Vanadium flow battery energy storage units at Pivot Power’s Energy Superhub site in Oxford, England. Image: Invinity Energy Systems.

Long-duration energy storage (LDES) technologies may have a difficult time competing with lithium-ion over the next decade as the latter’s cost-competitiveness at longer durations increases, possibly even to 24 hours, according to Haresh Kamath, Electric Power Research Institute (EPRI).

Just exactly when long-duration energy storage, including flow batteries like Invinity Energy System’s and ESS Inc’s, will take off is a hot topic. But with lithium-ion battery energy storage systems (BESS) being launched widely at four, six and now even eight hour durations, is there a danger for emerging long duration technologies that developers will just stick with the industry standard?

“They can and then they probably will. As the cost of lithium ion comes down I expect that number (of hours duration) to move out. By the end of the decade, I think that we will probably have cost effective lithium at maybe even 24 hours [duration] systems if they’re needed,” Kamath said.

“My feeling is that many of the other proposed energy storage systems have yet to meet their price targets and they certainly have not met their targets in terms of maturity. And so they’re going to have a tough go competing with lithium ion in the next decade.”

“The only way to really for them to establish themselves is if they are able to offer substantially longer times than lithium-ion. It can’t be eight hours; they’ve got to be competitive at the 20 hour or 50 hour point where, once you get up to those numbers, it’s very difficult for lithium-ion to compete because of the way it scales.”

Because the unit cost of lithium-ion BESS increases proportionally as a systems’ duration increases, larger systems are currently very expensive.

Longer duration battery technologies like vanadium flow and iron flow have a more marginal increase in cost as you increase the duration, and so are more cost competitive as you get to larger system sizes.

Long duration storage companies would agree with much of what Kamath says. Invinity CEO Larry Zulch told Energy-storage.news that talking about long duration ‘hours’ would soon be redundant – soon long duration would mean days, weeks or months of discharge.

Those groups would say it is on the cusp, but why it hasn’t taken off already relates to barriers around upfront cost, regulation, policy and market revenue mechanisms. And the most mature market of California clearly sees a role for technologies capable of discharging for days with US$380 million to support up to 20 long duration storage projects in the state included in its recent budget.

And take off it needs to, according to the Long Duration Energy Storage Council formed last year. It claims that LDES has the potential to deploy 1.5-2.5 TW power capacity globally by 2040: 8-15 times the total storage capacity deployed today. Though it concedes that LDES costs must decrease by 60% for it to be cost optimal.

Kamath appears sceptical of these figures, questioning the broader value proposition of long duration energy storage. “Long-duration storage in general, to me, is a little bit of a puzzle because nobody has, in my view, established that it’s needed and nobody has established that they can satisfy it with any of the technologies that are presently being proposed,” he said.

“Those (long-duration) companies are following the intuition that if you have tons of renewables then why would you not want long duration storage. But it’s not clear to me that the value proposition is there, and it’s not clear to me that the that these technologies that are being proposed will be able to serve that value proposition, even if it is there.”

He adds that EPRI is is doing a lot of research into the area and to demonstrate that the value proposition is there. And he’s no lithium-ion fanatic either, sounding a note of caution on just how popular the chemistry has become for stationary energy storage.

“Lithium-ion batteries are becoming so popular and are being used in so many different ways. Watching that number of deployed systems burdgeon to the degree that it has, it is very interesting to see how that all goes.”

“Especially since we don’t have as much data as we’d like from those systems as to how well they’re working. We have installed a huge number of systems, but it’s not clear how often they’re dispatched, or whether they are being used to the extent that they could be. That data is still not out there and it’s something that would be very helpful to understand if we’re making the right investments or not.”

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Four winners have been selected to receive financial incentives from India’s government, to support plans to build 50GWh annual manufacturing capacity of advanced batteries for EVs and ESS. 

The Ministry of Heavy Industries officially announced the winning bidders that competed for funds through the Production Linked Incentive (PLI) for Advanced Chemistry Cell (ACC) Battery Manufacturing today. 

PLI schemes exist for other technologies like solar cells, electronics and electric vehicles, with the government describing battery manufacturing as one of this century’s “largest economic opportunities”. 

A pot of INR181 billion (US$2.42 billion) has been made available for gigafactories with at least 5GWh of annual production capacity per site. The incentives will be disbursed over five years, and the factories must be operational within two years. 

