Greenpeace crashes coal meeting using phony front

Municipal Renewable Energy Procurement surged as cities contracted 3.7 GW of solar and wind, leveraging green tariffs, community solar, and utility partnerships across the Southeast, led by Houston, RMI, and WRI data.

Key Points

The process by which cities contract solar and wind via utilities or green tariffs to meet climate goals.

✅ 3.7 GW procured in 2020, nearly 25% year-over-year growth

✅ Houston runs city ops on 500 MW solar, a record purchase

✅ Southeast cities use green tariffs and community solar

Cities around the country bought more renewable energy last year than ever before, reflecting how renewables may soon provide one-fourth of U.S. electricity across the grid, with some of the most remarkable projects in the Southeast, according to new data unveiled Thursday.

Even amid the pandemic, about eight dozen municipalities contracted to buy nearly 3.7 gigawatts of mostly solar and wind energy — enough to power more than 800,000 homes. The figure is almost a quarter higher than the year before.

Half of the cites listed as “most noteworthy” in Thursday’s release —  from research groups Rocky Mountain Institute and World Resources Institute — are in the region that stretches from Texas to Washington, D.C. 

Houston stands out for the sheer enormity of its purchase: In July, it began powering city operations entirely from nearly 500 megawatts of solar power — the largest municipal purchase of renewable energy ever in the United States, as renewable electricity surpassed coal nationwide.

The groups also feature smaller deals in North Carolina and Tennessee, achieved through a utility partnership called a green tariff.

“We wanted to recognize that Nashville and Charlotte were really blazing a new trail,” said Stephen Abbott, principal at the Rocky Mountain Institute.

And the nation’s capital shows how renewable energy can be a source of revenue: It’s leasing out its public transit station rooftops for 10 megawatts of community solar.

All of these strategies will be necessary for scores of U.S. cities to meet their ambitious climate goals, researchers believe. An interactive clean energy targets tracker shows all 95 clean energy procurements from the year in detail.

Tracker 
Even before former President Donald Trump promised to remove the United States from the Paris Climate Accord, a lack of federal action on climate left a void that some cities and counties were beginning to fill, as renewables hit a record 28% in a recent month. In 2015, the first year tracked by researchers at the Rocky Mountain Institute and the World Resources Institute, municipalities contracted to buy more than 1 gigawatt of wind, solar and other forms of clean energy. 

But when Trump officially set in motion the withdrawal from the climate agreement, the ranks of municipalities dedicated to 100% clean energy multiplied. Today there are nearly 200 of them. The growth in activity last year reflects, in part, that surge of new pledges.

“It takes a while to get city staff up to speed and understand the options, and create the roadmap and then start executing,” Abbott said. “There is a bit of a lag, but we’re starting to see the impact.”

Even in Houston — one of the earliest to begin procuring renewable energy — there has been a steep learning curve as market forces change and prices drop, including cheaper solar batteries shaping procurement strategies, said Lara Cottingham, Houston’s chief of staff and chief sustainability officer.

No matter how well resourced and educated their staff, cities have to clear a thicket of structural, political and economic challenges to procure renewable energy. Most don’t own their own sources of power. Nearly all face budget constraints. Few have enough land or government rooftops to meet their goals within city limits.

“Cities face a situation where it’s a square peg in a round hole,” Cottingham said.

The hurdles are especially steep in much of the Southeast, where only publicly regulated utilities can sell electricity to retail customers, even large ones such as major cities. That’s where a green tariff regime comes in: Cities can purchase clean energy from a third party, such as a solar company, using the utility as a go-between.

Early last year, Charlotte became the largest city to use such a program, partnering with Duke Energy and two North Carolina solar developers to build a solar farm 50 miles north in Iredell County. At first, the city will pay a premium for the energy, but in the latter half of the 20-year contract, as gas prices rise, it will save money compared to business as usual.

“Over the course of 20 years, it’s projected we would save about $2 million,” Katie Riddle, sustainability analyst with Charlotte, told the Energy News Network last year.

The growing size of projects, innovative partnerships like green tariff programs, and the improving economics all give Abbott hope that renewable energy investments from cities will only grow — even with the Trump presidency over and the country back in the Paris agreement.

And when cities meet their goals for procuring renewable energy for their own operations, they must then turn to an even bigger task: reducing the carbon footprint of every person in their jurisdiction with broader decarbonization strategies and community engagement.

