Alberta power bills will “crush” consumers

NB Power Smart Meter Opt-Out Fees reflect cost causation principles set before the Energy and Utilities Board, covering meter reading charges, transmitter-disable options, rollout targets, and education plans across New Brunswick's smart metering program.

Key Points

Fees NB Power may apply to customers opting out of smart meters, reflecting cost causation and meter-reading costs.

✅ Based on cost causation and meter reading expenses

✅ BC and Quebec charge monthly opt-out surcharges

✅ Policy finalized during rollout after EUB review

NB Power customers who do not want a smart meter installed on their home could be facing a stiff fee for that decision, but so far the utility is not saying how much it might be.  

"It will be based on the principles of cost causation, but we have not gotten into the detail of what that fee would be at this point," said NB Power Senior Vice President of Operations Lori Clark at Energy and Utilities Board hearings on Friday.

In other jurisdictions that have already adopted smart meters, customers not wanting to participate have faced hundreds of dollars in extra charges, while Texas utilities' pullback from smart-home networks shows approaches can differ.

In British Columbia, power customers are charged a meter reading fee of $32.40 per month if they refuse a smart meter, or $20 per month if they accept a smart meter but insist its radio transmitter be turned off. That's a cost of between $240 and $388.80 per year for customers to opt out.

In Quebec, smart meters were installed beginning in 2012. Customers who refused the devices were initially charged $98 to opt out plus a meter reading fee of $17 per month. That was eventually cut by Quebec's energy board in 2014 to a $15 refusal fee and a $5 per month meter reading surcharge.

NB Power said it may be a year or more before it settles on its own fee.

"The opt out policy will be developed and implemented as part of the roll out.  It will be one of the last things we do," said Clark.

Customers need to be on board

NB Power is in front of the New Brunswick Energy and Utilities Board seeking permission to spend $122.7 million to install 350,000 smart meters province wide, as neighboring markets grapple with major rate increases that heighten affordability concerns.  

The meters are capable of transmitting consumption data of customers back to NB Power in real time, which the utility said will allow for a number of innovations in pricing and service, and help address old meter inaccuracies that affected some households.

The meters require near universal adoption by customers to maximize their financial benefit — like eliminating more than $20 million a year NB Power currently spends to read meters manually. The utility has said the switch will not succeed if too many customers opt out.

"We certainly wouldn't be looking at making an investment of this size without having the customer with us," said Clark.

On Thursday, Kent County resident Daniel LeBlanc, who along with Roger Richard, is opposing the introduction of smart meters for health reasons, predicted a cool reception for the technology in many parts of the province, given concerns that include health effects and billing disputes in Nova Scotia reported elsewhere.

"If one were to ask most of the people in the rural areas, I'm not sure you would get a lot of takers for this infrastructure," said LeBlanc, who is concerned with the long-term effect microwave frequencies used by the meters to transmit data may have on human health.

That issue is before the EUB next week.

Haven't tested the waters

NB Power acknowledged it has not measured public opinion on adopting smart meters but is confident it can convince customers it is a good idea for them and the utility, even as seasonal rate proposals in New Brunswick have prompted consumer backlash.

"People don't understand what the smart meter is," said Clark. "We need to educate our customers first to allow them to make an informed decision so that will be part of the roll out plan."

Clark noted that smart meters, helped by stiff opting out penalties, were eventually accepted by 98 per cent of customers in British Columbia and by 97.4 per cent of customers in Quebec.

"We will check and adjust along the way if there are issues with customer uptake," said Clark.

"This is very similar to what has been done in other jurisdictions and they haven't had those challenges."

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France-Germany Energy Solidarity underscores EU energy crisis cooperation: gas supply swaps, electricity imports, price cap talks, and curbs on speculation as Russian pipeline flows halt and winter demand rises across the bloc.

Key Points

A pact where France sends gas to Germany as Germany supplies power, bolstering EU cooperation and winter security.

✅ Gas to Germany; power to France amid nuclear outages.

✅ EU price cap, anti-speculation, joint gas purchasing.

✅ No new Spain-France pipeline unless case improves.

