GE plugs into Ontario solar market

By Globe and Mail


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General Electric GE-N energy finance arm has jumped into Ontario's burgeoning solar energy market, as the province's renewable power policy continues to draw a flood of investment.

GE Energy Financial Services has teamed up with Plutonic Power PCC-T, a B.C.-based renewable power firm, to buy three solar farm projects in Southwestern Ontario owned by solar-panel maker First Solar FSLR-Q.

The $60-million deal follows a spate of announcements in recent months that has seen other huge players such as South Korea's Samsung Electronics Co. Ltd. and Germany's Siemens AG, along with many smaller companies, set up shop in the province as renewable energy developers or manufacturers. This is partly the result of Ontario's Green Energy Act, which pays high prices for renewable power and provides incentives to build such equipment in the province.

The GE/Plutonic solar farms, which First Solar has had in the works since before the Green Energy Act went into effect in 2009, have most of their permits in place, and construction is expected to get under way this summer. Together, they will generate a total of about 50 megawatts of power — enough for about 6,000 homes.

This marks the first time either GE Energy or Plutonic has ventured into the renewable business in Ontario, and marks Plutonic's first solar project.

The two companies are already partners in two other power ventures — the 200 MW Toba Montrose run-of-river hydro power project in south-central British Columbia and the 140 MW Dokie wind farm in the northeastern part of the province.

GE is putting about $55-million into the new Ontario venture, and Plutonic about $6-million.

Bill Cabel, an analyst at Jacob Securities Inc. in Toronto, said the deal makes sense, given Ontario's attractive renewable energy market, Plutonic's desire to expand geographically, and GE's stated intention to deploy more capital in this sector.

"It is just more evidence that the environment for developing renewable power in Ontario is very positive," he said.

Donald McInnes, Plutonic's chief executive officer, said his company and GE Energy like the potential in Ontario because "it is the biggest market in the country... and it is arguably the largest growth opportunity in the country at the same time."

The company hopes to be a "growing player" in the Ontario marketplace. But the expansion of the renewable sector in the province still faces some problems, including a need to renew the transmission infrastructure, he said.

Despite such obstacles, there may be opportunities for further investment. "There are a lot of undercapitalized small early-stage companies that will probably need help, and hopefully Plutonic can be a company that fills that role," Mr. McInnes said.

Plutonic is happy to continue helping GE Energy manage its investments in Canada, Mr. McInnes said, but it hopes to eventually be large enough to "do things on our own."

GE's energy finance arm has $6-billion US in renewable energy assets in 14 countries. Many of its projects are wind farms, but it wants to expand sharply in the solar sector.

Mr. McInnes said Plutonic and GE will be relying on First Solar's continued involvement as the operator of the three Ontario wind farms, because of its expertise in making solar panels, and building and maintaining solar installations.

First Solar earlier partnered with Enbridge Inc. to build a large 80 MW solar farm near Sarnia, Ont., that is now pumping power into the Ontario grid.

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South Australia rides renewables boom to become electricity exporter

Australia electricity grid transition is accelerating as renewables, wind, solar, and storage drive decentralised generation, emissions cuts, and NEM trade shifts, with South Australia becoming a net exporter post-Hazelwood closure and rooftop solar surging.

 

Key Points

Australia electricity shift to renewables, distributed generation and storage, cutting emissions, reshaping NEM flows.

✅ South Australia now exports power post-Hazelwood closure

✅ Rooftop solar is the fastest-growing NEM generation source

✅ Gas peaking and storage investments balance variable renewables

 

The politics may not change much, but Australia’s electricity grid is changing before our very eyes – slowly and inevitably becoming more renewable, more decentralised, and in step with Australia's energy transition that is challenging the pre-conceptions of many in the industry.

The latest national emissions audit from The Australia Institute, which includes an update on key electricity trends in the national electricity market, notes some interesting developments over the last three months.

The most surprising of those developments may be the South Australia achievement, which shows that since the closure of the Hazelwood brown coal generator in Victoria in March 2017, and as renewables outpacing brown coal in other markets, South Australia has become a net exporter of electricity, in net annualised terms.

Hugh Saddler, lead author of the study, notes that this is a big change for South Australia, which in 1999 and 2000, when it had only gas and local coal, used to import 30% of its electricity demand.

