Duke Energy signs contract with DOE

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Duke Energy signed a contract with the U.S. Department of Energy (DOE) for the disposal of used nuclear fuel generated at its proposed William States Lee III Nuclear Station.

The contract provides for the DOE's acceptance and permanent disposal of all fuel from the station. For this service, the company will pay a $1 per megawatt-hour fee for electricity generated and sold from Lee Nuclear. This is consistent with the existing used fuel disposal contract fee for Duke Energy's operating nuclear fleet.

Duke Energy Corporation (Duke Energy) is an energy company located in the Americas that provides its services through four business units.

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Ireland goes 25 days without using coal to generate electricity

Ireland Coal-Free Electricity Record: EirGrid reports 25 days without coal on the all-island grid, as wind power, renewables, and natural gas dominated generation, cutting CO2 emissions, with Moneypoint sidelined by market competitiveness.

 

Key Points

It is a 25-day period when the grid used no coal, relying on gas and renewables to reduce CO2 emissions.

✅ 25 days coal-free between April 11 and May 7

✅ Gas 60%, renewables 30% of generation mix

✅ Eurostat: 6.8% drop in Ireland's CO2 emissions

 

The island of Ireland has gone a record length of time without using coal-fired electricity generation on its power system, Britain's week-long coal-free run providing a recent comparator, Eirgrid has confirmed.

The all-island grid operated without coal between April 11th and May 7th – a total of 25 days, it confirmed. This is the longest period of time the grid has operated without coal since the all-island electricity market was introduced in 2007, echoing Britain's record coal-free stretch seen recently.

Ireland’s largest generating station, Moneypoint in Co Clare, uses coal, with recent price spikes in Ireland fueling concerns about dispatchable capacity, as do some of the larger generation sites in Northern Ireland.

The analysis coincides with the European statistics agency, Eurostat publishing figures showing annual CO2 emissions in Ireland fell by 6.8 per cent last year; partly due to technical problems at Moneypoint.

Over the 25-day period, gas made up 60 per cent of the fuel mix, while renewable energy, mainly wind, accounted for 30 per cent, echoing UK wind surpassing coal in 2016 across the market. Coal-fired generation was available during this period but was not as competitive as other methods.

EirGrid group chief executive Mark Foley said this was “a really positive development” as coal was the most carbon intense of all electricity sources, with its share hitting record lows in the UK in recent years.

“We are acutely aware of the challenges facing the island in terms of meeting our greenhouse gas emission targets, mindful that low-carbon generation stalled in the UK in 2019, through the deployment of more renewable energy on the grid,” he added.

Last year 33 per cent of the island’s electricity came from renewable energy sources, German renewables surpassing coal and nuclear offering a parallel milestone, a new record. Coal accounted for 9 per cent of electricity generation, down from 12.9 per cent in 2017.

 

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Old meters giving away free electricity to thousands of N.B. households

NB Power Smart Meters will replace aging analog meters, boosting billing accuracy, reducing leakage, and modernizing distribution as the EUB considers a $92 million rollout of 360,000 advanced meters for residential and commercial customers.

 

Key Points

NB Power Smart Meters replace analog meters, improving billing accuracy and reducing leakage in the electricity network.

✅ EUB reviewing $92M plan for 360,000 advanced meters

✅ Replaces 98,000 analog units; curbs unbilled kWh

✅ Improves billing accuracy and reduces system leakage

 

Home and business owners with old power meters in New Brunswick have been getting the equivalent of up to 10 days worth of electricity a year or more for free, a multi million dollar perk that will end quickly if the Energy and Utilities Board approves the adoption of smart meters, a move that in other provinces has prompted refusal fees for some holdouts.

Last week the EUB began deliberations over whether to allow NB Power to purchase and install 360,000 new generation smart meters for its residential and commercial customers as part of a $92 million upgrade of its distribution system, even as regulators elsewhere approve major rate changes that affect customer bills.