The winners:

ApplicantCapacity quotedCapacity awardedRajesh Exports Limited5GWh5GWhHyundai Global Motors20GWh20GWhOla Electric Mobility20GWh20GWhReliance New Energy Solar 20GWh5GWh

India Energy Storage Alliance (IESA) president Dr Rahul Walawalkar told Energy-Storage.news that with the awards and the promise of a quick start to advanced battery manufacturing in the country, India has taken a step towards realising the alliance’s “dream of becoming a global hub for R&D and manufacturing of advanced energy storage technologies”.

While the awardees are mostly in the automotive space, Reliance New Energy Solar, a subsidiary of Indian industrial heavyweight Reliance Industries is very much in the renewable energy sector. In the last few months, Reliance New Energy has bought up UK startup Faradion, which works on sodium-ion battery tech and Lithium Werks, which makes lithium iron phosphate (LFP) batteries. 

Reliance had bid for support for 20GWh of manufacturing capacity and was awarded PLI for 5GWh through the scheme, with a further 15GWh on the waitlist. It was also a winning bidder under the PLI scheme for solar module and cell manufacturing.

A further five companies, Mahindra & Mahindra, Exide Industries, Larsen & Toubro, Amara Raja Batteries and India Power Corporation were also waitlisted for capacity plans ranging from 5GWh to 15GWh.

The competitive solicitation process had been oversubscribed, with 130GWh of plans submitted. 

‘Next couple of years are critical’

Dr Rahul Walawalkar from IESA said it was great to see not just the winners of the scheme announced, but that at least five other groups plan to go ahead with gigafactory investments in India within the next two to three years. 

“The next couple years are critical for India to focus on technology partnerships, skill development and capacity building to support the gigafactories as well as complete supply chain,” the IESA president said. 

IESA was among stakeholders that had input into the programme’s design and Walawalkar said that the organisation is now working with government think tank NITI Aayog, the Ministry of Power and Ministry of Heavy Industries to ensure demand creation policies and initiatives are accelerated in the next couple of years.

Companies that have shown the first-mover initiative in the space should be able to benefit from that leadership, he said.

A further 20 or so more bids are expected to come in for another PLI scheme on Niche ACC technologies when it launches in September this year, which would add an additional 5GWh of annual manufacturing capacity in the country. 

India’s Central Electricity Authority has modelled a need for 27GW/108GWh of battery storage by 2030 to meet national goals of adding 500GW of renewable energy capacity from solar and wind, while battery storage could be an export opportunity as well. 

Dr Walawalkar said IESA’s roadmap for the manufacturing sector targets India having at least 25GWh of production capacity by 2025, more than 70GWh by 2027 and over 100GWh by 2030.

By 2027, IESA anticipates the split of India’s battery manufacturing capacity will be about 60:40 between EVs and ESS.

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Bert Chen

The Renewables Consulting (RCG), an ERM Group company, is ramping up its renewable energy services and projects across Canada. The company has appointed Bert Chen as senior associate.

Before RCG, Chen was manager in business development at Brookfield Renewable Energy where he was responsible for due diligence and project management of greenfield and mid-stage development projects in North America. With a background in renewable energy and finance, Chen brings a commercial and financial perspective to RCG’s technical advisory offering.

“We’re excited that Bert has joined our Vancouver team,” says Francis Charbonneau, RCG’s associate director in Vancouver. He brings strong expertise in financial analysis, regulatory affairs, technical expertise, legal and commercial negotiations as well as project management within the North American renewable energy sector. He is a tremendous asset that will bring added value to our clients.”

RCG offers technical and management consulting services for mainstream and emerging renewable energy technologies. It works with the public sector, private equity and financial services firms, utilities and project developers, equipment manufacturers, and engineering and construction companies for wind, solar and emerging technologies, including wave and tidal and energy-storage projects.

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The U.S. energy storage market set a new record in the fourth quarter of 2021, with new system installations totaling 4,727 MWh. According to Wood Mackenzie, a Verisk business, and the American Clean Power Association’s (ACP) latest U.S. Energy Storage Monitor report, Q4 2021 saw more capacity installed than in the first three quarters combined, despite project delays.