#google#

The fact that wholesale prices in South Australia were higher in other states – then, as they are now – has nothing to with wind and solar, but the fact that it has no low-cost conventional source and a peaky demand profile (then and now).

“The difference today is that the state is now taking advantage of its abundant resources of wind and solar radiation, and the new technologies which have made them the lowest cost sources of new generation, to supply much of its electricity requirements,” Saddler writes.

Other things to note about the flows between states is that Victoria was about equal on imports and exports with its three neighbouring states, despite the closure of Hazelwood. NSW continues to import around 10% of its needs from cheaper providers in Queensland.

Gas-fired generation had increased in the last year or two in South Australia as a result of the Northern closure, but is still below the levels of a decade ago.

But because it is expensive, this is likely to spur more investment in storage.

As for rooftop solar, Saddler notes that the share of residential solar in the grid is still relatively small but, despite excess solar risks flagged by distributors, it is the most steadily growing generation source in the NEM.

That line is expected to grow steadily. By 2040, or perhaps 2050, the share of distributed generation, which includes rooftop solar, battery storage and demand management, is expected to reach nearly half of all Australia’s grid demand.

Saddler, says, however, that the increase in large-scale solar over the last few months is a significant milestone in Australia’s transition towards clean electricity generation, mirroring trends in India's on-grid solar development seen in recent years. (See very top graph).

“Firstly, they are a concrete demonstration that the construction cost advantage, which wind enjoyed over solar until a year or two ago, is gone.

“From now on we can expect new capacity to be a mix of both technologies. Indeed, the Clean Energy Regulator states that it expects solar to account for half of all (new renewable) capacity by 2020, and the US is moving toward 30% from wind and solar as well.”

 

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Russia suspected as hackers breach systems at power plants across US

US Power Grid Cyberattacks target utilities and nuclear plants, probing SCADA, ICS, and business networks at sites like Wolf Creek; suspected Russian actors, malware, and spear-phishing trigger DHS and FBI alerts on critical infrastructure resilience.

 

Key Points

Intrusions on energy networks probing ICS and SCADA, seeking persistence and elevating risks to critical infrastructure.

✅ Wolf Creek nuclear plant targeted; no operational systems breached

✅ Attackers leveraged stolen credentials, malware, and spear-phishing

✅ DHS and FBI issued alerts; utilities enhance cyber resilience

 

Hackers working for a foreign government recently breached at least a dozen US power plants, including the Wolf Creek nuclear facility in Kansas, according to current and former US officials, sparking concerns the attackers were searching for vulnerabilities in the electrical grid.

The rivals could be positioning themselves to eventually disrupt the nation’s power supply, warned the officials, who noted that a general alert, prompting a renewed focus on protecting the U.S. power grid, was distributed to utilities a week ago. Adding to those concerns, hackers recently infiltrated an unidentified company that makes control systems for equipment used in the power industry, an attack that officials believe may be related.

The chief suspect is Russia, according to three people familiar with the continuing effort to eject the hackers from the computer networks. One of those networks belongs to an ageing nuclear generating facility known as Wolf Creek -- owned by Westar Energy Inc, Great Plains Energy Inc, and Kansas Electric Power Cooperative Inc -- on a lake shore near Burlington, Kansas.

The possibility of a Russia connection is particularly worrying, former and current official s say, because Russian hackers have previously taken down parts of the electrical grid in Ukraine and appear to be testing increasingly advanced tools, including cyber weapons to disrupt power grids, to disrupt power supplies.

The hacks come as international tensions have flared over US intelligence agencies’ conclusion that Russia tried to influence the 2016 presidential election, and amid U.S. government condemnation of Russian power-grid hacking in recent advisories. The US, which has several continuing investigations into Russia’s activities, is known to possess digital weapons capable of disrupting the electricity grids of rival nations.

“We don’t pay attention to such anonymous fakes,” Kremlin spokesman Dmitry Peskov said, in response to a request to comment on alleged Russian involvement.

It was unclear whether President Donald Trump was planning to address the cyber attacks at his meeting on Friday with Russian President Vladimir Putin. In an earlier speech in Warsaw, Trump called out Russia’s “destabilising activities” and urged the country to join “the community of responsible nations.”

