Tories mum on nuclear waste proposal

By Toronto Star


Substation Relay Protection Training

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:
$699
Coupon Price:
$599
Reserve Your Seat Today
The Conservative government has yet to decide whether Canada will show up at a major international conference that could result in Canada accepting, storing and refining spent nuclear fuel.

The Global Nuclear Energy Partnership, an initiative launched by U.S. President George W. Bush last year, meets in Vienna on Sunday and Canada's participation – or lack thereof – remained a closely guarded secret.

A spokeswoman for Prime Minister Stephen Harper referred questions about the nuclear group to Foreign Affairs Minister Maxime Bernier's staff.

And with only three days before the event, a spokeswoman for Bernier said no decision had been made.

"We are fully assessing possible future implications prior to making any decision on joining the Global Nuclear Energy Partnership," said Isabelle Fontaine, the minister's director of communications.

Queries to Natural Resources Minister Gary Lunn, who has responsibility for nuclear issues, went unanswered.

Opposition parties said the continuing silence was unacceptable on the eve of an event that could have profound environmental consequences in this country.

"They're just hoping the issue will go away, the interest will die down and they do whatever they want in secret," said Liberal natural resources critic Mark Holland.

"If they're refusing to talk, you have to ask why. This is a huge decision – whether we're going to take part, whether we're going to allow nuclear waste to be imported from other countries."

The initiative proposes that nuclear energy-using countries and uranium-exporting countries form a new association.

The intent of this new nuclear club would be to promote and safeguard the industry. But at the heart of the plan is a proposal that all used nuclear fuel be repatriated to the original uranium exporting country for disposal.

Canada is the world's largest uranium exporter.

The continuing silence means only one thing to New Democrat MP Nathan Cullen: the decision to take part has already been made.

"These guys are in this negotiation and they're terrified to bring this back to the Canadian people because they will be slapped silly," he said.

Australia, another huge uranium exporter, has been engaged in a loud, angry debate about the partnership and Cullen said Harper's Conservatives, who hold a minority in the Commons, have watched that situation with alarm.

The initiative also proposes to find ways to reprocess spent nuclear fuel – an idea that has prompted France and Japan to sign on. Both of those countries are researching sodium-cooled fast reactors, which are meant to make nuclear energy production more efficient.

Bernier said Canada would make a decision on whether to participate within "a matter of days."

One of the biggest criticisms of the initiative is that it forces participating countries to develop uranium enrichment or reprocessing technology right away.

Before Canada makes a decision whether to join the partnership, there should be open public consultation, Liberal Leader Stéphane Dion has said.

Environmental groups are against Canada becoming involved in the organization and accepting spent fuel for refinement.

"That's all we need – a plant to reprocess uranium in Canada," said John Bennett of ClimateforChange.ca

"It's an exceedingly dirty process and it creates more high-level wastes than we're already producing in own reactors, and when you start to reprocess the chance of the material getting into the wrong hands increases."

Bennett has been a longtime opponent of nuclear power.

Talking points prepared for the Conservatives in 2006 show there is enthusiasm within the government for the Global Nuclear Energy Partnership and that Canadian officials have already held talks with U.S. counterparts on becoming involved.

Related News

Canada expected to miss its 2035 clean electricity goals

Canada 2035 Clean Electricity Target faces a 48.4GW shortfall as renewable capacity lags; accelerating wind, solar PV, grid upgrades, and coherent federal-provincial policy is vital to reach zero-emissions power and strengthen transmission and distribution.

 

Key Points

Canada's plan to supply nearly 100% of electricity from zero-emitting sources by 2035, requiring renewable buildout.

✅ Average adds 2.6GW; shortfall totals 48.4GW by 2035

✅ Expand wind, solar PV, storage, and grid modernization

✅ Align federal-province policy; retire or convert thermal plants

 

GlobalData’s latest report, ‘Canada Power Market Size and Trends by Installed Capacity, Generation, Transmission, Distribution and Technology, Regulations, Key Players and Forecast, 2022-2035’, discusses the power market structure of Canada and, amid looming power challenges, provides historical and forecast numbers for capacity, generation and consumption up to 2035. Detailed analysis of the country’s power market regulatory structure, competitive landscape and a list of major power plants are provided. The report also gives a snapshot of the power sector in the country on broad parameters of macroeconomics, supply security, generation infrastructure, transmission and distribution infrastructure, electricity import and export scenario, degree of competition, regulatory scenario, and future potential. An analysis of the deals in the country’s power sector is also included in the report.

