Australian wind farms face two-year delay

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Due to the uncertainty regarding the Renewable Energy Target (RET) in Australia, wind farm developers are postponing construction dates by up to two years.

What is the difference between the Carbon Pollution Reduction Scheme (CPRS) and the Renewable Energy Target, and why are these two things so polarizing to the industry?

The Carbon Pollution Reduction Scheme is a contentious proposed law in Australia regarding the amount of greenhouse gases produced by industry and proposes a Carbon Credit Trading Scheme as a way of regulating the emissions. The Renewable Energy Target is a commitment by the Australian Federal Government to make Australia's electricity mix 20% renewable by 2020.

The theory is that the CPRS will help to bring renewable energy technologies into the market over time, while the RET scheme will accelerate uptake and prepare the sector to reduce emissions significantly.

The main source of contention for the renewables industry in Australia is that solar water heaters (including domestic) and small-scale solar, wind and hydro electricity systems are eligible in the RET scheme, as well as native forest wood waste. This means that homeowners are eligible for the same renewable energy certificates (RECs) as the wind farm developers, and that funding for these larger scale projects is harder to get.

A renewable energy credit is equivalent to one megawatt-hour (MWh) of renewable energy, except for small-generation units to which a multiplier is applied. The scheme was designed to increase the deployment of renewable energy technology. It also created a market for additional renewable-based generation by legally obliging wholesaler electricity purchasers to source an increasing percentage of their electricity purchases from renewable-based generation.

This glut in renewable energy certificates has created a depression for the price of RECs. The minimum development cost for a 35-MW wind farm is about $50 million (Australian dollars), which does not include the costs involved for consultants, community consultations, and amendments for the protection local wildlife.

The industry has indicated that this would mean that capital-intensive plants will be run at a loss, and that the Renewable Energy Target has inadvertently caused investment for low-emission electricity generation to be shelved.

The REC and CPRS debate will be reopened in February, when the Australian Federal Government returns after the Christmas break. Until then, the wind energy industry will continue to be conservative with investment.

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Electricity Prices Surge to Record as Europe Struggles to Keep Lights on

France Electricity Crisis drives record power prices as nuclear outages squeeze supply, forcing energy imports, fuel oil and coal generation, amid gas market shocks, weak wind output, and freezing weather straining the grid.

 

Key Points

A French power shortfall from nuclear outages, record prices, heavy imports, and oil-fired backup amid cold weather.

✅ EDF halted reactors; 10% capacity offline, 30% by January

✅ Imports surge; fuel oil and coal units dispatched

✅ Prices spike as gas reverses flow and wind output drops

 

Electricity prices surged to a fresh record as France scrambled to keep its lights on, sucking up supplies from the rest of Europe.

France, usually an exporter of power, is boosting electricity imports and even burning fuel oil, and has at times limited nuclear output due to high river temperatures during heatwaves. The crunch comes after Electricite de France SA said it would halt four reactors accounting for 10% of the nation’s nuclear capacity, straining power grids already facing cold weather. Six oil-fired units were turned on in France on Tuesday morning, according to a filing with Entsoe.

“It’s illustrating how severe it is when they’re actually starting to burn fuel oil and importing from all these countries,” said Fabian Ronningen, an analyst at Rystad Energy. The unexpected plant maintenance “is reflected in the market prices,” he said

Europe is facing an energy crisis, with utilities relying on coal and oil. Almost 30% of France’s nuclear capacity will be offline at the beginning of January, leaving the energy market at the mercy of the weather. To make matters worse, Germany is closing almost half of its nuclear capacity before the end of the year, as Europe loses nuclear power just when it really needs energy.

German power for delivery next year surged 10% to 278.50 euros a megawatt-hour, while the French contract for January added 9.5% to a record 700.60 euros. Prices also gained, under Europe’s marginal pricing system, as gas jumped after shipments from Russia via a key pipeline reversed direction, flowing eastward toward Poland instead.

Neighboring countries are boosting their exports to France this week to cover for lost nuclear output, with imports from Germany rising to highest level in at least four years. In the U.K., four coal power units were operating on Tuesday with as much as 1.5 gigawatts of hourly output being sent across the channel. 

The power crisis is so severe that the French government has asked EDF to restart some nuclear reactors earlier than planned amid outage risks for nuclear-powered France. Ecology Minister Barbara Pompili said last weekend that, in addition to the early reactor restarts and past river-temperature limits, the country had contracts with some companies in which they agreed to cut production during peak demand hours in exchange for payments from the government.