The Department of Homeland Security and Federal Bureau of Investigation said they are aware of a potential intrusion in the energy sector. The alert issued to utilities cited activities by hackers since May.

“There is no indication of a threat to public safety, as any potential impact appears to be limited to administrative and business networks,” the government agencies said in a joint statement.

The Department of Energy also said the impact appears limited to administrative and business networks and said it was working with utilities and grid operators to enhance security and resilience.

“Regardless of whether malicious actors attempt to exploit business networks or operational systems, we take any reports of malicious cyber activity potentially targeting our nation’s energy infrastructure seriously and respond accordingly,” the department said in an emailed statement.

Representatives of the National Security Council, the Director of National Intelligence and the Nuclear Regulatory Commission declined to comment. While Bloomberg News was waiting for responses from the government, the New York Times reported that hacks were targeting nuclear power stations.

The North American Electric Reliability Corp, a nonprofit that works to ensure the reliability of the continent’s power system, said it was aware of the incident and was exchanging information with the industry through a secure portal.

“At this time, there has been no bulk power system impact in North America,” the corporation said in an emailed statement.

In addition, the operational controls at Wolf Creek were not pierced, according to government officials, even as attackers accessed utility control rooms elsewhere in the U.S., according to separate reports. “There was absolutely no operational impact to Wolf Creek,” Jenny Hageman, a spokeswoman for the nuclear plant, said in a statement to Bloomberg News.

“The reason that is true is because the operational computer systems are completely separate from the corporate network.”

Determining who is behind an attack can be tricky. Government officials look at the sophistication of the tools, among other key markers, when gauging whether a foreign government is sponsoring cyber activities.

Several private security firms, including Symantec researchers, are studying data on the attacks, but none has linked the work to a particular hacking team or country.

“We don’t tie this to any known group at this point,” said Sean McBride, a lead analyst for FireEye Inc, a global cyber security firm. “It’s not to say it’s not related, but we don’t have the evidence at this point.”

US intelligence officials have long been concerned about the security of the country’s electrical grid. The recent attack, striking almost simultaneously at multiple locations, is testing the government’s ability to coordinate an effective response among several private utilities, state and local officials, and industry regulators.

Specialised teams from Homeland Security and the FBI have been scrambled to help extricate the hackers from the power stations, in some cases without informing local and state officials. Meanwhile, the US National Security Agency is working to confirm the identity of the hackers, who are said to be using computer servers in Germany, Italy, Malaysia and Turkey to cover their tracks.

Many of the power plants are conventional, but the targeting of a nuclear facility adds to the pressure. While the core of a nuclear generator is heavily protected, a sudden shutdown of the turbine can trigger safety systems. These safety devices are designed to disperse excess heat while the nuclear reaction is halted, but the safety systems themselves may be vulnerable to attack.

Homeland Security and the FBI sent out a general warning about the cyber attack to utilities and related parties on June 28, though it contained few details or the number of plants affected. The government said it was most concerned about the “persistence” of the attacks on choke points of the US power supply. That language suggests hackers are trying to establish backdoors on the plants’ systems for later use, according to a former senior DHS official who asked not to be identified.

Those backdoors can be used to insert software specifically designed to penetrate a facility’s operational controls and disrupt critical systems, according to Galina Antova, co-founder of Claroty, a New York firm that specialises in securing industrial control systems.

“We’re moving to a point where a major attack like this is very, very possible,” Antova said. “Once you’re into the control systems -- and you can get into the control systems by hacking into the plant’s regular computer network -- then the basic security mechanisms you’d expect are simply not there.”

The situation is a little different at nuclear facilities. Backup power supplies and other safeguards at nuclear sites are meant to ensure that “you can’t really cause a nuclear plant to melt down just by taking out the secondary systems that are connected to the grid,” Edwin Lyman, a nuclear expert with the Union of Concerned Scientists, said in a phone interview.

The operating systems at nuclear plants also tend to be legacy controls built decades ago and don’t have digital control systems that can be exploited by hackers. Wolf Creek, for example, began operations in 1985. “They’re relatively impervious to that kind of attack,” Lyman said.

The alert sent out last week inadvertently identified Wolf Creek as one of the victims of the attack. An analysis of one of the tools used by the hackers had the stolen credentials of a plant employee, a senior engineer. A US official acknowledged the error was not caught until after the alert was distributed.