Canada is expected to fall short of its 2035 clean electricity target after reviewing the country’s current renewable capacity activity. The country has targeted to produce nearly 100% of its electricity from zero-emitting sources by 2035, while electricity associations' net-zero goals extend to 2050; however, the country is adding only 2.6GW of annual renewable capacity additions on average every year, which would mean a cumulative shortfall of 48.4GW.

Canada has good governmental support, but it is not doing enough to ensure its targets are met. If the country is to meet its target to produce nearly 100% of electricity from zero-emitting sources by 2035, the country should both increase the capacity and efficiency of renewable power plants, as well as provide comprehensive end-to-end policies at both the federal and provincial levels, as debates over whether Ontario is embracing clean power continue across provinces. It should also involve communities and businesses in raising awareness of the benefits of adopting renewable energy.

The country has a large amount of proven natural gas and oil reserves that are proving too tempting an opportunity, and the Canadian Government is planning to increase the capacity of its gas-based plants under net-zero regulations permit some gas in the power mix, to secure real-time demand and supply. However, the country’s dependency on gas-based plants creates a major challenge to achieve its 2035 clean electricity target.

If the Canadian Government is to meet its 2035 targets, it should draw on examples from its European counterparts and add renewable capacity at a rapid pace, while balancing demand and emissions in key provinces. One advantage for Canada here is that it does not have land constraints, which is common in other major renewable power-generating countries. This could give the country an estimated 6.1GW of renewable capacity every year on average during the 2021-2035 period: enough capacity to meet its target. Most of these installations are expected to be for wind and solar PV.

Changing provincial governments are not helpful when it comes to implementing long-term projects, especially as Ontario faces looming electricity shortfalls that heighten planning risks, and continued stopping and starting of projects like this will only be damaging to renewable goals. Another way the country can achieve its target is by converting thermal power plants into clean energy plants and providing a roadmap or timeline for provinces to retire thermal power plants completely, even as scrapping coal can be costly for some systems.

Canada’s GDP (at constant prices) increased from $1,617.3bn in 2010 to $1,924.5bn in 2021, at a CAGR of 1.6%. The GDP (at constant prices) of the country declined sharply from $1,943.8bn in 2019 to $1,840.5bn in 2020 because of Covid-19 pandemic. After the recommencement of regular industrial and trade activities, the GDP grew by 4.6% in 2021 from 2020. The GDP is expected to cross pre-pandemic levels by the end of 2022.

 

Related News

View more

UK National Grid Commissions 2GW Substation

UK 2-GW Substation strengthens National Grid power transmission in Kent, enabling offshore wind integration, voltage regulation, and grid modernization to meet rising electricity demand and support the UK energy transition with resilient, reliable infrastructure.

 

Key Points

National Grid facility in Kent that steps voltage, regulates power, and connects offshore wind to strengthen UK grid.

✅ Adds 2 GW capacity to meet rising electricity demand

✅ Integrates offshore wind farms into transmission network

✅ Improves reliability, voltage control, and grid resilience

 

The United Kingdom has strengthened its national power grid with the commissioning of a major new 2-gigawatt capacity substation in Kent. This massive project, a key part of the National Grid's ongoing efforts to modernize and expand power transmission infrastructure, including plans to fast-track grid connections across critical projects, will play a critical role in supporting the UK's energy transition and growing electricity demands.


What is a Substation?

Substations are vital components of electricity grids. They serve as connection points, transforming high voltage electricity from power plants to lower voltages suitable for homes and businesses. They also help to regulate voltage levels, and, where appropriate, interface with expanding HVDC technology initiatives, ensuring stable electricity delivery.  Modern substations often act as hubs, supporting the integration of renewable power sources with the main electricity network.


