in the DG space,” says Paul Gaynor, CEO of Longroad. “We are thrilled to have MEAG join with our existing investors to power our robust growth plans, and we appreciate their collective support as we make strides in implementing our ambitious near-term objectives.”

“This investment is a significant step to further increase the U.S. renewable portfolio for Munich Re,” comments Dr. Alexander Poll, MEAG’s senior investment manager responsible for U.S. infrastructure investments. “Given Munich Re’s strong position in the U.S. insurance market, we are interested in further investing in the United States.” 

“This investment makes an important contribution to Munich Re’s net-zero climate commitment under the Net-Zero Asset Owner Alliance (AOA), which Munich Re joined in 2020,” mentions Martin Kaufmann, senior investment manager at MEAG’s U.S. infrastructure investments. “We are also pleased to have teamed up with professional partners on this investment to build a successful long-term relationship.”

“Longroad has been one of the NZ Super Fund’s most successful investments and, in line with our long-term, partnership approach to infrastructure development, we are pleased to both welcome MEAG as a co-investor and contribute more capital ourselves,” adds Del Hart, NZ Super Fund’s head of external investments and partnerships. “It has been exciting to see Longroad grow since we first invested in 2016 and we look forward to seeing it continue to deliver both strong financial returns and positive environmental and social outcomes.”

“Infratil is extremely happy with this outcome,” says Jason Boyes, CEO of Infratil. “We remain very optimistic about the opportunities and outlook for Longroad. It is well-positioned in a key geography, with high-quality operating assets, built-in growth through its development portfolio and a proven team.  The new investment from a leading global infrastructure investor in MEAG is a strong endorsement of the business and the sector.”

In addition to its 1.5 GW net ownership operating portfolio, Longroad’s track record includes 3.2 GW of developed and acquired projects.  Longroad has a substantial development pipeline of ~15 GW of wind, solar and storage projects across 13 states, including in key growth markets. In Arizona and California, the company is operating and development portfolio of nearly 4 GW and over 3 GW of solar and storage, respectively. The company has a development pipeline of over 500 MW of solar and storage in Hawaii. In Maine, there is a development pipeline of over 1 GW of wind, solar and storage. Longroad operates 306 MW of wind assets, with a development pipeline of over 2 GW of wind, solar and storage in Utah.

In support of its pipeline development, Longroad has established a deep relationship with First Solar and has recently signed a multi-year contract with Powin Energy, affording favorable procurement status and supply chain benefits. Longroad is currently contracted with First Solar for nearly 4 GW of panel supply through 2026, as well as with Powin to procure up to 4.5 GWh of storage through 2025.

Longroad’s financial advisors on the transaction included lead advisor Goldman Sachs & Co., as well as KeyBanc Capital Markets and Lazard Frères & Co. LLC.  Morgan Lewis served as legal counsel. Barclays served as MEAG’s financial advisor, and Holland & Knight as its legal counsel.

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Another Standard Solar project, a 12-building solar carport project for the Northwest Fire District in Tucson, Ariz.

Standard Solar and Anne Arundel County Department of Public Works in Maryland are developing a solar project providing clean energy to Bureau of Utility Operations facilities. The systems will be located in Millersville and consist of a combination of four carports and seven rooftop solar arrays, totaling 1.3 MW.

“This project shows that saving tax-payer money and protecting the environment do not have to be mutually exclusive,” says County Executive Steuart Pittman. “I am proud that Anne Arundel County is a leader in efforts to create affordable clean energy solutions where possible.”

The system is expected to cover more than 90% of the total annual electricity needs of the Bureau’s Complex. In the first year of production, the combined systems are predicted to generate 1,645 MWh of clean electricity.

“This project is critical in helping Maryland further its position as a leader in the nation’s clean energy transition,” comments Daryl Pilon, director of business development at Standard Solar. “Working with local governments like Anne Arundel County to achieve sustainable operations while saving money is a fundamental piece of our nation’s energy solution. And we’re particularly proud to add this project to the company’s ever-expanding portfolio in our home state.”

The Anne Arundel County Department of Public Works solar project is partially funded by a grant from Maryland Governor Hogan’s Energy Water Infrastructure Program.

Currently, Maryland’s Renewable Portfolio Standards (RPS) are on target to reach 50% clean electricity by 2030 and 100% by 2040. This project is another step towards helping the state achieve these ambitious goals.