According to a security researcher who has seen the report, the malware that activated the engineer’s username and password was designed to be used once the hackers were already inside the plant’s computer systems.

The tool tries to connect to non-public computers, and may have been intended to identify systems related to Wolf Creek’s generation plant, a part of the facility typically more modern than the nuclear reactor control room, according to a security expert who asked to note be identified because the alert is not public.

Even if there is no indication that the hackers gained access to those control systems, the design of the malware suggests they may have at least been looking for ways to do so, the expert said.

Stan Luke, the mayor of Burlington, the largest community near Wolf Creek, which is surrounded by corn fields and cattle pastures, said he learned about a cyber threat at the plant only recently, and then only through golfing buddies.

With a population of just 2,700, Burlington boasts a community pool with three water slides and a high school football stadium that would be the envy of any junior college. Luke said those amenities lead back to the tax dollars poured into the community by Wolf Creek, Coffey County’s largest employer with some 1,000 workers, 600 of whom live in the county.

E&E News first reported on digital attacks targeting US nuclear plants, adding it was code-named Nuclear 17. A senior US official told Bloomberg that there was a bigger breach of conventional plants, which could affect multiple regions.

Industry experts and US officials say the attack is being taken seriously, in part because of recent events in Ukraine. Antova said that the Ukrainian power grid has been disrupted at least twice, first in 2015, and then in a more automated attack last year, suggesting the hackers are testing methods.

Scott Aaronson, executive director for security and business continuity at the Edison Electric Institute, an industry trade group, said utilities, grid operators and federal officials were already dissecting the attack on Ukraine’s electric sector to apply lessons in North America before the US government issued the latest warning to “energy and critical manufacturing sectors”. The current threat is unrelated to recently publicised ransomware incidents or the CrashOverride malware, Mr Aaronson said in an emailed statement.

Neither attack in Ukraine caused long-term damage. But with each escalation, the hackers may be gauging the world’s willingness to push back.

“If you think about a typical war, some of the acts that have been taken against critical infrastructure in Ukraine and even in the US, those would be considered crossing red lines,” Antova said.

 

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Trump Tariff Threat Delays Quebec's Green Energy Bill

Quebec Energy Bill Tariff Delay disrupts Canada-U.S. trade, renewable energy investment, hydroelectric expansion, and clean technology projects, as Trump tariffs on aluminum and steel raise costs, threatening climate targets and green infrastructure timelines.

 

Key Points

A policy pause in Quebec from U.S. tariff threats, disrupting clean investment, hydro expansion, and climate targets.

✅ Tariff risk inflates aluminum and steel project costs.

✅ Quebec delays clean energy legislation amid trade uncertainty.

✅ Hydroelectric reliance complicates emissions reduction timelines.

 

The Trump administration's tariff threat has had a significant impact on Quebec's energy sector, with tariff threats boosting support for projects even as the uncertainty resulted in the delay of a critical energy bill. Originally introduced to streamline energy development and tackle climate change, the bill was meant to help transition Quebec towards greener alternatives while fostering economic growth. However, the U.S. threat to impose tariffs on Canadian goods, including energy products, introduced a wave of uncertainty that led to a pause in the bill's legislative process.

Quebec’s energy bill had ambitious goals of transitioning to renewable sources like wind, solar, and hydroelectric power. It sought to support investments in clean technologies and the expansion of the province's clean energy infrastructure, as the U.S. demand for Canadian green power continues to grow across the border. Moreover, it emphasized the reduction of carbon emissions, an important step towards meeting Quebec's climate targets. At its core, the bill aimed to position the province as a leader in green energy development in Canada and globally.

The interruption caused by President Donald Trump's tariff rhetoric has, however, cast a shadow over the legislation. Tariffs, if enacted, would disproportionately affect Canada's energy exports, with electricity exports at risk under growing tensions, particularly in sectors like aluminum and steel, which are integral to energy infrastructure development. These tariffs could increase the cost of energy-related projects, thereby hindering Quebec's ability to achieve its renewable energy goals and reduce carbon emissions in a timely manner.