“The city needs to do its part for sure,” said Houston’s Cottingham. “Then we have this challenge of how do we get everyone else to.”

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Taltson Hydro Electric Heating directs surplus hydro power in the South Slave to space heat via discounted rates, displacing diesel and cutting greenhouse gas emissions, with rebates, separate metering, and backup systems shaping adoption.

Key Points

An initiative using Taltson's surplus hydro to heat buildings, discount rates replace diesel and cut emissions.

✅ 6.3 cents/kWh heating rate needs separate metering, backup heat

✅ 4-6 MW surplus hydro; outages require diesel; rebates available

✅ Program may be curtailed if new mines or mills demand power

A Northwest Territories green energy advocate says there's an obvious way to expand demand for electricity in the territory's South Slave region without relying on new mining developments — direct it toward heating.

One of the reasons the N.W.T. has always had some of the highest electricity rates in Canada is that a small number of people have to shoulder the huge costs of hydro facilities and power plants.

But some observers point out that residents consume as much energy for heat as they do for conventional uses of electricity, such as lighting and powering appliances. Right now almost all of that heat is generated by expensive oil imported from the United States.

The Northwest Territories Power Corporation says the 18-megawatt Taltson hydro system that serves the South Slave typically has four to six megawatts of excess generating capacity, even as record demand in Yukon is reported. It says using some of that to generate heat is a government priority.

But renewable energy advocate and former N.W.T. MP Dennis Bevington, who lives in the South Slave and heats his home using electricity, says the government is not making it easy for people to tap into that surplus to heat their homes and businesses, a debate that some say would benefit from independent planning at the national level.

Discount rate for heating, but there are catches
The power corporation offers hydro electricity from Taltson to use for heating at a much lower price than it charges for electricity generally. The discounted rate is not available to residential customers.

According to the corporation, consumers pay only 6.3 cents per kilowatt hour compared to the regular rate of just under 24 cents, while Manitoba Hydro financial pressures highlight the risks of expanding demand without new generation.

But to distinguish between the two, users are required to cover the cost of installing a separate power meter. Bevington, who developed the N.W.T.'s first energy strategy, says that is an unnecessary expense.

Taltson expansion key to reducing N.W.T.'s greenhouse gas emissions, says gov't
"The billing is how you control that," he said. "You establish an average electrical use in the winter months. That could be the base rate. Then, if you use power in the winter months above that, you get the discount."

Users are also required to have a back-up heating system. Taltson hydro power offers heating on the understanding that when the hydro system is down — such as during power outages or annual summer maintenance of the hydro system — electricity is not available for heating.
The president and CEO of the power corporation says there's a good reason for that. "The diesels are more expensive to run and they're actually greenhouse gas emitting," said Noel Voykin. "The whole idea of this [electric heat] program is to provide clean energy that is not otherwise being used."

According to the corporation, there have been huge savings for the few who have tapped into the hydro system to heat their buildings, and across Canada utilities are exploring novel generation such as NB Power's Belledune seawater project to diversify supply.

It's being used to heat Aurora College's Breynat Hall, and Joseph B. Tyrrell Elementary School and the transportation department garage in Fort Smith, N.W.T. Electricity is also used to heat the Jackfish power plant in the North Slave region.

The corporation says that during a four-year period, this saved more than 600,000 litres of diesel fuel and reduced greenhouse gas emissions by about 1,700 tonnes.

Bevington says the most obvious place to expand the use of electrical heat is to government housing.

"We have a hundred public housing units in Fort Smith," he said. "The government is putting diesel into those units [for heating] and they could be putting in their own electricity."

Heating a tiny part of energy market
The corporation says it sells only about 2.5 megawatts of electricity for heating each year, which is less than four per cent of the power it sells in the region. It says with some upgrades, another two megawatts of electricity could be made available for electrical heat.

Bevington says the corporation could do more to market electricity for heating. Voykin said that's the government's job. There are three programs that offer rebates to residents and businesses converting to electric heating.

If you build it, will they come? N.W.T. gov't hopes hydro expansion will attract investment
There are better options than billion dollar Taltson expansion, say energy leaders
There may be a reason why the government and the corporation are not more aggressively promoting using surplus electricity in the Taltson system for heating, as large hydro ambitions have reopened old wounds in places like Quebec and Newfoundland and Labrador during recent debates.