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University of Toledo President Dr. Gregory Postel

The U.S. Department of Energy (DOE) has launched the Cadmium Telluride Accelerator Consortium, a $20 million initiative designed to make cadmium telluride (CdTe) solar cells less expensive, more efficient and develop new markets for solar cell products. CdTe solar cells were first developed in the United States and are the second-most common photovoltaic technology in the world after silicon.

Without strengthened domestic manufacturing capacity, the U.S. will continue to rely on clean energy imports, exposing the nation to supply chain vulnerabilities while simultaneously losing out on the enormous job opportunities associated with the energy transition. The Consortium’s efforts to spur technological advancements will increase America’s competitiveness, bolster domestic innovation, and support clean electricity deployment supporting President Biden’s goal of achieving a net-zero economy by 2050.

“As solar continues its reign as one of the cheapest forms of energy powering our homes and businesses, we are committed to a solar future that is built by American workers,” states U.S. Secretary of Energy Jennifer M. Granholm. “DOE is proud to partner with leading solar researchers and companies to chart the future of CdTe technology, which presents an immense opportunity for domestic manufacturers to help ensure our nation’s security while providing family-sustaining jobs.”

The new Cadmium Telluride Accelerator Consortium will work on continued cost and efficiency improvements that will make CdTe cheaper and more efficient, and more competitive on the global market. To achieve these goals, the team has a broad research plan that includes CdTe doping strategies, characterizing and exploring new CdTe contacting materials, and work to enable a bifacial CdTe module that absorbs light from the front and back of the module. DOE’s National Renewable Energy Laboratory (NREL) will administer the consortium, whose leaders were chosen through a competitive solicitation NREL released last year. The consortium will be led by the University of Toledo, First Solar, Colorado State University, Toledo Solar Inc. and Sivananthan Laboratories Inc.

“To move America forward, we need an all-of-the-above strategy that propels our energy independence, lowers costs and creates good-paying jobs. Northern Ohio has already revolutionized the field of solar technology,” comments U.S. Rep. Marcy Kaptur (OH-09). “Now, through this remarkable partnership between the U.S. Department of Energy, the University of Toledo and First Solar, our region will become a hub of next-generation energy innovation that is built right here at home by Ohio’s workers.”

NREL will serve as a resource, support and technical analysis center as the consortium develops a technology roadmap, conducts research to meet targets set within the roadmap, and regularly assesses the domestic CdTe supply chain for challenges and opportunities. The consortium aims to expand domestic CdTe photovoltaic material and module production, support the domestic CdTe supply chain, and enhance U.S. competitiveness. 

“Our world requires scientific innovation to address the inefficient ways we find, produce and consume energy,” says University of Toledo President Dr. Gregory Postel. “The University of Toledo is proud to help power the future by leading this consortium that leverages our expertise in solar energy research and commercialization and strengthens our partnership with the U.S. Department of Energy and other leaders in this important and growing field.”

DOE, through NREL and a longstanding partnership with First Solar, has been a leader in CdTe research. DOE’s Solar Energy Technologies Office (SETO) supports innovative research focused on overcoming the current technological and commercial barriers for CdTe cells. SETO has awarded funding for research, development and demonstration of methods to improve reliability and lower the cost of CdTe technology.

DOE’s Solar Photovoltaics Supply Chain Review Report identified CdTe as an opportunity for expanding domestic production of solar panels, up to the limit that CdTe material availability allows, with little risk of being overtaken by low-cost foreign competition.

The FY22 Solar Manufacturing Incubator funding opportunity will support projects that ready new technologies and manufacturing processes for commercialization and demonstrate solutions that can boost domestic manufacturing of thin-film photovoltaics made from CdTe.

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Steve Greenley

CenterPoint Energy’s Indiana-based electric and natural gas business, CenterPoint Energy Indiana South, is seeking approval from the Indiana Utility Regulatory Commission (IURC) to acquire a 130 MW solar array as part of the company’s long-term electric generation transition plan.

CenterPoint Energy has entered into an agreement with Invenergy to construct the utility-owned project in Pike County, Ind., and to acquire the project upon its completion. This project represents the third round of solar agreements introduced as part of the utility’s plan to meet stakeholder sustainability goals and implement a more cost-effective and diversified energy generation portfolio. The agreement is subject to IURC approval. The company was previously granted approval to build a solar array in Posey County now sized at 200 MW, as well as enter into power purchase agreements totaling more than 400 MW in Warrick, Vermillion and Knox Counties in Indiana.