Higher energy prices threaten to derail Europe’s economic recovery just as the coronavirus omicron variety is spreading. Trafigura Group’s Nyrstar will pause production at its zinc smelter in France in the first week of January because of rising electricity prices. Norwegian fertilizer producer Yara International, which curbed output earlier this year, said it would continue to monitor the situation closely and curtail production where necessary.

Freezing weather this week is also sending short-term power prices surging as renewables can’t keep up, even though wind and solar overtook gas in the EU last year. German wind output plunged to a five-week low on Tuesday.

 

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Warren Buffett-linked company to build $200M wind power farm in Alberta

Rattlesnake Ridge Wind Project delivers 117.6 MW in southeast Alberta for BHE Canada, a Berkshire Hathaway Energy subsidiary, using 28 turbines near Medicine Hat under a long-term PPA, supplying renewable power to 79,000 homes.

 

Key Points

A 117.6 MW Alberta wind farm by BHE Canada supplying 79,000 homes via 28 turbines and a long-term PPA.

✅ 28 turbines near Medicine Hat, 117.6 MW capacity

✅ Long-term PPA with a major Canadian corporate buyer

✅ Developed with RES; no subsidies; competitive pricing

 

A company linked to U.S. investor Warren Buffett says it will break ground on a $200-million, 117.6-megawatt wind farm in southeastern Alberta next year.

In a release, Calgary-based BHE Canada, a subsidiary of Buffett's Berkshire Hathaway Energy, says its Rattlesnake Ridge Wind project will be located southwest of Medicine Hat and will produce enough energy to supply the equivalent of 79,000 homes.

"We felt that it was time to make an investment here in Alberta," said Bill Christensen, vice-president of corporate development for BHE Canada, in an interview with the Calgary Eyeopener.

"The structure of the markets here in Alberta, including frameworks for selling renewable energy, make it so that we can invest, and do it at a profit that works for us, and at a price that works for the off-taker," Christensen explained.

Berkshire Hathaway Energy also owns AltaLink, the regulated transmission company that supplies electricity to more than 85 per cent of the Alberta population.

BHE Canada says an unnamed large Canadian corporate partner has signed a long-term power purchase agreement, similar to RBC's solar purchase arrangements, for the majority of the energy output generated by the 28 turbines at Rattlesnake Ridge.

"If you look at just the raw power price that power is going for in Alberta right now, it's averaged around $55 a megawatt hour, or 5.5 cents a kilowatt hour. And we're selling the wind power to this customer at substantially less than that, reflecting wind power's competitiveness in the market, and there's been no subsidies," Christensen said.

 

Positive energy outlook

Christensen said he sees a good future for Alberta's renewable energy industry, not just in wind but also in solar power growth, particularly in the southeast of the province.

But he says BHE Canada is interested in making investments in traditional energy in Alberta, too, as the province is a powerhouse for both green energy and fossil fuels overall.

"It's not a choice of one or the other. I think there is still opportunity to make investments in oil and gas," he said.

"We're really excited about having this project and hope to be able to make other investments here in Alberta to help support the economy here, amid a broader renewable energy surge across the province."

The project is being developed by U.K.-based Renewable Energy Systems, part of a trend where more energy sources make better projects for developers, which is building two other Alberta wind projects totalling 134.6 MW this year and has 750 MW of renewable energy installed or currently under construction in Canada.

BHE Canada and RES are also looking for power purchase partners for the proposed Forty Mile Wind Farm in southeastern Alberta. They say that with generation capacity of 398.5 MW, it could end up being the largest wind power project in Canada.

 

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How vehicle-to-building charging can save costs, reduce GHGs and help balance the grid: study

Ontario EV Battery Storage ROI leverages V2B, V2G, two-way charging, demand response, and second-life batteries to monetize peak pricing, cut GHG emissions, and unlock up to $38,000 in lifetime value for commuters and buildings.

 

Key Points

The economic return from V2B/V2G two-way charging and second-life storage using EV batteries within Ontario's grid.

✅ Monetize peak pricing via workplace V2B discharging

✅ Earn up to $8,400 per EV over vehicle life

✅ Reduce gas generation and GHGs with demand response

 

The payback that usually comes to mind when people buy an electric vehicle is to drive an emissions-free, low-maintenance, better-performing mode of transportation.