It is anticipating that new industrial customers may require that excess capacity in the coming years, and experiences elsewhere show that accommodating new energy-intensive customers can be challenging for utilities. Voykin said those potential new customers include a proposed mine at Pine Point and a pellet mill in Enterprise, N.W.T., even as biomass use faces environmental pushback in some regions.

The corporation says any surplus power in the system will be sold at standard rates to any new industrial customers instead of at discount rates for heating. If that requires cutting back on the heating program, it will be cut back.

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Alliant Energy Net-Zero Carbon Plan outlines carbon-neutral electricity by 2050, coal retirements by 2040, major solar and wind additions, gas transition, battery storage, hydrogen, and carbon credits to reduce emissions and lower customer costs.

Key Points

Alliant Energy's strategy to reach carbon-neutral power by 2050 via coal phaseout, renewables, storage, and offsets.

✅ Targets net-zero electricity by 2050

✅ Retires all coal by 2040; expands solar and wind

✅ Uses storage, hydrogen, and offsets to bridge gaps

Alliant Energy has joined a small but growing group of utilities aiming for carbon-neutral electricity by 2050.

In a report released Wednesday, the Madison-based company announced a goal of “net-zero carbon dioxide emissions” from its electricity generation along with plans to eliminate all coal-powered generation by 2040, a decade earlier than the company’s previous target.

Alliant, which is pursuing plans that would make it the largest solar energy generator in Wisconsin, said it is on track to cut its 2005 carbon emissions in half by 2030.

Both goals are in line with targets an international group of scientists warn is necessary to avoid the most catastrophic impacts of climate change. But reducing greenhouse gasses was not the primary motivation, said executive vice president and general counsel Jim Gallegos.

“The primary driver is focused on our customers and communities and setting them up … to be competitive,” Gallegos said. “We do think renewables are going to do it better than fossil fuels.”

Alliant has told regulators it can save customers up to $6.5 billion over the next 35 years by adding more than 1,600 megawatts of renewable generation, closing one of its two remaining Wisconsin coal plants and taking other undisclosed actions.

In a statement, Alliant chairman and CEO John Larsen said the goal is part of broader corporate and social responsibility efforts “guided by our strategy and designed to deliver on our purpose — to serve customers and build stronger communities.”

Coal out; gas remains
The goal applies only to Alliant’s electricity generation — the company has no plans to stop distributing natural gas for heating — and is “net-zero,” meaning the company could use some form of carbon capture or purchase carbon credits to offset continuing emissions.

The plan relies heavily on renewable generation — seen in regions embracing clean power across North America — including the addition of up to 1,000 megawatts of new Wisconsin solar plants by the end of 2023 and 1,000 megawatts of Iowa wind generation added over the past four years — as well as natural gas generators to replace its aging coal fleet.

But Jeff Hanson, Alliant’s director of sustainability, said eliminating or offsetting all carbon emissions will require new tools, such as battery storage or possibly carbon-free fuels such as hydrogen, and awareness of the Three Mile Island debate over the role of nuclear power in the mix.

“Getting to the 2040 goals, that’s all based on the technologies of today,” Hanson said. “Can we get to net zero today? The challenge would be a pretty high bar to clear.”

Gallegos said the plan does not call for the construction of more large-scale natural gas generators like the recently completed $700 million West Riverside Energy Center in Beloit, though natural gas will remain a key piece of Alliant’s generation portfolio.

Alliant announced plans in May to close its 400-megawatt Edgewater plant in Sheboygan by the end of 2022, echoing how Alberta is retiring coal by 2023 as markets shift, but has not provided a date for the shutdown of the jointly owned 1,100-megawatt Columbia Energy Center near Portage, which received about $1 billion worth of pollution-control upgrades in the past decade.

Alliant’s Iowa subsidiary plans to convert its 52-year-old, 200-megawatt Burlington plant to natural gas by the end of next year and a pair of small coal-fired generators in Linn County by 2025. That leaves the 250-megawatt plant in Lansing, which is now 43 years old, and the 734-megawatt Ottumwa plant as the remaining coal-fired generators, even as others keep a U.S. coal plant running indefinitely elsewhere.

