Clean city plans scaled back

Medicine Hat Bitcoin Mining Facility drives massive electricity demand and energy use, leveraging natural gas and nearby wind power; Hut 8 touts economic growth, while critics cite carbon emissions, renewables integration, and climate impact.

Key Points

A Hut 8 project in Alberta that mines bitcoin at scale, consuming up to 60 MW and impacting energy and emissions.

✅ Consumes more than 60 MW, rivaling citywide electricity use

✅ Sited by natural gas plant; wind turbines nearby

✅ Economic gains vs. carbon emissions and climate risks

On the day of the grand opening of the largest bitcoin mining project in the country, the weather was partly cloudy and 15 C. On a Friday afternoon like this one, the new facility uses as much electricity as all of Medicine Hat, Alta., a city of more than 60,000 people and home to several large industrial plants.

The vast amount of electricity needed for bitcoin mining is why the city of Medicine Hat has championed the economic benefits of the project, while environmentalists say they are wary of the significant energy use.

Toronto-based Hut 8 has spent more than $100 million to develop the 4½-hectare site on the northern edge of the city. It has 56 shipping containers, each filled with 180 computer servers that digitally mine for bitcoin around the clock.

The company said it has already mined more than 3,300 bitcoins in Alberta, including at its much smaller site in Drumheller. On average, the Medicine Hat facility mines about 20 bitcoins per day. The value of bitcoin can fluctuate daily, but has sold recently for around $9,000.

The bitcoin mining facility is located right beside the city of Medicine Hat's new natural gas-fired power plant and four wind turbines are a short distance away. The bitcoin plant can consume more than 60 megawatts of power, more than 10 times more electricity used by any other facility in the city, according to the mayor.

That's why, in the event of a summer heat wave, the city has provisions in place to pull the plug on the electricity it provides to Hut 8, mirroring utility pauses on crypto loads seen elsewhere, so there won't be any blackouts for residents, according to the mayor.

Still, some say the bitcoin mining industry wastes far too much energy

"It's a huge magnitude when you talk about the carbon emissions," said Saeed Kaddoura, an analyst with the Pembina Institute, an environmental think-tank. "Moving forward, there needs to be some consideration on what the environmental impact of this is."

Medicine Hat owns its own natural gas and electricity generation and distribution businesses. The city leases the land to Hut 8 and the facility employs 40 full-time workers. Add up the economic benefits and the city of Medicine Hat will receive a significant financial boost from the new project, says Ted Clugston, the city's mayor.

Financial details of the city's deal with Hut 8 are not disclosed.

For more than a century, the city has attracted business by offering low-cost energy, and the mayor said this project is no different.

"They could have gone anywhere in the world and they chose Medicine Hat," said Clugston. "[Hut 8] is not here for renewable energy because it is not reliable. They need gas-fired generation and we have it in spades."

Environmental groups are concerned by the sheer amount of energy consumed by bitcoin mining, with some utilities warning they can't serve new energy-intensive customers right now, especially in places like Medicine Hat where most of the electricity is produced by fossil fuels.

The bitcoin system is designed, so only a limited number of the cryptocurrency can be mined everyday. Over time, as more miners compete for a decreasing number of available bitcoins, facilities will have to use more electricity compared to the amount of the cryptocurrency they collect.

"The way the bitcoin algorithm works is that it's designed to waste as much electricity as possible. And the more popular bitcoin becomes, the more electricity it wastes," said Keith Stewart, a spokesperson for Greenpeace.

Stewart questions whether natural gas should be used to produce a digital product.

"If you live in Alberta, you want to have heat and light, those types of things. I don't think bitcoin is a necessity of life for anyone," he said.

The CEO of Hut 8 completely disagrees, arguing the cryptocurrency is essential.  

"Bitcoin was created during the financial crisis. It has really served a purpose in terms of providing the opportunity for people who don't necessarily trust their government or their central banks," said Andrew Kiguel.

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Germany 2025 Energy Costs forecast electricity and heating price trends amid gas volatility, renewables expansion, grid upgrades, and policy subsidies, highlighting impacts on households, industries, efficiency measures, and the Energiewende transition dynamics.

Key Points

Electricity stabilizes, gas-driven heating stays high; renewables, subsidies, and efficiency measures moderate costs.