On top of that, you can now add $38,000.

That, according to a new report from Ontario electric vehicle education and advocacy nonprofit, Plug‘n Drive, is the potential lifetime return for an electric car driven as a commuter vehicle while also being used as an electricity storage option amid an energy storage crunch in Ontario’s electricity system.

“EVs contain large batteries that store electric energy,” says the report. “Besides driving the car, [those] batteries have two other potentially useful applications: mobile storage via vehicle-to-grid while they are installed in the vehicle, and second-life storage after the vehicle batteries are retired.”

Pricing and demand differentials
The study, prepared by the research firm Strategic Policy Economics, modeled a two-stage scenario calculating the total benefits from both mobile and second-life storage when taking advantage of differences in daytime and nighttime electricity pricing and demand.


If done systematically and at scale, the combined benefits to EV owners, building operators and the electricity system in Ontario could reach $129 million per year by 2035, according to the report. Along with the financial gains, the province would also cut GHG emissions by up to 67.2 kilotons annually.

The math might sound complicated, but the concepts are simple. All it requires is for drivers to charge their batteries with low-cost electricity overnight at home, then plug them into two-way EV charging stations at work and discharge their stored electricity for use by the building by day when buying power from the grid is more expensive.

“Workplace buildings could avoid high daytime prices by purchasing electricity from EVs parked onsite and enjoy savings as a result,” says the report.

Based on average commuting distances, EVs in this scenario could make half their storage capacity available for discharge. Drivers would be paid out of the building’s savings, effectively selling electricity back to the grid and earning up to $8,400 over the life of their vehicle.

According to the report, Ontario could have as many as 18,555 vehicles participating in mobile storage by 2030. At this level, the daily electricity demand would be reduced by 565 MWh. This, in turn, would reduce demand for natural gas-fired electricity generation, a fossil-fuel electricity source, avoiding the expense of gas purchases while reducing GHG emissions.

The second-life storage opportunity begins when the vehicle lifespan ends. “EV batteries will still have over 80% of their storage capacity after being driven for 13 years and providing mobile storage,” the report states. “Those-second life batteries could provide a low-cost energy storage solution for the electricity grid and enhance grid stability over time.”

Some of the savings could be shared with EV owners in the form of a rebate worth up to 20 per cent of the batteries’ initial cost.

Call to action
The report concludes with a call to action for EV advocates to press policy makers and other stakeholders to take actions on building codes, the federal Clean Fuel Standard and other business models in order to maximize the benefits of using EV batteries for the electricity system in this way, even as growing adoption could challenge power grids in some regions.

“EVs are often approached as an environmental solution to climate change,” says Cara Clairman, Plug’n Drive president and CEO. “While this is true, there are significant economic opportunities that are often overlooked.”

 

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Energy Security Support to Ukraine

U.S. Energy Aid to Ukraine delivers emergency electricity grid equipment, generators, transformers, and circuit breakers, supports ENTSO-E integration, strengthens energy security, and advances decarbonization to restore power and heat amid Russian attacks.

 

Key Points

U.S. funding and equipment stabilize Ukraine's power grid, strengthen energy security, and advance ENTSO-E integration.

✅ $53M for transformers, breakers, surge arresters, disconnectors

✅ $55M for generators and emergency heat to municipalities

✅ ENTSO-E integration, cybersecurity, nuclear safety support

 

In the midst of Russia’s continued brutal attacks against Ukraine’s energy infrastructure, Secretary of State Blinken announced today during a meeting of the G7+ on the margins of the NATO Ministerial in Bucharest that the United States government is providing over $53 million to support acquisition of critical electricity grid equipment. This equipment will be rapidly delivered to Ukraine on an emergency basis to help Ukrainians persevere through the winter, as the country prepares for winter amid energy challenges. This supply package will include distribution transformers, circuit breakers, surge arresters, disconnectors, vehicles and other key equipment.

This new assistance is in addition to $55 million in emergency energy sector support for generators and other equipment to help restore emergency power and heat to local municipalities impacted by Russia’s attacks on Ukraine’s power system, while both sides accuse each other of energy ceasefire violations that complicate repairs. We will continue to identify additional support with allies and partners, and we are also helping to devise long-term solutions for grid restoration and repair, along with our assistance for Ukraine’s effort to advance the energy transition and build an energy system decoupled from Russian energy.

