Abengoa, Acciona to start work on 110MW Cerro Dominador CSP plant in Chile


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Cerro Dominador CSP Plant delivers 110MW concentrated solar power in Chile's Atacama Desert, with 10,600 heliostats, 17.5-hour molten salt storage, and 24/7 dispatchable energy; built by Acciona and Abengoa within a 210MW complex.

 

Key Points

A 110MW CSP solar-thermal plant in Chile with heliostats and 17.5h molten salt storage, delivering 24/7 dispatchable clean power.

✅ 110MW CSP with 17.5h molten salt for 24/7 dispatch

✅ 10,600 heliostats; part of a 210MW hybrid CSP+PV complex

✅ Built by Acciona and Abengoa; first of its kind in LatAm

 

A consortium formed by Spanish groups Abengoa and Acciona, as Spain's renewable sector expands with Enel's 90MW wind build activity, has signed a contract to complete the construction of the 110MW Cerro Dominador concentrated solar power (CSP) plant in Chile.

The consortium received notice to proceed to build the solar-thermal plant, which is part of the 210MW Cerro Dominador solar complex.

Under the contract, Acciona, which has 51% stake in the consortium and recently launched a 280 MW Alberta wind farm, will be responsible for building the plant while Abengoa will act as the technological partner.

Expected to be the first of its kind in Latin America upon completion, the plant is owned by Cerro Dominador, which in turn is owned by funds managed by EIG Global Energy Partners.

The project will add to a Abengoa-built 100MW PV plant, comparable to California solar projects in scope, which was commissioned in February 2018, to form a 210MW combined CSP and PV complex.

Spread across an area of 146 hectares, the project will feature 10,600 heliostats and will have capacity to generate clean and dispatachable energy for 24 hours a day using its 17.5 hours of molten salt storage technology, a field complemented by battery storage advances.

Expected to prevent 640,000 tons of CO2 emission, the plant is located in the commune of María Elena, in the Atacama Desert, in the Antofagasta Region.

“In total, the complex will avoid 870,000 tons of carbon dioxide emissions into the atmosphere every year and, in parallel with Enel's 450 MW U.S. wind operations, will deliver clean energy through 15-year energy purchase agreements with distribution companies, signed in 2014.

“The construction of the solarthermal plant of Cerro Dominador will have an important impact on local development, with the creation of more than 1,000 jobs in the area during its construction peak, and that will be priority for the neighbors of the communes of the region,” Acciona said in a statement.

The Cerro Dominador plant represents Acciona’s fifth solar thermal plant being built outside of Spain. The firm has constructed 10 solarthermal plants with total installed capacity of 624MW.

Acciona has been operating in Chile since 1993. The company, through its Infrastructure division, executed various construction projects for highways, hospitals, hydroelectric plants and infrastructures for the mining sector.

 

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Told "no" 37 times, this Indigenous-owned company brought electricity to James Bay anyway

Five Nations Energy Transmission Line connects remote First Nations to the Ontario power grid, delivering clean, reliable electricity to Western James Bay through Indigenous-owned transmission infrastructure, replacing diesel generators and enabling sustainable community growth.

 

Key Points

An Indigenous-owned grid link providing reliable power to Western James Bay First Nations, replacing polluting diesel.

✅ Built by five First Nations; fully Indigenous-owned utility

✅ 270 km line connecting remote James Bay communities

✅ Ended diesel dependence; enabled sustainable development

 

For the Indigenous communities along northern Ontario’s James Bay — the ones that have lived on and taken care of the lands as long as anyone can remember — the new millenium marked the start of a diesel-less future, even as Ontario’s electricity outlook raised concerns about getting dirtier in policy debates. 

While the southern part of the province took Ontario’s power grid for granted, despite lessons from Europe’s power crisis about reliability, the vast majority of these communities had never been plugged in. Their only source of power was a handful of very loud diesel-powered generators. Because of that, daily life in the Attawapiskat, Kashechewan and Fort Albany First Nations involved deliberating a series of tradeoffs. Could you listen to the radio while toasting a piece of bread? How many Christmas lights could you connect before nothing else was usable? Was there enough power to open a new school? 

The communities wanted a safe, reliable, clean alternative, with Manitoba’s clean energy illustrating regional potential, too. So did their chiefs, which is why they passed a resolution in 1996 to connect the area to Ontario’s grid, not just for basic necessities but to facilitate growth and development, and improve their communities’ quality of life. 

