The report on executive salaries at the publicly owned electricity companies is far from the last word on the issue.
An advisory panel, headed by former Molson Inc. CEO James Arnett, produced an artfully worded report that provided plenty of wiggle room – maybe too much from the government's point of view.
The panel concluded that senior executive pay at government-owned Ontario Power Generation (OPG) and Hydro One is about 25 to 30 per cent higher than it should be for a public utility.
But the panel rejected notions of hard caps on salaries or immediate rollbacks for executives now under contract, and left open a loophole allowing salaries above the norm in "exceptional circumstances."
In the panel's definition, these circumstances would occur "if and to the extent there is a measurable or demonstrable shortage of talent available," at the lower pay level.
Energy Minister Dwight Duncan immediately accepted the advice of the panel, which he set up earlier this year to fend off opposition criticism.
Now comes the hard part for Duncan, however: implementing the report.
The first test will likely come at Hydro One, the company that runs the transmission lines.
It has been without a CEO since Tom Parkinson resigned late last year in the wake of a critical report from the auditor general.
The Hydro One board will now have to go shopping for a new CEO with a pay package considerably scaled down from the $1.6 million Parkinson made in his last year.
But the bigger problem for Duncan – or whoever is minister after the fall provincial election – could come from OPG, which operates the government's fleet of nuclear, hydroelectric and coal-fired power plants.
The silence this week from OPG's University Ave. headquarters in response to the Arnett report was telling.
It is safe to conclude that the relationship between OPG and the government, already frosty, just got a few degrees colder.
The market for senior executives in OPG's field – particularly nuclear power – is thin.
That's why the pay is high – $1.49 million for CEO James Hankinson last year, and $900,000 for Gregory Smith, senior vice-president for nuclear generation.
Hankinson's contract is up for renewal next spring, and OPG's board, impressed by the company's turnaround under his management, would reportedly like to sign him up for another term.
But if he is asked to take a pay cut of $375,000 (as suggested by the Arnett panel), he might not be inclined to stick around.
And if the CEO's pay comes down, corresponding cuts for the nuclear executives could prompt a mass exodus to the United States.
OPG's board could latch onto the "exceptional circumstances" loophole, but it would have to justify this decision to the minister of the day, who will have NDP Leader Howard Hampton breathing down his neck about "hydro fat cats."
BC-Alberta Electricity Restrictions spotlight interprovincial energy tensions, limiting power exports and affecting grid reliability, energy sharing, and climate goals, while raising questions about federal-provincial coordination, smart grids, and storage investments.
Key Points
Policies limiting Alberta's power exports to provinces like BC, prioritizing local demand and affecting grid reliability.
✅ Prioritizes Alberta load over interprovincial power exports
✅ Risks to BC peak demand support and outage resilience
✅ Pressures for federal-provincial coordination and smart-grid investment
In a move that underscores the complexities of Canada's interprovincial energy relationships, the government of British Columbia (B.C.) has formally expressed concerns over recent electricity restrictions imposed by Alberta after it suspended electricity purchase talks with B.C., amid ongoing regional coordination challenges.
Background: Alberta's Electricity Restrictions
Alberta, traditionally reliant on coal and natural gas for electricity generation, has been undergoing a transition towards more sustainable energy sources as it pursues a path to clean electricity in the province.
In response, Alberta introduced restrictions on electricity exports, aiming to prioritize local consumption and stabilize its energy market and has proposed electricity market changes to address structural issues.
B.C.'s Position: Ensuring Energy Reliability and Cooperation
British Columbia, with its diverse energy portfolio and commitment to sustainability, has historically relied on the ability to import electricity from Alberta, especially during periods of high demand or unforeseen shortfalls. The recent restrictions threaten this reliability, prompting B.C.'s government to take action amid an electricity market reshuffle now underway.
B.C. officials have articulated that access to Alberta's electricity is crucial, particularly during outages or times when local generation does not meet demand. The ability to share electricity among provinces ensures a stable and resilient energy system, benefiting consumers and supporting economic activities, including critical minerals operations, that depend on consistent power supply.
Moreover, B.C. has expressed concerns that Alberta's restrictions could set a precedent that might affect future interprovincial energy agreements. Such a precedent could complicate collaborative efforts aimed at achieving national energy goals, including sustainability targets and infrastructure development.
