The National Electrical Manufacturers Association (NEMA) has published OS 1-2008 Sheet-Steel Outlet Boxes, Device Boxes, Covers, and Box Supports and OS 2-2008 Nonmetallic Outlet Boxes, Device Boxes, Covers, and Box Supports.
OS 1-2008 and OS 2-2008 describe standard configurations for outlet boxes 100 cubic inches or less, as well as manufacturer specifications for materials, corrosion protection, dimensions of openings, supports, cover screws, markings, and provisions for grounding. The standards specify dimensions necessary for compatibility with NEMA standard wiring devices and help manufacturers ensure that box constructions comply with the National Electrical Code as well as UL listing requirements.
“OS 1 and OS 2 are the essential industry standards for maintaining compatibility of metal and nonmetallic outlet boxes with standardized wiring devices and conduit and cable systems,” said Daniel Kissane, chairman of the Outlet & Switch Box Section. “These revisions serve to increase both standards’ utility to manufacturers and building specifiers.”
The standards were last revised in 2003. Two of the changes made to OS 1 include additional marking requirements for boxes for ceiling-suspended fan support and clarification to marking requirements for clamps furnished as part of a box. OS 2 includes updated definitions, revised requirements for fixture boxes, and a modified Table 2-2.
The contents and scope of OS 1 may be viewed, or a hardcopy or electronic copy purchased for $129, by visiting www.nema.org/stds/os1.cfm. The contents and scope of OS 2 may be viewed, or a hardcopy or electronic copy purchased for $82, by visiting www.nema.org/stds/os2.cfm. Standards may also be purchased by contacting IHS at 800-854-7179 (within the U.S.), 303-397-7956 (international), 303-397-2740 (fax), or global.ihs.com.
NEMA is the association of electrical and medical imaging equipment manufacturers. Founded in 1926 and headquartered near Washington, D.C., its approximately 450 member companies manufacture products used in the generation, transmission and distribution, control, and end use of electricity.
Crosbie Hydro Energy Action Plan outlines rate mitigation for Muskrat Falls, leveraging Nalcor oil revenues, export sales, Holyrood savings, and potential Hydro-Quebec taxation to keep Newfoundland and Labrador electricity rates near 14.67 cents/kWh.
Key Points
PC plan to cap post-Muskrat rates by using Nalcor revenues, exports, and savings, with optional Accord funds.
✅ $575.4M yearly to hold rates near 14.67 cents/kWh
Newfoundland and Labrador PC Leader Ches Crosbie says Muskrat Falls won't drive up electricity rates, a goal consistent with an agreement to shield ratepayers from cost overruns, if he's elected premier.
According to Crosbie, who presented the party's Crosbie Hydro Energy Action Plan — acronym CHEAP — at a press conference Monday, $575.4 million is needed per year in order to keep rates from ballooning past 14.67 cents per kilowatt hour.
Here's where he thinks the money could come from:
Hydro rates and dividends — $123.4 million
Export sales — $40.1 million
Nalcor restructuring — $30 million
Holyrood savings — $150 million
Nalcor oil revenue — $231 million
The oil money, Crosbie said, isn't going into government coffers but being invested into the offshore which, he said, is a good place for it.
"But the plan from the beginning around Muskrat Falls was that if there was need for it — for mitigation for rates — that those revenues and operating cash flows from Nalcor oil and gas would be available to be recycled into rate mitigation, as reflected in a recent financial update on the pandemic's impact. and that's what we're going to have to do," he said.
According to Crosbie, his numbers come from the preliminary stage of the Public Utilities Board process, even as rate mitigation talks have lacked public details.
This is a recent aerial view of the Muskrat Falls project in central Labrador. The project is more than 90 per cent complete, with first power forecast for late 2019, alongside Ottawa's $5.2B support for the project. (Nalcor)
"I'm telling you this is the best information available to anyone outside of government," he said. "We're working on what we can."
The PUB estimated Nalcor restructuring could save between $10 million and $15 million, according to Crosbie, but he figures there's "enough duplication and overpayment involved in the way things are now set up that we can find $30 million there."
Crosbie's $575.4-million figure would put rates at 14.67 cents per kilowatt-hour in 2021, where his plan pledges to keep them.
A recent Public Utilities Board Report says there's a potential $10 million to $15 million in savings from Nalcor, but Crosbie says he can find $30 million. (CBC)
"The promise is that Muskrat Falls, when it comes online — comes in service — will not increase your rates. Between now and when that happens there are rate increases already in the pipeline up to that level of [14.67 cents per kilowatt-hour] … so that is the baseline target rate at which rates will be kept.
