DOE buys geothermal plant in Wyoming

By Associated Press


High Voltage Maintenance Training Online

Our customized live online or in‑person group training can be delivered to your staff at your location.

  • Live Online
  • 12 hours Instructor-led
  • Group Training Available
Regular Price:
$599
Coupon Price:
$499
Reserve Your Seat Today
The U.S. Energy Department has bought a geothermal plant north of Casper for an undisclosed amount.

Ormat Technologies, of Reno, Nev., built the test plant at the Teapot Dome oil field to prove the technical feasibility of using hot water associated with oil production to generate electricity.

The plant was designed to produce 250 kilowatts of electricity. It has been operating for over a year, providing electricity to operate the oil wells.

Officials say while the plant proves the technology's viability, more study is needed to see if it would work at other oil fields in the country.

The federal government plans to continue testing for another two years and collect more data related to long-term durability of the plant.

Related News

Alberta shift from coal to cleaner energy

Alberta Coal-to-Gas Transition will retire coal units, convert plants to natural gas, boost renewables, and affect electricity prices, with policy tools like a price cap and carbon tax shaping the power market.

 

Key Points

Shift retiring coal units and converting to natural gas and renewables, targeting coal elimination by 2030.

✅ TransAlta retires Sundance coal unit; more units convert to gas.

✅ Forward prices seen near $40 to low $50/MWh in 2018.

✅ 6.8-cent cap shields consumers; carbon tax backstops costs.

 

The turn of the calendar to 2018 saw TransAlta retire one of its coal power generating units at its Sundance plant west of Edmonton and mothball another as it begins the transition to cleaner sources of energy across Alberta.

The company will say goodbye to three more units over the next year and a half to prepare them for conversion to natural gas.

This is part of a fundamental shift in Alberta, which will see coal power retired ahead of schedule by 2030, replaced by a mix of natural gas and renewable sources.

“We’re going to see that transition continue right up from now until 2030, and likely beyond 2030 as wind generation starts to outpace coal and new technologies become available.”

Coal has long been the backbone of Alberta’s grid, currently providing nearly 40 per cent of the provinces power. Analysts believe removing it will come with a cost to consumers, according to a report on coal phase-out costs published recently.

“The open question over the next couple of years is whether they’re going to inch up gradually, or whether they’re going to inch up like they did in 2012 and 2013, by having periods of very high power prices.”

Albertans are currently paying historically low power prices, with generation costs last year averaging below $23/MWh, less than half of the average of the past 10 years.

A report released in mid-December by electricity consultant firm EDC Associates showed forward prices moving from the $40/MWh in the first three months of 2018, to the low $50/MWh range.

“The forwards tend to take several weeks to fully react to announcements, so its anticipated that prices will continue to gradually track upwards over the coming weeks,” the report reads.

The NDP government has taken steps to protect consumers against price surges. Last spring, a price cap of 6.8 cents/MWh was put in place until the spring of 2021, with any cost above that to be covered by carbon tax revenue.

 

Related News

View more

7 steps to make electricity systems more resilient to climate risks

Electricity System Climate Resilience underpins grid reliability amid heatwaves and drought, integrating solar, wind, hydropower, nuclear, storage, and demand response with efficient transmission, flexibility, and planning to secure power for homes, industry, and services.

 

Key Points

Power systems capacity to endure extreme weather and integrate clean energy, maintaining reliability and flexibility.

✅ Grid hardening, transmission upgrades, and digital forecasting.

✅ Flexible low-carbon supply: hydropower, nuclear, storage.

✅ Demand response, efficient cooling, and regional integration.

 

Summer is just half done in the northern hemisphere and yet we are already seeing electricity systems around the world struggling to cope with the severe strain of heatwaves and low rainfall.

These challenges highlight the urgent need for strong and well-planned policies and investments to improve the security of our electricity systems, which supply power to homes, offices, factories, hospitals, schools and other fundamental parts of our economies and societies. This means making our electricity systems more resilient to the effects of global warming – and more efficient and flexible as they incorporate rising levels of solar and wind power, as solar is now the cheapest electricity in history according to the IEA, which will be critical for reaching net-zero emissions in time to prevent even worse impacts from climate change.