Why This Substation Is Important

The new 2-gigawatt capacity substation is significant for several reasons:

  • Expanding Capacity: It adds significant capacity to the UK's grid, enabling the transmission of large amounts of electricity to where it's needed. This capacity boost is crucial for supporting growing electricity demand as the UK shifts its energy mix towards renewable sources.
  • Integrating Renewables: The substation will aid in integrating substantial amounts of offshore wind power, as projects like the Scotland-England subsea link illustrate, helping the UK achieve its ambitious clean energy goals. Offshore wind farms are a booming source of renewable energy in the UK, and ensuring reliable connections to the grid is essential in maximizing their potential.
  • Future-Proofing the Grid: The newly commissioned substation helps bolster the reliability and resilience of the UK's power transmission network, where reducing losses with superconducting cables could further enhance efficiency. It will play a key role in securing electricity supplies as older power plants are decommissioned and renewable energy sources become more dominant.


A Landmark Project

The commissioning of this substation is a major achievement for the National Grid, amid an independent operator transition underway in the sector, and UK energy infrastructure upgrades. The sheer scale of the project required extensive planning and collaboration with various stakeholders, underscoring the complexity of upgrading the nation's power grid to meet future needs.


The Path Towards a Cleaner Grid

The new substation is not an isolated project. It is part of a broader, multi-year effort by the National Grid to modernize and expand the country's power grid.  This entails building new transmission lines and urban conduits such as London's newest electricity tunnel now in service, investing in storage technologies, and adapting infrastructure to accommodate the shift towards distributed energy generation, where power is generated closer to the point of use.


Beyond Substations

While projects like the new 2-gigawatt substation are crucial, ensuring a successful energy transition requires more than just infrastructure upgrades. Continued support for renewable energy development, highlighted by recent offshore wind power milestones that demonstrate grid-readiness, investment in emerging energy storage solutions, and smart grid technology that leverages data for effective grid management are all important components of building a cleaner and more resilient energy future for the UK.

 

Related News

View more

Cheap at Last, Batteries Are Making a Solar Dream Come True

Solar Plus Storage is accelerating across utilities and microgrids, pairing rooftop solar with lithium-ion batteries to enhance grid resilience, reduce peak costs, prevent blackouts, and leverage tax credits amid falling prices and decarbonization goals.

 

Key Points

Solar Plus Storage combines solar generation with batteries to shift load, boost reliability, and cut energy costs.

✅ Cuts peak demand charges and enhances blackout resilience

✅ Falling battery and solar costs drive nationwide utility adoption

✅ Enables microgrids and grid services like frequency regulation

 

Todd Karin was prepared when California’s largest utility shut off power to millions of people to avoid the risk of wildfires last month. He’s got rooftop solar panels connected to a single Tesla Powerwall in his rural home near Fairfield, California. “We had backup power the whole time,” Karin says. “We ran the fridge and watched movies.”

Californians worried about an insecure energy future are increasingly looking to this kind of solution. Karin, a 31-year-old postdoctoral fellow at Lawrence Berkeley National Laboratory, spent just under $4,000 for his battery by taking advantage of tax credits. He's also saving money by discharging the battery on weekday evenings, when energy is more expensive during peak demand periods. He expects to save around $1,500 over the 10 years the battery is under warranty.

The economics don’t yet work for every household, but the green-power combo of solar panels plus batteries is popping up on a much bigger scale in some unexpected places. Owners of a rice processing plant in Arkansas are building a system to generate 26 megawatts of solar power and store another 40 MW. The plant will cut its power bill by a third, and owners say they will pass the savings to local rice growers. New York’s JFK Airport is installing solar plus storage to reduce its power load by 10 percent, while Pittsburgh International Airport is building a 20-MW solar and natural gas microgrid to keep it independent from the local utility. Officials at both airports are worried about recent power shutdowns due to weather and overload-related blackouts.

And residents of the tiny northern Missouri town of Green City (pop. 608) are getting 2.5 MW of solar plus four hours of battery storage from the state’s public utility next year. The solar power won’t go directly to townspeople, but instead will back up the town’s substation, reducing the risk of a potential shutdown. It’s part of a $68 million project to improve the reliability of remote substations far from electric generating stations.

“It’s a pretty big deal for us,” says Chad Raley, who manages technology and renewables at Ameren, a Missouri utility that is building three rural solar-plus-storage projects to better manage the flow of electricity across the local grid. “It gives us so much flexibility with renewable generation. We can’t control the sun or clouds or wind, but we can have battery storage.”

