Future power production in the Northwest may depend partly on whether Canada and the United States agree to extend the Columbia River Treaty.
The 1964 treaty with Canada authorized construction of 3 large dams in British Columbia to protect against regional flooding and boost electricity generation.
Recently in Portland, the Bonneville Power Administration briefed the Northwest Power and Conservation Council on the first phase of an international review of the treaty.
The initial phase includes technical studies about possible power and flood control dam operations after 2024 with and without the treaty.
The treaty has no expiration date, but either country can request that it be terminated after 2024, 60 years after its ratification.
NL Hydro electricity credit delivers a one-time on-bill rebate from the rate stabilization fund, linked to oil prices and the Holyrood plant, via the Public Utilities Board, with payment deferrals and interest relief for customers.
Key Points
A one-time on-bill credit from the rate stabilization fund to cut power costs as oil prices remain low.
✅ One-time on-bill credit via the Public Utilities Board
✅ Funded by surplus in the rate stabilization fund
✅ Deferrals and 15 months interest assistance available
Most people who pay electricity bills will get a one-time credit as early as July.
The provincial government on Thursday outlined a new directive to the Public Utilities Board to provide a one-time credit for customers whose electricity rates are affected by the price of oil, part of an effort to shield ratepayers from Muskrat Falls overruns through recent agreements.
Electricity customers who are not a part of the Labrador interconnected system, including those using diesel on the north coast of Labrador, will receive the credit.
The credit, announced at a press conference Thursday morning, will come from the rate stabilization fund and comes as many customers have begun paying for Muskrat Falls on their bills, which has an estimated surplus of about $50 million because low oil prices mean NL Hydro has spent less on fuel for the Holyrood thermal generating station.
Normally a surplus would be paid out over a year, but customers this year will get the credit in a lump sum, as early as July, with the amount varying based on electricity usage.
"Given the difficult times many are finding themselves in, we believe an upfront, one-time on-bill credit would be much more helpful for customers than a small monthly decrease over the next 12 months," said Natural Resources Minister Siobhan Coady at the provincial government's announcement Thursday morning.
"We have requested that the board of commissioners of the Public Utilities Board, even as Nova Scotia's regulator approved a 14% increase recently, adopt a policy so that a credit will be dispersed immediately," Ball said.
"This is to help people when they need it the most.… We're doing what we can to support you."
The provincial government estimates someone whose power costs an average of $200 a month would get a one-time credit of about $130. Details of the plan will be left to the PUB.
Deferred payments allowed Ball said the credit will make a "significant impact" on customers' July bills.
Both businesses and residential customers will also be able to defer payments, similar to Alberta's deferral program that shifted costs for unpaid bills, with up to $2.5 million in interest being waived on overdue accounts. Customers will be required to make agreed-upon monthly payments to their account, and there will be interest assistance for 15 months, beginning June 1.
Coady said customers can renegotiate their bills and defer payments, with the province picking up the tab for the interest.
"You can speak to a customer service agent and they will make accommodations, but you have to continue to make some version of a monthly payment," Coady
"The interest that may be accrued is going to be paid for by the provincial government, so if you're a business, a person, and you're having difficulty and you can't make what I would say is your normal payment, call your utility, make some arrangements."
Labrador's interconnected grid isn't affected by the price of oil, but those customers can take advantage of the interest relief.
Relief policies already put in place during the pandemic, like not disconnecting customers and providing options for more flexible bill payments, will continue, as utilities such as Hydro One reconnecting customers demonstrate in Ontario.
Credit not enough to support customers: PCs While Ball said his government is doing what they can to help ratepayers, the opposition doesn't believe the announcement does enough to support those who need it.
Tony Wakeham, the Progressive Conservative MHA for Stephenville-Port au Port, said in a statement Thursday the credit simply gives people's money back to them, after the NL Consumer Advocate called an 18% rate hike unacceptable, and Newfoundland Power stands to benefit.
"The Liberal government would like ratepayers to believe that they are getting electricity rate relief, but in reality, customers would have been entitled to receive the value of this credit anyway over a 12-month period. Furthermore, in providing a one-time credit, Newfoundland Power will also be able to collect an administrative fee, adding to their revenues," Wakeham said in the statement.
"People and businesses in this province are struggling to pay their utility bills, and the Liberal government should help them by putting extra money into their pockets, not by recycling an already existing program to the benefit of a large corporation."