✅ Power prices stabilize above pre-crisis levels

✅ Gas volatility keeps heating bills elevated

✅ Subsidies and efficiency upgrades offset some costs

As Germany moves into 2025, the country is facing significant shifts in heating and electricity costs. With a variety of factors influencing energy prices, including geopolitical tensions, government policies, and the ongoing transition to renewable energy sources, consumers and businesses alike are bracing for potential changes in their energy bills. In this article, we will explore how heating and electricity costs are expected to evolve in Germany in the coming year and what that means for households and industries.

Energy Price Trends in Germany

In recent years, energy prices in Germany have experienced notable fluctuations, particularly due to the aftermath of the global energy crisis, which was exacerbated by the Russian invasion of Ukraine. This geopolitical shift disrupted gas supplies, which in turn affected electricity prices and strained local utilities across the country. Although the German government introduced measures to mitigate some of the price increases, many households have still felt the strain of higher energy costs.

For 2024, experts predict that electricity prices will likely stabilize but remain higher than pre-crisis levels. While electricity prices nearly doubled in 2022, they have gradually started to decline, and the market has adjusted to the new realities of energy supply and demand. Despite this, the cost of electricity is expected to stay elevated as Germany continues to phase out coal and nuclear energy while ramping up the use of renewable sources, which often require significant infrastructure investments.

Heating Costs: A Mixed Outlook

Heating costs in Germany are heavily influenced by natural gas prices, which have been volatile since the onset of the energy crisis. Gas prices, although lower than the peak levels seen in 2022, are still considerably higher than in the years before. This means that households relying on gas heating can expect to pay more for warmth in 2024 compared to previous years.

The government has implemented measures to cushion the impact of these increased costs, such as subsidies for vulnerable households and efforts to support energy efficiency upgrades. Despite these efforts, consumers will still feel the pinch, particularly in homes that use older, less efficient heating systems. The transition to more sustainable heating solutions, such as heat pumps, remains a key goal for the German government. However, the upfront cost of such systems can be a barrier for many households.

The Role of Renewable Energy and the Green Transition

Germany has set ambitious goals for its energy transition, known as the "Energiewende," which aims to reduce reliance on fossil fuels and increase the share of renewable energy sources in the national grid. In 2024, Germany is expected to see further increases in renewable energy generation, particularly from wind and solar power. While this transition is essential for reducing carbon emissions and improving long-term energy security, the shift comes with its own challenges already documented in EU electricity market trends reports.

One of the main factors influencing electricity costs in the short term is the intermittency of renewable energy sources. Wind and solar power are not always available when demand peaks, requiring backup power generation from fossil fuels or stored energy. Additionally, the infrastructure needed to accommodate a higher share of renewables, including grid upgrades and energy storage solutions, is costly and will likely contribute to rising electricity prices in the near term.

On a positive note, Germany's growing investment in renewable energy is expected to make the country less reliant on imported fossil fuels, particularly natural gas, which has been a major source of price volatility. Over time, as the share of renewables in the energy mix grows, the energy system should become more stable and less susceptible to geopolitical shocks, which could lead to more predictable and potentially lower energy costs in the long run.

Government Interventions and Subsidies

To help ease the burden on consumers, the German government has continued to implement various measures to support households and businesses. One of the key programs is the reduction in VAT (Value Added Tax) on electricity, which has been extended in some regions. This measure is designed to make electricity more affordable for all households, particularly those on fixed incomes facing EU energy inflation pressures that have hit the poorest hardest.

Moreover, the government has been providing financial incentives for households and businesses to invest in energy-efficient technologies, such as insulation and energy-saving heating systems, complementing the earlier 200 billion euro energy shield announced to buffer surging prices. These incentives are intended to reduce overall energy consumption, which could offset some of the rising costs.

The outlook for heating and electricity costs in Germany for 2024 is mixed, even as energy demand hit a historic low amid economic stagnation. While some relief from the extreme price spikes of 2022 may be felt, energy costs will still be higher than they were in previous years. Households relying on gas heating will likely see continued elevated costs, although those who invest in energy-efficient solutions or renewable heating technologies may be able to offset some of the increases. Similarly, electricity prices are expected to stabilize but remain high due to the country’s ongoing transition to renewable energy sources.

While the green transition is crucial for long-term sustainability, consumers must be prepared for potentially higher energy costs in the short term. Government subsidies and incentives will help alleviate some of the financial pressure, but households should consider strategies to reduce energy consumption, such as investing in more efficient heating systems or adopting renewable energy solutions like solar panels.

As Germany navigates these changes, the country’s energy future will undoubtedly be shaped by a delicate balance between environmental goals and the economic realities of transitioning to a greener energy system.