The idea was unthinkable at the time — scorned and dismissed by those who held the keys to Ontario’s (electrical) power, much like independent power projects can be in other jurisdictions. Even some in the community didn’t fully understand it. When the idea was first proposed at a gathering of Nishnawbe Aski Nation, which represents 49 First Nations, one attendee said the only way he could picture the connection was as “a little extension cord running through the bush from Moosonee.” 

But the leadership of Attawapiskat, Kashechewan and Fort Albany First Nations had been dreaming and planning. In 1997, along with members of Taykwa Tagamou and Moose Cree First Nations, they created the first, and thus far only, fully Indigenous-owned energy company in Canada: Five Nations Energy Inc., as partnerships like an OPG First Nation hydro project would later show in action, too. 

Over the next five years, the organization built Omushkego Ishkotayo, the Cree name for the Western James Bay transmission line: “Omushkego” refers to the Swampy Cree people, and “Ishkotayo” to hydroelectric power, while other regions were commissioning new BC generating stations in parallel. The 270-kilometre-long transmission line is in one of the most isolated regions of Ontario, one that can only be accessed by plane, except for a few months in winter when ice roads are strong enough to drive on. The project went online in 2001, bringing reliable power to over 7,000 people who were previously underserved by the province’s energy providers. It also, somewhat controversially, enabled Ontario’s first diamond mine in Attawapiskat territory.

The future the First Nations created 25 years ago is blissfully quiet, now that the diesel generators are shut off. “When the power went on, you could hear the birds,” Patrick Chilton, the CEO of Five Nations Energy, said with a smile. “Our communities were glowing.”

Power, politics and money: Five Nations Energy needed government, banks and builders on board
Chilton took over in 2013 after the former CEO, his brother Ed, passed away. “This was all his idea,” Chilton told The Narwhal in a conversation over Zoom from his office in Timmins, Ont. The company’s story has never been told before in full, he said, because he felt “vulnerable” to the forces that fought against Omushkego Ishkotayo or didn’t understand it, a dynamic underscored by Canada’s looming power problem reporting in recent years. 

The success of Five Nations Energy is a tale of unwavering determination and imagination, Chilton said, and it started with his older brother. “Ed was the first person who believed a transmission line was possible,” he said.

In a Timmins Daily Press death notice published July 2, 2013, Ed Chilton is described as having “a quiet but profound impact on the establishment of agreements and enterprises benefitting First Nations peoples and their lands.” Chilton doesn’t describe him that way, exactly. 

“If you knew my brother, he was very stubborn,” he said. A certified engineering technologist, Ed was a visionary whose whole life was defined by the transmission line. He was the first to approach the chiefs with the idea, the first to reach out to energy companies and government officials and the one who persuaded thousands of people in remote, underserved communities that it was possible to bring power to their region.

After that 1996 meeting of Nishnawbe Aski Nation, there came a four-year-long effort to convince the rest of Ontario, and the country, the project was possible and financially viable. The chiefs of the five First Nations took their idea to the halls of power: Queen’s Park, Parliament Hill and the provincial power distributor Hydro One (then Ontario Hydro). 

“All of them said no,” Chilton said. “They saw it as near to impossible — the idea that you could build a transmission line in the ‘swamp,’ as they called it.” The Five Nations Energy team kept a document at the time tracking how many times they heard no; it topped out at 37. 

One of the worst times was in 1998, at a meeting on the 19th floor of the Ontario Hydro building in the heart of downtown Toronto. There, despite all their preparation and planning, a senior member of the Ontario Hydro team told Chilton, Martin and other chiefs “you’ll build that line over my dead body,” Chilton recalled. 

At the time, Chilton said, Ontario Hydro was refusing to cooperate: unwilling to let go of its monopoly over transmission lines, but also saying it was unable to connect new houses in the First Nations to diesel generators it said were at maximum capacity. (Ontario Hydro no longer exists; Hydro One declined to comment.)

“There’s always naysayers no matter what you’re doing,” Martin said. “What we were doing had never been done before. So of course people were telling us how we had never managed something of this size or a budget of this size.” 

“[Our people] basically told them to blow it up your ass. We can do it,” Chilton said.

So the chiefs of the five nations did something they’d never done before: they went to all of the big banks and many, many charitable foundations trying to get the money, a big ask for a project of this scale, in this location. Without outside support, their pitch was that they’d build it themselves.

This was the hardest part of the process, said Lawrence Martin, the former Grand Chief of Mushkegowuk Tribal Council and a member of the Five Nations Energy board. “We didn’t know how to finance something like this, to get loans,” he told The Narwhal. “That was the toughest task for all of us to achieve.”