Since Russia’s further invasion on February 24, working together with Congress, the Administration has provided nearly $32 billion in assistance to Ukraine, including $145 million to help repair, maintain, and strengthen Ukraine’s power sector in the face of continued attacks. We also have provided assistance in areas such as EU integration and regional electricity trade, including electricity imports to stabilize supply, natural gas sector support to maximize resource development, support for nuclear safety and security, and humanitarian relief efforts to help Ukrainians to overcome the impacts of energy shortages.

Since 2014, the United States has provided over $160 million in technical support to strengthen Ukraine’s energy security, including to strengthen EU interconnectivity, increase energy supply diversification, and promote investments in energy efficiency, renewable energy, and clean energy technologies and innovation.  Much of this support has helped prepare Ukraine for its eventual interconnection with Europe’s ENTSO-E electricity grid, aligning with plans to synchronize with ENTSO-E across the integrated power system, including the island mode test in February 2022 that not only demonstrated Ukraine’s progress in meeting the EU’s technical requirements, but also proved to be critical considering Russia’s subsequent military activity aimed at disrupting power supplies and distribution in Ukraine.

 

Department of Energy (DOE)

  • With the increased attacks on Ukraine’s electricity grid and energy infrastructure in October, DOE worked with the Ukrainian Ministry of Energy and DOE national laboratories to collate, vet, and help prioritize lists of emergency electricity equipment for grid repair and stabilization amid wider global energy instability affecting supply chains.
  • Engaged at the CEO level U.S. private sector and public utilities and equipment manufacturers to identify $35 million of available electricity grid equipment in the United States compatible with the Ukrainian system for emergency delivery. Identified $17.5 million to support purchase and transportation of this equipment.
  • With support from Congress, initiated work on full integration of Ukraine with ENTSO-E to support resumption of Ukrainian energy exports to other European countries in the region, including funding for energy infrastructure analysis, collection of satellite data and analysis for system mapping, and work on cyber security, drawing on the U.S. rural energy security program to inform best practices.
  • Initiated work on a new dynamic model of interdependent gas and power systems of Europe and Ukraine to advance identification and mitigation of critical vulnerabilities.
  • Delivered emergency diesel fuel and other critical materials needed for safe operation of Ukrainian nuclear power plants, as well as initiated the purchase of three truck-mounted emergency diesel backup generators to be delivered to improve plant safety in the event of the loss of offsite power.

U.S. Department of State

  • Building on eight years of technical engagement, the State Department continued to provide technical support to Naftogaz and UkrGasVydobuvannya to advance corporate governance reform, increase domestic gas production, provide strategic planning, and assess critical sub-surface and above-ground technical issues that impact the company’s core business functions.
  • The State Department is developing new programs focused on emissions abatement, decarbonization, and diversification, acknowledging the national security benefits of reducing reliance on fossil fuels to support Ukraine’s ambitious clean energy and climate goals and address the impacts of reduced supplies of natural gas from Russia.
  • The State Department led a decades-long U.S. government engagement to develop and expand natural gas reverse flow (west-to-east) routes to enhance European and Ukrainian energy security. Ukraine is now able to import natural gas from Europe, eliminating the need for Ukraine to purchase natural gas from Gazprom.

 

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Germany turns to coal for a third of its electricity

Germany's Coal Reliance reflects an energy crisis, soaring natural gas prices, and a nuclear phase-out, as Destatis data show higher coal-fired electricity despite growing wind and solar generation, impacting grid stability and emissions.

 

Key Points

Germany's coal reliance is more coal power due to gas spikes and a nuclear phase-out, despite wind and solar growth.

✅ Coal share near one-third of electricity, per Destatis

✅ Gas-fired output falls as prices soar after Russia's invasion

✅ Wind and solar rise; grid stability and recession risks persist

 

Germany is relying on highly-polluting coal for almost a third of its electricity, as the impact of government policies, reflecting an energy balancing act for the power sector, and the war in Ukraine leads producers in Europe’s largest economy to use less gas and nuclear energy.

In the first six months of the year, Germany generated 82.6 kWh of electricity from coal, up 17 per cent from the same period last year, according to data from Destatis, the national statistics office, published on Wednesday. The leap means almost one-third of German electricity generation now comes from coal-fired plants, up from 27 per cent last year. Production from natural gas, which has tripled in price to €235 per megawatt hour since Russia’s invasion in late February, fell 18 per cent to only 11.7 per cent of total generation.