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Scottish Renewable Grid Upgrades address outdated infrastructure, expanding transmission lines, pylons, and substations to move clean energy, meet rising electricity demand, and integrate onshore wind, offshore wind, and battery storage across Scotland.

Key Points

Planned transmission upgrades in Scotland to move clean power via new lines and substations for a low-carbon grid.

✅ Fivefold expansion of transmission lines by 2030

✅ Enables onshore and offshore wind integration

✅ New pylons, substations, and routes face local opposition

Renewable energy in Scotland is being held back by outdated grid infrastructure, industry leaders said, with projects stuck on hold underscoring their warning that new pylons and power lines are needed to "ensure our lights stay on".

Scottish Renewables said new infrastructure is required to transmit the electricity generated by green power sources and help develop "a clean energy future" informed by a broader green recovery agenda.

A new report from the organisation - which represents companies working across the renewables sector - makes the case for electricity infrastructure to be updated, aligning with global network priorities identified elsewhere.

But it comes as electricity firms looking to build new lines or pylons face protests, with groups such as the Strathpeffer and Contin Better Cable Route challenging power giant SSEN over the route chosen for a network of pylons that will run for about 100 miles from Spittal in Caithness to Beauly, near Inverness.

Scottish Renewables said it is "time to be upfront and honest" about the need for updated infrastructure.

It said previous work by the UK National Grid estimated "five times more transmission lines need to be built by 2030 than have been built in the past 30 years, at a cost of more than £50bn".

The Scottish Renewables report said: "Scotland is the UK's renewable energy powerhouse. Our winds, tides, rainfall and longer daylight hours already provide tens of thousands of jobs and billions of pounds of economic activity.

"But we're being held back from doing more by an electricity grid designed for fossil fuels almost a century ago, a challenge also seen in the Pacific Northwest today."

Investment in the UK transmission network has "remained flat, and even decreased since 2017", echoing stalled grid spending trends elsewhere, the report said.

It added: "We must build more power lines, pylons and substations to carry that cheap power to the people who need it - including to people in Scotland.

"Electricity demand is set to increase by 50% in the next decade and double by mid-century, so it's therefore wrong to say that Scottish households don't need more power lines, pylons and substations.

Renewable energy in Scotland is being held back by outdated grid infrastructure, industry leaders said, as they warned new pylons and power lines are needed to "ensure our lights stay on".

Scottish Renewables said new infrastructure is required to transmit the electricity generated by green power sources and help develop "a clean energy future".

A new report from the organisation - which represents companies working across the renewables sector - makes the case for electricity infrastructure to be updated.

But it comes as electricity firms looking to build new lines or pylons face protests, with groups such as the Strathpeffer and Contin Better Cable Route challenging power giant SSEN over the route chosen for a network of pylons that will run for about 100 miles from Spittal in Caithness to Beauly, near Inverness.

Scottish Renewables said it is "time to be upfront and honest" about the need for updated infrastructure.

It said previous work by the UK National Grid estimated "five times more transmission lines need to be built by 2030 than have been built in the past 30 years, at a cost of more than £50bn".

The Scottish Renewables report said: "Scotland is the UK's renewable energy powerhouse. Our winds, tides, rainfall and longer daylight hours already provide tens of thousands of jobs and billions of pounds of economic activity.

"But we're being held back from doing more by an electricity grid designed for fossil fuels almost a century ago."

Investment in the UK transmission network has "remained flat, and even decreased since 2017", the report said.

It added: "We must build more power lines, pylons and substations to carry that cheap power to the people who need it - including to people in Scotland.

"Electricity demand is set to increase by 50% in the next decade and double by mid-century, so it's therefore wrong to say that Scottish households don't need more power lines, pylons and substations.

"We need them to ensure our lights stay on, as excess solar can strain networks in the same way consumers elsewhere in the UK need them.

"With abundant natural resources, Scotland's home-grown renewables can be at the heart of delivering the clean energy needed to end our reliance on imported, expensive fossil fuel.

"To do this, we need a national electricity grid capable of transmitting more electricity where and when it is needed, echoing New Zealand's electricity debate as well."

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Nick Sharpe, director of communications and strategy at Scottish Renewables, said the current electricity network is "not fit for purpose".

He added: "Groups and individuals who object to the construction of power lines, pylons and substations largely do so because they do not like the way they look.

"By the end of this year, there will be just over 70 months left to achieve our targets of 11 gigawatts (GW) offshore and 12 GW onshore wind.