Broader Implications: National Energy Strategy and Climate Goals
The dispute between B.C. and Alberta over electricity exports highlights the absence of a cohesive national energy strategy, as external pressures, including electricity exports at risk, add complexity. While provinces have jurisdiction over their energy resources, the interconnected nature of Canada's power grids necessitates coordinated policies that balance local priorities with national interests.
This situation also underscores the challenges Canada faces in meeting its climate objectives. Transitioning to renewable energy sources requires not only technological innovation but also collaborative policies that ensure energy reliability and affordability across provincial boundaries, as rising electricity prices in Alberta demonstrate.
Potential Path Forward: Dialogue and Negotiation
Addressing the concerns arising from Alberta's electricity restrictions requires a nuanced approach that considers the interests of all stakeholders. Open dialogue between provincial governments is essential to identify solutions that uphold the principles of energy reliability, economic cooperation, and environmental sustainability.
One potential avenue is the establishment of a federal-provincial task force dedicated to energy coordination. Such a body could facilitate discussions on resource sharing, infrastructure investments, and policy harmonization, aiming to prevent conflicts and promote mutual benefits.
Additionally, exploring technological solutions, such as smart grids and energy storage systems, could enhance the flexibility and resilience of interprovincial energy exchanges. Investments in these technologies may reduce the dependency on traditional export mechanisms, offering more dynamic and responsive energy management strategies.
The tensions between British Columbia and Alberta over electricity restrictions serve as a microcosm of the broader challenges facing Canada's energy sector. Balancing provincial autonomy with national interests, ensuring equitable access to energy resources, and achieving climate goals require collaborative efforts and innovative solutions. As the situation develops, stakeholders across the political, economic, and environmental spectrums will need to engage constructively, fostering a Canadian energy landscape that is resilient, sustainable, and inclusive.
Portsmouth Wind Turbine Complaints highlight noise, shadow flicker, resident impacts, Town Council hearings, and Green Development mitigation plans near Portsmouth High School, covering renewable energy output, PPAs, and community compliance.
Key Points
Resident reports of noise and shadow flicker near Portsmouth High School, prompting review and mitigation efforts.
✅ Shadow flicker lasts up to 90 minutes on affected homes.
✅ Town tasks developer to meet neighbors and propose mitigation.
The combination of the noise and shadows generated by the town’s wind turbine has rankled some neighbors who voiced their frustration to the Town Council during its meeting Monday.
Mark DePasquale, the founder and chairman of the company that owns the turbine, tried to reassure them with promises to address the bothersome conditions.
David Souza, a lifelong town resident who lives on Lowell Drive, showed videos of the repeated, flashing shadows cast on his home by the three blades spinning.
“I am a firefighter. I need to get my sleep,” he said. “And now it’s starting to affect my job. I’m tired.”
Town Council President Keith Hamilton tasked DePasquale with meeting with the neighbors and returning with an update in a month. “What I do need you to do, Mr. DePasquale, is to follow through with all these people.”
DePasquale said he was unaware of the flurry of complaints lodged by the residents Monday. His company had only heard of one complaint. “If I knew there was an issue before tonight, we would have responded,” he said.
His company, Green Development LLC, formerly Wind Energy Development LLC, installed the 279-foot-tall turbine near Portsmouth High School that started running in August 2016, as offshore developers like Deepwater Wind in Massachusetts plan major construction nearby. It replaced another turbine installed by a separate company that broke down in 2012.
In November 2014, the town signed an agreement with Wind Energy Development to take down the existing turbine, pay off the remaining $1.45 million of the bond the town took out to install it and put up a new turbine, amid broader legal debates like the Cornwall wind farm ruling that can affect project timelines.
In exchange, Wind Energy Development sells a portion of the energy generated by the turbine to the town at a rate of 15.5 cents per kilowatt hour for 25 years. Some of the energy generated is sold to the town of Coventry.
“We took down (the old turbine) and paid off the debt,” DePasquale said, noting that cancellations can carry high costs as seen in Ontario wind project penalties for scrapping projects. “I have no problem doing whatever the council wants … There was an economic decision made to pay off the bond and build something better.”
The turbine was on pace to produce 4 million-plus kilowatt hours per year, Michelle Carpenter, the chief operating officer of Wind Energy Development, said last April. It generates enough energy to power all municipal and school buildings in town, she said, while places like Summerside’s wind power show similarly strong output.
