Report foresees carbon tax on polluting countries

By Toronto Star


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Countries such as Canada and the United States may impose a "carbon tariff" on goods from China and other developing countries in the next few years, a move that could bring manufacturing jobs back to North America, CIBC World Markets predicts.

The investment bank's report says the economies of China, India and other developing countries have expanded so much that they now surpass the established industrialized world in belching out carbon dioxide pollution blamed for climate change.

"It becomes absurdly quixotic to ban coal plants in North America while at the same time China's got 570 coal plants slated to go into production between now and 2012, 30 plants between now and the Olympics," CIBC economist Jeff Rubin said.

"We're moving in opposite directions."

With some advanced countries enacting carbon taxes, carbon trading systems and other measures to lower emissions, CIBC believes the growing pollution from developing countries will provoke penalties against their exports.

That would benefit the environment, and will also bring certain jobs back to North America, since carbon emission taxes and high oil prices would offset the benefit of cheap labour, Rubin says.

"Chinese goods will have to pay for the carbon that they emitted and they'll pay for that when they enter our market place by paying that tariff," Rubin said in an interview.

"Once we impose the tariff on Chinese goods, some of those industries will be coming home, because... energy and carbon efficiency is going to matter more than labour costs."

Non-metallic mineral products – cement, glass and lime – with energy intensity 130 per cent higher than the Chinese industrial average, are likely to return to North America, as well as the printing, primary metal manufacturing and machinery industries.

Rubin believes the tariff, based on $45 per tonne of carbon dioxide or equivalent, would raise roughly $55 billion a year from Chinese exports to the United States, and raise U.S. consumer price inflation by more than 0.6 percentage points.

Many in the West assumed that since industrialized nations were primarily responsible for the historical build-up of greenhouse gases in the world, they should bear the brunt of efforts to cut back, a view that underpinned the Kyoto Protocol in 1997, which exempted developing countries.

But Rubin sees a shift in sentiment.

"What I'm suggesting is that the minute that we start putting a price on our own domestic emissions, then our tolerance of those who do not is going to fade very quickly," he said.

"What we're going to say is that if you don't play by the same carbon rules, that's an unfair trade subsidy that we're gong to countervail against."

British Columbia became the first jurisdiction in North America to introduce a carbon tax on consumers in February, when the provincial government announced that starting July 1, it will introduce an escalating carbon tax of $10 per tonne of carbon or about 2.4 cents on a litre of gasoline.

The tax will be applied to most fossil fuels such as gasoline, diesel, coal, propane, natural gas and home heating fuel. The levy will rise to $30 per tonne of carbon – about 7.2 cents on a litre of gasoline – by 2012.

But such taxes have yet to catch on in the rest of the country. Federal Environment Minister John Baird said earlier this month the Conservatives would continue with regulations targeting big polluters to control carbon emissions rather than taxes.

Alberta, by far the largest greenhouse gas emitter in Canada, opposes a carbon tax, and both Ontario and Manitoba have said they won't consider it. Quebec, for its part, introduced a form of carbon tax last year that directs revenues to initiatives supporting green technology.

Europe, which is well ahead of North America in terms of domestic carbon pricing, is already talking about a carbon tariff that it can apply to imports from countries that don't play by the same carbon rules, the CIBC report said, adding that concept is likely to gain currency in the U.S. and Canada.

"We're going to be following the Europeans," Rubin said.

"It doesn't matter who wins the White House after the next election, both (Republican nominee John) McCain, (Democratic contenders Barack) Obama and (Hillary) Clinton are all on record for cap-and-trade, and putting a price on carbon emissions on the U.S. economy.

"When that happens, you can rest assured that we'll follow suit here in Canada."

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Electricity exports to New York from Quebec will happen as early as 2025: Hydro-Quebec

Hertel-New York Interconnection delivers Hydro-Quebec renewable energy via a cross-border transmission line to New York City by 2025, supplying 1,250 MW through underground and underwater routes under a 25-year contract.

 

Key Points

A cross-border line delivering 1,250 MW of Hydro-Quebec hydropower to New York City via underground routes.