"To ensure we maximise the enormous socioeconomic benefits this will bring to local communities, we will need a grid fit for the 21st century."

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China Power Rationing disrupts the solar supply chain as coal shortages, price controls, and dual-control emissions policy curb electricity, squeezing polysilicon, aluminum, and module production and raising equipment costs amid surging post-Covid industrial demand.

Key Points

China's electricity curbs from coal shortages, price caps, and emissions targets disrupt solar output and materials.

✅ Polysilicon and aluminum output cut by power rationing

✅ Coal price spikes and power price caps squeeze generators

✅ Dual-control emissions policy triggers provincial curbs

The solar manufacturing supply chain is among the industries being affected by a combination of soaring power demand, coal shortages, and carbon emission reduction measures which have seen widespread power cuts in China.

In Yunnan province, in southwest China, producers of the silicon metal which feeds polysilicon have been operating at 10% of the output they achieved in August. They are expected to continue to do so for the rest of the year as provincial authorities try to control electricity demand with a measure that is also affecting the phosphorus industry.

Fellow solar supply chain members from the aluminum industry in Guangxi province, in the south, have been forced to operate just two days per week, alongside peers in the concrete, steel, lime, and ceramics segments. Manufacturers in neighboring Guangdong have access to normal power supplies only on Fridays and Saturdays with electricity rationed to a 15% grid security load for the rest of the time.

pv magazine USA reported that a Tier 1 solar module manufacturer warned customers in an email that energy shortages in China have forced it to reduce or stop production at its Chinese manufacturing sites. The company warned the event will also affect output from its downstream cell and module production facilities in Southeast Asia.

The memo said that in order to recover from the effects of the “potential Force Majeure event,” it may delay or stop equipment delivery or seek to renegotiate contracts to pass through higher prices.

Raw material sourcing
With reports of drastic power shortages emerging from China in recent days, the country has actually been experiencing problems since late June, and similar pressures have seen India ration coal supplies this year, but rationing is not unusual during the peak summer hours.

What has changed this time is that the outages have continued and prompted rationing measures across 19 of the nation’s provinces for the rest of the year. The problems have been caused by a combination of rising post-Covid electricity demand at a time when the politically-motivated ban on imports of Australian coal has tightened supply; and the manner in which Beijing controls power prices, with the situation further exacerbated by carbon emissions reduction policy.

Demand
Electricity demand from industry, underscoring China’s electricity appetite, was 13.5 percentage points higher in the first eight months of the year than in the same period of 2020, at 3,585 TWh. That reflected a 13.8% year-on-year rise in total consumption, following earlier power demand drops when coronavirus shuttered plants, to 5.47 PWh, according to data from state energy industry trade body the China Electricity Council.

Figures produced by the China General Administration of Customs tell the same story: a rebound driven by the global recovery from the pandemic, as global power demand surges above pre-pandemic levels, with China recording import and export trade worth RMB2.48 trillion ($385 billion) in January-to-August. That was up 23.7% on the same period of last year and 22.8% higher than in the first eight months of 2019.

With Beijing having enforced an unofficial ban on imports of Australian coal for the last year or so – as the result of an ongoing diplomatic spat with Australia – rising demand for coal (which provided around 73% of Chinese electricity in the first half of the year) has further raised prices for the fossil fuel.

The problem for Chinese coal-fired power generators is that Beijing maintains strict controls on the price of electricity. As a result, input costs cannot be passed on to consumers. The mismatch between a liberalized coal market and centrally controlled end-user prices is illustrated by the current situation in Guangdong. There, a coal price of RMB1,560 per ton ($242) has pushed the cost of coal-fired electricity up to RMB0.472 per kilowatt-hour ($0.073). With coal power companies facing an electricity price ceiling of around RMB0.463/kWh ($0.071), generators are losing around RMB0.12 for every kilowatt-hour they generate. In that situation, rationing electricity supplies is an obvious remedy.

The crisis has been worsened by the introduction of China’s “dual control” energy policy, which aims to help meet President Xi Jinping’s climate change pledge of hitting peak carbon emissions this decade and a net zero economy by 2060, and to reduce coal power production over time. Dual control refers to attempts to wind down greenhouse gas emissions at both a national level and in more local areas, such as provinces and cities.