A range of different countries, including the US, Canada and Iraq, have been hard hit by extreme weather recently in the form of unusually high temperatures. In North America, the heat soared to record levels in the Pacific Northwest. An electricity watchdog says that five US regions face elevated risks to the security of their electricity supplies this summer, underscoring US grid climate risks that could worsen, and that California’s risk level is even higher.

Heatwaves put pressure on electricity systems in multiple ways. They increase demand as people turn up air conditioning, driving higher US electricity bills for many households, and as some appliances work harder to maintain cool temperatures. At the same time, higher temperatures can also squeeze electricity supplies by reducing the efficiency and capacity of traditional thermal power plants, such as coal, natural gas and nuclear. Extreme heat can reduce the availability of water for cooling plants or transporting fuel, forcing operators to reduce their output. In some cases, it can result in power plants having to shut down, increasing the risk of outages. If the heat wave is spread over a wide geographic area, it also reduces the scope for one region to draw on spare capacity from its neighbours, since they have to devote their available resources to meeting local demand.

A recent heatwave in Texas forced the grid operator to call for customers to raise their thermostats’ temperatures to conserve energy. Power generating companies suffered outages at much higher rates than expected, providing an unwelcome reminder of February’s brutal cold snap when outages – primarily from natural gas power plants – left up to 5 million customers across the US without power over a period of four days.

At the same time, lower than average rainfall and prolonged dry weather conditions are raising concerns about hydropower’s electricity output in various parts of the world, including Brazil, China, India and North America. The risks that climate change brings in the form of droughts adds to the challenges faced by hydropower, the world’s largest source of clean electricity, highlighting the importance of developing hydropower resources sustainably and ensuring projects are climate resilient.

The recent spate of heatwaves and unusually long dry spells are fresh warnings of what lies ahead as our climate continues to heat up: an increase in the scale and frequency of extreme weather events, which will cause greater impacts and strains on our energy infrastructure.

Heatwaves will increase the challenge of meeting electricity demand while also decarbonizing the electricity supply. Today, the amount of energy used for cooling spaces – such as homes, shops, offices and factories – is responsible for around 1 billion tonnes of global CO2 emissions. In particular, energy for cooling can have a major impact on peak periods of electricity demand, intensifying the stress on the system. Since the energy demand used for air conditioners worldwide could triple by 2050, these strains are set to grow unless governments introduce stronger policy measures to improve the energy efficiency of air conditioning units.

Electricity security is crucial for smooth energy transitions
Many countries around the world have announced ambitious targets for reaching net-zero emissions by the middle of this century and are seeking to step up their clean energy transitions. The IEA’s recent Global Roadmap to Net Zero by 2050 makes it clear that achieving this formidable goal will require much more electricity, much cleaner electricity and for that electricity to be used in far more parts of our economies than it is today. This means electricity reaching much deeper into sectors such as transport (e.g. EVs), buildings (e.g. heat-pumps) and industry (e.g. electric-arc steel furnaces), and in countries like New Zealand's electrification plans it is accelerating broader efforts. As clean electricity’s role in the economy expands and that of fossil fuels declines, secure supplies of electricity become ever-more important. This is why the climate resilience of the electricity sector must be a top priority in governments’ policy agendas.

Changing climate patterns and more frequent extreme weather events can hit all types of power generation sources. Hydropower resources typically suffer in hot and dry conditions, but so do nuclear and fossil fuel power plants. These sources currently help ensure electricity systems have the flexibility and capacity to integrate rising shares of solar and wind power, whose output can vary depending on the weather and the time of day or year.

As governments and utilities pursue the decarbonization of electricity systems, mainly through growing levels of solar and wind, and carbon-free electricity options, they need to ensure they have sufficiently robust and diverse sources of flexibility to ensure secure supplies, including in the event of extreme weather events. This means that the possible decommissioning of existing power generation assets requires careful assessments that take into account the importance of climate resilience.