✅ 1,250 MW clean power to NYC by 2025

✅ 56.1 km underground, 1.6 km underwater in Quebec

✅ 25-year contract; Mohawk partnership revenue

 

Hydro-Quebec announced Thursday it has chosen the route for the Hertel-New York interconnection line, which will begin construction in the spring of 2023 in Quebec.

The project will deliver 1,250 megawatts of Quebec hydroelectricity to New York City starting in 2025, even as a recent electricity shortage report warns about rising demand at home.

It's a 25-year contract for Hydro-Quebec, the largest export contract for the province-owned company, and comes as hydrogen production investments gain traction in Eastern Canada.

The Crown corporation has not disclosed potential revenues from the project, but Premier François Legault mentioned on social media last September that a deal in principle worth more than $20 billion over 25 years was in the works.

The route includes a 56.1-kilometre underground and a 1.6-kilometre underwater section, similar to the Lake Erie Connector project planned under Lake Erie.

Eight municipalities in the Montérégie region will be affected: La Prairie, Saint-Philippe, Saint-Jacques-le-Mineur, Saint-Édouard, Saint-Patrice-de-Sherrington, Saint-Cyprien-de-Napierville, Saint-Bernard-de-Lacolle and Lacolle.

Across the country, new renewables such as wind projects in Yukon are receiving federal support, reflecting broader grid decarbonization.

The last part of the route will run along Fairbanks Creek to the Richelieu River, where it will connect with the American network.

Further south, there will be a 545-kilometre link between the Canada-U.S. border and New York City, while a separate Maine transmission approval advances a New England pathway for Quebec power.

Hydro-Quebec is holding two consultations on the project, on Dec. 8 in Lacolle and Dec. 9 in Saint-Jacques-le-Mineur.

Elsewhere in Atlantic Canada, EV-to-grid integration pilots are underway to test how vehicles can support the power system.

Once the route is in service, the Quebec line will be subject to a partnership between Hydro-Quebec and the Mohawk Council of Kahnawake, which will benefit from economic remunerations for 40 years.

To enhance reliability, grid-scale battery storage projects are also expanding in Ontario.

 

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Tornadoes and More: What Spring Can Bring to the Power Grid

Spring Storm Grid Risks highlight tornado outbreaks, flooding, power outages, and transmission disruptions, with NOAA flood outlooks, coal and barge delays, vulnerable nuclear sites, and distribution line damage demanding resilience, reliability, and emergency preparedness.

 

Key Points

Spring Storm Grid Risks show how tornadoes and floods disrupt power systems, fuel transport, and plants guide resilience.

✅ Tornado outbreaks and derechos damage distribution and transmission

✅ Flooding drives outages via treefall, substation and plant inundation

✅ Fuel logistics disrupted: rail coal, river barges, road access

 

The storm and tornado outbreak that recently barreled through the US Midwest, South and Mid-Atlantic was a devastating reminder of how much danger spring can deliver, despite it being the “milder” season compared to summer and winter.  

Danger season is approaching, and the country is starting to see the impacts. 

The event killed at least 32 people across seven states. The National Weather Service is still tallying up the number of confirmed tornadoes, which has already passed 100. Communities coping with tragedy are assessing the damage, which so far includes at least 72 destroyed homes in one Tennessee county alone, and dozens more homes elsewhere. 

On Saturday, April 1–the day after the storm struck–there were 1.1 million US utility customers without power, even as EIA reported a January power generation surge earlier in the year. On Monday morning, April 3, there were still more than 80,000 customers in the dark, according to PowerOutage.us. The storm system brought disruptions to both distribution grids–those networks of local power lines you generally see running overhead to buildings–as well as the larger transmission grid in the Midwest, which is far less common than distribution-level issues. 

While we don’t yet have a lot of granular details about this latest storm’s grid impacts, recent shifts in demand like New York City's pandemic power patterns show how operating conditions evolve, and it’s worth going through what else the country might be in for this spring, as well as in future springs. Moreover, there are steps policymakers can take to prepare for these spring weather phenomena and bolster the reliability and resilience of the US power system. 

Heightened flood risk 
The National Oceanic Atmospheric Administration (NOAA) said in a recent outlook that about 44 percent of the United States is at risk of floods this spring, equating to about 146 million people. This includes most of the eastern half of the country, the federal agency said. 