Red status
With the finer details of the carbon reduction policy yet to be ironed out, government departments and provincial and city authorities have started to set their own emission-reduction targets. In mid-August, state planning body the China National Development and Reform Commission (NDRC) published a table of the energy control situation across the nation. With nine provinces marked red for their energy consumption, and a further 10 highlighted as yellow, officials received another motivation to introduce power rationing.

China’s solar industry is being impacted by coal shortages for electric power generation. In this 2014 photo, a thermal generating plant’s cooling towers loom over a street in Henan Province.
Image: flickr/V.T. Polywoda

The current approach of rolling blackouts seems unlikely to be a sustainable solution, as surging electricity demand strains power systems worldwide, given the damage it could inflict on industry and the resentment it would cause in parts of the nation already preparing for winter.

The choice facing China’s policymakers is whether to ramp up coal supplies to force prices down by using decommissioned domestic supplies and halting the ban on Australian imports, or to raise electricity prices to prompt generators to get the lights back on. While the drawbacks of raising household electricity bills seem obvious, the first approach of using more coal could endanger the nation’s climate change commitments on the even of the COP26 meeting in Glasgow, Scotland, in November. Sources close to the NDRC have suggested the electricity price may be set to rise soon.

GDP
What is clear is the effect the energy crisis is having on the Chinese economy and on the solar supply chain. Leading up to a  national day holiday in China, the coal price in northern China rose to around RMB2,000 per ton ($310), three times higher than at the beginning of the year.

Investment bank China International Capital Corp. blamed the dual control emission reduction policy for the electricity shortages. It predicted a 0.1-0.15 percentage point impact on economic growth in the last quarter of 2021.  Morgan Stanley has put that figure at 1% in the current quarter, if industrial output restrictions continue. And Japan’s Nomura Securities revised down its annual forecast on Chinese growth from 8.2% to 7.7%. It now expects GDP gains in the third and fourth quarters to cool from 5.1% to 4.7%, and from 4.4% to 3%, respectively.

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Hydro One CEO Salary shapes debate on Ontario electricity costs, executive compensation, sunshine list transparency, and public disclosure rules, as officials argue pay is not driving planned hydro rate cuts for consumers.

Key Points

Hydro One CEO pay disclosed in public filings, central to debates on Ontario electricity rates and transparency.

✅ 2016 compensation: $4.5M (salary + bonuses)

✅ Excluded from Ontario's sunshine list after privatization

✅ Government says pay won't affect planned hydro rate cuts

The $4.5 million in pay received by Hydro One's CEO is not a factor in the government's plan to cut electricity costs for consumers, an Ontario cabinet minister said Thursday amid opposition concerns about the executive's compensation and wider sector pressures such as Manitoba Hydro's rising debt in other provinces.

Treasury Board President Liz Sandals made her comments on the eve of the release of the province's so-called sunshine list.

The annual disclosure of public-sector salaries over $100,000 will be released Friday, but Hydro One salaries such as that of company boss Mayo Schmidt won't be on it.Though the government still owns most of Hydro One — 30 per cent has been sold — the company is required to follow the financial disclosure rules of publicly traded companies, which means disclosing the salaries of its CEO, CFO and next three highest-paid executives, and financial results such as a Q2 profit decline in filings.

New filings show that Schmidt was paid $4.5 million in 2016 — an $850,000 salary plus bonuses — and those top five executives were paid a total of about $11.7 million. 

"Clearly that's a very large amount," said Sandals. Sandals wouldn't say whether or not she thought the pay was appropriate at a time when the government is trying to reduce system costs and cut people's hydro bills.

Mayo Schmidt, President & CEO of Hydro One Limited and Hydro One Inc. (Hydro One )

But she suggested the CEO's salary was not a factor in efforts to bring down hydro prices, even as Hydro One shares fell after a leadership shakeup in a later period. "The CEO salary is not part of the equation of will 'we be able to make the cut,"' she said. "Regardless of what those salaries are, we will make a 25-per-cent-off cut." The cut coming this summer is actually an average of 17 per cent -- the 25-per-cent figure factors in an earlier eight-per-cent rebate.

NDP Leader Andrea Horwath, who has proposed to make hydro public again in Ontario, said the executive salaries are relevant to cutting hydro costs.

"All of this is cost of operating the electricity system, it's part of the operating of Hydro One and so of course those increased salaries are going to impact the cost of our electricity," she said.

Schmidt was appointed Aug. 31, 2015, and in the last four months of that year earned $1.3 million, but the former CEO was paid $745,000 in 2014. About 3,800 workers were paid over $100,000 that year, none of whom will be on the sunshine list this year.