Wakeham called on government to direct the PUB to lower Newfoundland Power's guaranteed rate of return to give cash refunds to customers, and for Newfoundland Power to waive its fees.
Renewable Energy Cost Trends highlight IRENA data showing solar and wind undercut coal, as utility-scale projects drive lower levelized electricity costs worldwide, with the Middle East and UAE advancing mega solar parks.
Key Points
They track how solar and wind undercut new fossil fuels as utility-scale costs drop and investment accelerates.
✅ IRENA reports renewables cheapest for new installations
Renewable power projects have undercut traditional coal fuel plants, with solar and wind power costs in particular falling as record-breaking growth continues worldwide.
“Installing new renewables increasingly costs less than the cheapest fossil fuels. With or without the health and economic crisis, dirty coal plants were overdue to be consigned to the past, said Francesco La Camera, director-general of IRENA said in the report.
In 2019, renewables accounted for around 72 percent of all new capacity added worldwide, IRENA said, following a 2016 record year that highlighted the momentum, with lowering costs and technological improvements in solar and wind power helping this dynamic. For solar energy, IRENA notes that the cost for electricity from utility-scale plants fell by 82 percent in the decade between 2010 and 2019, as China's solar PV growth underscored in 2016.
“More than half of the renewable capacity added in 2019 achieved lower electricity costs than new coal, while new solar and wind projects are also undercutting the cheapest and least sustainable of existing coal-fired plants,” Camera added.
Costs for solar and wind power also fell year-on-year by 13 and 9 percent, respectively, with offshore wind costs showing steep declines as well. In 2019, more than half of all newly commissioned utility-scale renewable power plants provided electricity cheaper than the lowest cost of a new fossil fuel plant.
The Middle East
In mid-May, a report by UK-based law firm Ashurst suggested the Middle East is the second most popular region for renewable energy investment after North America, at a time when clean energy investment is outpacing fossil fuels.
The region is home to some of the largest renewable energy bets in the world, with Saudi wind expansion gathering pace. The UAE, for instance, is currently developing the Mohammed Bin Rashid Solar Park, the world’s largest concentrated solar power project in the world.
Around 26 percent of Middle East respondents in Ashurst’s survey said that they were presently investing in energy transition, marking the region as the most popular for current investment in renewables, while 11 percent added that they were considering investing.
In North America, the most popular region, 28 percent said that they were currently investing, with 11 percent stating they are considering investing.
Site C Dam Controversy highlights Peace River risks, BC Hydro claims, Indigenous rights under Treaty 8, environmental assessment findings, and potential impacts to agriculture and the Peace-Athabasca Delta across Alberta and the Northwest Territories.
Key Points
Debate over BC Hydro's Site C dam: clean energy vs Indigenous rights, Peace-Athabasca Delta impacts, and agriculture.
✅ Potential drying of Peace-Athabasca Delta and wildlife habitat
✅ Treaty 8 rights and First Nations legal challenges
✅ Loss of prime Peace Valley farmland; alternatives in renewables
One of the leading opponents of the Site C dam in northeastern B.C. is sharing her concerns with northerners this week.
Proponents of the Site C dam say it will be a cost-effective source of clean electricity, even as a major Alberta wind farm was scrapped elsewhere in Canada, and that it will be able to produce enough energy to power the equivalent of 450,000 homes per year in B.C. But a number of Indigenous groups and environmentalists are against the project.
Wendy Holm is an economist and agronomist who did an environmental assessment of the dam focusing on its potential impacts on agriculture.
On Tuesday she spoke at a town hall presentation in Fort Smith, N.W.T., organized by the Slave River Coalition. She is also speaking at an event in Yellowknife on Friday, as small modular reactors in Yukon receive study as a potential long-term option.
Worried about downstream impacts, Northern leaders urge action on Site C dam
"I learned that people outside of British Columbia are as concerned with this dam as we are," Holm said.
"There's just a lot of concern with what's happening on the Peace River and this dam and the implications for Alberta, where hydro's share has diminished in recent decades, and the Northwest Territories."
If completed, BC Hydro's Site C energy project will be the third dam on the Peace River in northeast B.C. and the largest public works project in B.C. history. The $10.7-billion project was approved by both the provincial and federal governments as B.C. moves to streamline clean energy permitting for future projects.
Amy Lusk, co-ordinator of the Slave River Coalition, said many issues were discussed at the town hall, but she also left with a sense of hope.
"I think sometimes in our little corner of the world, we are up against so much when it comes to industrial development and threats to our water," she said.