Earlier this year, the utility asked regulators to approve a roughly $900 million investment in six solar farms across the state with a total capacity of 675 megawatts, similar to plans in Ontario to seek new wind and solar to address supply needs. The company plans to apply next year for permission to add up to 325 additional megawatts.

Alliant said the carbon-neutral plan, which entails closing Edgewater along with other undisclosed actions, would save customers between $2 billion and $6.5 billion through 2055 compared to the status quo.

Tom Content, executive director of the Citizens Utility Board, said the consumer advocacy group wants to ensure that ratepayers aren’t forced to continue paying for coal plants that are no longer needed while also paying for new energy sources and would like to see a bigger role for energy efficiency and more transparency about the utilities’ pathways to decarbonization.

‘They could do better’
Environmental groups said the announcement is a step in the right direction, though they say utilities need to do even more to protect the environment and consumers.

Amid competition from cheaper natural gas and renewable energy and pressure from environmentally conscious investors, U.S. utilities have been closing coal plants at a record pace in recent years, as industry CEOs say a coal comeback is unlikely in the U.S., a trend that is expected to continue through the next decade.

“This is not industry leadership when we’re talking about emission reductions,” said Elizabeth Katt Reinders, regional campaign director for the Sierra Club, which has called on Alliant to retire the Columbia plant by 2026.

Closing Edgewater and Columbia would get Alliant nearly halfway to its emissions goals while saving customers more than $250 million over the next decade, according to a Sierra Club study released earlier this year.

“Retiring Edgewater was a really good decision. Investing in 1,000 megawatts of new solar is game-changing for Wisconsin,” Katt Reinders said. “In the same breath we can say this emissions reduction goal is unambitious. Our analysis has shown they can do far more far sooner.”

Scott Blankman, a former Alliant executive who now works as director of energy and air programs for Clean Wisconsin, said Alliant should not run the Columbia plant for another 20 years.

“If they’re saying they’re looking to get out of coal by 2040 in Wisconsin I’d be very disappointed,” Blankman said. “I do think they could do better.”

Alliant is the 15th U.S. investor-owned utility to set a net-zero target, according to the Natural Resources Defense Council, joining Madison Gas and Electric, which announced a similar goal last year. Minnesota-based Xcel Energy, which serves customers in western Wisconsin, was the first large investor-owned utility to set such a target, as state utilities report declining returns in coal operations.

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Ontario Clean Energy Adjustment lowers hydro bills by shifting global adjustment costs, cutting time-of-use rates, and using OPG debt financing; ratepayers get inflation-capped increases for four years, then repay costs over 20 years.

Key Points

A 20-year line item repaying debt used to lower rates for 10 years by shifting global adjustment costs off hydro bills.

✅ 17% average bill cut takes effect after royal assent

✅ OPG-managed entity assumes debt for 10 years

✅ 20-year surcharge repays up to $28B plus interest

Ontarians will see lowered hydro bills for the next 10 years, but will then pay higher costs for the following 20 years, under new legislation tabled Thursday.

Ten weeks after announcing its plan to lower hydro bills, the Liberal government introduced legislation to lower time-of-use rates, take the cost of low-income and rural support programs off bills, and introduce new social programs.

It will lower time-of-use rates by removing from bills a portion of the global adjustment, a charge consumers pay for above-market rates to power producers. For the next 10 years, a new entity overseen by Ontario Power Generation will take on debt to pay that difference.

Then, the cost of paying back that debt with interest -- which the government says will be up to $28 billion -- will go back onto ratepayers' bills for the next 20 years as a "Clean Energy Adjustment."

An average 17-per-cent cut to bills will take effect 15 days after the hydro legislation receives royal assent, even as a Nov. 1 rate increase was set by the Ontario Energy Board, but there are just eight sitting days left before the Ontario legislature breaks for the summer. Energy Minister Glenn Thibeault insisted that leaves the opposition "plenty" of time for review and debate.

Premier Kathleen Wynne promised to cut hydro bills and later defended a 25% rate cut after widespread anger over rising costs helped send her approval ratings to record lows.

Electricity bills in the province have roughly doubled in the last decade, due in part to green energy initiatives, and Thibeault said the goal of this plan is to better spread out those costs.

"Like the mortgage on your house, this regime will cost more as we refinance over a longer period of time, but this is a more equitable and fair approach when we consider the lifespan of the clean energy investments, and generating stations across our province," he said.

NDP critic Peter Tabuns called it a "get-through-the-election" next June plan.