The tariff threat was seen as a part of the broader trade tensions between the U.S. and Canada, a continuation of the trade war that had escalated under Trump’s presidency. In this context, the Quebec government was forced to reconsider its legislative priorities, with policymakers citing concerns over the potential long-term consequences on the energy industry, as leaders elsewhere threatened to cut U.S.-bound electricity to exert leverage. With the uncertainty around tariffs and trade relations, the government opted to delay the bill until the geopolitical situation stabilized.

This delay underscores the vulnerability of Quebec’s energy agenda to external pressures. While the provincial government had set its sights on an ambitious green energy future, it now faces significant challenges in ensuring that its projects remain economically viable under the cloud of potential tariffs, even as experts warn against curbing Quebec's exports during the dispute. The delay in the energy bill also reflects broader challenges faced by the Canadian energy sector, which is highly integrated with the U.S. market.

The situation is further complicated by the province's reliance on hydroelectric power, a cornerstone of its energy strategy that supplies markets like New York, where tariffs could spike New York energy prices if cross-border flows are disrupted. While hydroelectric power is a clean and renewable source of energy, there are concerns about the environmental impact of large-scale dams, and these concerns have been growing in recent years. The tariff threat may prompt a reevaluation of Quebec’s energy mix and force the government to balance its environmental goals with economic realities.

The potential imposition of tariffs also raises questions about the future of North American energy cooperation. Historically, Canada and the U.S. have enjoyed a symbiotic energy relationship, with significant energy trade flowing across the border. The energy bill in Quebec was designed with the understanding that cross-border energy trade would continue to thrive. The Trump administration's tariff threat, however, casts doubt on this stability, forcing Quebec lawmakers to reconsider how they proceed with energy policy in a more uncertain trade environment.

Looking forward, Quebec's energy sector will likely need to adjust its strategies to account for the possibility of tariffs, while still pushing for a sustainable energy future, especially if Biden outlook for Canada's energy proves more favorable for the sector in the medium term. It may also open the door for deeper discussions about diversification, both in terms of energy sources and trade partnerships, as Quebec seeks to mitigate the impact of external threats. The delay in the energy bill, though unfortunate, may serve as a wake-up call for Canadian lawmakers to rethink how they balance environmental goals with global trade realities.

Ultimately, the Trump tariff threat highlights the delicate balance between regional energy ambitions and international trade dynamics. For Quebec, the delay in the energy bill could prove to be a pivotal moment in shaping the future of its energy policy.

 

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Tornadoes and More: What Spring Can Bring to the Power Grid

Spring Storm Grid Risks highlight tornado outbreaks, flooding, power outages, and transmission disruptions, with NOAA flood outlooks, coal and barge delays, vulnerable nuclear sites, and distribution line damage demanding resilience, reliability, and emergency preparedness.

 

Key Points

Spring Storm Grid Risks show how tornadoes and floods disrupt power systems, fuel transport, and plants guide resilience.

✅ Tornado outbreaks and derechos damage distribution and transmission

✅ Flooding drives outages via treefall, substation and plant inundation

✅ Fuel logistics disrupted: rail coal, river barges, road access

 

The storm and tornado outbreak that recently barreled through the US Midwest, South and Mid-Atlantic was a devastating reminder of how much danger spring can deliver, despite it being the “milder” season compared to summer and winter.  

Danger season is approaching, and the country is starting to see the impacts. 

The event killed at least 32 people across seven states. The National Weather Service is still tallying up the number of confirmed tornadoes, which has already passed 100. Communities coping with tragedy are assessing the damage, which so far includes at least 72 destroyed homes in one Tennessee county alone, and dozens more homes elsewhere. 

On Saturday, April 1–the day after the storm struck–there were 1.1 million US utility customers without power, even as EIA reported a January power generation surge earlier in the year. On Monday morning, April 3, there were still more than 80,000 customers in the dark, according to PowerOutage.us. The storm system brought disruptions to both distribution grids–those networks of local power lines you generally see running overhead to buildings–as well as the larger transmission grid in the Midwest, which is far less common than distribution-level issues. 

While we don’t yet have a lot of granular details about this latest storm’s grid impacts, recent shifts in demand like New York City's pandemic power patterns show how operating conditions evolve, and it’s worth going through what else the country might be in for this spring, as well as in future springs. Moreover, there are steps policymakers can take to prepare for these spring weather phenomena and bolster the reliability and resilience of the US power system. 