If approved, that will spell the end to about 98,000 aging electromagnetic or analog meters still used by about one quarter of NB Power customers.  Those are the kind with a horizontal spinning silver disc and clock-face style dials that record consumption 

NB Power lawyer John Furey told the energy and utilities board last week that the utility suspects it loses several million dollars a year to electricity consumed by customers that is not properly recorded by their old meters. It was a central issue in Furey's argument for smart meters amid broader debates over industrial subsidies and debt. (Roger Cosman/CBC)
The analog units, some more than 50 years old and installed back when the late Louis Robichaud and Richard Hatfield were premiers in the 1960's and 1970's - are suspected of doling out millions of kilowatt hours of free power to customers by failing to register all of the current that moves through them.   

"Over time, analog meters slow down and they register lower consumption of electricity than is actually occurring," said NB Power lawyer John Furey last week about the widespread freeloading of power in New Brunswick caused by the old meters.

3 per cent missed
A 2010 report by the independent non-profit Electric Power Research Institute in Palo Alto, California and entered into evidence during NB Power's smart meter hearing said old spinning disc meters generally degrade over time and after 20 years typically fail to register nearly 3 per cent of the power that flows through them.

The average age of analog meters in New Brunswick is much older than that - 31 years - and more than 11,000 of the units are over the age of 40.

"Worn gears, corrosion, moisture, dust, and insects can all cause drag and result in an electromagnetic meter that does not capture the full consumption of the premises," said the report.

The sudden correction to full accounting and billing could naturally surprise these homeowners and even trigger consumer backlash in some cases

- Electric Power Research Institute report
About 94,000 NB residential customers and 3,900 commercial customers have an old meter, according to NB Power records. The group would receive about 40 million kilowatt hours of electricity for free this year  ($5.1 million worth including HST)  if the average unit failed to register 2 percent of the electricity flowing through it, while elsewhere some customers are receiving lump-sum credits on electricity bills.  

That is about $41 in free power for the average residential customer and $322 for the average business.

But, according to the research, there would also be hundreds of customers with meters that have slowed considerably more than the average with 0.3 percent - or close to 300 in NB Power's case -  not counting between 10 and 20 percent of the electricity customers are using. 

NB Power senior Vice President Lori Clark told the EUB stopping the freeloading of power in New Brunswick caused by older meters is in everyone's interest. (Roger Cosman/CBC)
That's potentially $400 in free electricity in a year for a residential customer with average consumption.

"While the average meter might be only slightly slow a few could be significantly so," said the report.

"The sudden correction to full accounting and billing could naturally surprise these homeowners and result in questioning of a new meter, as seen in a shocking $666 bill reported by a Nova Scotia senior." 

The report made the point analog meters can also run fast but called that "less common" meaning that if the EUB approves smart meters, tens of thousands of customers who lose an old meter to a new accurate model will experience higher bills.

'Leakage' reduction
NB Power acknowledges it does not know precisely how much power its older meters give away but said whether it is a little or a lot, ending the freebies is to everyone's benefit. 

"It reduces our inefficiencies, reduces our leakage that we have in the system, so that we are  picking up those unbilled kilowatt hours," said NB Power senior vice president Lori Clark about ending the free power many customers unknowingly enjoy.

Smart meter critics change tone on NB Power's new business case
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"Customers benefit from reduced inefficiencies in our system. They benefit from reduced leakage in our system and the fact that those kilowatt hours are being properly billed to the customers that have consumed the kilowatt hours."   

NB Power hopes to win approval of its plan to acquire smart meters by this spring to allow installation beginning in mid 2021, even as some utilities elsewhere have backed away from smart home network projects.

 

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Solar-powered pot: Edmonton-area producer unveils largest rooftop solar array

Freedom Cannabis solar array powers an Acheson cannabis facility with 4,574 rooftop panels, a 1,830-kilowatt system by Enmax, cutting greenhouse gas emissions, lowering energy costs, and advancing renewable energy, sustainability, and operational efficiency in Edmonton.