Annual deployments of grid-scale storage nearly tripled year-over-year to 3 GW/9.2 GWh. Despite a record year, the grid-scale market didn’t meet expectations in 2021, with supply chain challenges delaying more than 2 GW of capacity into 2022 and 2023. Wood Mackenzie forecasts that supply chain pressures and delays within interconnection queue processing will persist through 2024.

“Year 2021 was yet another record for the U.S. energy storage market, with annual installations of multiple gigawatts for the first time,” says Jason Burwen, ACP’s vice president for energy storage. “Even in the face of continued macro-economic headwinds, interconnection delays and lack of proactive federal policy, increasing demand for resilient clean energy and volatility in the price of fuel-based generation will drive energy storage deployment forward. Despite supply tightness leading to some project delays, the grid-scale market is still on track for exponential growth.”

System component price gains experienced over recent years have nearly been wiped out by higher costs for raw materials and transportation. Specifically, battery module pricing saw the largest increase of all system components due to the increased cost of raw materials.

Residential storage had its strongest quarter to date with 123 MW installed, beating the previous quarterly record of 110 MW in the first quarter of 2021. Increasingly effective solar-plus-storage sales in markets outside of California helped establish the new quarterly benchmark and resulted in a national annual total of 436 MW.

By 2026, annual installations in the residential segment are expected to hit 2 GW/5.4 GWh, with frontrunners in California, Puerto Rico, Texas and Florida leading that market segment.

“Puerto Rico’s position in the residential U.S. solar-plus-storage market comes as no surprise, and demonstrates how outages can drive battery adoption, with thousands of new residential installs emerging each quarter and competition increasing between local installers,” states Chloe Holden, an analyst with Wood Mackenzie’s energy storage team.

“Outages in Puerto Rico are also driving customers to recognize the added value of resilience that solar-plus-storage systems offer, despite premium pricing and lack of incentive programs,” adds Holden. “This is also driving solar-plus-storage market growth in Florida, the Carolinas and parts of the Midwest.”

The report found that the California storage market remains resilient as policy and market developments, such as NEM 3.0, shakes up the solar market. And by 2027, California will remain the largest residential storage market, with three-and-a-half times more storage installed annually in 2027 compared to 2021.

The non-residential storage segment delivered 131 MWh in the fourth quarter resulting in 162 MW/350 MWh of total annual deployments in 2021. Segment demand was driven by increased storage attachment rates within the community solar markets of New York and Massachusetts.

Read the full report here.

Image: Photo by Mariana Proença on Unsplash

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Slate, a recently-completed large-scale California solar-plus-storage project. Image: Goldman Sachs Renewable Power.

Battery storage will be a valuable asset for enhancing and upgrading the electric transmission and distribution (T&D) system of California.  

The board of CAISO last week approved the California grid operator’s 10-Year Transmission Plan, which will upgrade the network and make it better able to accommodate renewable energy. 

As reported by our sister site PV Tech, resource requirements for decarbonising California’s energy system by 2045 and enhancing reliability of the electricity network demand significant increases in the amount of battery storage and different renewable energy technologies.

Identifying 23 separate transmission projects representing about US$2.9 billion of investment in expansion, upgrade and reinforcement, the transmission plan has been put together with California’s energy needs in mind. The state needs to add about 4,000MW of new resources each year over the next decade — four times more than the 1,000MW of additions expected and modelled for in CAISO’s previous 2020-2021 transmission plan. 

California is known as the global regional leading market for battery storage, driven largely by procurements through the state’s three big investor-owned utilities (IOUs) for Resource Adequacy — capacity to guarantee customers their lights will stay on. 

CAISO, the California Energy Commission and regulatory California Public Utilities Commission (CPUC) are all aware the state will need dramatically more energy storage, as well as renewables, to decarbonise while replacing capacity from retiring fossil fuel and nuclear. 

The CPUC in February unanimously approved a US$49 billion plan to accommodate more than 25.5GW of new renewable energy and 14,751MW of battery storage by 2032. 

CAISO’s 10-year plan meanwhile models the different forecasted and required capacities of battery storage in each of the regions around its network.

In specific instances, battery storage is recommended as an alternative to grid upgrade projects. For instance 50MW/200MWh of BESS should be procured at a 115kV substation in Mesa to address a maintenance window for the network instead of carrying out a full transmission 230kV line upgrade project. 