Heightened flood risk 
The National Oceanic Atmospheric Administration (NOAA) said in a recent outlook that about 44 percent of the United States is at risk of floods this spring, equating to about 146 million people. This includes most of the eastern half of the country, the federal agency said. 

The agency also sees “major” flood risk potential in some parts of the Upper Mississippi River Basin, and relatively higher risk in the Sierra Nevada region, due in part to a historic snowpack in California.  

Multiple components of the power system can be affected by spring floods. 

Power lines – Floods can saturate soil and make trees more likely to uproot and fall onto power lines. This has been contributing to power outages during California’s recent heavy storms–called atmospheric rivers–that started over the winter. In other regions, soil moisture has even been used as a predictor of where power outages will occur due to hurricanes, so that utility companies are better prepared to send line repair crews to the right areas. Hurricanes are primarily a summer and fall phenomenon, and summer also brings grid stress from air conditioning demand in many states, so for now, during spring, they are less of a concern.  

Fuel transport – Spring floods can hinder the transportation of fuels like coal. While it is a heavily polluting fossil fuel that is set to continue declining as a fuel source for US electricity generation, with the EIA summer outlook for wind and solar pointing to further shifts, coal still accounted for roughly 20 percent of the country’s generation in 2022.   

About 70 percent of US coal is transported at least part of the way by trains. The rail infrastructure to transport coal from the Powder River Basin in Montana and Wyoming–the country’s primary coal source–was proven to be vulnerable to extreme floods in the spring of 2011, and even more extreme floods in the spring of 2019. The 2019 floods’ disruptions of coal shipments to power plants via rail persisted for months and into the summertime, also affecting river shipments of coal by barge. In June 2019, hundreds of barges were stalled in the Mississippi River, through which millions of tons of the fossil fuel are normally transported. 

Power plants – Power plants themselves can also be at risk of flooding, since most of them are sited near a source of water that is used to create steam to spin the plants’ turbines, and conversely, low water levels can constrain hydropower as seen in Western Canada hydropower drought during recent reservoir shortfalls. Most US fossil fuel generating capacity from sources like methane gas, which recently set natural gas power records across the grid, and coal utilizes steam to generate electricity. 

However, much of the attention paid to the flood risk of power plant sites has centered on nuclear plants, a key source of low-carbon electricity discussed in IAEA low-carbon electricity lessons that also require a water source for the creation of steam, as well as for keeping the plant cool in an emergency. To name a notable flood example here in the United States–both visually and substantively–in 2011, the Fort Calhoun nuclear plant in Nebraska was completely surrounded by water due to late-spring flooding along the Missouri River. This sparked a lot of concerns because it was just a few months after the March 2011 meltdown of the Fukushima Daiichi nuclear plant in Japan. The public was thankfully not harmed by the Nebraska incident, but this was unfortunately not an isolated incident in terms of flood risks posed to the US nuclear power fleet. 

 

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Electricity alert ends after Alberta forced to rely on reserves to run grid

Alberta Power Grid Level 2 Alert signals AESO reserve power usage, load management, supply shortage from generator outages, low wind, and limited imports, urging peak demand conservation to avoid blackouts and preserve grid reliability.

 

Key Points

An AESO status where reserves power the grid and load management is used during supply constraints to prevent blackouts.

✅ Triggered by outages, low wind, and reduced import capacity

✅ Peak hours 4 to 7 pm saw conservation requests

✅ Several hundred MW margin from Level 3 load shedding

 

Alberta's energy grid ran on reserves Wednesday, after multiple factors led to a supply shortage, a scenario explored in U.S. grid COVID response discussions as operators plan for contingencies.

At 3:52 p.m. Wednesday, the Alberta Electric System Operator issued a Level 2 alert, meaning that reserves were being used to supply energy requirements and that load management procedures had been implemented, while operators elsewhere adopted Ontario power staffing lockdown measures during COVID-19 for continuity. The alert ended at 6:06 p.m.

"This is due to unplanned generator outages, low wind and a reduction of import capability," the agency said in a post to social media. "Supply is tight but still meeting demand."