Ensuring electricity security requires long-term planning and stronger policy action and investment
The IEA is committed to helping governments make well-informed decisions as they seek to build a clean and secure energy future. With this in mind, here are seven areas for action for ensuring electricity systems are as resilient as possible to climate risks:

1. Invest in electricity grids to make them more resilient to extreme weather. Spending today is far below the levels needed to double the investment for cleaner, more electrified energy systems, particularly in emerging and developing economies. Economic recovery plans from the COVID-19 crisis offer clear opportunities for economies that have the resources to invest in enhancing grid infrastructure, but much greater international efforts are required to mobilize and channel the necessary spending in emerging and developing economies.

2. Improve the efficiency of cooling equipment. Cost-effective technology already exists in most markets to double or triple the efficiency of cooling equipment. Investing in higher efficiency could halve future energy demand and reduce investment and operating costs by $3 trillion between now and 2050. In advance of COP26, the Super-Efficient Equipment and Appliance Deployment (SEAD) initiative is encouraging countries to sign up to double the energy efficiency of equipment sold in their countries by 2030.

3. Enable the growth of flexible low-carbon power sources to support more solar and wind. These electricity generation sources include hydropower and nuclear, for countries who see a role for one or both of them in their energy transitions. Guaranteeing hydropower resilience in a warming climate will require sophisticated methods and tools – such as the ones implemented in Brazil – to calculate the necessary level of reserves and optimize management of reservoirs and hydropower output even in exceptional conditions. Batteries and other forms of storage, combined with solar or wind, can also provide important amounts of flexibility by storing power and releasing it when needed.

4. Increase other sources of electricity system flexibility. Demand-response and digital technologies can play an important role. The IEA estimates that only a small fraction of the huge potential for demand response in the buildings sector is actually tapped at the moment. New policies, which associate digitalization and financial behavioural incentives, could unlock more flexibility. Regional integration of electricity systems across national borders can also increase access to flexible resources.

5. Expedite the development and deployment of new technologies for managing extreme weather threats. The capabilities of electricity utilities in forecasting and situation awareness should be enhanced with the support of the latest information and communication technologies.

6. Make climate resilience a central part of policy-making and system planning. The interconnected nature of recent extreme weather events reminds us that we need to account for many contingencies when planning resilient power systems. Climate resilience should be integral to policy-making by governments and power system planning by utilities and relevant industries, and debates over Canadian climate policy underscore how grid implications must be considered. According to the recent IEA report on climate resilience, only nine out of 38 IEA member and association countries include concrete actions on climate adaptation and resilience for every segment of electricity systems.

7. Strengthen international cooperation on electricity security. Electricity underpins vital services and basic needs, such as health systems, water supplies and other energy industries. Maintaining a secure electricity supply is thus of critical importance. The costs of doing nothing in the face of growing climate threats are becoming abundantly clear. The IEA is working with all countries in the IEA family, as well as others around the world, by providing unrivalled data, analysis and policy advice on electricity security issues. It is also bringing governments together at various levels to share experiences and best practices, and identify how to hasten the shift to cleaner and more resilient energy systems.


 

 

Related News

View more

FortisAlberta Takes Necessary Precautions to Provide Electricity Service for Alberta

FortisAlberta COVID-19 response delivers safe electricity distribution across Alberta, with remote monitoring, 24/7 support, outage alerts, dispersed crews, and business continuity measures to sustain essential services for customers and communities.

 

Key Points

Plan ensuring reliable electricity in Alberta through 24/7 support, remote monitoring, outage alerts, and dispersed crews.

✅ 24/7 customer support via 310-WIRE and mobile app

✅ Remote monitoring and rapid outage restoration

✅ Dispersed crews in 50 communities for faster response

 

As the COVID-19 pandemic continues to evolve in Alberta (and around the world), FortisAlberta is taking the necessary actions and precautions informed by utility disaster planning to protect the health and well-being of its employees and to provide electricity service to its customers. FortisAlberta serves more than half a million customers with the electricity they depend on to take care of their families and community members throughout our province.

"We recognize these are challenging times as while most Albertans are asked to stay home others continue to work in the community to provide essential services, including utility workers in Ontario demonstrating support efforts. As your electricity distribution provider, please be assured you can count on us to do what we do best – provide our customers with safe and reliable electricity service wherever and whenever they need it," says Michael Mosher, FortisAlberta President and CEO.