"To kind of take away that message of, this is not a done deal, and that we do have a few options in place to try and stop this and not to lose hope, I think was a very important message for the community."
Drying of the Peace-Athabasca Delta
Holm said her main concern for the Northwest Territories is how it could affect the Peace-Athabasca Delta. She said the two dams already on the river are responsible for two-thirds of the drying that's happening in the delta.
"These are very real issues and very present in the minds of northerners who want to stay connected to a traditional lifestyle, want to have access to those wild foods," she said.
Lusk said northerners are fed up with defending waters "time after time after time."
BC Hydro, however, said studies commissioned during the environmental assessment of Site C show the project will have no measurable effect on the delta, which is located 1,100 kilometres away.
Holm said the fight against the Site C dam is also important when it comes to First Nations treaty rights.
The West Moberly and Prophet River First Nations applied for an injunction to halt construction on Site C, as well as a treaty infringement lawsuit against the B.C. government. They argue the dam would cause irreparable harm to their territories and way of life, which are rights protected under Treaty 8.
Agricultural land
While the project is located in B.C., Holm said its impacts on prime horticulture land would also affect northerners, something that's important given issues of food security and nutrition.
"This is some of the best agriculture land in all of Canada," she said of the Peace Valley.
According to BC Hydro, around 2.6 million hectares of land in the Peace agricultural region would remain available for agricultural production while 3,800 hectares would be unavailable. It has also proposed a number of mitigation efforts, including a $20-million agricultural compensation fund.
Holm said renewable energy, including tidal energy for remote communities, will be cheaper and less destructive than the dam, and there's a connection between the dams on the Peace River and water sharing with the U.S.
"When you run out of water there's nothing else you can use. You can't use orange juice to irrigate your fields or to run your industries or to power your homes," she said.
Western Canada Electric Grid could deliver interprovincial transmission, reliability, peak-load support, reserve sharing, and wind and solar integration, lowering costs versus new generation while respecting AESO markets and Crown utility structures.
Key Points
Interprovincial transmission to share reserves, boost reliability, integrate wind and solar, and cut peak capacity costs.
✅ Cuts reserve margins via diversity of peak loads
✅ Enables wind and solar balancing across provinces
✅ Saves ratepayers vs replacing retiring thermal plants
The 2017 Canadian Free Trade Agreement does not do much to encourage provinces to trade electric energy east and west. Would a western Canada electric grid help electricity consumers in the western provinces? Some Alberta officials feel that their electric utilities are investor owned and they perceive the Crown corporations of BC Hydro, SaskPower and Manitoba Hydro to be subsidized by their provincial governments, so an interprovincial electric energy trade would not be on a level playing field.
Because of the limited trade of electric energy between the western provinces, each utility maintains an excessive reserve of thermal and hydroelectric generation greater than their peak loads, to provide a reliable supply during peak load days as grids are increasingly exposed to harsh weather across Canada. This excess does not include variable wind and solar generation, which within a province can’t be guaranteed to be available when needed most.
This attitude must change. Transmission is cheaper than generation, and coordinated macrogrids can further improve reliability and cut costs. By constructing a substantial grid with low profile and aesthetically designed overhead transmission lines, the excess reserve of thermal and hydroelectric generation above the peak electric load can be reduced in each province over time. Detailed assessments will ensure each province retains its required reliability of electric supply.
As the provinces retire aging thermal and coal-fired generators, they only need to replace them to a much lower level, by just enough to meet their future electric loads and Canada's net-zero grid by 2050 goals. Some of the money not spent in replacing retired generation can be profitably invested in the transmission grid across the four western provinces.
But what about Alberta, which does not want to trade electric energy with the other western provinces? It can carry on as usual within the Alberta Electric System Operator’s (AESO) market and will save money by keeping the installed reserve of thermal and hydroelectric generation to a minimum. When Alberta experiences a peak electric load day and some generators are out of service due to unplanned maintenance, it can obtain the needed power from the interprovincial electric grid. None of the other three western provinces will peak at the same time, because of different weather and time zones, so they will have spare capacity to help Alberta over its peak. The peak load in a province only lasts for a few hours, so Alberta will get by with a little help from its friends if needed.
The grid will have no energy flowing on it for this purpose except to assist a province from time to time when it’s unable to meet its peak load. The grid may only carry load five per cent of the time in a year for this purpose. Under such circumstances, the empty grid can then be used for other profitable markets in electric energy. This includes more effective use of variable wind and solar energy, by enabling a province to better balance such intermittent power as well as allowing increased installation of it in every province. This is a challenge for AESO which the grid would substantially ease.