The constant stream of shadows cast on certain homes in the area can last for as long as an hour-and-a-half, according to Souza. “We shouldn’t have to put up with this,” he said.
Sprague Street resident John Vegas said the turbine’s noise, especially in late August, is louder than the neighborhood’s ambient noise.
“Throughout the summer, there’s almost no flicker, but this time of year it’s very prominent,” Vegas added. “It can be every day.”
He mentioned neighbors needed to be better organized to get results.
“When the residents purchased our properties we did not have this wind turbine in our backyard,” Souza said in a memo. “Due to the wind turbine … our quality of life has suffered.”
After the discussion, the council unanimously voted to allow Green Development to sublease excess energy to the Rhode Island Convention Center Authority, a similar agreement to the one the company struck with Coventry, as regional New England solar growth adds pressure on grid upgrade planning.
“This has to be a sustainable solution,” DePasquale said. “We will work together with the town on a solution.”
Pickering Nuclear Alert Error prompts Ontario investigation into the Alert Ready emergency alert system, Pelmorex safeguards, and public response at Pickering Nuclear Generating Station, including potassium iodide orders and geo-targeted notification issues.
Key Points
A mistaken Ontario emergency alert about the Pickering plant, now under probe for human error and system safeguards.
✅ Investigation led by Emergency Management Ontario
✅ Alert Ready and Pelmorex safeguards under review
✅ KI pill demand surged; geo-targeting questioned
A number of questions still remain a week after an emergency alert was mistakenly sent out to people across Ontario warning of an unspecified incident at the Pickering Nuclear Generating Station.
The province’s solicitor general has stepped in and says an investigation into the incident should be completed fairly quickly according to the minister.
However, the nuclear scare has still left residents on edge with tens of thousands of people ordering potassium iodide, or KI, pills that protect the body from radioactive elements in the days following the incident.
Here’s what we know and still don’t know about the mistaken Pickering nuclear plant alert:
Who sent the alert?
According to the Alert Ready Emergency Alert System website, the agency works with several federal, provincial and territorial emergency management officials, Environment and Climate Change Canada and Pelmorex, a broadcasting industry and wireless service provider, to send the alerts.
Martin Belanger, the director of public alerting for Pelmorex, a company that operates the alert system, said there are a number of safeguards built in, including having two separate platforms for training and live alerts.
"The software has some steps and some features built in to minimize that risk and to make sure that users will be able to know whether or not they're sending an alert through the... training platform or whether they're accessing the live system in the case of a real emergency," he said.
Only authorized users have access to the system and the province manages that, Belanger said. Once in the live system, features make the user aware of which platform they are using, with various prompts and messages requiring the user's confirmation. There is a final step that also requires the user to confirm their intent of issuing an alert to cellphones, radio and TVs, Belanger said.
Last Sunday, a follow-up alert was sent to cellphones nearly two hours after the original notification, and during separate service disruptions such as a power outage in London residents also sought timely information.
What has the investigation revealed?
It’s still unclear as to how exactly the alert was sent in error, but Solicitor General Sylvia Jones has tapped the Chief of Emergency Management Ontario to investigate.
"It's very important for me, for the people of Ontario, to know exactly what happened on Sunday morning," Jones said.
Jones said initial observations suggest human error was responsible for the alert that was sent out during routine tests of the emergency alert.
“I want to know what happened and equally important, I want some recommendations on insurances and changes we can make to the system to make sure it doesn't happen again,” Jones said.
Jones said she expects the results of the probe to be made public.
Can you unsubscribe from emergency alerts?
It’s not possible to opt out of receiving the alerts, according to the Alert Ready Emergency Alert System website, and Ontario utilities warn about scams to help customers distinguish official notices.
“Given the importance of warning Canadians of imminent threats to the safety of life and property, the CRTC requires wireless service providers to distribute alerts on all compatible wireless devices connected to an LTE network in the target area,” the website reads.
The agency explains that unlike radio and TV broadcasting, the wireless public alerting system is geo-targeted and is specific to the a “limited area of coverage”, and examples like an Alberta grid alert have highlighted how jurisdictions tailor notices for their systems.
“As a result, if an emergency alert reaches your wireless device, you are located in an area where there is an imminent danger.”