FortisAlberta is proud to be a part of the communities it serves and commits to keeping the lights on for its customers. The company is providing a full range of services for its customers and has instilled best practices within critical parts of its business. The company's control centre continues to remotely monitor, control, and restore, where possible, the delivery of power across the entire province, including during events such as an Alberta grid alert that stress the system. Early in March, FortisAlberta implemented its business continuity plan and the company remains fully accessible to customers 24/7 by phone at 310-WIRE (9473) or through its mobile app where customers can report outages online or view details of an outage. Customers can also sign up for outage alerts to their mobile phone and/or email address to let them know if an outage does occur.

FortisAlberta's power line employees are geographically dispersed across 50 different communities so they can quickly address any issues that may arise. The company has implemented work from home measures and isolation best practices, and is planning for potential on-site lockdowns where necessary to ensure no disruption to customers.

FortisAlberta will continue to remain in close communication with its stakeholders to provide updates to customers and with industry associations to share guidance specific to the electricity sector, including insights on the evolving U.S. grid response to COVID-19 from peer utilities. FortisAlberta will also continue to invest in and empower its communities by contributing to organizations that offer programs and services aligned with the greatest needs in the communities it serves.

With the Alberta Government's recent announcement to provide relief to eligible Albertans by deferring electricity and gas charges for up to 90 days, similar to some B.C. relief measures being implemented, FortisAlberta is committed to working with stakeholders and retail partners to ensure this option is available to customers quickly and efficiently, and to learn from initiatives like the Hydro One relief fund that support customers.

 

Related News

View more

Scientists Built a Genius Device That Generates Electricity 'Out of Thin Air'

Air-gen Protein Nanowire Generator delivers clean energy by harvesting ambient humidity via Geobacter-derived conductive nanowires, generating continuous hydrovoltaic electricity through moisture gradients, electrodes, and proton diffusion for sustainable, low-waste power in diverse climates.

 

Key Points

A device using Geobacter protein nanowires to harvest humidity, producing continuous DC power via proton diffusion.

✅ 7 micrometer film between electrodes adsorbs water vapor.

✅ Output: ~0.5 V, 17 uA/cm2; stack units to scale power.

✅ Geobacter optimized via engineered E. coli for mass nanowires.

 

They found it buried in the muddy shores of the Potomac River more than three decades ago: a strange "sediment organism" that could do things nobody had ever seen before in bacteria.

This unusual microbe, belonging to the Geobacter genus, was first noted for its ability to produce magnetite in the absence of oxygen, but with time scientists found it could make other things too, like bacterial nanowires that conduct electricity.

For years, researchers have been trying to figure out ways to usefully exploit that natural gift, and they might have just hit pay-dirt with a device they're calling the Air-gen. According to the team, their device can create electricity out of… well, almost nothing, similar to power from falling snow reported elsewhere.

"We are literally making electricity out of thin air," says electrical engineer Jun Yao from the University of Massachusetts Amherst. "The Air-gen generates clean energy 24/7."

The claim may sound like an overstatement, but a new study by Yao and his team describes how the air-powered generator can indeed create electricity with nothing but the presence of air around it. It's all thanks to the electrically conductive protein nanowires produced by Geobacter (G. sulfurreducens, in this instance).

The Air-gen consists of a thin film of the protein nanowires measuring just 7 micrometres thick, positioned between two electrodes, referencing advances in near light-speed conduction in materials science, but also exposed to the air.

Because of that exposure, the nanowire film is able to adsorb water vapour that exists in the atmosphere, offering a contrast to legacy hydropower models, enabling the device to generate a continuous electrical current conducted between the two electrodes.

The team says the charge is likely created by a moisture gradient that creates a diffusion of protons in the nanowire material.

"This charge diffusion is expected to induce a counterbalancing electrical field or potential analogous to the resting membrane potential in biological systems," the authors explain in their study.

"A maintained moisture gradient, which is fundamentally different to anything seen in previous systems, explains the continuous voltage output from our nanowire device."

The discovery was made almost by accident, when Yao noticed devices he was experimenting with were conducting electricity seemingly all by themselves.