"In other words, Muskrat will not drive up prices for electricity to consumers beyond that point."
In addition to those savings, Crosbie's plan outlined two further steps.
"We think it could be done out of the resources that I've just identified now, but if there's a problem with that, and as a temporary measure, we can use a modest amount of the Atlantic Accord review, fiscal review, revenues," he said.
Plan 'nothing new'
Premier Dwight Ball slammed the plan at the House of Assembly on Monday, saying it lacked insight.
"It was a copy and paste exercise," he told reporters. "There's nothing new in that plan. Not at all."
"We're not leaving any stone unturned of where the opportunity would be to actually generate revenue," he said. "We are genuinely concerned about rate mitigation and we've got to get a plan in place."
Potential to tax Hydro-Québec
Crosbie also said there's potential to tax Hydro-Québec.
According to Crosbie, tax exemptions that expired in 2016 allow the province to tax exports from the Upper Churchill, which, he said, could result in "hundreds of millions or billions" in revenue.
"It's not my philosophy to immediately go and do that because that would generate litigation — who needs more of that? — but we do need to let Quebec know that we're very aware of that, and aware of that opportunity, and invite them to come talk about a whole host of issues," Crosbie said.
Crosbie said the tax would also have to be applied to domestic consumption.
"But so massive is the potential revenue from the Upper Churchill export that there would be ways to mitigate that and negate the effect of that on consumers in the province."
Crosbie said with the Atlantic Accord revenue, he could still present a balanced budget by 2022.
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.”
Ontario Hydrogen Strategy accelerates green hydrogen via electrolysis, reduced electricity rates, and IESO pilots, leveraging ICI, interruptible rates, and surplus power to grow clean tech, low-carbon energy, and export markets across Ontario.
Key Points
A provincial plan to scale green hydrogen with electricity costs, IESO pilots, and surplus power to boost tech.
✅ Amends ICI to admit hydrogen producers from 50 kW demand
✅ Enables co-located electrolysers to use surplus curtailed power
✅ Offers interruptible rates via IESO pilot for flexible loads
The Ontario Ministry of Energy is seeking input on accelerating Ontario’s hydrogen economy. The province has been promoting growth in the clean tech sector, including low-carbon energy production and the Hydrogen Innovation Fund, as an avenue for post-COVID-19 economic recovery. Hydrogen produced through electrolysis (or “green hydrogen”) has been central to these efforts, complimenting both federal and provincial initiatives to create vibrant domestic and export markets for the energy as a principal alternative to conventional fossil fuels.
On April 14, 2022, the Ministry filed a proposal (the Proposal) on the Environmental Registry of Ontario (ERO) to gather input from stakeholders, aligning with the province’s industrial electricity pricing consultation underway. As part of Ontario’s Hydrogen Strategy, the Ministry is considering several options that would provide reduced electricity rates for green hydrogen producers to make production more economically competitive with other energies. To date, the relatively high production cost of green hydrogen has been a challenge facing its adoption, both domestically and internationally.
The Proposal features three options:
Amending the rules for the Industrial Conservation Initiative (ICI) applicable to hydrogen producers;
Enabling onsite hydrogen production using electricity that would otherwise be curtailed; and
Providing an interruptible electricity rate for hydrogen producers.
Option 1: Amending the ICI rules
Option 1 would amend the ICI rules to allow all hydrogen producers with an average monthly peak demand of 50kW to participate. Hydrogen producers’ facilities could qualify for ICI in the first year of operation with a peak demand factor determined based on a deemed consumption profile, using a method yet to be determined by the Ministry. At the end of the first year, their global adjustment (GA) charges would be reconciled based on their actual consumption pattern. As set out in our prior article, GA was introduced by the province in January 2005 to ensure reliable, sustainable and a diverse supply of power at stable and competitive prices, aligning with plans to rely on battery storage to meet rising energy demand. The Ministry’s current proposal would require hydrogen producers to place a security deposit for their facilities’ first year of operation with the Independent Electricity System Operator (IESO) or their Local Distribution Company (LDC) to ensure other consumer would not be adversely affected.
Option 2: Enable onsite hydrogen production using surplus electricity
Option 2 would allow businesses to co-locate hydrogen electrolysers at electricity generation facilities, drawing on recent electrolyzer investment trends, to make use of what would become curtailed generation. Under this option in the Proposal, the developer for the hydrogen production facility would be required to be a separate legal entity from the one that owns or operates the electricity generation facility. Based on this required level of independence, the hydrogen developer would be required to pay the electricity generator for the electricity supply.