France will send gas to Germany if needed while Germany stands ready to provide it with electricity, President Emmanuel Macron said on Monday, saying this showcased European solidarity in the face of the energy crisis stemming from the war in Ukraine, which many view as a wake-up call to ditch fossil fuels across the bloc.

European gas prices surged, share prices slid and the euro sank on Monday after Russia stopped pumping gas via a major supply route, and Germany's 200 billion euro package sought to cushion the blow, in another warning to the 27-nation EU as it scrambled to respond to the crisis ahead of winter. read more

"Germany needs our gas and we need power from the rest of Europe, notably Germany," France's president told a news conference as EU electricity reform remains under debate following a phone call with German Chancellor Olaf Scholz.

The necessary connections for France to deliver gas to Germany when needed would be finalised in the coming weeks, he said, adding that France, which had long been a net exporter of electricity, will need help from its neighbours because of technical problems its nuclear plants face. read more

Macron, however, said that he did not understand demand for a third gas link between France and Spain, rejecting calls to increase capacity with a new pipeline.

He added he was open to changing his mind on that point, especially as Germany's utility troubles deepen, should Scholz or Prime Minister Pedro Sanchez argue convincingly for it.

Ahead of a meeting on Friday of EU energy ministers, Macron said France was in favour of buying gas at a European rather than a national level, as emergency electricity measures are weighed, and called for European Union measures to control energy prices.

He said it was necessary to act against speculation on energy prices at EU level, as the EU outlines possible gas price cap strategies for discussion, and also said France was in favour of putting a cap on the price of pipeline Russian gas.

Macron also repeated calls for all to turn down air conditioners when it's hot and to limit heating to 19 degrees Celsius this winter, noting that rolling back electricity prices is tougher than it appears this year.

"Everyone has to do their bit," he said.

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Calgary EV Charging for Apartments and Condos streamlines permitting for multi-unit dwellings, guiding condo boards and property managers to install EV charging stations, expand infrastructure, and advance sustainability with cleaner air and lower emissions.

Key Points

A Calgary program simplifying permits and guidance to add EV charging stations in multi-unit residential buildings.

✅ Streamlined permitting for condo boards and property managers

✅ Technical assistance to install EV charging stations

✅ Boosts property value and reduces emissions citywide

As the demand for electric vehicles (EVs) continues to rise, and as national EV targets gain traction, Calgary is taking significant strides to enhance its charging infrastructure, particularly in apartment and condominium complexes. A recent initiative has been introduced to facilitate the installation of EV charging stations in these residential buildings, addressing a critical barrier for potential EV owners living in multi-unit dwellings.

The Growing EV Market

Electric vehicles are no longer a niche market; they have become a mainstream option for many consumers. As of late 2023, EV sales have surged, with projections indicating that the trend will only continue. However, a significant challenge remains for those who live in apartments and condos, where high-rise charging can be a mixed experience and the lack of accessible charging stations persists. Unlike homeowners with garages, residents of multi-unit dwellings often rely on public charging infrastructure, which can be inconvenient and limiting.

The New Initiative

In response to this growing concern, the City of Calgary has launched a new initiative aimed at easing the process of installing EV chargers in apartment and condo buildings. This program is designed to streamline the permitting process, reduce red tape, and provide clear guidelines for property managers and condo boards, similar to strata installation rules adopted in other jurisdictions to ease installations.

The initiative includes various measures, such as providing technical assistance and resources to building owners and managers. By simplifying the installation process, the city hopes to encourage more residential complexes to adopt EV charging stations. The initiative also emphasizes practical support, such as providing technical assistance, including condo retrofit guidance, and resources to building owners and managers. This is a significant step towards creating an eco-friendly urban environment and meeting the growing demand for sustainable transportation options.

Benefits of the Initiative

The benefits of this initiative are manifold. Firstly, it supports Calgary's broader climate goals by promoting electric vehicle adoption. As more residents gain access to charging stations, the city can expect a corresponding reduction in greenhouse gas emissions, contributing to cleaner air and a healthier urban environment.