The agency also sees “major” flood risk potential in some parts of the Upper Mississippi River Basin, and relatively higher risk in the Sierra Nevada region, due in part to a historic snowpack in California.  

Multiple components of the power system can be affected by spring floods. 

Power lines – Floods can saturate soil and make trees more likely to uproot and fall onto power lines. This has been contributing to power outages during California’s recent heavy storms–called atmospheric rivers–that started over the winter. In other regions, soil moisture has even been used as a predictor of where power outages will occur due to hurricanes, so that utility companies are better prepared to send line repair crews to the right areas. Hurricanes are primarily a summer and fall phenomenon, and summer also brings grid stress from air conditioning demand in many states, so for now, during spring, they are less of a concern.  

Fuel transport – Spring floods can hinder the transportation of fuels like coal. While it is a heavily polluting fossil fuel that is set to continue declining as a fuel source for US electricity generation, with the EIA summer outlook for wind and solar pointing to further shifts, coal still accounted for roughly 20 percent of the country’s generation in 2022.   

About 70 percent of US coal is transported at least part of the way by trains. The rail infrastructure to transport coal from the Powder River Basin in Montana and Wyoming–the country’s primary coal source–was proven to be vulnerable to extreme floods in the spring of 2011, and even more extreme floods in the spring of 2019. The 2019 floods’ disruptions of coal shipments to power plants via rail persisted for months and into the summertime, also affecting river shipments of coal by barge. In June 2019, hundreds of barges were stalled in the Mississippi River, through which millions of tons of the fossil fuel are normally transported. 

Power plants – Power plants themselves can also be at risk of flooding, since most of them are sited near a source of water that is used to create steam to spin the plants’ turbines, and conversely, low water levels can constrain hydropower as seen in Western Canada hydropower drought during recent reservoir shortfalls. Most US fossil fuel generating capacity from sources like methane gas, which recently set natural gas power records across the grid, and coal utilizes steam to generate electricity. 

However, much of the attention paid to the flood risk of power plant sites has centered on nuclear plants, a key source of low-carbon electricity discussed in IAEA low-carbon electricity lessons that also require a water source for the creation of steam, as well as for keeping the plant cool in an emergency. To name a notable flood example here in the United States–both visually and substantively–in 2011, the Fort Calhoun nuclear plant in Nebraska was completely surrounded by water due to late-spring flooding along the Missouri River. This sparked a lot of concerns because it was just a few months after the March 2011 meltdown of the Fukushima Daiichi nuclear plant in Japan. The public was thankfully not harmed by the Nebraska incident, but this was unfortunately not an isolated incident in terms of flood risks posed to the US nuclear power fleet. 

 

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US Automakers Will Build 30,000 Electric Vehicle Chargers

Automaker EV Fast-Charging Network will deploy 30,000 DC fast chargers across US and Canada, supporting CCS and NACS, integrating Tesla compatibility, easing range anxiety, and expanding highway and urban charging infrastructure with amenities and uptime.

 

Key Points

A $1B joint venture by seven automakers to build 30,000 DC fast chargers with CCS and NACS across the US and Canada.

✅ 30,000 DC fast chargers by 2030 across US and Canada

✅ Supports CCS and NACS; Tesla compatibility planned

✅ Launching mid-2024; focus on highways, urban hubs, amenities

 

Seven major automakers announced a plan on Wednesday to nearly double the number of fast chargers in the United States in an effort to address one of the main reasons that people hesitate to buy electric cars, even as the age of electric cars accelerates.

The carmakers — BMW Group, General Motors, Honda, Hyundai, Kia, Mercedes-Benz Group and Stellantis — will initially invest at least $1 billion in a joint venture that will build 30,000 charging ports on major highways and other locations in the United States and Canada.

The United States and Canada have about 36,000 fast chargers — those that can replenish a drained battery in 30 minutes or less. In some sparsely populated areas, such chargers can be hundreds of miles apart. Surveys show that fear about not being able to find a charger during longer journeys is a major reason that some car buyers are reluctant to buy electric vehicles.

Sales of electric vehicles have risen quickly in the United States as the market hits an inflection point, but there are signs that demand is softening. As a result, Tesla, Ford and other carmakers have cut prices in recent months and are offering incentives. Popular models that had long waiting lists last year are now available in a few days or weeks.