Destatis said that the shift from gas to coal was sharper in the second quarter. Coal-fired electricity increased by an annual rate of 23 per cent in the three months to June, while electricity generation from natural gas fell 19 per cent.

The figures highlight the challenge facing European governments in meeting clean energy goals after the Kremlin announced this week that the Nordstream 1 pipeline that takes Russian gas to Germany would remain closed until Europe removed sanctions on the country’s oil.

Germany has been trying to reduce its reliance on coal, which releases almost twice as many emissions as gas and more than 60 times those of nuclear energy, according to estimates from the Intergovernmental Panel on Climate Change, though grid expansion challenges have slowed renewable build-out in recent years.

Chancellor Olaf Scholz said the opposition CDU bore “complete responsibility” for the exit from coal and nuclear power that formed part of his predecessor Angela Merkel’s Energiewende policies, amid a continuing nuclear option debate in climate policy, which in turn raised reliance on Russian gas. At the beginning of this year, more than 50 per cent of Germany’s gas imports came from Russia, a figure that fell slightly over the opening half of 2022.

But CDU leader Friedrich Merz accused the government of “madness” over its decision to idle the country’s three remaining nuclear power stations from the end of this year, though officials have argued that nuclear would do little to solve the gas issue in the short term.

Electricity generation from nuclear energy has already halved after three of the six nuclear power plants that were still in operation at the end of 2021 were closed during the first half of this year. Berlin said on Monday it would keep on standby two of its remaining three nuclear power stations, a move to extend nuclear power during the energy crisis, which were all due to close at the end of the year.

The German government has warned of the risk of electricity shortages this winter. “We cannot be sure that, in the event of grid bottlenecks in neighbouring countries, there will be enough power plants available to help stabilise our electricity grid in the short term,” said German economy minister Robert Habeck on Monday.

However Scholz said that, after raising gas storage levels to 86 per cent of capacity, Germany would “probably get through this winter, despite all the tension”.

One bright spot from the data was the increase in use of renewable energy, highlighting a recent renewables milestone in Germany. The proportion of electricity generated from wind power generation rose by 18 per cent to 25 per cent of all electricity generation, while solar energy production increased 20 per cent.

Ángel Talavera, head of Europe economics at the consultancy Oxford Economics, said that the success in moving away from gas towards other energy sources “means that the risks of hard energy rationing over the winter are less severe now, even with little to no Russian gas flows”.

However, economists still expect a recession in the eurozone’s largest economy, amid a deteriorating German economy outlook over the near term, as a large part of the impact comes via higher prices and because industries and households still rely on gas for heating.

Separate official data also published on Wednesday showed that German industrial production slid 0.3 per cent between June and July. Production at Germany’s most energy intensive industries fell almost 7 per cent in the five months after Russia’s invasion of Ukraine.

“The demand destruction caused by the surge in prices will still send the German economy into recession over the winter,” said Talavera.

 

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Court reinstates constitutional challenge to Ontario's hefty ‘global adjustment’ electricity charge

Ontario Global Adjustment Charge faces constitutional scrutiny as a regulatory charge vs tax; Court of Appeal revives case over electricity pricing, feed-in tariff contracts, IESO policy, and hydro rate impacts on consumers and industry.

 

Key Points

A provincial electricity fee funding generator contracts, now central to a court fight over tax versus regulatory charge.

✅ Funds gap between market price and contracted generator rates

✅ At issue: regulatory charge vs tax under constitutional law

✅ Linked to feed-in tariff, IESO policy, and hydro rate hikes

 

Ontario’s court of appeal has decided that a constitutional challenge of a steep provincial electricity charge should get its day in court, overturning a lower-court judgment that had dismissed the legal bid.

Hamilton, Ont.-based National Steel Car Ltd. launched the challenge in 2017, saying Ontario’s so-called global adjustment charge was unconstitutional because it is a tax — not a valid regulatory charge — that was not passed by the legislature.

The global adjustment funds the difference between the province’s hourly electricity price and the price guaranteed under contracts to power generators. It is “the component that covers the cost of building new electricity infrastructure in the province, maintaining existing resources, as well as providing conservation and demand management programs,” the province’s Independent Electricity System Operator says.