Eventually, they got nearly $50 million in funding from a series of financial organizations including the Bank of Montreal, Pacific and Western Capital, the Northern Ontario Heritage Fund Corporation (an Ontario government agency) and the engineering and construction company SNC Lavalin, which did an assessment of the area and deemed the project viable. 

And in 1999, Ed Chilton, other members of the Chilton family and the chiefs were able to secure an agreement with Ontario Hydro that would allow them to buy electricity from the province and sell it to their communities. 

 

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Lawmakers push bill to connect Texas grid to rest of the nation

Connect the Grid Act links ERCOT to neighboring grids via high-voltage interconnections, enhancing reliability, resilience, and renewables integration. It enables power imports and exports with SPP, MISO, and the Western Interconnection under FERC oversight.

 

Key Points

A plan to link ERCOT with neighboring grids, improving reliability, enabling energy trade, and integrating renewables.

✅ High-voltage ties with SPP, MISO, and the Western Interconnection

✅ Enables imports during crises and exports of surplus power

✅ Brings ERCOT under FERC oversight; DoE to study Mexico links

 

In the aftermath of the devastating 2021 Texas blackouts, which exposed the vulnerabilities of the state's energy infrastructure, a significant legislative effort is underway to transform Texas from an energy island into a connected component of the broader U.S. power grid. Spearheaded by U.S. Representative Greg Casar, D-Austin, the proposed Connect the Grid Act is part of a push for smarter electricity infrastructure that seeks to remedy the isolation of the Electric Reliability Council of Texas (ERCOT) from neighboring power grids, a condition that significantly contributed to the crisis during Winter Storm Uri.

The blackouts, which left millions without power and resulted in significant loss of life and economic damage, underscored the inherent risks of Texas's unique energy infrastructure. Unlike the rest of the continental U.S., Texas's grid operates independently, limiting its ability to import electricity during emergencies. This isolation was a critical factor in the state's inability to respond effectively to the increased demand for power during the storm.

Recognizing the urgent need for a more resilient and integrated energy system, Rep. Casar's legislation aims to establish high-voltage connections between ERCOT and adjacent grid-operating organizations, including the Southern Power Pool, MISO, and the Western Interconnection. This would not only improve the reliability of Texas's power supply by enabling energy imports during crises but also allow the state to export surplus energy, thereby enhancing the economic efficiency and sustainability of its energy market.

The Connect the Grid Act proposes a range for the new connections' transfer capabilities, aiming to significantly boost the amount of power that can be shared between Texas and its neighbors. Such interconnectivity is anticipated to reduce energy costs for consumers by mitigating scarcity and enabling access to Texas's vast renewable energy resources, even as grid modernization affordability remains a point of debate among stakeholders. However, the bill faces opposition due to concerns over federal oversight, as it would bring ERCOT under the jurisdiction of the Federal Energy Regulatory Commission (FERC).

Some analysts note that policies such as later school start dates can ease late-summer peak demand as well.

At a press conference held at the IBEW Local 520 headquarters, Rep. Casar, along with environmental groups, labor unions, and frontline workers, highlighted the benefits of the proposed legislation. The bill also includes provisions for a Department of Energy study on the potential benefits of interconnecting with Mexico, and parallels proposals for macrogrids in Canada that seek greater reliability across borders.

The Connect the Grid Act reflects a broader national trend towards increasing the interconnectivity of regional power grids, a move deemed essential for the transition to renewable energy and combating climate change risks to the U.S. grid through expanded interconnection. By enabling the flow of clean energy from renewable-rich areas like Texas to energy-hungry urban centers, the legislation supports a more sustainable and resilient national energy infrastructure.

Critics of Texas's grid independence, including energy experts and federal regulators, have long advocated for such interconnections. They argue that increased access to neighboring grids could have mitigated the effects of the 2021 blackouts and emphasize the importance of a grid that can withstand extreme weather events. The Federal Energy Regulatory Commission and the North American Electric Reliability Corp. have both explored mandates and studies to promote electricity transfer between regional grids, while states like California grid upgrades are investing to modernize networks as well, highlighting the national importance of grid interconnectivity.

Despite the potential challenges of increased federal regulation, proponents of the Connect the Grid Act argue that the benefits of interconnection far outweigh the drawbacks. By reducing energy costs, enhancing grid reliability, and promoting renewable energy, the legislation aims to secure a more sustainable and equitable energy future for Texas and the nation.