"We're going to take on a huge debt so Kathleen Wynne can look good on the hustings in the next few months and for decades we're going to pay for it," he said.

The legislation also holds rate increases to inflation for the next four years. After that, they'll rise more quickly, as illustrated by a leaked cabinet document the Progressive Conservatives unveiled Thursday.

The Liberals dismissed the document as containing outdated projections, but confirmed that it went before cabinet at some point before the government decided to go ahead with the hydro plan.

From about 2027 onward -- when consumers would start paying off the debt associated with the hydro plan -- Ontario electricity consumers will be paying about 12 per cent more than they would without the Liberal government's plan to cut costs in the short term, even though a deal with Quebec was not expected to reduce hydro bills, the government document projected.

But that was just one of many projections, said Energy Minister Glenn Thibeault.

"We have been working on this plan for months, and as we worked on it the documents and calculations evolved," he said.

The government's long-term energy plan is set to be updated this spring, and Thibeault said it will provide a more accurate look at how the hydro plan will reduce rates, even as a recovery rate could lead to higher hydro bills in certain circumstances.

Progressive Conservative critic Todd Smith said the "Clean Energy Adjustment" is nothing more than a revamped debt retirement charge, which was on bills from 2002 to 2016 to pay down debt left over from the old Ontario Hydro, the province's giant electrical utility that was split into multiple agencies in 1999 under the previous Conservative government.

"The minister can call it whatever he wants but it's right there in the graph, that there is going to be a new charge on the line," Smith said. "It's the debt retirement charge on steroids."

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B.C. EV Charging Rebates boost CleanBC incentives as NRCan and ZEVIP funding covers up to 75% of Level 2 and DC fast-charger purchase and installation costs for homes, workplaces, condos, apartments, and fleet operators.

Key Points

Incentives in B.C. cover up to 75% of Level 2 and DC fast charger costs for homes, workplaces, and fleets.

✅ Up to 75% back; Level 2 max $5,000; DC fast max $75,000 for fleets.

✅ Eligible sites: homes, workplaces, condos, apartments, fleet depots.

✅ Funded by CleanBC with NRCan ZEVIP; time-limited top-up.

The Province and Natural Resources Canada (NRCan) are making it more affordable for people to install electric vehicle (EV) charging stations in their homes, businesses and communities, as EV demand ramps up across the province.

B.C. residents, businesses and municipalities can receive higher rebates for EV charging stations through the CleanBC Go Electric EV Charger Rebate and Fleets programs. For a limited time, funding will cover as much as 75% of eligible purchase and installation costs for EV charging stations, which is an increase from the previous 50% coverage.

“With electric vehicles representing 13% of all new light-duty vehicles sold in B.C. last year, our province has the strongest adoption rate of electric vehicles in Canada. We’re positioning ourselves to become leaders in the EV industry,” said Bruce Ralston, B.C.’s Minister of Energy, Mines and Low Carbon Innovation. “We’re working with our federal partners to increase rebates for home, workplace and fleet charging, and making it easier and more affordable for people to make the switch to electric vehicles.”

With a $2-million investment through NRCan’s Zero-Emission Vehicle Infrastructure Program (ZEVIP) to top up the Province’s EV Charger Rebate program, workplaces, condominiums and apartments can get a rebate for a Level 2 charging station for as much as 75% of purchase and installation costs to a maximum of $5,000. As many as 360 EV chargers will be installed through the program.

“We’re making electric vehicles more affordable and charging more accessible where Canadians live, work and play,” said Jonathan Wilkinson, federal Minister of Natural Resources. “Investing in more EV chargers, like the ones announced today in British Columbia, will put more Canadians in the driver’s seat on the road to a net-zero future and help achieve our climate goals.”

Through the CleanBC Go Electric Fleets program and in support of B.C. businesses that own and operate fleet vehicles, NRCan has invested $1.54 million through ZEVIP to top up rebates. Fleet operators can get combined rebates from NRCan and the Province for a Level 2 charging station as much as 75% to a maximum of $5,000 of purchase and installation costs, and 75% to a maximum of $75,000 for a direct-current, fast-charging station. As many as 450 EV chargers will be installed through the program.

CleanBC is a pathway to a more prosperous, balanced and sustainable future. It supports government’s commitment to climate action to meet B.C.’s emission targets and build a cleaner, stronger economy.