"I saw that when the nanowires were contacted with electrodes in a specific way the devices generated a current," Yao says.

"I found that exposure to atmospheric humidity was essential and that protein nanowires adsorbed water, producing a voltage gradient across the device."

Previous research has demonstrated hydrovoltaic power generation using other kinds of nanomaterials – such as graphene-based systems now under study – but those attempts have largely produced only short bursts of electricity, lasting perhaps only seconds.

By contrast, the Air-gen produces a sustained voltage of around 0.5 volts, with a current density of about 17 microamperes per square centimetre, and complementary fuel cell solutions can help keep batteries energized, with a current density of about 17 microamperes per square centimetre. That's not much energy, but the team says that connecting multiple devices could generate enough power to charge small devices like smartphones and other personal electronics – concepts akin to virtual power plants that aggregate distributed resources – all with no waste, and using nothing but ambient humidity (even in regions as dry as the Sahara Desert).

"The ultimate goal is to make large-scale systems," Yao says, explaining that future efforts could use the technology to power homes via nanowire incorporated into wall paint, supported by energy storage for microgrids to balance supply and demand.

"Once we get to an industrial scale for wire production, I fully expect that we can make large systems that will make a major contribution to sustainable energy production."

If there is a hold-up to realising this seemingly incredible potential, it's the limited amount of nanowire G. sulfurreducens produces.

Related research by one of the team – microbiologist Derek Lovley, who first identified Geobacter microbes back in the 1980s – could have a fix for that: genetically engineering other bugs, like E. coli, to perform the same trick in massive supplies.

"We turned E. coli into a protein nanowire factory," Lovley says.

"With this new scalable process, protein nanowire supply will no longer be a bottleneck to developing these applications."

 

Related News

View more

New England Emergency fuel stock to cost millions

Inventoried Energy Program pays ISO-NE generators for fuel security to boost winter reliability, with FERC approval, covering fossil, nuclear, hydropower, and batteries, complementing capacity markets to enhance grid resilience during severe cold snaps.

 

Key Points

ISO-NE program paying generators to hold fuel or energy reserves for emergencies, boosting winter reliability.

✅ FERC-approved stopgap for 2023 and 2024 winter seasons

✅ Pays for on-site fuel or stored energy during cold-trigger events

✅ Open to fossil, nuclear, hydro, batteries; limited gas participation

 

Electricity ratepayers in New England will pay tens of millions of dollars to fossil fuel and nuclear power plants later this decade under a program that proponents say is needed to keep the lights on during severe winters but which critics call a subsidy with little benefit to consumers or the grid, even as Connecticut is pushing a market overhaul across the region.

Last week the Federal Energy Regulatory Commission said ISO-New England, which runs the six-state power grid, can create what it calls the Inventoried Energy Program or IEP. This basically will pay certain power plants to stockpile of fuel for use in emergencies during two upcoming winters as longer-term solutions are developed.

The federal commission called it a reasonable short-term solution to avoid brownouts which doesn’t favor any given technology.

Not all agree, however, including FERC Commissioner Richard Glick, who wrote a fiery dissent to the other three commissioners.

“The program will hand out tens of millions of dollars to nuclear, coal and hydropower generators without any indication that those payments will cause the slightest change in those generators’ behavior,” Glick wrote. “Handing out money for nothing is a windfall, not a just and reasonable rate.”

The program is the latest reaction by ISO-NE to the winter of 2013-14 when New England almost saw brownouts because of a shortage of natural gas to create electricity during a pair of week-long deep freezes.

ISO-New England says the situation is more critical now because of the possible retirement of the gas-fired Mystic Generating Station in Massachusetts. As with closed nuclear plants such as Vermont Yankee and Pilgrim in Massachusetts, power plant owners say lower electricity prices, partly due to cheap renewables and partly to stagnant demand, means they can’t be profitable just by selling power.

Programs like the IEP are meant to subsidize such plants – “incentivize” is the industry term – even though some argue there is no need to subsidize nuclear in deregulated markets so they’ll stay open if they are needed.