If passed, the Connect the Grid Act would mark a historic shift in Texas's energy policy, ending the state's long-standing isolation and positioning it as a key player in the national and potentially international energy landscape, and echoes calls for a western Canadian electricity grid to strengthen regional ties. The bill sets a completion deadline of January 1, 2035, for the construction of the new connections, with other projects, like the one by Pattern Energy, potentially connecting ERCOT to parts of the Southeastern grid even earlier, by 2029. This legislative effort represents a critical step towards ensuring that Texas can meet its energy needs reliably and sustainably, while also contributing to the broader goal of transitioning to a cleaner, more resilient power system.

 

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Trump's Proposal to Control Ukraine's Nuclear Plants Sparks Controversy

US Control of Ukraine Nuclear Plants sparks debate over ZNPP, Zaporizhzhia, sovereignty, safety, ownership, and international cooperation, as Washington touts utility expertise, investment, and modernization to protect critical energy infrastructure amid conflict.

 

Key Points

US management proposal for Ukraine's nuclear assets, notably ZNPP, balancing sovereignty, safety, and investment.

✅ Ukraine retains ownership; any transfer requires parliament approval.

✅ ZNPP safety risks persist amid occupation near active conflict.

✅ International reactions split: sovereignty vs. cooperation and investment.

 

In a recent phone call with Ukrainian President Volodymyr Zelenskyy, U.S. President Donald Trump proposed that the United States take control of Ukraine's nuclear power plants, including the Zaporizhzhia Nuclear Power Plant (ZNPP), which has been under Russian occupation since early in the war and where Russia is reportedly building power lines to reactivate the plant amid ongoing tensions. Trump suggested that American ownership of these plants could be the best protection for their infrastructure, a proposal that has sparked controversy in policy circles, and that the U.S. could assist in running them with its electricity and utility expertise.

Ukrainian Response

President Zelenskyy promptly addressed Trump's proposal, stating that while the conversation focused on the ZNPP, the issue of ownership was not discussed. He emphasized that all of Ukraine's nuclear power plants belong to the Ukrainian people and that any transfer of ownership would require parliamentary approval . Zelenskyy clarified that while the U.S. could invest in and help modernize the ZNPP, ownership would remain with Ukraine.

Security Concerns

The ZNPP, Europe's largest nuclear facility, has been non-operational since its occupation by Russian forces in 2022. The plant's location near active conflict zones raises significant safety risks that the IAEA has warned of in connection with attacks on Ukraine's power grids, and its future remains uncertain. Ukrainian officials have expressed concerns about potential Russian provocations, such as explosions, especially after UN inspectors reported mines at the Zaporizhzhia plant near key facilities, if and when Ukraine attempts to regain control of the plant.

International Reactions

The proposal has elicited mixed reactions both within Ukraine and internationally. Some Ukrainian officials view it as an opportunistic move by the U.S. to gain control over critical infrastructure, while others see it as a potential avenue for modernization and investment, alongside expanding wind power that is harder to destroy in wartime. The international community remains divided on the issue, with some supporting Ukraine's sovereignty over its nuclear assets and others advocating for a possible agreement on power plant attacks to ensure the plant's safety and future operation.

President Trump's proposal to have the U.S. take control of Ukraine's nuclear power plants has sparked significant controversy. While the U.S. offers expertise and investment, Ukraine maintains that ownership of its nuclear assets is a matter of national sovereignty, even as it has resumed electricity exports to bolster its economy. The situation underscores the complex interplay between security, sovereignty, and international cooperation in conflict zones.

 

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New president at Manitoba Hydro to navigate turmoil at Crown corporation

Jay Grewal Manitoba Hydro Appointment marks the first woman CEO at the Crown utility, amid debt, rate increase plans, privatization debate, and Metis legal challenge, following board turmoil and Premier Pallister's strained relations.

 

Key Points

The selection of Jay Grewal as Manitoba Hydro's first woman CEO amid debt, rate hikes, and legal disputes.

✅ First woman CEO of Manitoba Hydro

✅ Faces debt, rate hikes, and project overruns

✅ Amid privatization debate and Metis legal action

 

The Manitoba government has appointed a new president and chief executive officer at its Crown-owned energy utility.

Jay Grewal becomes the first woman to head Manitoba Hydro, and takes over the top spot as the utility faces mounting financial challenges, rising electricity demand and turmoil.