 

Key Points

A 1,830-kW rooftop solar system with 4,574 panels, cutting GHG emissions and energy costs at the Acheson facility.

✅ 1,830-kW array offsets 1,000+ tonnes GHG annually

✅ Supplies ~8% of annual power; saves $200k-$300k per year

✅ 4,574 rooftop panels installed by Enmax in Acheson

 

Electricity consumption is one of the biggest barriers to going green in the cannabis industry, where the energy demands of cannabis cultivation often complicate sustainability, but an Edmonton-area pot producer has come up with a sunny solution.

Freedom Cannabis unveiled the largest rooftop solar system used by a cannabis facility in Canada at its 126,000-square foot Acheson location, 20 kilometres west of Edmonton, as solar power in Alberta continues to surge, on Tuesday.

The "state-of-the-art" 1,830-kilowatt solar array—made up of 4,574 panels—was supplied by Enmax and will offset more than 1,000 tonnes of greenhouse gas emissions each year, reflecting how new Alberta solar facilities are undercutting natural gas on price, the company said.

The state-of-the-art solar array—made up of 4,574 panels—was supplied by Enmax and will offset more than 1,000 tonnes of greenhouse gas emissions at Freedom Cannabis every year. Nov. 12, 2019. (Freedom Cannabis)

That will supply roughly eight per cent of the building's annual power consumption and reduce costs by $200,000 to $300,000 annually.

"This strategy will supplement our operating costs for power by up to eight to 10 per cent, so it is something that in time will save us costs on power requirements," said Troy Dezwart, co-founder of Freedom Cannabis.

Dezwart said sustainability was an important issue to the company from its outset, aligning with an Alberta renewable energy surge that is expected to power thousands of jobs.

"We're fortunate enough to be able to have these types of options and pursue them," said Dezwart.

The entire system cost Freedom Cannabis $2.6 million to build, but nearly a million of that came from a provincial rebate program that has since been cancelled by the UCP government, even as a federal green electricity deal with an Edmonton company signals ongoing support.

The company cited a 2017 report that found cannabis growers in the U.S. used enough electricity to power 1.7-million homes, and said cannabis-related power consumption is expected to increase by 1,250 per cent in Ontario over the next five years, even though Canadian solar demand has been lagging overall.

“It’s more important than ever for businesses to manage their energy footprint, and solar is an important part of that solution,” Enmax director Jason Atkinson, said. “This solar installation will help reduce operating costs and offset a significant portion of GHG emissions for decades to come.”

Freedom says it has other initiatives underway to reduce its footprint, in a region planning the Edmonton airport solar farm among other projects, including water remediation and offering 100 per cent recyclable cannabis packaging tins.

The company's first crops are expected to go to market in December.

 

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Hydro One deal to buy Avista receives U.S. antitrust clearance

Hydro One-Avista Acquisition secures U.S. antitrust clearance under Hart-Scott-Rodino, pending approvals from state utility commissions, the FCC, and CFIUS, with prior FERC approval and shareholder vote supporting the cross-border utility merger.

 

Key Points

A $6.7B cross-border utility merger cleared under HSR, still awaiting state, FCC, and CFIUS approvals; FERC approved earlier.

✅ HSR waiting period expired; U.S. antitrust clearance obtained

✅ Approvals pending: state commissions, FCC, and CFIUS

✅ FERC and Avista shareholders have approved the transaction

 

Hydro One Ltd. says it has received antitrust clearance in the United States for its deal to acquire U.S. energy company Avista Corp., even as it sought to redesign customer bills in Ontario.

The Ontario-based utility says the 30-day waiting period under the Hart-Scott-Rodino Antitrust Improvements Act expired Thursday night.

Hydro One announced the friendly deal to acquire Avista last summer, amid customer backlash in some service areas, in an agreement that valued the company at $6.7 billion.