The IEP approved last week will be applied to the winters of 2023 and 2024, after a different subsidy program expires. It sets prices, despite warnings about rushing pricing changes from industry groups, for stocking certain amounts of fuel and payments during any “trigger” event, defined as a day when the average of high and low temperatures at Bradley International Airport in Connecticut is no more than 17 degrees Fahrenheit.

These payments will be made on top of a complex system of grid auctions used to decide how much various plants get paid for generating electricity at which times.

ISO-NE estimates the new program will cost between $102 million and $148 million each winter, depending on weather and market conditions.

It says the payments are open to plants that burn oil, coal, nuclear fuel, wood chips or trash; utility-scale battery storage facilities; and hydropower dams “that store water in a pond or reservoir.” Natural gas plants can participate if they guarantee to have fuel available, but that seems less likely because of winter heating contracts.

A major complaint and groups that filed petitions opposing the project is that ISO-NE presented little supporting evidence of how prices, amount and overall cost were determined. ISO-NE argued that there wasn’t time for such analysis before the Mystic shutdown, and FERC agreed.

“The proposal is a step in the right direction … while ISO-NE finishes developing a long-term market solution,” the commission said in its ruling.

The program is the latest example of complexities facing the nation’s electricity system evolves in the face of solar and wind power, which produce electricity so cheaply that they can render traditional power uneconomic but which can’t always produce power on demand, prompting discussions of Texas grid improvements among policymakers. Another major factor is climate change, which has increased the pressure to support renewable alternatives to plants that burn fossil fuels, as well as stagnant electricity demand caused by increased efficiency.

Opponents, including many environmental groups, say electricity utilities and regulators are too quick to prop up existing systems, as the 145-mile Maine transmission line debate shows, built when electricity was sent one way from a few big plants to many customers. They argue that to combat climate change as well as limit cost, the emphasis must be on developing “non-wire alternatives” such as smart systems for controlling demand, in order to take advantage of the current system in which electricity goes two ways, such as from rooftop solar back into the grid.

 

Related News

View more

Clean-energy generation powers economy, environment

Atlin Hydro and Transmission Project delivers First Nation-led clean energy via hydropower to the Yukon grid, replacing diesel, cutting emissions, and creating jobs, with a 69-kV line from Atlin, B.C., supplying about 35 GWh annually.

 

Key Points

A First Nation-led 8.5 MW hydropower and 69-kV line supplying clean energy to the Yukon, reducing diesel use.

✅ 8.5 MW capacity; ~35 GWh annually to Yukon grid

✅ 69-kV, 92 km line links Atlin to Jakes Corner

✅ Creates 176 construction jobs; cuts diesel and emissions

 

A First Nation-led clean-power generation project for British Columbia’s Northwest will provide a significant economic boost and good jobs for people in the area, as well as ongoing revenue from clean energy sold to the Yukon.

“This clean-energy project has the potential to be a win-win: creating opportunities for people, revenue for the community and cleaner air for everyone across the Northwest,” said Premier John Horgan. “That’s why our government is proud to be working in partnership with the Taku River Tlingit First Nation and other levels of government to make this promising project a reality. Together, we can build a stronger, cleaner future by producing more clean hydropower to replace fossil fuels – just as they have done here in Atlin.”

The Province is contributing $20 million toward a hydroelectric generation and transmission project being developed by the Taku River Tlingit First Nation (TRTFN) to replace diesel electricity generation in the Yukon, which is also supported by the Government of Yukon and the Government of Canada, and comes as BC Hydro demand fell during COVID-19 across the province.

“Renewable-energy projects are helping remote communities reduce the use of diesel for electricity generation, which reduces air pollution, improves environmental outcomes and creates local jobs,” said Bruce Ralston, Minister of Energy, Mines and Low Carbon Innovation. “This project will advance reconciliation with TRTFN, foster economic development in Atlin and support intergovernmental efforts to reduce greenhouse gas emissions.”

TRTFN is based in Atlin with territory in B.C., the Yukon, and Alaska. TRTFN is an active participant in clean-energy development and, since 2009, has successfully replaced diesel-generated electricity in Atlin with a 2.1-megawatt (MW) hydro facility amid oversight issues such as BC Hydro misled regulator elsewhere in the province today.