“By seeking to add another universal solar project to our renewable energy portfolio, we continue to move forward with our long-term generation transition plan and remain committed to our economic and environmental goals for the region,” says Steve Greenley, senior vice president of generation development at CenterPoint Energy. “If approved, with the addition of this project, CenterPoint Energy will be adding nearly 800 MW of solar generation to power our southwestern Indiana customers.”

“Invenergy is pleased to be working with CenterPoint Energy to support the utility’s generation transition goals and to provide its customers in Indiana with clean energy,” states Michael Kaplan, senior vice president of renewable development at Invenergy. “Our team looks forward to the completion of this project and growing our project portfolio within the state.”

Construction of the Pike County solar project is expected to begin upon obtaining a decision from the IURC which is expected in early 2023. The project is expected to be placed into service in 2025.

“We are committed to delivering reliable energy generation in the most cost-effective manner for our customers, while contributing to Indiana’s clean energy infrastructure,” adds Greenley. “CenterPoint Energy would like to recognize officials in Pike County for their support of this project and efforts to bring cleaner energy solutions to our communities.”

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Laura Pagliarulo

SolaREIT, a solar real estate investment fund, has executed agreements totaling $12.2 million for solar land with developer Norbut Solar Farms. The deal involves four projects across 500+ acres of land in New York on which are sited more than 84 MW of community solar. SolaREIT, which launched in late 2020, provides a model for financing solar land and offers options to compensate landowners for utilizing their land to host solar farms.

“We’re excited to work with Norbut Solar Farms to grow their business by financing their land holdings,” says Laura Pagliarulo, President of SolaREIT. “Dave Norbut and his team have been developing projects throughout New York for more than two decades and are one of the most well-respected developers in the state. Solar projects require large expanses of land and lease payments that tie-up capital and increase costs for developers. Now more than ever, developers need financial flexibility, so they can focus on doing what they do best – develop solar projects.”

“SolaREIT is providing valuable financial innovation and flexibility to the solar development industry,” states Dave Norbut of Norbut Solar Farms. “We are accessing capital through this deal, which will fuel the expansion of our early-stage solar development efforts across New York. Financial innovation has helped expand residential solar over the past decade; now SolaREIT is bringing innovation to community solar development.”

Community solar development is land and capital intensive. SolaREIT can offer alternative options to developers and project owners that free up capital or reduce their lease costs. Last year, SolaREIT announced their Pre-Paid Solar Land Lease program allowing solar developers to provide landowners with up-front payment for up to 30-years of lease payments.

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RES’ BESS containers in the background at the Scott project. Image: RES.

As Virginia pushes towards one of the US’s most ambitious energy storage targets, pilot battery storage projects have been brought online from the state’s biggest investor-owned utility (IOU).

At the time it passed into law in 2020, Virginia’s target to deploy 3.1GW of energy storage on the grid by 2035 was the biggest of its kind in the nation, aimed at facilitating 100% emissions-free electricity in the state by 2050.

Although the target has since been surpassed by New York Governor Kathy Hochul doubling a 3GW target by 2030 for that state to 6GW, Virginia’s target remains comfortably at the higher end of targets and goals set in the 10 US states so far to have adopted them.

Virginia’s utilities have been instructed to deliver that rollout, with the state setting various rules and frameworks to enable it in early 2021. As the biggest investor-owned utility (IOU) operating in the state, Dominion Energy has to put 2,700MW of that total 3.1GW into service by the middle of the next decade.

In 2019, shortly before the target was set, Dominion had said it would build pilot battery energy storage system (BESS) projects adding up to 16MW of output. The pilot was enabled by an earlier piece of legislation, the 2018 Grid Transformation and Security Act, which let the utility invest in up to 30MW of BESS.

Approval for those projects from the State Corporation Commission came a few months later.

At that time, in February 2020, Dominion Energy Virginia said it aimed to commission the four projects by the first quarter of 2021, but of course the COVID-19 pandemic was declared shortly after that. Dominion said the pilots would cost a total of US$33 million.  

Last week, Dominion Energy Virginia announced that the largest among its pilot projects has just been commissioned.

A closer look at BESS enclosures at the Scott site in Powhatan. Image: Dominion.

Virginia projects try out different applications and configurations

It comprises three independently operating BESS at the same site, adding up to 12MW output. According to renewable energy and energy storage company RES, which delivered the project for Dominion, the storage capacity of the three combined systems is 48MWh.