The approved 10-year Transmission Plan can be found here on CAISO’s website.

CAISO’s 20-year Transmission Outlook, aimed at providing a framework for long-term planning, can be found here.

Interconnection: ‘the real challenge’ for California and CAISO

At present, getting interconnection agreements for battery storage projects in California is proving very difficult, Energy-Storage.news heard from Seth Hilton, a California-focused specialist renewable energy industry lawyer at legal firm Stoel Rives. 

CAISO is dealing with far more interconnection requests than it can deal with and has extended the timelines developers have to work with. 

“They can’t process the volume of interconnection requests along the timeline that’s provided for in their tariff. So that’s the real challenge. And California ISO has been looking at what some of the solutions are, but they have to give non-discriminatory access to the transmission system,” Hilton said. 

A good indicator of just how much lead times for BESS projects are impacted by the interconnection agreement process is that state governor Gavin Newsom’s emergency proclamation over energy issues last summer ordered the California Energy Commission to expedite permitting for clean energy projects, including energy storage. 

With permitting often cited as a reason for lengthening the project development process, it might be considered that this step would have been beneficial to the industry.

However, Seth Hilton said: “Not a single energy storage project took advantage of that expedited process that was set up by the Energy Commission — because of interconnection issues, which the Commission couldn’t deal with”.

“Even if you had expedited permitting at the Energy Commission, it didn’t solve the interconnection problem, which was really the the long lead time item and the issue which is the real challenge we’re dealing with in California.”

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Jamaica is seeking to fix water scarcity issues in the Kingston area, which is currently reliant on the Mona Reservoir. Image: CC.

Jamaica has received proposals from a consortium of local and international companies to implement a proposed pumped hydro electric storage (PHES) project.

Prime minister Andrew Holness told the parliament last week that an ‘unsolicited’ proposal had been received to implement the project, which has not yet been approved by the government.

The pumped hydro project involves pumping desalinated seawater into elevated reservoirs using solar power, then feeding that water back down through a hydroelectric power turbine into downstream reservoirs for household use. The project is primarily being presented as a way to fix water shortages in some regions.

It is widely reported the power generation could be up to 200MWh annually and Holness said the project, along with other proposals, could increase Jamaica’s proportion of renewable electricity generation to 50% from 13% today.

“The proposal is currently undergoing technical and due-diligence reviews. Subject to the satisfactory completion of those reviews, it is the intention of the Government to designated the project a Jamaica 60 National Development Project and enter into direct negotiations with the consortium, in order to fast-track its implementation,” he said, referring to this year being Jamaica’s 60th as an independent nation.

The country last made headlines in the energy storage world in 2019 when it commissioned a 24.5MW hybrid energy storage system comprising a lithium-ion battery energy storage system (BESS) as well as high-speed and low-speed flywheels, first announced in 2017.

That project is located next to a substation operated by Jamaica Public Service Company (JPS), the country’s sole electricity distributor, which called the wider microgrid project it is part of a “model for other countries in the Caribbean and beyond”.

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The proposed BESS would be more than double the size of the Victorian Big Battery, currently Australia’s largest BESS. Image: Victoria State government.

The state government of New South Wales (NSW) in Australia is opening up a competitive procurement process for Waratah Super Battery, a 700MW/1,400MWh battery energy storage system (BESS) project. 

The battery system will be built to increase electric transmission system capacity across the state, serving as a giant ‘shock absorber’ for the grid and allowing power lines to operate at higher capacity.

It is part of a plan to ease the network’s adaptation to life after the closure of Eraring coal power plant, a 2,880MW generation station that owner Origin Energy has proposed closing down in 2025. 

Integrated energy company Origin has said that retiring the plant will free up dozens of millions of dollars it spends on operating Eraring each year as well as aiding the company’s decarbonisation efforts.

Origin is itself building a separate 700MW BESS as well as aggressively expanding its virtual power plant (VPP) network to as much as 2GW to replace the coal plant’s lost capacity, as well as leaning on its fleet of gas plants to help balance the network as renewable energy penetration goes up.  

NSW’s government meanwhile issued a plan back in February to support workers and create new jobs after Eraring closes: investing AU$250 million (US$186.9 million) to boost locally manufactured content in clean energy technologies, build up the green hydrogen industry and fast-track the delivery of critical transmission upgrades.