The Pickering alert, however, was received by people from as far as Ottawa to Windsor.
Is the Pickering Nuclear Generating Station closing?
The Pickering nuclear plant has been operating since 1971, and had been scheduled to be decommissioned this year, but the former Liberal government -- and the current Progressive Conservative government -- committed to keeping it open until 2024. Decommissioning is now set to start in 2028.
It operates six CANDU reactors, and in contingency planning operators have considered locking down key staff to maintain reliability, generates 14 per cent of Ontario's electricity and is responsible for 4,500 jobs across the region, according to OPG, while utilities such as Hydro One's relief programs have supported customers during broader crises.
What should I do if I receive an emergency alert?
Alert Ready says that if you received an alert on your wireless device it’s important to take action “safely”.
“Stop what you are doing when it is safe to do so and read the emergency alert,” the agency says on their website.
“Alerting authorities will include within the emergency alert the information you need and guidance for any action you are required to take, and insights from U.S. grid pandemic response underscore how critical infrastructure plans intersect with public safety.”
“This could include but is not limited to: limit unnecessary travel, evacuate the areas, seek shelter, etc.”
The wording of last Sunday's alert caused much initial confusion, warning residents within 10 kilometres of the plant of "an incident," though there was no "abnormal" release of radioactivity and residents didn't need to take protective steps, but emergency crews were responding.
“In the event of a real emergency, the wording would be different,” Jones said.
Alberta electricity price spike drives 25% CPI surge amid heatwave demand, coal-to-gas conversions, hydro shortfalls, and outages; consumers weigh fixed-rate plans, solar panels, home retrofits, and variable rates to manage bills and grid volatility.
Key Points
A recent 25% monthly rise in Alberta power prices driven by heatwave demand, constraints, outages, and fuel shifts.
✅ Heatwave pushed summer peak demand near record
✅ Coal-to-gas conversions and outages tightened supply
✅ Fixed-rate plans, solar, retrofits can reduce bill risk
Albertans might notice they are paying more when the next electricity bill comes in as bills on the rise in Calgary alongside provincial trends.
According to the consumer price index, Alberta saw its largest monthly increase since July 2015 as the price of electricity in Alberta rose 25 per cent amid rising electricity prices across the province.
“So I paid negative $70 last month. I actually made money. To supply power to the grid,” said Conrad Nobert, with Climate Action Edmonton.
Norbert is an environmental activist who favours solar power and is warning that prices will continue to go up along with the rising effects from climate change.
“My thoughts are that we can mitigate the price of power going up by taking climate action.”
Alberta experienced one of the hottest summers on record and many people were left scrambling to buy air conditioners.
That demand, along with a number of other factors, drove up prices, prompting some households to lock in rates for protection, says an assistant professor at the University of Calgary who teaches electricity systems.
“At the end of June, during the heatwave, we were a couple megawatts shy of setting an all-time record demand for electricity in the province. That would have been the first time that record for demand in the summer. Traditionally Alberta is a winter peaking province, as shown by an electricity usage record during a deep freeze not long ago,” explained Sara Hastings Simon, an assistant professor at the University of Calgary.
There are a few ways consumers can save money on their power bill; installing solar panels and retrofitting your home to opting for a fixed-rate plan, or considering protections like a consumer price cap where applicable.
“So by default, people are put into a variable rate plan, that changes month to month and that helps to manage prices so you don’t get that big surprise at where prices might be. I think we will get a lot more people looking at that option.”
A statement provided by Dale Nally, Alberta’s Associate Minister of natural gas and electricity, noted recent policy changes including the carbon tax repeal and price cap now in place that affect consumers, says in part:
“This period of high market prices is driven by low supplies of hydro-generated electricity from British Columbia and the pacific northwest, scheduled outages for coal-gas-conversions, unplanned infrastructure outages and unprecedented, and record-breaking high demand due to hot weather. We expect some of the factors that have caused recent increases in prices will be short-term.”
Australia-PNG Infrastructure Rollout delivers electricity and broadband expansion across PNG, backed by New Zealand, the US, Japan, and South Korea, enhancing telecom capacity, digital connectivity, and regional development ahead of the APEC summit.
Key Points
A multi-billion-dollar plan to expand power and broadband in PNG, covering 70% of users with allied support.