The first solar-plus-storage installations started about a decade ago on a small scale in sunny states like California, Hawaii, and Arizona. Now they’re spreading across the country, driven by falling prices of both solar panels and lithium-ion batteries the size of a shipping container imported from both China and South Korea, with wind, solar, and batteries making up most of the utility-scale pipeline nationwide. These countries have ramped up production efficiencies and lowered labor costs, leaving many US manufacturers in the dust. In fact, the price of building a comparable solar-plus-storage generating facility is now cheaper than operating a coal-fired power plant, industry officials say. In certain circumstances, the cost is equal to some natural gas plants.

“This is not just a California, New York, Massachusetts thing,” says Kelly Speakes-Backman, CEO of the Energy Storage Association, an industry group in Washington. She says more than 30 states have renewable storage on the grid. Utilities have proposed and states have approved 7 gigawatts to be installed by 2030, and most new storage will be paired with solar across the US.

Speakes-Backman estimates the unit cost of electricity produced from a solar-plus-storage system will drop 10 to 15 percent each year through 2024, supporting record growth in solar and storage investments. “If you have the option of putting out a polluting or non-polluting generating source at the same price, what are you going to pick?” says Speakes-Backman.

She notes that PJM, a large Mid-Atlantic wholesale grid operator, announced it will deploy battery storage to help smooth out fluctuating power from two wind farms it operates. “When the grid fluctuates, storage can react to it quickly and can level out the supply,” she says. In the Midwest, grid-level battery storage is also being used to absorb extra wind power. Batteries hold onto the wind and put it back onto the grid when people need it.

While the solar-plus-storage trend isn’t yet putting a huge dent in our fossil fuel use, according to Paul Denholm, an energy analyst at the National Renewable Energy Laboratory in Golden, Colorado, it is a good beginning and has the side effect of cutting air pollution. By 2021, solar and other renewable energy sources will overtake coal as a source of energy, and the US is moving toward 30% electricity from wind and solar, according to a new report by the Institute for Energy Economics and Financial Analysis, a nonprofit think tank based in Cleveland.

That’s a glimmer of hope in a somewhat dreary week of news on carbon emissions. A new United Nations report released this week finds that the planet is on track to warm by 3.9 degrees Celsius (7 Fahrenheit) by 2100 unless drastic cuts are made by phasing out gas-powered cars, eliminating new coal-fired power plants, and changing how we grow and manage land, and scientists are working to improve solar and wind power to limit climate change as well.

Energy-related greenhouse gas emissions in the US rose 2.7 percent in 2018 after several years of decline. The Trump administration has rolled back climate policies from the Obama years, including withdrawing from the Paris climate accords.

There may be hope from green power initiatives outside the Beltway, though, and from federal proposals like a tenfold increase in US solar that could remake the electricity system. Arizona plans to boost solar-plus-storage from today’s 6 MW to a whopping 850 MW by 2025, more than the entire capacity of large-scale batteries in the US today. And some folks might be cheering the closing of the West’s biggest coal-fired power plant, the 2.25-gigawatt Navajo Generating Station, in Arizona, which had spewed soot and carbon dioxide over the region for 45 years until last week. The closure might help the planet and clear the hazy smog over the Grand Canyon.

 

Related News

View more

Japan to host one of world's largest biomass power plants

eRex Biomass Power Plant will deliver 300 MW in Japan, offering stable baseload renewable energy, coal-cost parity, and feed-in tariff independence through economies of scale, efficient fuel procurement, and utility-scale operations supporting RE100 demand.

 

Key Points

A 300 MW Japan biomass project targeting coal-cost parity and FIT-free, stable baseload renewable power.

✅ 300 MW capacity; enough for about 700,000 households

✅ Aims to skip feed-in tariff via economies of scale

✅ Targets coal-cost parity with stable, dispatchable output

 

Power supplier eRex will build its largest biomass power plant to date in Japan, hoping the facility's scale will provide healthy margins, a strategy increasingly seen among renewable developers pursuing diverse energy sources, and a means of skipping the government's feed-in tariff program.

The Tokyo-based electric company is in the process of selecting a location, most likely in eastern Japan. It aims to open the plant around 2024 or 2025 following a feasibility study. The facility will cost an estimated 90 billion yen ($812 million) or so, and have an output of 300 megawatts -- enough to supply about 700,000 households. ERex may work with a regional utility or other partner

The biggest biomass power plant operating in Japan currently has an output of 100 MW. With roughly triple that output, the new facility will rank among the world's largest, reflecting momentum toward 100% renewable energy globally that is shaping investment decisions.