TRTFN owns the Tlingit Homeland Energy Limited Partnership (THELP), which promotes economic development through clean energy. THELP plans to expand its hydro portfolio by constructing the Atlin Hydro and Transmission Project and selling electricity to the Yukon via a new transmission line, in a landscape shaped by T&D rates decisions in jurisdictions like Ontario for cost recovery.

The Government of Yukon is requiring its Yukon Energy Corporation (YEC) to generate 97% of its electricity from renewable resources by 2030. This project provides an opportunity for the Yukon government to reduce reliance on diesel generators and to meet future load growth, at a time when Manitoba Hydro's debt pressures highlight utility cost challenges.

The new transmission line between Atlin and the Yukon grid will include a fibre-optic data cable to support facility operations, with surplus capacity that can be used to bring high-speed internet connectivity to Atlin residents for the first time.

“Opportunities like this hydroelectricity project led by the Taku River Tlingit First Nation is a great example of identifying and then supporting First Nations-led clean-energy opportunities that will support resilient communities and provide clean economic opportunities in the region for years to come. We all have a responsibility to invest in projects that benefit our shared climate goals while advancing economic reconciliation.” said George Heyman, Minister of Environment and Climate Change Strategy.

“Thank you to the Government of British Columbia for investing in this important project, which will further strengthen the connection between the Yukon and Atlin. This ambitious initiative will expand renewable energy capacity in the North in partnership with the Taku River Tlingit First Nation while reducing the Yukon’s emissions and ensuring energy remains affordable for Yukoners.“ said Sandy Silver, Premier of Yukon.

“The Atlin Hydro Project represents an important step toward meeting the Yukon’s growing electricity needs and the renewable energy targets in the Our Clean Future strategy. Our government is proud to contribute to the development of this project and we thank the Government of British Columbia and all partners for their contributions and commitment to renewable energy initiatives. This project demonstrates what can be accomplished when communities, First Nations and federal, provincial and territorial governments come together to plan for a greener economy and future.” said John Streicker, Minister Responsible for the Yukon Development Corporation. 

“Atlin has enjoyed clean and renewable energy since 2009 because of our hydroelectric project. Over its lifespan, Atlin’s hydro opportunity will prevent more than one million tonnes of greenhouse gases from being created to power the southern Yukon. We are looking forward to the continuation of this project. Our collective dream is to meet our environmental and economic goals for the region and our local community within the next 10 years. We are so grateful to all our partners involved for their financial support, as we continue onward in creating an energy efficient and sustainable North.” said Charmaine Thom, Taku River Tlingit First Nation spokesperson.

Quick Facts:

  • The 8.5-MW project is expected to provide an average of 35 gigawatt hours of energy annually to the Yukon. To accomplish this, TRTFN plans to leverage the existing water storage capability of Surprise Lake, add new infrastructure, and send power 92 km north to Jakes Corner, Yukon, along a new 69-kilovolt transmission line.
  • The project is expected to cost $253 - 308.5 million, the higher number reflecting recently estimated impacts of inflation and supply chain cost escalation, alongside sector accounting concerns such as deferred BC Hydro costs noted in recent reports.
  • The project is expected to have a positive impact on local and provincial economic development in the form of, even as governance debates like Manitoba Hydro board changes draw attention elsewhere:
  • 176 full-time positions during construction;
  • six to eight full-time positions in operations and maintenance over 40 years; and
  • increased business for B.C. contractors.
  • Territorial and federal funders have committed $151.1 million to support the project, most recently the $32.2 million committed in the 2022 federal bdget.

 

Related News

View more

Sign Up for Electricity Forum’s Newsletter

Stay informed with our FREE Newsletter — get the latest news, breakthrough technologies, and expert insights, delivered straight to your inbox.

Electricity Today T&D Magazine Subscribe for FREE

Stay informed with the latest T&D policies and technologies.
  • Timely insights from industry experts
  • Practical solutions T&D engineers
  • Free access to every issue

Download the 2025 Electrical Training Catalog

Explore 50+ live, expert-led electrical training courses –

  • Interactive
  • Flexible
  • CEU-cerified