However, the global adjustment now makes up most of the commodity portion of a household electricity bill, and its costs have ballooned, as regulators elsewhere consider a proposed 14% rate hike in Nova Scotia.

Ontario’s auditor general said in 2015 that global adjustment fees had increased from $650 million in 2006 to more than $7 billion in 2014. She added that consumers would pay $133 billion in global adjustment fees from 2015 to 2032, after having already paid $37 billion from 2006 to 2014.

National Steel Car, which manufactures steel rail cars and faces high electricity rates that hurt Ontario factories, said its global adjustment costs went from $207,260 in 2008 to almost $3.4 million in 2016, according to an Ontario Court of Appeal decision released on Wednesday.

The company claimed the global adjustment was a tax because one of its components funds electricity procurement contracts under a “feed-in tariff” program, or FIT, which National Steel Car called “the main culprit behind the dramatic price increases for electricity,” the decision said.

Ontario’s auditor general said the FIT program “paid excessive prices to renewable energy generators.” The program has been ended, but contracts awarded under it remain in place.


National Steel Car claimed the FIT program “was actually designed to accomplish social goals unrelated to the generation of electricity,” such as helping rural and indigenous communities, and was therefore a tax trying to help with policy goals.

“The appellant submits that the Policy Goals can be achieved by Ontario in several ways, just not through the electricity pricing formula,” the decision said.

National Steel Car also argued the global adjustment violated a provincial law that requires the government to hold a referendum for new taxes.

“The appellant’s principal claim is that the Global Adjustment was a ‘colourable attempt to disguise a tax as a regulatory charge with the purpose of funding the costs of the Policy Goals,’” the decision said. “The appellant pressed this argument before the motion judge and before this court. The motion judge did not directly or adequately address it.”

The Ontario government applied to have the challenge thrown out for having “no reasonable cause of action,” and a Superior Court judge did so in 2018, saying the global adjustment is not a tax.

National Steel Car appealed the decision, and the decision published Wednesday allowed the appeal, set aside the lower-court judgment, and will send the case back to Superior Court, where it could get a full hearing.

“The appellant’s claim is sufficiently plausible on the evidentiary record it put forward that the applications should not have been dismissed on a pleadings motion before the development of a full record,” wrote Justice Peter D. Lauwers. “It is not plain, obvious and beyond doubt that the Global Adjustment, and particularly the challenged component, is properly characterized as a valid regulatory charge and not as an impermissible tax.”

Jerome Morse of Morse Shannon LLP, one of National Steel Car’s lawyers, said the Ontario government would now have 60 days to decide whether to seek permission to appeal to the Supreme Court of Canada.

“What the court has basically said is, ‘this is a plausible argument, here are the reasons why it’s plausible, there was no answer to this,’” Morse told the Financial Post.

Ontario and the IESO had supported the lower-court decision, but there has been a change in government since the challenge was first launched, with Progressive Conservative Premier Doug Ford replacing the Liberals and Kathleen Wynne in power. The Liberals had launched a plan aimed at addressing hydro costs before losing in a 2018 election, the main thrust of which had been to refinance global adjustment costs.

Wednesday’s decision states that “Ontario’s counsel advised the court that the current Ontario government ‘does not agree with the former government’s electricity procurement policy (since-repealed).’

“The government’s view is that: ‘The solution does not lie with the courts, but instead in the political arena with political actors,’” it adds.

A spokesperson for Ontario Energy Minister Greg Rickford said in an email that they are reviewing the decision but “as this matter is in the appeal period, it would be inappropriate to comment.” 

Ontario had also requested to stay the matter so a regulator, the Ontario Energy Board, could weigh in, while the Nova Scotia regulator approved a 14% hike in a separate case.

“However, Ontario only sought this relief from the motion judge in the alternative, and given the motion judge’s ultimate decision, she did not rule on the stay,” Thursday’s decision said. “It would be premature for this court to rule on the issue, although it seems incongruous for Ontario to argue that the Superior Court is the convenient forum in which to seek to dismiss the applications as meritless, but that it is not the convenient forum for assessing the merits of the applications.”

National Steel Car’s challenge bears a resemblance to the constitutional challenges launched by Ontario and other provinces over the federal government’s carbon tax, but Justice Lauwers wrote “that the federal legislative scheme under consideration in those cases is distinctly different from the legislation at issue in this appeal.”

“Nothing in those decisions impacts this appeal,” the judge added.
 

 

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