At this stage, it is not clear whether, or how the generator would be required to share the revenue with other consumers. The next steps of the Proposal may require regulatory amendments, and/or amendments to electricity generator’s contracts, consistent with efforts enabling storage in Ontario's electricity system to integrate flexible resources.
Option 3: Interruptible electricity rates for hydrogen producers
In 2021, the Ministry posted a proposal on the ERO including an Interruptible Rate Pilot that was to be developed in conjunction with the IESO in order to address stakeholder feedback received during the 2019 Industrial Consultation specific to the challenges of identifying and responding to peak demand events while participating in the ICI. The pilot was targeted towards large electricity consumers, where participants were charged GA at a reduced rate in exchange for agreeing to reduce consumption during system or local reliability events, as identified by IESO.
Option 3 would allow for the introduction for a dedicated stream for hydrogen producers into the interruptible rate pilot, which is currently under development with the IESO. This would take into account the unique circumstances of hydrogen producers, as well as the importance of the hydrogen sector in Ontario’s Low-Carbon Hydrogen Strategy. Under the pilot, participants would be given advance notice by the IESO to reduce demand over a fixed number of hours, several times each year, and emerging vehicle-to-grid models where EV owners can sell electricity back to the grid highlight additional flexibility options. Ultimately, the pilot would support low-carbon hydrogen production by offering large electricity consumers, such as hydrogen producers, reduced electricity rates in exchange for reduces consumption during system or local reliability events.
Following this initial development work, the Ministry intends to consult with stakeholders later this year to determine design details, as well as the timing for the potential roll out of the proposed pilot.
Key takeaways
The design options are not meant to be mutually exclusive, and might be pursued by the Ministry in combination. Ultimately, Ontario is focusing on ways to reduce electricity rates in an attempt to make the province a leader in the adoption of green hydrogen, as made clear in the Ontario Hydrogen Strategy, even as an electricity supply crunch looms, underscoring the urgency. Stakeholders will want to participate in this process given its long-term implications for both the hydrogen and power sectors.
Northern Pass Project faces rejection by New Hampshire regulators, halting Hydro-Quebec clean energy transmission lines to Massachusetts; Eversource vows appeal as the Site Evaluation Committee cites development concerns and alternative routes through Vermont and Maine.
Key Points
A project to transmit Hydro-Quebec power to Massachusetts via New Hampshire, recently rejected by state regulators.
✅ New Hampshire SEC denied the transmission application
✅ Up to 9.45 TWh yearly from Hydro-Quebec to Massachusetts
✅ Eversource plans appeal; alternative routes via Vermont, Maine
Regulators in the state of New Hampshire on Thursday rejected a major electricity project being piloted by Quebec’s hydro utility and its American partner, Eversource.
Members of New Hampshire’s Site Evaluation Committee unanimously denied an application for the Northern Pass project a week after the state of Massachusetts green-lit the proposal.
Both states had to accept the project, as the transmission lines were to bring up to 9.45 terawatt hours of electricity per year from Quebec’s hydroelectric plants to Massachusetts as part of Hydro-Quebec’s export bid to New England, through New Hampshire.
The 20-year proposal was to be the biggest export contract in Hydro-Quebec’s history, in a region where Connecticut is leading a market overhaul that could affect pricing, and would generate up to $500 million in annual revenues for the provincial utility.
Hydro-Quebec’s U.S. partner, Eversource, said in a new release it was “shocked and outraged” by the New Hampshire regulators’ decision and suggested it would appeal.
“This decision sends a chilling message to any energy project contemplating development in the Granite State,” said Eversource. “We will be seeking reconsideration of the SEC’s decision, as well as reviewing all options for moving this critical clean energy project forward, including lessons from electricity corridor construction in Maine.”
The New Hampshire Union Leader reported Thursday the seven members of the evaluation committee said the project’s promoters couldn’t demonstrate the proposed energy transport lines wouldn’t interfere with the region’s orderly development.
Hydro-Quebec spokesman Serge Abergel said the decision wasn’t great news but it didn’t put a end to the negotiations between the company and the state of Massachusetts.
The hydro utility had proposed alternatives routes through Vermont and Maine amid a 145-mile transmission line debate over the corridor should the original plan fall through.
“There is a provision included in the process in the advent of an impasse, which allows Massachusetts to go back and choose the next candidate on the list,” Abergel said in an interview. “There are still cards left on the table.”
Ontario Utility Scam Alert: protect against phishing, spoofed calls, texts, and emails, disconnection threats, and demands for prepaid cards or bitcoin. Tips from Alectra, Elexicon, Hydro One, Hydro Ottawa, and Toronto Hydro.