Progressive Conservative energy critic Todd Smith has a private member's bill that would put Hydro One salaries back on the list, amid investor concerns about Hydro One that cite too many unknowns.

"The Wynne Liberals don't want the people of Ontario to know that their rates have helped create a new millionaire's club at Hydro One," Smith said. "Hydro One is still under the majority ownership of the public, but Premier Kathleen Wynne has removed these salaries from the public's watchful eye."

The previous sunshine list showed 115,431 people were earning more than $100,000 — an increase of nearly 4,000 people despite the fact 3,774 Hydro One workers were not on the list for the first time.

Tom Mitchell, the former CEO at Ontario Power Generation who resigned last summer, topped the 2015 list at $1.59 million.

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Cabin Creek Solar Project Montana delivers 150 MW of utility-scale solar under a Power Purchase Agreement, with Basin Electric and Clenera supplying renewable energy, enhancing grid reliability, and reducing carbon emissions for 30,000 homes.

Key Points

A 150 MW solar PPA near Baker by Basin Electric and Clenera, delivering reliable renewable power and carbon reduction.

✅ 150 MW across two 75 MW sites near Baker, Montana

✅ PPA supports Basin Electric's diverse, cost-effective portfolio

✅ Cuts 265,000 tons CO2 and powers 30,000 homes

A new solar project in Montana will provide another 150 megawatts (MW) of affordable, renewable power to Basin Electric customers and co-op members across the region.

Basin Electric Power Cooperative (Basin Electric) and Clenera Renewable Energy, announced today the execution of a Power Purchase Agreement (PPA) for the Cabin Creek Solar Project. Cabin Creek is Basin Electric's second solar PPA, and the result of the cooperative's continuing goal of providing a diverse mix of energy sources that are cost-effective for its members.

When completed, Cabin Creek will consist of two, 75-MW projects in southeastern Montana, five miles west of Baker. According to Clenera, the project will eliminate 265,000 tons of carbon dioxide per year and power 30,000 homes, while communities such as the Ermineskin First Nation advance their own generation efforts.

"Renewable technology has advanced dramatically in recent years, with rapid growth in Alberta underscoring broader trends, which means even more affordable power for Basin Electric's customers," said Paul Sukut, CEO and general manager of Basin Electric. "Basin Electric is excited to purchase the output from this project to help serve our members' growing energy needs. Adding solar further promotes our all-of-the-above energy solution as we generate energy using a diverse resource portfolio including coal, natural gas, and other renewable resources to provide reliable, affordable, and environmentally safe generation.

"Clenera is proud to partner with Basin Electric Power Cooperative to support the construction of the Cabin Creek Solar projects in Montana," said Jared McKee, Clenera's director of Business Development. "We truly believe that Basin Electric will be a valuable partner as we aim to deliver today's new era of reliable, battery storage increasingly enabling round-the-clock service, affordable, and clean energy."

"We're pleased that Southeast Electric will be home to the Cabin Creek Solar Project," said Jack Hamblin, manager of Southeast Electric Cooperative, a Basin Electric Class C member headquartered in Ekalaka, Montana. "This project is one more example of cooperatives working together to use economies of scale to add affordable generation for all their members - similar to what was done 70 years ago when cooperatives were first built."

Basin Electric Class A member Upper Missouri Power Cooperative, headquartered in Sidney, Montana, provides wholesale power to Southeast Electric and 10 other distribution cooperatives in western North Dakota and eastern Montana. "It is encouraging to witness the development of cost-competitive energy, including projects in Alberta contracted at lower cost than natural gas that demonstrate market shifts, like the Cabin Creek Solar Project, which will be part of the energy mix we purchase from Basin Electric for our member systems, said Claire Vigesaa, Upper Missouri's general manager. "The energy needs in our region are growing and this project will help us serve both our members, and our communities as a whole."

Cabin Creek will bring significant economic benefits to the local area. According to Clenera, the project will contribute $8 million in property taxes to Fallon County and $5 million for the state of Montana over 35 years. They say it will also create approximately 300 construction jobs and two to three full-time jobs.

"This project underscores the efforts by Montana's electric cooperatives to continue to embrace more carbon-free technology," said Gary Wiens, CEO of Montana Electric Cooperatives' Association. "It also demonstrates Basin Electric's commitment to seek development of renewable energy projects in our state. It's exciting that these two projects combined are 50 times larger than our current largest solar array in Montana."

Cabin Creek is anticipated to begin operations in late 2023.

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