Grewal has previously held senior roles at Capstone Mining Corp and B.C. Hydro, and is currently president of the Northwest Territories Power Corporation.

She will replace outgoing president Kelvin Shepherd, who recently announced he is retiring, on Feb. 4.

The utility was hit by the sudden resignations of nine of its 10 board members in March, who said they had been unable to meet with Premier Brian Pallister to discuss pressing issues like servicing energy-intensive customers facing the utility.

Manitoba Hydro is also in the middle of a battle between the Progressive Conservative government and the Manitoba Metis Federation over the cancellation of two agreements that would have given the Metis $87 million.

The federation has launched a legal challenge over one deal and says its likely going to do the same over the second agreement.

Grewal also takes over the utility at a time when it has racked up billions of dollars in debt building new generating stations and transmission lines. Manitoba Hydro has told the provincial regulatory agency it needs rate increases of nearly eight per cent a year for the next few years to help pay for the projects.

The utility also exports electricity, with deals such as SaskPower's purchase agreement expanding sales to Saskatchewan.

"Ms. Grewal is a proven leader, with extensive senior leadership experience in the utility, resource and consulting sectors," Crown Services Minister Colleen Mayer said in a written statement Thursday.

The Opposition New Democrats said Grewal's appointment is a sign the government wants to privatize Manitoba Hydro. Grewal's time at B.C. Hydro coincided with the privatization of some parts of that Crown utility, the NDP said.

The B.C. premier at the time, Gordon Campbell, was recently hired by Manitoba to review two major projects that ran over-budget and have added to the provincial debt.

NDP Leader Wab Kinew asked Pallister in the legislature Thursday to promise not to privatize Manitoba Hydro. Pallister would only point to a law that requires a referendum to be held before a Crown entity can be sold off.

"We stand by that (law)," Pallister said. "We believe Manitobans are the proper decision-makers in respect of any of the future structuring of Manitoba Hydro."

 

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In a record year for clean energy purchases, Southeast cities stand out

Municipal Renewable Energy Procurement surged as cities contracted 3.7 GW of solar and wind, leveraging green tariffs, community solar, and utility partnerships across the Southeast, led by Houston, RMI, and WRI data.

 

Key Points

The process by which cities contract solar and wind via utilities or green tariffs to meet climate goals.

✅ 3.7 GW procured in 2020, nearly 25% year-over-year growth

✅ Houston runs city ops on 500 MW solar, a record purchase

✅ Southeast cities use green tariffs and community solar

 

Cities around the country bought more renewable energy last year than ever before, reflecting how renewables may soon provide one-fourth of U.S. electricity across the grid, with some of the most remarkable projects in the Southeast, according to new data unveiled Thursday.

Even amid the pandemic, about eight dozen municipalities contracted to buy nearly 3.7 gigawatts of mostly solar and wind energy — enough to power more than 800,000 homes. The figure is almost a quarter higher than the year before.

Half of the cites listed as “most noteworthy” in Thursday’s release —  from research groups Rocky Mountain Institute and World Resources Institute — are in the region that stretches from Texas to Washington, D.C. 

Houston stands out for the sheer enormity of its purchase: In July, it began powering city operations entirely from nearly 500 megawatts of solar power — the largest municipal purchase of renewable energy ever in the United States, as renewable electricity surpassed coal nationwide.

The groups also feature smaller deals in North Carolina and Tennessee, achieved through a utility partnership called a green tariff.

“We wanted to recognize that Nashville and Charlotte were really blazing a new trail,” said Stephen Abbott, principal at the Rocky Mountain Institute.

And the nation’s capital shows how renewable energy can be a source of revenue: It’s leasing out its public transit station rooftops for 10 megawatts of community solar.

All of these strategies will be necessary for scores of U.S. cities to meet their ambitious climate goals, researchers believe. An interactive clean energy targets tracker shows all 95 clean energy procurements from the year in detail.


Tracker 
Even before former President Donald Trump promised to remove the United States from the Paris Climate Accord, a lack of federal action on climate left a void that some cities and counties were beginning to fill, as renewables hit a record 28% in a recent month. In 2015, the first year tracked by researchers at the Rocky Mountain Institute and the World Resources Institute, municipalities contracted to buy more than 1 gigawatt of wind, solar and other forms of clean energy. 

But when Trump officially set in motion the withdrawal from the climate agreement, the ranks of municipalities dedicated to 100% clean energy multiplied. Today there are nearly 200 of them. The growth in activity last year reflects, in part, that surge of new pledges.