Key Points
A joint warning by Ontario utilities on tactics and steps to prevent customer fraud, phishing, and spoofed contacts.
✅ Verify bills; call your utility using the official number.
✅ Ignore links; do not accept unexpected e-transfers.
✅ Never pay with gift cards, prepaid cards, or bitcoin.
Five of Ontario's largest utilities have joined forces to raise awareness about ongoing sophisticated utility scams targeting utility customers.
Some common tactics fraudsters use to target Ontarians include impersonation of the local utility or its employees; sending threatening phone calls, texts and emails; or showing up in-person at a customer's home or business and requesting personal information or payment. The requests can include pressure for immediate payment, threats to disconnect service the same day, and demands to purchase prepaid debit cards, gift cards or bitcoin.
The utilities are encouraging all customers to protect themselves and are providing them with the following tips to stay safe, noting that customers want more choice and flexibility in how they manage accounts:
Never make a payment for a charge that isn't listed on your most recent bill
Ignore text messages or emails with suspicious links promising refunds
Don't call the number provided to you — instead, call your utility directly to check the status of your account
Only provide personal information or details about your account when you have initiated the contact with the utility representative
Utility companies will never threaten immediate disconnection for non-payment, and many offer relief programs during hardship
If you feel threatened in any way, contact your local police
Steps you can take to protect yourself against fraud:
Take five minutes to ask additional questions and listen to your instincts — if something doesn't seem right, ask someone about it, and look for news of official utility support efforts that confirm legitimate outreach
Immediately hang up on suspicious phone calls
Don't click any links in emails/text messages asking you to accept electronic transfers
Avoid sharing personal information
Always compare bills to previous ones, including the dollar amount and account number, and stay informed about any official rate changes from your utility
Reporting suspicious behaviour, including suspected electricity theft, helps authorities
If you believe you may be a victim of fraud, please contact the Canadian Anti-Fraud Centre at 1-888-495-8501 and your local utility.
Alberta Rate of Last Resort streamlines electricity regulations to stabilize the default rate, curb price volatility, and protect rural communities, low-income households, and seniors while preserving competition in the province's energy market.
Key Points
Alberta's Rate of Last Resort sets biennial default electricity prices, curbing volatility and protecting customers.
✅ Biennial default rate to limit price spikes
✅ Focus on rural, senior, and low-income customers
✅ Encourages competitive contracts and market stability
The Alberta government is overhauling its electricity regulations as part of a market overhaul aimed at reducing spikes in electricity prices for consumers and businesses. The new rules, set to be introduced this spring, are intended to stabilize the default electricity rate paid by many Albertans.
Background on the Rate of Last Resort
Albertans currently have the option to sign up for competitive contracts with electricity providers. These contracts can sometimes offer lower rates than the default electricity rate, officially known as the Regulated Rate Option (RRO). However, these competitive rates can fluctuate significantly. Currently, those unable to secure these contracts or those who are on the default rate are experiencing rising electricity prices and high levels of price volatility.
To address this, the Alberta government is renaming the default rate as the Rate of Last Resort designation (RoLR) under the new framework. This aims to reduce the sense of security that some consumers might associate with the current name, which the government feels is misleading.
Price Stabilization: Default electricity rates will be set every two years for each utility provider, providing greater predictability by enabling a consumer price cap and reducing the potential for extreme price swings.
Rural and Underserved Communities: The changes are intended to particularly benefit rural Albertans and those on the default rate, including low-income individuals and seniors. These groups often lack access to the competitive rates offered by some providers and have been disproportionately affected by recent price increases.
Promoting Economic Stability: The goal is to lower the cost of utilities for all Albertans, leading to overall lower costs of living and doing business. The government anticipates these changes will create a more attractive environment for investment and job creation.
Opposition Views
Critics argue that limiting the flexibility of prices for the default electricity rate could interfere with market dynamics and stifle market competition among providers. Some worry it could ultimately lead to higher prices in the long term. Others advocate directly subsidizing low-income households rather than introducing broad price controls.
Balancing Affordability and the Market
The Alberta government maintains that the proposed changes will strike a balance between ensuring affordable electricity for vulnerable Albertans and preserving a competitive energy market. Provincial officials emphasize that the new regulations should not deter consumers from seeking out competitive rates if they choose to.
The Path Ahead
The new electricity regulations are part of the Alberta government's broader Affordable Utilities Program, alongside electricity policy changes across the province. The legislation is expected to be introduced and debated in the provincial legislature this spring with the potential of coming into effect later in the year. Experts expect these changes will significantly impact the Alberta electricity market and ignite further discussion about how best to manage rising utility costs for consumers and businesses.