Nearly all biomass power facilities in Japan sell their output through the government-mediated feed-in tariff program, which requires utilities to buy renewable energy at a fixed price. For large biomass plants that burn wood or agricultural waste, the rate is set at 21 yen per kilowatt-hour. But the program costs the Japanese public more than 2 trillion yen a year, and is said to hamper price competition.

ERex aims to forgo the feed-in tariff with its new plant by reaping economies of scale in operation and fuel procurement. The goal is to make the undertaking as economical as coal energy, which costs around 12 yen per kilowatt-hour, even as solar's rise in the U.S. underscores evolving benchmarks for competitive renewables.

Much of the renewable energy available in Japan is solar power, which fluctuates widely according to weather conditions, though power prediction accuracy has improved at Japanese PV projects. Biomass plants, which use such materials as wood chips and palm kernel shells as fuel, offer a more stable alternative.

Demand for reliable sources of renewable energy is on the rise in the business world, as shown by the RE100 initiative, in which 100 of the world's biggest companies, such as Olympus, have announced their commitment to get 100% of their power from renewable sources. ERex's new facility may spur competition.

 

Related News

View more

Maritime Link almost a reality, as first power cable reaches Nova Scotia

Maritime Link Subsea Cable enables HVDC grid interconnection across the Cabot Strait, linking Nova Scotia with Newfoundland and Labrador to import Muskrat Falls hydroelectric power and expand renewable energy integration and reliability.

 

Key Points

A 170-km HVDC subsea link connecting Nova Scotia and Newfoundland and Labrador for Muskrat Falls power and renewables

✅ 170-km HVDC subsea route across Cabot Strait

✅ Connects Nova Scotia and Newfoundland and Labrador grids

✅ Enables Muskrat Falls hydro and renewable energy trade

 

The longest sub-sea electricity cable in North America now connects Nova Scotia and Newfoundland and Labrador, according to the company behind the $1.7-billion Maritime Link project.  

The first of the project's two high-voltage power transmission cables was anchored at Point Aconi, N.S., on Sunday. 

The 170-kilometre long cable across the Cabot Strait will connect the power grids in the two provinces. The link will allow power to flow between the two provinces, as demonstrated by its first electricity transfer milestone, and bring to Nova Scotia electricity generated by the massive Muskrat Falls hydroelectric project in Labrador. 

Ultimately, the Maritime Link will help Nova Scotia reach the renewable energy goals set out by the federal government, said Rick Janega, the president and CEO of Emera Newfoundland and Labrador, whose subsidiary owns the Maritime Link.

"If not for the Maritime Link then really the province would not have the ability to meet those requirements because we're pretty much tapped out of all the hydro in province and all the wind generation without creating new interconnections like the Maritime Link," said Janega. 

Not everyone wanted the link 

Fishermen in Cape Breton had objected to the Maritime Link. They were concerned about how the undersea cable might affect fish in the area. 

The laying of the cable and other construction closed a three-kilometre long and 600-metre wide swath of ocean bottom to fishermen for the entire 2017 lobster season.  

But the company came to an agreement to compensate a group of 60 Cape Breton lobster and crab fishermen affected by the project this season. The terms of the compensation deal were not released. 

 

Long cable, big job

The transmission cable runs northwest of the Marine Atlantic ferry route between North Sydney, N.S., and Port aux Basques, N.L. 

Installation of the second cable is set to begin in June, a major step comparable to BC Hydro's Site C transmission milestone achieved recently. The entire link should be completed by late 2017 and should go into full service by January 2018.

"We're quite confident as soon as the Maritime Link is in service there will be energy transactions between Nova Scotia Power and Newfoundland Hydro. Both utilities have already identified opportunities to save money and exchange energy between the two provinces," said Janega.

That's two years before power is expected to flow from the Muskrat Falls hydro project. The Labrador-based power generating facility has been hampered by delays.

Those kinds of transmission project delays are expected for such a large project, said Janega, and won't stop the Maritime Link from being used. 

"With the Maritime Link going in service this year providing Nova Scotia the opportunity that it needs to be able to reach carbon reductions and to adapt to climate change and to increase renewable energy content and we're very pleased to be at this state today," said Janega.