The deal still requires several other approvals, including those from utility commissions in Washington, Idaho, Oregon, Montana and Alaska.

Analysts also warned of political risk for Hydro One during this period, reflecting concerns about provincial influence.

The U.S. Federal Communications Commission must also sign off on the transaction, and although U.S. regulators later rejected the $6.7B takeover following review, clearance is required by the Committee on Foreign Investment in the United States.

The agreement has received approval from the U.S. Federal Energy Regulatory Commission as well as Avista shareholders, and it mirrored other cross-border deals such as Algonquin Power's acquisition of Empire District that closed in the sector.

 

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Minister approves 30-megawatt wind farm expansion in Eastern Kings

Eastern Kings Wind Farm Expansion advances P.E.I. renewable energy with seven new wind turbines, environmental assessment, wildlife monitoring of birds and bats, and community consultation to double output to 30 MW for domestic consumption.

 

Key Points

A P.E.I. project adding seven turbines for 30 MW, under 17 conditions, with wildlife monitoring and community oversight.

✅ Seven new turbines, larger than existing units

✅ 17 conditions, monthly compliance reporting

✅ Two-year wildlife study for birds and bats

 

A proposal to expand an existing wind farm in eastern P.E.I. has been given the go-ahead, according to P.E.I.’s Department of Environment, Water and Climate Change, as related grid work like a new transmission line progresses in the region.

Minister Natalie Jameson approved the P.E.I. Energy Corporation’s Eastern Kings Wind Farm expansion project, the province announced in a release Wednesday afternoon, as Atlantic Canada advances other renewable initiatives like tidal power to diversify supply.

The project will be subject to 17 conditions, which were drawn from a review of the 80 responses the province received from the public on the proposed Eastern Kings Wind Farm expansion.

The corporation must provide a summary on the status of each condition to the department on a monthly basis.

“This decision balances the needs of people, communities, wellness and the environment,” Jameson said in the release.

“It allows this renewable energy project to proceed and reduce greenhouse [gas] emissions that cause climate change while mitigating the project’s impact to the Island’s ecosystem.”

The P.E.I. Energy Corporation wants to double the output of its Eastern Kings Wind Farm with the installation of seven wind turbines between the communities of Elmira and East Point to develop 30 megawatts of wind power for domestic consumption, according to the minister’s impact assessment, aligning with regional moves to expand wind and solar projects across Atlantic Canada.

The new turbines are expected to be larger than the existing 10 at the site, even as regional utilities study major grid changes to integrate more renewables.

Project must comply with conditions

In February, the province said it would identify any specific questions or concerns it felt needed to be addressed in the submissions, according to Greg Wilson, manager of environmental land management for the province, while some advocate for independent electricity planning to guide such decisions.

Public feedback closed in January, after an earlier extension to wait for a supplemental report on birds and bats.

The corporation needs to comply with all conditions – such as monitoring environmental impact, setting up an environmental management plan and creating a committee to address concerns – listed in the release on Wednesday, amid calls from environmental advocates to reduce biomass use in electricity generation.

A condition in the release suggests representatives from L’nuey, the Souris and Area Wildlife Branch, the Rural Municipality of Eastern Kings and local residents to make up the committee.

The corporation will also need to conduct a study over two years after construction to look at the impact on bats and birds, and implement a protocol to report deaths of birds to federal and provincial authorities.

According to Canada Energy Regulator, roughly 98 per cent of power generated on P.E.I. comes from wind farms. It also said there were 203 megawatts installed on P.E.I. as of 2018, and the majority of energy consumed on the Island comes from New Brunswick from a mix of nuclear, fossil fuels and hydroelectricity, while in Nova Scotia, the utility has increased biomass generation as part of its supply mix.

 

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Snohomish PUD Hikes Rates Due to Severe Weather Impact

Snohomish PUD rate increase addresses storm recovery after a bomb cyclone and extended cold snap, stabilizing finances and grid reliability while offering assistance programs, payment plans, and energy efficiency for customers.