The Waratah Super Battery will go towards providing reliable and affordable electricity, particularly as it will increase the transmission capacity across NSW to demand centre areas like Sydney, Newcastle and Wollongong.

Transmission constraints prevent existing generation capacity being made available in those areas during peak times. Lines operate at strict limits below their capacity in case of shocks to the system, such as lightning strikes or bushfires. The BESS can therefore step in and instead act to absorb that shock, leaving the lines capable of carrying more electrons. 

NSW government said that its Energy Security Target policy provides a roadmap to ensuring reliability of electricity and that the Australian Energy Market Operator (AEMO) has said its post-Eraring plan, including the Waratah BESS, will be sufficient to meet the target’s standards. 

“The Waratah Super Battery will allow for more electricity to flow through the network, unlocking this excess capacity and supplying the families and businesses of NSW a reliable and stable energy supply,” NSW treasurer and energy minister Matt Kean said.

The battery project will need to be in service before the coal plant closes in 2025, with the government open to proposals on any suitable site, which could include state-owned land.

The Energy Corporation of NSW (EnergyCo) kicks off its launch of the procurement with a Market Forum event on 31 March, with the Expressions of Interest to be solicited from the beginning of April. 

The tender will be evaluated from August to October before award and contracts are announced in November. 

Interested parties can see the EnergyCo portal for the tender here.

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The KOREPlex facility in Arizona will open next year. Image: KORE Power.

KORE Power, a company building a lithium-ion gigafactory in Arizona, has launched a full service storage integrator division with the acquisition of an existing provider.

KORE has acquired Northern Reliability (NRI) and simultaneously launched KORE Solutions, which will operate as a full-service storage integrator division of the company, it said. NRI has deployed over 1,000 energy storage projects globally.

This makes KORE a vertically integrated energy solutions provider, with a lithium-ion gigafactory for electric vehicles and energy storage in development for opening in the second quarter of 2023. Dubbed KOREPlex, at full output the facility in Arizona will manufacture 12GWh of lithium-ion batteries for the electric vehicle (EV) and energy storage markets and employ 3,000 people.

The company said that KORE Solutions combines KORE Power’s manufacturing capabilities with NRI’s 50 years’ experience advancing energy storage solutions to offer customers end-to-end capabilities and service. It said that NRI has a robust US-made project pipeline.

KORE designs and makes energy storage systems as well as battery cells including both lithium-iron phosphate (LFP) and nickel manganese cobalt (NMC) chemistries, battery modules and packs in VDA format. It also has its own battery management system (BMS). It already has operations in China through a supply partner.

NRI CEO Jay Bellows will stay on as President of KORE Power and the deal adds 25 staff to KORE’s Waterbury, Vermont office. The two companies started working together two years ago on the Nomad Transportable Power project, which provides utility-scale mobile storage units integrated with a docking system.

KORE Power CEO Lindsay Gorrill wrote a guest blog on Energy-storage.news two years ago which you can read here.

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The Clark Road project, one of two solar + storage projects that Nexamp has activated in Massachusetts. Image: Nexamp.

Nexamp completes two colocated storage projects in Massachusetts

US community solar provider Nexamp has completed two energy storage projects colocated with solar in Massachusetts.

The two battery energy storage system (BESS) sites adjoin existing Nexamp community solar farms in and projects will provide critical frequency regulation and capacity services for the ISO New England market.

The first, Brockelman Road, has a 1.7MW solar park combined with a 1MW/2MWh BESS while Clark Road has 7.1 MW of solar power and a 3MW/6.1MWh BESS. Nexamp says these are located in a particularly-grid congested area in Central Masachussetts in a service area managed by UK operator National Grid.

Both participate in the Solar Massachusetts Renewable Target (SMART) Program and the Massachusetts Clean Peak Energy Standard program. The latter provides incentives to clean energy technologies that can supply electricity or reduce demand during seasonal peak demand periods.

The SMART programme incentivises households to invest in residential or community – I.e. utility-scale but ownership shared amongst local people – solar power by being guaranteed payment by their utility for 10 years for residential systems and 20 years for community ones.

Developer chosen for Canadian’ province’s first battery storage project

Saskpower, the main utility in the central Canadian province of Saskatchewan, has chosen Quebec-based power solutions provider On Power to build its first BESS.