“It takes a while to get city staff up to speed and understand the options, and create the roadmap and then start executing,” Abbott said. “There is a bit of a lag, but we’re starting to see the impact.”

Even in Houston — one of the earliest to begin procuring renewable energy — there has been a steep learning curve as market forces change and prices drop, including cheaper solar batteries shaping procurement strategies, said Lara Cottingham, Houston’s chief of staff and chief sustainability officer.

No matter how well resourced and educated their staff, cities have to clear a thicket of structural, political and economic challenges to procure renewable energy. Most don’t own their own sources of power. Nearly all face budget constraints. Few have enough land or government rooftops to meet their goals within city limits.

“Cities face a situation where it’s a square peg in a round hole,” Cottingham said.

The hurdles are especially steep in much of the Southeast, where only publicly regulated utilities can sell electricity to retail customers, even large ones such as major cities. That’s where a green tariff regime comes in: Cities can purchase clean energy from a third party, such as a solar company, using the utility as a go-between.

Early last year, Charlotte became the largest city to use such a program, partnering with Duke Energy and two North Carolina solar developers to build a solar farm 50 miles north in Iredell County. At first, the city will pay a premium for the energy, but in the latter half of the 20-year contract, as gas prices rise, it will save money compared to business as usual.

“Over the course of 20 years, it’s projected we would save about $2 million,” Katie Riddle, sustainability analyst with Charlotte, told the Energy News Network last year.

The growing size of projects, innovative partnerships like green tariff programs, and the improving economics all give Abbott hope that renewable energy investments from cities will only grow — even with the Trump presidency over and the country back in the Paris agreement.

And when cities meet their goals for procuring renewable energy for their own operations, they must then turn to an even bigger task: reducing the carbon footprint of every person in their jurisdiction with broader decarbonization strategies and community engagement.

“The city needs to do its part for sure,” said Houston’s Cottingham. “Then we have this challenge of how do we get everyone else to.”

 

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Summerland solar power project will provide electricity

Summerland Solar+Storage Project brings renewable energy to a municipal utility with photovoltaic panels and battery storage, generating 1,200 megawatts from 3,200 panels on Cartwright Mountain to boost grid resilience and local clean power.

 

Key Points

A municipal solar PV and battery system enabling Summerland Power to self-generate electricity on Cartwright Mountain.

✅ 3,200 panels, 20-year batteries, 35-year panel lifespan

✅ Estimated $7M cost, $6M in grants, utility reserve funding

✅ Site near grid lines; 2-year timeline with 18-month lead

 

A proposed solar energy project, to be constructed on municipally-owned property on Cartwright Mountain, will allow Summerland Power to produce some of its own electricity, similar to how Summerside's wind power supplies a large share locally.

On Monday evening, municipal staff described the Solar+Storage project, aligning with insights from renewable power developers that combining resources yields better projects.

The project will include around 3,200 solar panels and storage batteries, giving Summerland Power the ability to generate 1,200 megawatts of electrical power.

This is the amount of energy used by 100 homes over the course of a year.

The solar panels have an estimated life expectancy of 35 years, while the batteries have a life expectancy of 20 years.

“It’s a really big step for a small utility like ours,” said Tami Rothery, sustainability/alternative energy coordinator for Summerland. “We’re looking forward to moving towards a bright, sunny energy future.”

She said the price of solar panels has been dropping, with lower-cost solar contracts reported in Alberta, and the quality and efficiency of the panels has increased in recent years.

The total cost of the project is around $7 million, with $6 million to come from grant funding and the remainder to come from the municipality’s electrical utility reserve fund, while policy changes such as Nova Scotia's solar charge delay illustrate evolving market conditions.

The site, a former public works yard and storage area, was selected from 108 parcels of land considered by the municipality.

She said the site, vacant since the 1970s, is close to main electrical lines and will not be highly visible once the panels are in place, much like unobtrusive rooftop solar arrays in urban settings.

Access to the site is restricted, resulting in natural security to the solar installation.

Jeremy Storvold, general manager of Summerland’s electrical utility, said the site is 2.5 kilometres from the Prairie Valley electrical substation and close to the existing public works yard.

However, some in the audience on Monday questioned the location of the proposed solar installation, suggesting the site would be better suited for affordable housing in the community.

The timeline for the project calls for roughly two years before the work will be completed, since there is an 18-month lead time in order to receive good quality solar panels, reflecting the surge in Alberta's solar growth that is straining supply chains.

 

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