Major carmakers are investing billions of dollars to manufacture electric vehicles and batteries and to establish supplier networks. Having staked their futures on the technology, they have a strong incentive to ensure that electric vehicles catch on with car buyers, even as gas-electric hybrids help bridge the transition.

The chargers installed by the joint venture will have plugs designed for the connections used by most carmakers other than Tesla, as well as the standard developed by Tesla, amid fights for control over charging, that Ford, G.M. and other companies have said they intend to switch to in 2025.

“The better experience people have, the faster E.V. adoption will grow,” Mary T. Barra, the chief executive of General Motors, said in a statement.

The seven automakers plan to formalize the joint venture and announce its name by the end of the year, Chris Martin, a Honda spokesman, said. The first chargers will begin operating around the middle of 2024, he said, with all 30,000 in place by the end of the decade.

The joint venture is open to adding other partners, he said. Among major automakers, Ford was a notable absence from the announcement on Wednesday. The company said in a statement on Wednesday that it would continue to iThe partnership also does not include Volkswagen. The company is a majority shareholder of Electrify America, one of the largest fast-charging providers.

Tesla accounts for more than half the fast chargers in the United States and has said it will open its networks to other car brands, though, so far, it has only made fewer than 100 ports available. Owners of Ford and G.M. vehicles, among others, will be able to connect to 12,000 Tesla fast chargers using an adapter beginning next year. In 2025, Ford and G.M. plan to make models designed to take the Tesla plug without an adapter.

The decision by the seven carmakers to form the joint venture is an indication that they do not intend to rely solely on Tesla, which dominates sales of electric vehicles, for charging.

The chargers being built by the joint venture will be concentrated in urban areas and along major highways, especially those used most heavily by vacationers and other travelers, the companies said in a joint statement. Charging stations will be close to restrooms, restaurants and other amenities. The partners said they would try to take advantage of federal and state funds available for charging infrastructure amid questions about whether the U.S. has the power to charge it at scale.

Most electric vehicle owners charge at home and rarely need to use public chargers. Home chargers typically replenish batteries overnight. Most public chargers, about 125,000 in the United States and Canada, also operate relatively slowly — taking four to 10 hours to do the job.nvest in its own network, which allows Ford owners to charge from a variety of providers with one mobile phone app.

 

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Hydro wants B.C. residents to pay an extra $2 a month for electricity

BC Hydro Rate Increase proposes a 2.3% hike from April, with BCUC review, aligning below inflation and funding clean energy, electrification, and grid upgrades across British Columbia while keeping electricity prices among North America's lowest.

 

Key Points

A proposed 2.3% BC Hydro hike from April, under BCUC review, funds clean energy and keeps average bills below inflation.

✅ Adds about $2 per month to average residential bill

✅ Sixth straight increase below inflation since 2018

✅ Supports renewable projects and grid modernization

 

The British Columbia government says the province’s Crown power utility is applying for a 2.3-per-cent rate increase starting in April, with higher BC Hydro rates previously outlined, adding about $2 a month to the average residential bill.

A statement from the Energy Ministry says it’s the sixth year in a row that BC Hydro has applied for an increase below the rate of inflation, similar to a 3 per cent rise noted in a separate approval, which still trailed inflation.

It says rates are currently 15.6 per cent lower than the cumulative rate of inflation over the last seven years, starting in 2017-2018, with a provincial rate freeze among past measures, and 12.4 per cent lower than the 10-year rates plan established by the previous government in 2013.

The ministry says the “modest” rate increase application comes after consideration of a variety of options and their long-term impacts, including scenarios like a 3.75% two-year path evaluated alongside others, and the B.C. Utilities Commission is expected to decide on the plan by the end of February.

Chris O’Riley, president of BC Hydro, says the rates application would keep electricity costs in the province among the lowest in North America, even as a BC Hydro fund surplus prompted calls for changes, while supporting investments in clean energy to power vehicles, homes and businesses.

Energy Minister Josie Osborne says it’s more important than ever to keep electricity bills down, especially as Ontario hydro rates increase in a separate jurisdiction, as the cost of living rises at rates that are unsustainable for many.