RES’ Scott Battery Energy Storage System pilot is paired with Scott Solar, an existing solar PV facility in Virginia’s Powhatan County.

It includes one AC-coupled BESS of 10MW/40MWh (four-hours’ duration) to help Dominion match peak load with peak production, i.e. storing energy for when it is most needed by the grid.

The AC-coupled system uses CATL battery cells, Dynapower power conversion system (PCS) and other power electronics with RES’ own energy management system (EMS) controller, RESolve.

The other two BESS at the Scott project are DC-coupled, each one of 1MW/4MWh that demonstrate the ability of the DC-coupled configuration to capture electricity generated at the solar power plant’s peak production, which is otherwise lost.

While battery and PCS providers were not disclosed by RES for the two smaller systems, the company did say it integrates the DC-coupled technology into the solar plant’s existing inverters, using a custom-made solution developer by RES, EVS and ConnectPV.

RES’ Americas CEO John Rhode said the Scott project “paves the way for additional energy storage projects needed to support a carbon free future,” calling it a milestone project for both RES and Dominion in Virginia.

Dominion noted that in addition to the project at Scott Solar, the pilot project portfolio includes two more sites: both are 2MW/2MWh BESS installations at substation sites.

One is in the Hanover County town of Ashland and will demonstrate that BESS technology can be used to bolster the existing grid and allow Dominion to keep serving customers in a region of growing demand without needing to make expensive transmission and distribution (T&D) infrastructure upgrades.

The use case is what has been called the application of batteries as a ‘non-wires alternative’ to those upgrades. The Hanover County project is scheduled to come online later this year.

The other 2MW BESS has already been online since February at a substation in Virginia’s New Kent County. Paired with a 20MW solar PV plant, the system serves to demonstrate how batteries can help manage voltage and loading issues that can be caused by reverse energy flow.

Dominion noted that in March the Virginia State Corporation Commission also approved Dry Bridge, a 20MW BESS project in Chesterfield County and a 50MW BESS project paired with 100MW solar PV at Dulles International Airport, Loudoun County alongside utility-scale and distributed solar PV projects totalling about 1GW.  

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Sites have been selected that have limited access to Eskom’s distribution network, but in proximity to large-scale renewables.

South Africa’s primary electricity supplier Eskom has announced details of forthcoming major battery storage deployments, including project sites and sizes.

The utility and electricity grid operator said on Friday (31 July) that it intends to have the first 343MW of a 500MW national energy storage rollout announced by South Africa’s president Cyril Ramaphosa online by December 2024.

Eskom selected two battery energy storage system (BESS) providers, South Korea’s Hyosung Heavy Industries, and Chinese company Pinggao Group, from bidders in a competitive solicitation process.  

The 343MW of BESS will be four-hour duration, meaning a total of 1,440MWh capacity. The systems will be built in two phases. Phase 1 will see 199MW/833MWh of battery storage built, alongside 2MW of solar PV, while Phase 2 will see 144MW/616MWh of BESS installed together with 58MW of solar PV.

As reported by Energy-Storage.news in March when Eskom said it was in the process of finalising Phase 1 contract discussions, the battery storage systems will help manage peak load on the electricity network, as well as providing other applications like ancillary services.

In April, Hyosung had revealed that had received an Eskom letter of acceptance for a separate 48MW/192MWh project near the city of Durban.

The rollout is being financially supported by groups including the World Bank and the African Development Bank, the latter providing US$58 million support.

Projects will be sited at remote areas with limited access to the electricity distribution network, but which are nonetheless not far from renewable energy plants operated by independent power producers (IPPs).

Eskom described the buildout as a flagship proof-of-concept programme for the role of batteries on the South African grid in enabling the integration of large-scale solar PV and wind into the energy mix, while increasing network stability, reliability and security of supply.

The utility will also build a research and development and testing centre for battery storage systems in Rosherville, Gauteng province.

Phase 1 will see BESS deployed at eight sites, with systems ranging from 1.54MW/6.16MWh for the smallest and 80MW/320MWh at the largest, to be commissioned by the end of June 2023.

Phase 2 comprises installations at four sites, ranging from 17MW/68MWh to 70MW/280MWh, for completion by December 2024.

It is well-documented that keeping lights on in the country has been a challenge for Eskom and South African authorities. One big step already taken by Eskom was the launch of so-called Risk Mitigation Power Procurement Programme tenders, through which it has contracted for energy from dispatchable resources, including natural gas and a significant volume of solar-plus-storage projects.