Natural Resources Canada promoted the “Regional Electricity Co-Operative and Strategic Infrastructure” initiative for completion this year and contracted through AESO, alongside an Atlantic grid study to explore regional improvements. This is a first step, but more is needed to achieve the full benefit of a western grid.
In 1970 a study was undertaken to electrically interconnect Britain with France, which was justified based on the ability to reduce reserve generation in both countries. Initially Britain rejected it, but France was partially supportive. In time, a substantial interconnection was built, and being a profitable venture, they are contemplating increasing the grid connections between them.
For the sake of the western consumers of electricity and to keep electricity rates from rising too quickly, as well as allowing productive expansion of wind and solar energy in places like British Columbia's clean energy shift efforts, an electric grid is essential across western Canada.
Dennis Woodford is president of Electranix Corporation in Winnipeg, which studies electric transmission problems, particularly involving renewable energy generators requiring firm connection to the grid.
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.”
EU Clean Energy Transition underscores the shift from fossil fuels to renewable energy, decarbonization, and hydrogen, as soaring gas prices and electricity volatility spur resilience, storage, and joint procurement across the single market.
Key Points
EU Clean Energy Transition shifts from fossil fuels to renewables, enhancing resilience and reducing price volatility.
✅ Cuts reliance on Russian gas and fossil imports
✅ Scales renewables, hydrogen, and energy storage
✅ Stabilizes electricity prices via market resilience
Soaring energy prices, described as Europe's energy nightmare, are a stark reminder of how dependent Europe is on fossil fuels and should serve to accelerate the shift towards renewable forms of energy.
"This experience today of the rising energy prices is a clear wake up call... that we should accelerate the transition to clean energy, wean ourselves off the fossil fuel dependency," a senior EU official told reporters as the European Commission unveiled a series of emergency electricity measures aimed at tackling the crisis.
The European Union is facing a sharp spike in energy prices, driven by increased global demand as the world recovers from the pandemic and lower-than-expected natural gas deliveries from Russia. Wholesale electricity prices have increased by 200% compared to the 2019 average, underscoring why rolling back electricity prices is tougher than it appears, according to the European Commission.
"Winter is coming and for many electricity costs are larger than they have been for a decade," Energy Commissioner Kadri Simson told reporters on Wednesday.
80 million European households struggle to stay warm Wholesale gas prices — which have surged to record highs in France, Spain, Germany and Italy, amid reports of Germany's local utilities crying for help — are expected to remain high through the winter.
Prices are expected to fall in the spring, but remain higher than the average of past years, according to the Commission. Most EU countries rely on gas-fired power stations to meet electricity demand, and about 40% of that gas comes from Russia, with the EU outlining a plan to dump Russian energy to reduce this reliance, according to Eurostat.
Simson said that the Commission's initial assessment indicates that Russia's Gazprom has been fulfilling its long-term contracts "while providing little or no additional supply." Kremlin spokesman Dmitry Peskov told journalists on Wednesday that Russia has increased gas supplies to Europe to the maximum possible level under existing contracts, but could not exceed those thresholds. "We can say that Russia is flawlessly fulfilling all contractual obligations," he said.
Measures EU states can take to help consumers and businesses cope with soaring electricity costs include emergency income support to households to help them pay their energy bills, alongside potential gas price cap strategies, state aid for companies, and targeted tax reductions. Member states can also temporarily delay bill payments and put in place processes to ensure that no one is disconnected from the grid.
Green energy the solution The Commission also published a series of longer term measures the bloc should consider to reduce its dependence on fossil fuels and tackle energy price volatility, despite opposition from nine countries to electricity market reforms.
"Our immediate priority is to protect Europe's consumers, especially the most vulnerable," Simson said. "Second, we want to make our energy system better prepared and more resilient, so we don't have to face a similar situation in the future," she added.
Energy crisis could force more UK factories to close This would require speeding up the green energy transition rather than slowing it down, Simson said. "We are not facing an energy price surge because of our climate policy or because renewable energy is expensive. We are facing it because the fossil fuel prices are spiking," she continued.
"The only long term remedy against demand shocks and price volatility is a transition to a green energy system."
Simson said she will propose to EU leaders a package of measures to decarbonize Europe's gas and hydrogen markets by 2050. Other measures to improve energy market stability could include increasing gas storage capacity and buying gas jointly at an EU level.