Additionally, providing charging infrastructure can enhance property values. Buildings equipped with EV chargers become more attractive to potential tenants and buyers who prioritize sustainability. As the market for electric vehicles expands, properties that offer charging facilities are likely to see increased demand, making them a sound investment for landlords and developers.

Overcoming Challenges

While this initiative marks a positive step forward, there are still challenges to address. Property managers and condo boards may face initial resistance from residents who are uncertain about the costs associated with installing and maintaining EV chargers, though rebates for home and workplace charging can offset upfront expenses and ease adoption. Clear communication about the long-term benefits, including potential energy savings and the value of sustainable living, will be essential in overcoming these hurdles.

Furthermore, the city will need to ensure that the installation of EV chargers is done in a way that is equitable and inclusive. This means considering the needs of all residents, including those who may not own an electric vehicle but would benefit from a greener community.

Looking Ahead

As Calgary moves forward with this initiative, it sets a precedent for other cities, as seen in Vancouver's EV-ready policy, facing similar challenges in promoting electric vehicle adoption. By prioritizing charging infrastructure in multi-unit residential buildings, Calgary is taking important steps towards a more sustainable future.

In conclusion, the push for EV charging stations in apartments and condos is a critical move for Calgary. It reflects a growing recognition of the role that urban planning and infrastructure play in supporting the transition to electric vehicles, which complements corridor networks like the BC Electric Highway for intercity travel. With the right support and resources, Calgary can pave the way for a greener, more sustainable urban landscape that benefits all its residents. As the city embraces this change, it will undoubtedly contribute to a broader shift towards sustainable living, ultimately helping to combat climate change and improve the quality of life for all Calgarians.

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Advanced Nuclear Reactors redefine nuclear energy with SMRs, diverse fuels, passive safety, digital control rooms, and flexible heat and power, pairing veteran operator expertise with cost-efficient, carbon-free electricity for a resilient grid.

Key Points

SMR-based advanced reactors with passive cooling and digital controls deliver flexible power and process heat.

✅ Veteran operators transfer proven safety culture and risk management.

✅ SMRs, passive safety, and digital controls simplify operations.

✅ Flexible output: electricity, process heat, and grid support.

Advanced reactors will break the mold of what we think next-gen nuclear power can accomplish: some will be smaller, some will use different kinds of fuel and others will do more than just make electricity. This new technology may seem like uncharted waters, but when operators, technicians and other workers start up the first reactors of the new generation, they will bring with them years of nuclear experience to run machines that have been optimized with lessons from the current fleet.

While advanced reactors are often portrayed as the future of nuclear energy, and atomic energy is heating up across markets, its our current plants that have paved the way for these exciting innovations and which will be workhorses for years to come.

Reactor Veterans Bring Their Expertise to New Designs

Many of the workers who will operate the next generation of reactors come from a nuclear background. Even though the design of an advanced reactor may be different, the experience and instincts these operators have gained from working at the current fleet will help new plants get off to a more productive start.

They have a questioning attitude; they are always exploring what could go wrong and always understanding the notion of risk management in nuclear operations, whether its the oldest design or the newest design, said Chip Pardee, the president of Terrestrial Energy USA, who is the former chief operating officer at two nuclear utilities, Exelon Corp. and the Tennessee Valley Authority.

They have respect for the technology and a bias towards conservative decision-making.

Jhansi Kandasamy, vice president of engineering at GE Hitachi Nuclear Energy, agrees. She said that the presence of industry veterans will benefit the new modelslike the 300 megawatt boiling water reactor her company is developing.

From the beginning, a new reactor will have people who have touched it, worked on it, and experienced it, she said.

Theyre going to be able to tell you if something doesnt look right, because theyve lived through it.

Experience Informs New Reactor Design

Advanced reactors are designed by engineers who are fully familiar with existing plants and can use that experience to optimize the new ones, like a family building a house and wanting the kitchen just so. New reactors will be simpler to operate because of insights gained from years of operations of the current fleet, and some designs even integrate molten salt energy storage to enhance flexibility.