“Affordable, stable BC Hydro rates are good for people, businesses and climate as we work together to power our growing economy with renewable energy instead of fossil fuels,” Osborne says in a statement issued Monday.

Earlier this year, the ministry said BC Hydro provided $315 million in cost-of-living bill credits, while in another province Manitoba Hydro scaled back an increase to ease pressure, to families and small businesses in the province, including those who receive their electricity service from FortisBC or a municipal utility.

 

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Ontario prepares to extend disconnect moratoriums for residential electricity customers

Ontario Electricity Relief outlines an extended disconnect moratorium, potential time-of-use price changes, and Ontario Energy Board oversight to support residential customers facing COVID-19 hardship and bill payment challenges during the emergency in Ontario.

 

Key Points

Plan to extend disconnect moratorium and weigh time-of-use price relief for residential customers during COVID-19.

✅ Extends winter disconnect ban by 3 months

✅ Considers time-of-use price adjustments

✅ Requires Ontario Energy Board approval

 

The Ontario government is preparing to announce electricity relief for residential electricity users struggling because of the COVID-19 emergency, according to sources.

Sources close to those discussions say a decision has been made to lengthen the existing five-month disconnect moratorium by an additional three months.

Separately, Hydro One's relief fund has offered support to its customers during the pandemic.

News releases about the moratorium extension are currently being drafted and are expected to be released shortly, as the pandemic has reduced electricity usage across Ontario.

Electricity utilities in Ontario are currently prohibited from disconnecting residential customers for non-payment during the winter ban period from November 15 to April 30.

The province is also looking at providing further relief by adjusting time-of-use prices, such as off-peak electricity rates, which are designed to encourage shifting of energy use away from periods of high total consumption to periods of low demand.

For businesses, the province has provided stable electricity pricing to support industrial and commercial operations.

But that would require Ontario Energy Board approval and no decision has been finalized, our sources advise.

 

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In 2021, 40% Of The Electricity Produced In The United States Was Derived From Non-Fossil Fuel Sources

Renewable Electricity Generation is accelerating the shift from fossil fuels, as wind, solar, and hydro boost the electric power sector, lowering emissions and overtaking nuclear while displacing coal and natural gas in the U.S. grid.

 

Key Points

Renewable electricity generation is power from non-fossil sources like wind, solar, and hydro to cut emissions.

✅ Driven by wind, solar, and hydro adoption

✅ Reduces fossil fuel dependence and emissions

✅ Increasing share in the electric power sector

 

The transition to electric vehicles is largely driven by a need to reduce our reliance on fossil fuels and reduce emissions associated with burning fossil fuels, while declining US electricity use also shapes demand trends in the power sector. In 2021, 40% of the electricity produced by the electric power sector was derived from non-fossil fuel sources.

Since 2007, the increase in non-fossil fuel sources has been largely driven by “Other Renewables” which is predominantly wind and solar. This has resulted in renewables (including hydroelectric) overtaking nuclear power’s share of electricity generation in 2021 for the first time since 1984. An increasing share of electricity generation from renewables has also led to a declining share of electricity from fossil fuel sources like coal, natural gas, and petroleum, with renewables poised to eclipse coal globally as deployment accelerates.

Includes net generation of electricity from the electric power sector only, and monthly totals can fluctuate, as seen when January power generation jumped on a year-over-year basis.

Net generation of electricity is gross generation less the electrical energy consumed at the generating station(s) for station service or auxiliaries, and the projected mix of sources is sensitive to policies and natural gas prices over time. Electricity for pumping at pumped-storage plants is considered electricity for station service and is deducted from gross generation.

“Natural Gas” includes blast furnace gas and other manufactured and waste gases derived from fossil fuels, while in the UK wind generation exceeded coal for the first time in 2016.

“Other Renewables” includes wood, waste, geo-thermal, solar and wind resources among others.

“Other” category includes batteries, chemicals, hydrogen, pitch, purchased steam, sulfur, miscellaneous technologies, and, beginning in 2001, non-renewable waste (municipal solid waste from non-biogenic sources, and tire-derived fuels), noting that trends vary by country, with UK low-carbon generation stalling in 2019.

 

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