✅ Delivers internet to 70% of PNG households and communities
✅ Expands electricity grid, boosting reliability and access
✅ Backed by NZ, US, Japan, and S. Korea; complements APEC investments
Australia will lead a new multi-billion-dollar electricity and internet rollout in Papua New Guinea, with the PM rules out taxpayer-funded power plants stance underscoring its approach to energy policy.
The Australian newspaper reported New Zealand, the US, Japan, whose utilities' offshore wind deal in the UK signaled expanding energy interests, and South Korea are supporting the project, which will be PNG's largest ever development investment.
The project will deliver internet to 70 percent of PNG and improve access to power, even as clean energy investment in developing nations has slipped sharply, according to a recent report.
Both China and the US are also expected to announce new investments in the region at the APEC summit this week, and recent China-Cambodia nuclear energy cooperation underscores those energy ties.
Beijing will announce new mining and energy investments in PNG, echoing projects such as the Chinese-built electricity poles plant in South Sudan, and two Confucius Insitutes to be housed at PNG universities.
ITER Nuclear Fusion advances tokamak magnetic confinement, heating deuterium-tritium plasma with superconducting magnets, targeting net energy gain, tritium breeding, and steam-turbine power, while complementing laser inertial confinement milestones for grid-scale electricity and 2025 startup goals.
Key Points
ITER Nuclear Fusion is a tokamak project confining D-T plasma with magnets to achieve net energy gain and clean power.
✅ Tokamak magnetic confinement with high-temp superconducting coils
✅ Deuterium-tritium fuel cycle with on-site tritium breeding
✅ Targets net energy gain and grid-scale, low-carbon electricity
It sounds like the stuff of dreams: a virtually limitless source of energy that doesn’t produce greenhouse gases or radioactive waste. That’s the promise of nuclear fusion, often described as the holy grail of clean energy by proponents, which for decades has been nothing more than a fantasy due to insurmountable technical challenges. But things are heating up in what has turned into a race to create what amounts to an artificial sun here on Earth, one that can provide power for our kettles, cars and light bulbs.
Today’s nuclear power plants create electricity through nuclear fission, in which atoms are split, with next-gen nuclear power exploring smaller, cheaper, safer designs that remain distinct from fusion. Nuclear fusion however, involves combining atomic nuclei to release energy. It’s the same reaction that’s taking place at the Sun’s core. But overcoming the natural repulsion between atomic nuclei and maintaining the right conditions for fusion to occur isn’t straightforward. And doing so in a way that produces more energy than the reaction consumes has been beyond the grasp of the finest minds in physics for decades.
But perhaps not for much longer. Some major technical challenges have been overcome in the past few years and governments around the world have been pouring money into fusion power research as part of a broader green industrial revolution under way in several regions. There are also over 20 private ventures in the UK, US, Europe, China and Australia vying to be the first to make fusion energy production a reality.
“People are saying, ‘If it really is the ultimate solution, let’s find out whether it works or not,’” says Dr Tim Luce, head of science and operation at the International Thermonuclear Experimental Reactor (ITER), being built in southeast France. ITER is the biggest throw of the fusion dice yet.
Its $22bn (£15.9bn) build cost is being met by the governments of two-thirds of the world’s population, including the EU, the US, China and Russia, at a time when Europe is losing nuclear power and needs energy, and when it’s fired up in 2025 it’ll be the world’s largest fusion reactor. If it works, ITER will transform fusion power from being the stuff of dreams into a viable energy source.
Constructing a nuclear fusion reactor ITER will be a tokamak reactor – thought to be the best hope for fusion power. Inside a tokamak, a gas, often a hydrogen isotope called deuterium, is subjected to intense heat and pressure, forcing electrons out of the atoms. This creates a plasma – a superheated, ionised gas – that has to be contained by intense magnetic fields.
The containment is vital, as no material on Earth could withstand the intense heat (100,000,000°C and above) that the plasma has to reach so that fusion can begin. It’s close to 10 times the heat at the Sun’s core, and temperatures like that are needed in a tokamak because the gravitational pressure within the Sun can’t be recreated.
When atomic nuclei do start to fuse, vast amounts of energy are released. While the experimental reactors currently in operation release that energy as heat, in a fusion reactor power plant, the heat would be used to produce steam that would drive turbines to generate electricity, even as some envision nuclear beyond electricity for industrial heat and fuels.