 

Key Points

Temp 5.8% residential hike in Feb 2025 to recover storm costs, meet cold snap demand, and uphold reliable service.

✅ 5.8% residential increase effective Feb 2025

✅ Driven by bomb cyclone damage and cold snap demand

✅ Aid includes payment plans, efficiency rebates, low income support

 

In early February 2025, the Snohomish County Public Utility District (PUD) announced a temporary increase in electricity rates to offset the financial impact of severe weather events, including a bomb cyclone and an extended cold snap, that occurred in late 2024. This decision aims to stabilize the utility's finances, a pattern seen at other utilities such as Florida Power & Light, which pursued a hurricane surcharge to recover storm costs, while ensuring continued service reliability for its customers.

Background of the Weather Events

In November 2024, the Pacific Northwest experienced a powerful bomb cyclone—a rapidly intensifying storm characterized by a significant drop in atmospheric pressure. This event brought heavy rainfall, strong winds, and widespread power outages across the region. Compounding the situation, a prolonged cold weather period in December 2024 and January 2025 led to increased energy demand, and similar conditions drove up Pennsylvania power rates in the same winter season, as residents and businesses relied heavily on heating systems.

Impact on Snohomish PUD

The combination of the bomb cyclone and the subsequent cold weather placed considerable strain on the Snohomish PUD's infrastructure and financial resources. The utility incurred substantial costs for emergency repairs, restoration efforts, and the procurement of additional electricity to meet the heightened demand during the cold snap. These unforeseen expenses prompted the PUD to seek a temporary rate adjustment to maintain financial stability and continue providing reliable service to its customers.

Details of the Rate Increase

Effective February 2025, the Snohomish PUD implemented a temporary electricity rate increase of 5.8% for residential customers, compared with a 3% BC Hydro increase in the same region for context. This adjustment is designed to recover the additional costs incurred during the severe weather events. The PUD has communicated that this rate increase is temporary and will be reevaluated after a specified period to determine if further adjustments are necessary.

Customer Impact and Assistance Programs

While the rate increase is intended to be temporary, it may still pose a financial burden for some customers, even as some markets expect rates to stabilize in 2025 in other jurisdictions. To mitigate this impact, the Snohomish PUD has outlined several assistance programs:

  • Payment Plans: Customers facing financial hardship can enroll in extended payment plans to spread the cost of the increased rates over a longer period.

  • Energy Efficiency Programs: The PUD offers incentives and resources to help customers reduce energy consumption, potentially lowering their overall bills.

  • Low-Income Assistance: Eligible low-income customers may qualify for additional support through state and federal assistance programs.

The utility encourages customers to contact their customer service department to explore these options and find the best solutions for their individual circumstances.

Community Response and Future Considerations

The announcement of the rate increase has elicited mixed reactions from the community. Some residents express understanding, recognizing the necessity of maintaining infrastructure and service reliability. Others have voiced concerns about the financial impact, particularly among vulnerable populations, a debate also seen with higher BC Hydro rates in nearby British Columbia.

Looking ahead, the Snohomish PUD is committed to enhancing its infrastructure to better withstand future extreme weather events, an approach aligned with other utilities' multi-year rate proposals to fund upgrades. This includes investing in grid modernization, implementing advanced weather forecasting tools, and developing comprehensive emergency response plans. The utility also plans to engage with the community through public forums and surveys to gather feedback and collaboratively develop strategies that balance financial sustainability with customer affordability.

The temporary electricity rate increase by the Snohomish County Public Utility District reflects the financial challenges posed by severe weather events and parallels regional trends, including BC Hydro's 3.75% over two years adjustments, and underscores the importance of proactive infrastructure investment and community engagement. While the rate adjustment aims to stabilize the utility's finances, the PUD remains focused on supporting its customers through assistance programs and ongoing efforts to enhance service reliability and resilience against future climate-related events.

 

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