NuScale Power LLC, for example, has a very different design from the current fleet amid an advanced nuclear push that is reshaping development: up to 12 small reactorsinstead of one or two large reactorsmanaged from a single digital control roominstead of one full of analog switches and dials. When the company designed its control room, it brought in industry veterans who had collectively worked at more than two dozen nuclear plants.

The experts that NuScale brought in critiqued everything, even down to the shape of the symbols on the computer screens to make them easier to read for operators who sometimes need to quickly interpret lots of incoming data. The control panels for NuScales small modular reactor (SMR) present information according to its importance and automatically call up appropriate procedures for operators.

Many advanced reactors are also smaller than those currently operating, which makes their components simpler and less expensive. Kandasamy pointed out that the giant mechanical pumps in todays reactors generate a lot of heat and require a lot of supporting systems, including air conditioning in the rooms that house them.

GE Hitachis SMR design relies more on passive cooling so it needs fewer pumps, and those that remain use magnets, so they generate less heat. Fewer, smaller pumps means a smaller building and less cost.

Advanced Nuclear Will Further the Work of Current Reactors

Advanced reactors promise improved flexibility and the ability to do more kinds of work, including nuclear beyond electricity applications, to displace carbon and stabilize the climate. And they will continue nuclear energys legacy of providing reliable, carbon-free electricity, as a recent new U.S. reactor startup illustrates in practice. As new designs come on line over the next decade, we will continue to rely on operating plants which provide nearly 55 percent of the countrys carbon-free electricity.

The world will need all the carbon-free generation it can get for many years to come, as companies, states and countries aim for zero emissions by mid-century and pursue strategies like the green industrial revolution to accelerate deployment. That means it will need wind, solar, advanced reactors and current plants.

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Manitoba Hydro 3.5 Percent Rate Increase proposes a smaller electricity rate hike under Public Utilities Board oversight to bolster financial reserves, address debt and Bipole III costs, amid shifting export sales and water flow conditions.

Key Points

It is Manitoba Hydro's proposed 3.5% electricity rate hike for 2019-20 to shore up finances under PUB oversight.

✅ PUB review sought without lengthy hearing

✅ Revenue boost forecast at 59 million dollars

✅ Natural gas rates flat; class shifts adjust bills

Manitoba Hydro is scaling back its rate hike request for next year, instead of the annual 7.9 per cent hikes the Crown corporation previously said it would need until 2023-24 to address debt. 

Hydro is asking the Public Utilities Board for a 3.5 per cent rate increase next year, which would take effect on April 1.

In last week's application, Hydro said its new board is reviewing the corporation's financial picture. Once that is complete, the utility expects to submit a new multi-year rate plan in late 2019 that addresses the organization's long-term future.

"It's too speculative at this point to discuss any possible future rate increases," spokesperson Bruce Owen said in an email.

The proposed increase next year is similar to other jurisdictions and nearly in line with the Public Utilities Board's decision to allow an average 3.6 per cent jump in electricity rates in 2018-19, which began this summer.

"The requested 3.5 per cent rate increase … generates a modest level of net income under average water flow conditions that will assist in gradually building the revenue base and reduce the risk of the corporation incurring a loss" in 2019-20, the rate application said.

If approved, consumers would face their second rate increase from Hydro in under a year.

Crown Services Minister Colleen Mayer said she's sympathetic to customers bracing for another rate increase amid NL rate hike concerns that far exceeds the rate of inflation.

"I hear that, very clearly," she said. "The NDP left us with an insurmountable problem — we're trying to fix that."

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Next year's rate increase is projected to bring in $59 million of revenue, boosting the Crown corporation's financial reserves by $31 million.

Without it, the utility would deal with a net loss, it said.

This time, Hydro officials are asking PUB to forgo a rate hearing, suggesting neither itself nor the board has the resources for a lengthy six- to nine-month process to review an application where not much has changed financially and would generate a "minimum level of net income," Hydro said in a letter to the board.

The short-term rate relief, the letter recommends, should be "awarded in a timely and cost-effective manner, recognizing that the corporation's long-term financial forecasts will be finalized and available for review" in late 2019.

Hydro's net income next year will be lower than projected, the rate application said, due to a reduction in export sales and increases in depreciation and financing costs from Bipole III.