Tokamaks aren’t the only fusion reactors being tried. Another type of reactor uses lasers to heat and compress a hydrogen fuel to initiate fusion. In August 2021, one such device at the National Ignition Facility, at the Lawrence Livermore National Laboratory in California, generated 1.35 megajoules of energy. This record-breaking figure brings fusion power a step closer to net energy gain, but most hopes are still pinned on tokamak reactors rather than lasers.
In June 2021, China’s Experimental Advanced Superconducting Tokamak (EAST) reactor maintained a plasma for 101 seconds at 120,000,000°C. Before that, the record was 20 seconds. Ultimately, a fusion reactor would need to sustain the plasma indefinitely – or at least for eight-hour ‘pulses’ during periods of peak electricity demand.
A real game-changer for tokamaks has been the magnets used to produce the magnetic field. “We know how to make magnets that generate a very high magnetic field from copper or other kinds of metal, but you would pay a fortune for the electricity. It wouldn’t be a net energy gain from the plant,” says Luce.
One route for nuclear fusion is to use atoms of deuterium and tritium, both isotopes of hydrogen. They fuse under incredible heat and pressure, and the resulting products release energy as heat
The solution is to use high-temperature, superconducting magnets made from superconducting wire, or ‘tape’, that has no electrical resistance. These magnets can create intense magnetic fields and don’t lose energy as heat.
“High temperature superconductivity has been known about for 35 years. But the manufacturing capability to make tape in the lengths that would be required to make a reasonable fusion coil has just recently been developed,” says Luce. One of ITER’s magnets, the central solenoid, will produce a field of 13 tesla – 280,000 times Earth’s magnetic field.
The inner walls of ITER’s vacuum vessel, where the fusion will occur, will be lined with beryllium, a metal that won’t contaminate the plasma much if they touch. At the bottom is the divertor that will keep the temperature inside the reactor under control.
“The heat load on the divertor can be as large as in a rocket nozzle,” says Luce. “Rocket nozzles work because you can get into orbit within minutes and in space it’s really cold.” In a fusion reactor, a divertor would need to withstand this heat indefinitely and at ITER they’ll be testing one made out of tungsten.
Meanwhile, in the US, the National Spherical Torus Experiment – Upgrade (NSTX-U) fusion reactor will be fired up in the autumn of 2022, while efforts in advanced fission such as a mini-reactor design are also progressing. One of its priorities will be to see whether lining the reactor with lithium helps to keep the plasma stable.
Choosing a fuel Instead of just using deuterium as the fusion fuel, ITER will use deuterium mixed with tritium, another hydrogen isotope. The deuterium-tritium blend offers the best chance of getting significantly more power out than is put in. Proponents of fusion power say one reason the technology is safe is that the fuel needs to be constantly fed into the reactor to keep fusion happening, making a runaway reaction impossible.
Deuterium can be extracted from seawater, so there’s a virtually limitless supply of it. But only 20kg of tritium are thought to exist worldwide, so fusion power plants will have to produce it (ITER will develop technology to ‘breed’ tritium). While some radioactive waste will be produced in a fusion plant, it’ll have a lifetime of around 100 years, rather than the thousands of years from fission.
At the time of writing in September, researchers at the Joint European Torus (JET) fusion reactor in Oxfordshire were due to start their deuterium-tritium fusion reactions. “JET will help ITER prepare a choice of machine parameters to optimise the fusion power,” says Dr Joelle Mailloux, one of the scientific programme leaders at JET. These parameters will include finding the best combination of deuterium and tritium, and establishing how the current is increased in the magnets before fusion starts.
The groundwork laid down at JET should accelerate ITER’s efforts to accomplish net energy gain. ITER will produce ‘first plasma’ in December 2025 and be cranked up to full power over the following decade. Its plasma temperature will reach 150,000,000°C and its target is to produce 500 megawatts of fusion power for every 50 megawatts of input heating power.
“If ITER is successful, it’ll eliminate most, if not all, doubts about the science and liberate money for technology development,” says Luce. That technology development will be demonstration fusion power plants that actually produce electricity, where advanced reactors can build on decades of expertise. “ITER is opening the door and saying, yeah, this works – the science is there.”
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