On Power will build Saskatchewan’s first ever utility-scale BESS totalling 20MW/20MWh of capacity in northeast Regina, the province’s largest city. Construction will begin this spring and be completed in 2023.

It will cost an estimated CA$26 million (US$20.7 million) and will be funded in part by the Government of Canada through the Investing in Canada Infrastructure Program.

The facility will balance the power system and support the integration of renewable energy sources like wind and solar into the Saskatchewanian grid, Saskpower said.

The Regina facility will also serve as an opportunity for SaskPower to gain experience operating and maintaining BESS projects, the company said.

Greenko bags another deal for pumped hydro

Indian renewables firm Greenko Group’s pumped hydro storage capacity will flatten out the intermittent generation of a new 975MW renewable energy project in India being developed by Greenko and metals giant ArcelorMittal.

The two companies are developing a US$600 million wind and solar project in Andhra Pradesh which will provide 250MW of power to ArcelorMittal’s Hazira steel plant under a power purchase agreement (PPA).

Greenko will use its nearby pumped hydro project to ensure the PPA delivers a consistent supply of power to the plant though has not revealed more details.

Last month, it tied up with fellow independent power producer (IPP) Ayana to deliver round-the-clock renewable power to customers. Greenko is bringing 6GW of power to that deal with 1.5GW being PHES. According to reports, a similar deal has been signed with Adani.

Greenko Group claims to be the world’s largest energy storage company and one of the largest clean energy companies globally. It has 30GWh of ‘low-cost’ storage capacity under construction as part of its plan to develop as much as 100GWh of storage.

Its ‘low cost’ claim has some merit. A few years ago, it won a government tender for the Pinnapuram Pumped Storage Project at a tariff of US$0.054 per kWh, which was considered the lowest cost solar-plus-storage project proposal in the world.

It achieved a US$5.75 billion valuation in 2020 when a Japanese investment firm ORIX injected US$1 billion in equity.

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Hanwha Solutions, the Korean energy-to-material company that owns energy solutions provider Q CELLS, has become the largest shareholder of REC Silicon, a major U.S. manufacturer of polysilicon, the key raw material used to produce solar panels. Moving forward, Hanwha intends to implement a multi-phase, multi-billion-dollar investment plan across the full solar value chain from, polysilicon to solar modules.

Following its initial $160 million acquisition to acquire a 16.67% stake in REC Silicon in January 2022, Hanwha will now become the largest shareholder of REC Silicon by acquiring an additional 4.67% stake from Aker Horizons, a sustainability investment firm that had been co-owner of REC Silicon with

Hanwha Solutions. The deal is valued at around $44 million.

“Our commitment to the U.S. is more serious than ever before,” says Justin Lee, CEO of Q CELLS. “We plan to make investments to secure capabilities across the entire solar supply chain, with the goal of supplying our partners with ‘Made in America’ products that will help the U.S. regain its leadership in clean energy solutions.”

REC Silicon operates two polysilicon manufacturing facilities in the U.S. in Moses Lake, Wash. and Butte, Mont. Their combined annual production capacity totals 18,000 metric tons (MT), including 16,000 MT of granular, solar grade polysilicon at Moses Lake and 2,000 MT of electronic grade polysilicon at Butte.

Using hydropower-based clean energy, REC Silicon produces low-carbon polysilicon without emitting greenhouse gases. Compared to carbon-heavy polysilicon manufactured overseas that often relies on coal power, REC Silicon’s “clean polysilicon” is expected to draw more demand in the coming years as international scrutiny over industrial emissions and carbon footprints grows.

Besides solar grade polysilicon, REC Silicon also manufactures other materials such as electronic grade silicon and silane gas, which are essential for producing hi-tech devices including semiconductors, smartphones, flat screen televisions, laptops and hybrid electric vehicles.

“Increasing energy market turbulence tells us why securing key raw material production is so critical,” comments a Hanwha Solutions spokesperson. “Given upward pressure on oil prices and scrutiny over the environmentally damaging impacts from fossil fuels, we believe that strengthening the renewable-based energy supply chain is important – and producing low-carbon solar material is a good starting point to achieve the goal.”

Currently, Hanwha operates a module production facility in the U.S. through its solar panel business unit, Q CELLS. The Georgia-based factory can produce 1.7 GW of solar modules per year.

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