Quick Facts:

• A direct-current fast charger on the BC Electric Highway allows an EV to get 100-300 kilometres of range from 30 minutes of charging.
• Faster chargers, which give more range in less time, are coming out every year.
• A Level 2 charger allows an EV to get approximately 30 kilometres of range per hour of charging.
• It uses approximately the same voltage as a clothes dryer and is usually installed in homes, workplaces or for fleets to get a faster charge than a regular outlet, or in public places where people might park for a longer time.
• A key CleanBC action is to strengthen the Zero-Emission Vehicles Act to require light-duty vehicle sales to be 26% zero-emission vehicles (ZEVs) by 2026, 90% by 2030 and 100% by 2035, five years ahead of the original target.
• At the end of 2021, B.C. had more than 3,000 public EV charging stations and almost 80,000 registered ZEVs.

Learn More:

To learn more about home and workplace EV charging-station rebates, eligibility and application processes, visit: https://goelectricbc.gov.bc.ca/   

To learn more about the Fleets program, visit: https://pluginbc.ca/go-electric-fleets/    

To learn more about Natural Resources Canada’s Zero-Emission Vehicle Infrastructure Program, visit:
https://www.nrcan.gc.ca/energy-efficiency/transportation-alternative-fuels/zero-emission-vehicle-infrastructure-program/21876

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25% Tariff on Canadian Imports threatens New York energy markets, disrupting hydroelectric power and natural gas supply chains, raising electricity prices, increasing gas costs, and intensifying trade tensions, policy uncertainty, and cross-border logistics risks.

Key Points

A U.S. policy imposing 25% duties on Canadian goods, risking higher New York electricity and natural gas costs.

✅ Hydroelectric and gas imports face costlier cross-border flows

✅ Higher utility bills for NY households and businesses

✅ Supply chain volatility and policy uncertainty increase

President Donald Trump announced the imposition of a 25% tariff on all imports from Canada, citing concerns over drug trafficking and illegal immigration. This decision has raised significant concerns among experts and residents in New York, who warn that the tariff could lead to increased electricity and gas prices in the state.

Impact on New York's Energy Sector

New York relies heavily on energy imports from Canada, particularly electricity and natural gas. Canada is a major supplier of hydroelectric power to the northeastern United States, including New York, with its electricity exports at risk amid trade tensions. The imposition of a 25% tariff on Canadian goods could disrupt this supply chain, leading to higher energy costs for consumers and businesses in New York. Justin Wilcox, an energy analyst, stated, "If the tariff is implemented, it could lead to increased costs for electricity and gas, affecting both consumers and businesses."

Potential Economic Consequences

The increased energy costs could have broader economic implications for New York, and some experts advise against cutting Quebec's exports to avoid exacerbating market volatility. Higher electricity and gas prices may lead to increased operational costs for businesses, potentially resulting in higher prices for goods and services, while tariff threats have boosted support for Canadian energy projects that could reshape regional supply. This could exacerbate the cost-of-living challenges faced by residents and strain the state's economy.

Political and Diplomatic Reactions

The tariff has also sparked political and diplomatic reactions, including threats to cut U.S. electricity exports from Ontario that raised tensions. New York Governor Kathy Hochul expressed concern over the potential economic impact, stating, "We are closely monitoring the situation and are prepared to take necessary actions to protect New York's economy." Additionally, Canadian officials have expressed their disapproval of the tariff, and Ontario Premier Doug Ford's Washington meeting underscored ongoing discussions, emphasizing the importance of the trade relationship between the two countries.

Historical Context

This development is part of a broader pattern of trade tensions between the United States and its neighbors. In 2018, the U.S. imposed tariffs on Canadian steel and aluminum, leading to retaliatory measures from Canada. The current situation underscores the ongoing challenges in international trade relations, where a recent tariff threat delayed Quebec's green energy bill and highlighted the potential domestic impacts of such policies.

The imposition of a 25% tariff on Canadian imports by President Trump has raised significant concerns in New York regarding potential increases in electricity and gas prices. Experts warn that this could lead to higher costs for consumers and businesses, with broader economic implications for the state. As the situation develops, it will be crucial to monitor the responses from both state and federal officials, as well as how Canadians support tariffs on energy and minerals may influence policy, and the potential for diplomatic negotiations to address these trade tensions.

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