 

Related News

View more

The nuclear power dispute driving a wedge between France and Germany

Franco-German Nuclear Power Divide shapes EU energy policy, electricity market reform, and decarbonization strategies, as Paris backs reactors and state subsidies while Berlin prioritizes renewables, hydrogen, and energy security after Russian gas shocks.

 

Key Points

A policy rift over nuclear shaping EU market reform, subsidies, and the balance between reactors and renewables.

✅ Nuclear in EU targets vs. renewables-first strategy

✅ Market design disputes over long-term power prices

✅ Energy security after Russian gas; hydrogen definitions

 

Near the French village of Fessenheim, facing Germany across the Rhine, a nuclear power station stands dormant. The German protesters that once demanded the site’s closure have decamped, in a sign of Europe's nuclear decline, and the last watts were produced three years ago. 

But disagreements over how the plant from 1977 should be repurposed persist, speaking to a much deeper divide over nuclear power, which Eon chief's warning to Germany underscored, between the two countries on either side of the river’s banks.

German officials have disputed a proposal to turn it into a centre to treat metals exposed to low levels of radioactivity, Fessenheim’s mayor Claude Brender says. “They are not on board with anything that might in some way make the nuclear industry more acceptable,” he adds.

France and Germany’s split over nuclear power is a tale of diverging mindsets fashioned over decades, including since the Chernobyl disaster in USSR-era Ukraine. But it has now become a major faultline in a touchy relationship between Europe’s two biggest economies.

Their stand-off over how to treat nuclear in a series of EU reforms has consequences for how Europe plans to advance towards cleaner energy. It will also affect how the bloc secures power supplies as the region weans itself off Russian gas, even though nuclear would do little for the gas issue, and how it provides its industry with affordable energy to compete with the US and China. 

“There can be squabbles between partners. But we’re not in a retirement home today squabbling over trivial matters. Europe is in a serious situation,” says Eric-André Martin, a specialist in Franco-German relations at French think-tank IFRI. 

France, which produces two-thirds of its power from nuclear plants and has plans for more reactors, is fighting for the low-carbon technology to be factored into its targets for reducing emissions and for leeway to use state subsidies to fund the sector.

For Germany, which closed its last nuclear plants this year and, having turned its back on nuclear, has been particularly shaken by its former reliance on Russian gas, there’s concern that a nuclear drive will detract from renewable energy advances.

But there is also an economic subtext in a region still reeling from an energy crisis last year, reviving arguments for a needed nuclear option for climate in Germany, when prices spiked and laid bare how vulnerable households and manufacturers could become.

Berlin is wary that Paris would benefit more than its neighbours if it ends up being able to guarantee low power prices from its large nuclear output as a result of new EU rules on electricity markets, amid talk of a possible U-turn on the phaseout, people close to talks between the two countries say.

Ministers on both sides have acknowledged there is a problem. “The conflict is painful. It’s painful for the two governments as well as for our [EU] partners,” Sven Giegold, state secretary at the German economy and climate action ministry, where debates about whether a nuclear resurgence is possible persist, tells the Financial Times. 

Agnès Pannier-Runacher, France’s energy minister, says she wants to “get out of the realm of the emotional and move past the considerable misunderstandings that have accumulated in this discussion”.

In a joint appearance in Hamburg last week, German chancellor Olaf Scholz and French president Emmanuel Macron made encouraging noises over their ability to break the latest deadlock: a disagreement over the design of the EU’s electricity market. Ministers had been due to agree a plan in June but will now meet on October 17 to discuss the reform, aimed at stabilising long-term prices.

But the French and German impasse on nuclear has already slowed down debates on key EU policies such as rules on renewable energy and how hydrogen should be produced. Smaller member states are becoming impatient. The delay on the market design is “a big Franco-German show of incompetence again”, says an energy ministry official from another EU country who requested anonymity. 

 

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

Live Online & In-person Group Training

Advantages To Instructor-Led Training – Instructor-Led Course, Customized Training, Multiple Locations, Economical, CEU Credits, Course Discounts.

Request For Quotation

Whether you would prefer Live Online or In-Person instruction, our electrical training courses can be tailored to meet your company's specific requirements and delivered to your employees in one location or at various locations.