"Even though they had a total implosion of their previous board, on this very issue, they haven't learned lessons and they continue to be cheerleaders for these rapid rate increases," Kinew said, referring to the exodus of every board member but one earlier this year.

Manitoba Hydro's burgeoning debt surpasses $19 billion

On natural gas, Manitoba Hydro is asking PUB for no rate increase for the next two years.

There will, however, be some changes in rates in different customer classes, Owen said, resulting in modest rate reductions for mainly residential customers and increases for customers who use a lot of natural gas.

The corporation also wants to stop collecting fees to support the furnace replacement program. The initiative will continue with existing fees.

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SM-1A Nuclear Plant Decommissioning details the US Army Corps of Engineers' removal of the Fort Greely reactor, Cold War facility dismantling, environmental monitoring, remote-site power history, and timeline to 2026 under a deactivated nuclear program.

Key Points

Army Corps plan to dismantle Fort Greely's SM-1A reactor and complete decommissioning of remaining systems by 2026.

✅ Built for remote Arctic radar support during the Cold War

✅ High costs beat diesel; program later deemed impractical

✅ Reactor parts removed; residuals monitored; removal by 2026

The US Army Corps of Engineers has begun decommissioning Alaska’s only nuclear power plant, SM-1A, which is located at Fort Greely, even as new US reactors continue to take shape nationwide. The $17m plant closed in 1972 after ten years of sporadic operation. It was out of commission from 1967 to 1969 for extensive repairs. Much of has already been dismantled and sent for disposal, and the rest, which is encased in concrete, is now to be removed.

The plant was built as part of an experimental programme to determine whether nuclear facilities, akin to next-generation nuclear concepts, could be built and operated at remote sites more cheaply than diesel-fuelled plants.

"The main approach was to reduce significant fuel-transportation costs by having a nuclear reactor that could operate for long terms, a concept echoed in the NuScale SMR safety evaluation process, with just one nuclear core," Brian Hearty said. Hearty manages the Army Corps of Engineers’ Deactivated Nuclear Power Plant Program.

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He said the Army built SM-1A in 1962 hoping to provide power reliably at remote Arctic radar sites, where in similarly isolated regions today new US coal plants may still be considered, intended to detect incoming missiles from the Soviet Union at the height of the Cold War. He added that the programme worked but not as well as Pentagon officials had hoped. While SM-1A could be built and operated in a cold and remote location, its upfront costs were much higher than anticipated, and it costs more to maintain than a diesel power plant. Moreover, the programme became irrelevant because of advances in Soviet rocket science and the development of intercontinental ballistic missiles.

Hearty said the reactor was partially dismantled soon after it was shut down. “All of the fuel in the reactor core was removed and shipped back to the Atomic Energy Commission (AEC) for them to either reprocess or dispose of,” he noted. “The highly activated control and absorber rods were also removed and shipped back to the AEC.”

The SM-1A plant produced 1.8MWe and 20MWt, including steam, which was used to heat the post. Because that part of the system was still needed, Army officials removed most of the nuclear-power system and linked the heat and steam components to a diesel-fired boiler. However, several parts of the nuclear system remained, including the reactor pressure vessel and reactor coolant pumps. “Those were either kept in place, or they were cut off and laid down in the tall vapour-containment building there,” Hearty said. “And then they were grouted and concreted in place.” The Corps of Engineers wants to remove all that remains of the plant, but it is as yet unclear whether that will be feasible.

Meanwhile, monitoring for radioactivity around the facility shows that it remains at acceptable levels. “It would be safe to say there’s no threat to human health in the environment,” said Brenda Barber, project manager for the decommissioning. Work is still in its early stages and is due to be completed in 2026 at the earliest. Barber said the Corps awarded the $4.6m contract in December to a Virginia-based firm to develop a long-range plan for the project, similar in scope to large reactor refurbishment efforts elsewhere. Among other things, this will help officials determine how much of the SM-1A will remain after it’s decommissioned. “There will still be buildings there,” she said. “There will still be components of some of the old structure there that may likely remain.”

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