Of the total 2GW awarded through that tender process, around 430MWh/1,300MWh of energy storage paired with renewables was included. Its biggest winner, Norwegian renewable energy developer Scatec, recently began work on an awarded 540MW of solar PV and 225MW/1,140MWh of battery storage, Energy-Storage.news reported a couple of weeks ago.

Eskom group chief executive André de Ruyter described energy storage as one of the “key initiatives to assist in addressing the country’s electricity challenges in the long-term,” and fitting the aims of South Africa’s long-term Integrate Resource Plan.

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Greener Power Solutions provides mobile temporary storage solutions. Image: Greener Power Solutions.

Mobile battery storage rental company Greener Power Solutions plans to diversify its supply base away from Alfen and has already bought a unit from Northvolt.

The Netherlands-based company recently raised €45 million (US$45.98 million) from DIF Capital Partners, as reported by Energy-Storage.news, to expand its service offering, strengthen in its home market and expand internationally.

It is active in the Netherlands, UK, Belgium and Switzerland, the company told Energy-Storage.news.

Its business model currently centres around buying Alfen’s mobile energy storage system (ESS) units (TheBattery Mobile) and adding value through the delivery and service provided to rental customers looking to replace diesel generators.

“We want the customer to have the same experience as it would have had with a genset, but now a more sustainable choice,” a spokesperson said.

It currently only uses Alfen’s product but has plans to expand to other suppliers and has already tested the waters, as they explained: “We will definitely expand. We already bought one unit from Northvolt, to test if this one also satisfies our high demands for the systems in the very diverse market.”

Northvolt is the European battery gigafactory company which has raised over US$8 billion.

Greener Power also explained that its software can control renewable generation resources integrated with the mobile ESS unit which further allows customers to decarbonise their operations.

“We can control solar, wind and hydrogen. We foresee that we will have a solar array that can be curtailed in the moments the battery is full. We will add a kite power system, so that we can also charge our battery when there is no sun. And for the moments that there is no sun nor wind, we can then use the hydrogen generator. At this point in time there is no good (big enough system) hydrogen generator for our use cases, so we use a temporary diesel generator instead,” the spokesperson said.  

In 2019, Greener Power Solutions co-founder Dieter Castelein wrote a case study article for our quarterly technical journal PV Tech Power, looking at how mobile battery storage can reduce downtime during grid maintenance operations.

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Another TurningPoint Energy project, the RI King Community Solar Project, located in North Smithfield, R.I.

TurningPoint Energy, a renewable energy company focused on community solar development, has expanded its community solar efforts to include the state of Illinois. The company’s Midwest team is engaging with landowners interested in leasing or selling their property for solar development, residential and commercial customers interested in participating in solar projects, and pro-solar communities seeking to bring clean energy to its residents.

TurningPoint Energy plans to develop more than 40 projects in Illinois over the coming years with an aggregate value of more than half a billion dollars providing bill credits that support more than an estimated 45,000 homes each year. As a community solar development company, that means the creation of meaningful construction and ongoing operational jobs along with collaboration and investment into local Illinois businesses on legal, permitting, engineering, construction and related activities to support these developments.

Additionally, for every community the company develops projects in, TurningPoint Energy makes a charitable community investment commitment that is actualized as community solar projects start and complete construction. In Illinois, the aggregate charitable investment is targeted to exceed half of a million dollars spread out amongst the communities it develops and therefore invests in as well.

In September 2021, Illinois substantially expanded its community solar program when Governor JB Pritzker signed into law S.B. 2408, The Climate and Equitable Jobs Act. The comprehensive renewable bill created a pathway to 100% clean energy in the state by 2050, including expanding community solar for the benefit of local homeowners, businesses, municipalities and other organizations.

“Our entrance and commitment to the Illinois community solar market is in direct response of the clear market signal provided by the State of Illinois’s political leadership that it is committed to climate and equitable jobs for its energy industry forward,” says Jared Schoch, president of TurningPoint Energy.

“Our team has been delivering community solar to communities throughout the country, and we’re excited to expand our services to communities in Illinois,” continues Schoch. “These projects not only help bring clean, renewable energy to people who do not have access to solar power, such as those who may not have a suitable roof for panels, renters, or low-to-moderate income earners, but also help bring jobs, tax revenue and economic growth to the state.”

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