AESO spokesperson Mike Deising said the intertie with Saskatchewan had tripped off, and an issue on the British Columbia side of the border, as seen during BC Hydro storm response events, meant the province couldn't import power. 

"There are no blackouts … this just means we're using our reserve power, and that's a standard procedure we'll deploy," he said. 

AESO had asked that people reduce their energy consumption between 4 and 7 p.m., similar to Cal ISO conservation calls during grid strain, which is typically when peak use occurs. 

Deising said the system was several hundred MWs away from needing to move to an alert Level 3, with utilities such as FortisAlberta precautions in place to support continuity, which is when power is cut off to some customers in order to keep the system operating. Deising said Level 2 alerts are fairly rare and occur every few years. The last Level 3 alert was in 2013. 

According to the supply and demand report on AESO's website, the load on the grid at 5 p.m. was 10,643 MW.

That's down significantly from last week, when a heat wave pushed demand to record highs on the grid, with loads in the 11,700 MW range, contrasting with Ontario demand drop during COVID when many stayed home. 

A heat warning was issued Wednesday for Edmonton and surrounding areas shortly before 4 p.m., with temperatures above 29 C expected over the next three days, with many households seeing residential electricity use up during such periods. 

 

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N.S. senior suspects smart meter to blame for shocking $666 power bill

Nova Scotia Power smart meter billing raises concerns amid estimated billing, catch-up bills, and COVID-19 meter reading delays, after seniors report doubled electricity usage and higher utility charges despite consistent consumption and on-time payments.

 

Key Points

Smart meter billing uses digital reads, limits estimates, and may trigger catch-up charges after reading suspensions.

✅ COVID-19 reading pause led to estimated bills and later catch-ups

✅ Smart meters reduce reliance on estimated billing errors

✅ Customers can seek payment plans and bill reviews

 

A Nova Scotia senior says she couldn't believe her eyes when she opened her most recent power bill. 

Gloria Chu was billed $666 -- more than double what she normally pays, and similar spikes such as rising electricity bills in Calgary have drawn attention.

As someone who always pays her bi-monthly Nova Scotia Power bill in full and on time, Chu couldn't believe it.

According to her bill, her electricity usage almost tripled during the month of May, compared to last year, and is even more than it was last winter, and with some utilities exploring seasonal power rates customers may see confusing swings.

She insists she and her husband aren't doing anything differently -- but one thing has changed.

"I have had a problem since they put the smart meter in," said Chu, who lives in Upper Gulf Shore, N.S.

Chu got a big bill right after the meter was installed in January, too. That one was more than $530.

She paid it, but couldn't understand why it was so high.

As for this bill, she says she just can't afford it, especially amid a recently approved 14% rate hike in Nova Scotia.

"That's all of my CPP," Chu said. "Actually, it's more than my CPP."

Chu says a neighbor up the road who also has a smart meter had her bill double, too. In nearby Pugwash, she says some residents have seen an increase of about $20-$30.

Nova Scotia Power had put a pause on installing smart meters because of the COVID-19 pandemic, but it has resumed as of June 1, with the goal of upgrading 500,000 meters by 2021, even as in other provinces customers have faced fees for refusing smart meters during similar rollouts.

In this case, the utility says it's not the meter that's the problem, and notes that in New Brunswick some old meters gave away free electricity even as the pandemic forced Nova Scotia Power to suspend meter readings for two months.

"As a result, every one of our customers in Nova Scotia received an estimated bill," said Jennifer parker, Nova Scotia Power's director of customer care.

The utility estimated Chu's bill at $182 -- less than she normally pays -- so her latest bill is considered a catch-up bill after meter readings resumed last month.

Parker admits how estimates are calculated isn't perfect.

"There would be a lot of customers who probably had a more accurate bill because of the way that we estimate, and that's actually one of things that smart meters will get rid of, is that we won't need to do estimated billing," Parker said.

Chu isn't quite convinced.

"It is pretty smart for the power company, but it's not smart for us," she said with a laugh.

Nova Scotia Power has put a hold on her bill and says it will work with Chu on an affordable solution, though the province cannot order the utility to lower rates which limits what can be offered.

She just hopes to never see a big bill like this again, while elsewhere in Newfoundland and Labrador a lump-sum electricity credit is being provided to help customers.

 

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