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Gander Curling Club Debt Forgiveness Agreement explained: town council tax relief, loan write-off conditions, community benefits, and economic impact, covering long-standing taxes and loans while protecting the facility with asset clauses and compliance terms.

Key Points

Town plan erasing 25 years of tax and loan debt, with conditions to keep the curling facility open for residents.

✅ Conditions: no borrowing against property without consent.

✅ Water and sewer taxes must be paid annually.

✅ If sold or use changes, debt due; transfer for $1.

Gander town council has agreed to forgive the local curling club's debt of over $250,000.

Gina Brown, chair of the town council's finance committee, says the agreement has been put in place to help the curling club survive, amid broader discussions on electricity affordability in Newfoundland and Labrador.

"When we took a look at this and realized there was a significant outstanding debt for Gander curling club … we have to mitigate," Brown told CBC Newfoundland Morning. "[Getting] what the taxpayers are owed, with also understanding and appreciating the role that that recreational facility plays in our community."

According to Brown, the debt comes from a combination of taxes and loans, going back about 25 years. She says the curling club understood there was debt, but didn't know the number was so high. The club has been in the black since 2007, but used their profits for other items like renovations.

"Like so many cases when you're dealing with an organization with a changing board, and the same for council … [people are] coming in and coming out," Brown said. "And as a result, my understanding from the curling club's perspective is they weren't aware of how much was outstanding."

Chris McLeod, president of the Gander Curling Club, told CBC the club had been trying to address the debt since he became president in 2014.

Terms of agreement
The town's agreement with the club comes with the following stipulations:

The club will not use the property as security for any form of borrowing without the town's consent.
 
The club will continue to pay water and sewer tax annually.
 
If the club sells the property, the town reserves the right to void the agreement and the debt will immediately become due in full.
 
If the club stops using the facility as a curling club, the property will be transferred to the town for $1.
McLeod says the club will not attempt to pay back the debt, as it is not part of the agreement. The only way the debt would be paid is if the building is sold, which McLeod says it won't be, and there are also no plans to use the building for anything other than a curling club.

"[The debt] is basically gone now," McLeod said.

McLeod says the move was made to help get the debt off the books, and make sure the curling club can be financially responsible in the future, similar to relief programs some utilities offered during the pandemic.

The curling club is something that encourages people. So we felt that this has to be maintained.
- Gina Brown

Brown says keeping the curling club in Gander is important for the town, and brings different benefits to the area, as regional power cooperation debates illustrate broader trends.

"They are servicing people from as young as Grade 1 to seniors," Brown said. "You need little to no equipment, you need no background. So for the town itself, for its social and health implications, as provinces advance emissions plans that can affect communities, is one. But the other thing is the economic benefit that comes from having this facility here."

The Gander Curling Club's debt forgiveness comes with several conditions. (Google Maps)
The curling club can help attract people into the community, as recreational facilities are often a key draw for families, she added, while other provinces are creating transition funds to support communities.

"When you're as a town, trying to attract people coming in … whether you're a doctor, nurse, anybody looking at the recreational facilities, the curling club is something that encourages people," Brown said. "So we felt that this has to be maintained."

Brown says the town understands they might be setting a precedent with other businesses in forgiving the debts of the curling club, as major infrastructure like B.C.'s Site C dam has faced budget overruns.

"That's another thing we had to consider, what kind of precedents are [we] establishing?" Brown said. "From our standpoint, I think one of the things about this agreement that we felt was beneficial to the town is that they have an asset, helping to avoid costly delays seen with large projects. And the asset is a great building. To us, the taxpayers are in a win-win situation."

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California Income-Based Utility Fees would overhaul electricity bills as CPUC weighs fixed charges tied to income, grid maintenance costs, AB 205 changes, and per-kilowatt-hour rates, shifting from pure usage pricing to hybrid utility rate design.

Key Points

Income-based utility fees are fixed monthly charges tied to earnings, alongside per-kWh rates, to help fund grid costs.

✅ CPUC considers fixed charges by income under AB 205

✅ Separates grid costs from per-kWh energy charges

✅ Could shift rooftop solar and EV charging economics

Electricity bills in California are likely to change dramatically in 2026, with major changes under discussion statewide.

The California Public Utilities Commission (CPUC) is in the midst of an unprecedented overhaul of the way most of the state’s residents pay for electricity, as it considers revamping electricity rates to meet grid and climate goals.

Utility bills currently rely on a use-more pay-more system, where bills are directly tied to how much electricity a resident consumes, a setup that helps explain why prices are soaring for many households.

California lawmakers are asking regulators to take a different approach, and some are preparing to crack down on utility spending as oversight intensifies. Some of the bill will pay for the kilowatt hours a customer uses and a monthly fixed fee will help pay for expenses to maintain the electric grid: the poles, the substations, the batteries, and the wires that bring power to people’s homes.

The adjustments to the state’s public utility code, section 739.9, came about because of changes written into a sweeping energy bill passed last summer, AB 205, though some lawmakers now aim to overturn income-based charges in subsequent measures.

A stroke of a pen, a legislative vote, and the governor’s signature created a move toward unprecedented income-based fixed charges across the state.

“This was put in at the last minute,” said Ahmad Faruqui, a California economist with a long professional background in utility rates. “Nobody even knew it was happening. It was not debated on the floor of the assembly where it was supposedly passed. Of course, the governor signed it.”

Faruqui wonders who was responsible for legislation that was added to the energy bill during the budget writing process. That process is not transparent.

“It’s a very small clause in a very long bill, which is mostly about other issues,” Faruqui said.

But that small adjustment could have a massive impact on California residents, because it links the size of a monthly flat fee for utility service to a resident’s income. Earn more money and pay a higher flat fee.

That fee must be paid even before customers are charged for how much power they draw.

Regulators interpreted legislative change as a mandate, but Faruqui is not sold.

“They said the commission may consider or should consider,” Faruqui said. “They didn’t mandate it. It’s worth re-reading it.”

In fact, the legislative language says the commission “may” adopt income-based flat fees for utilities. It does not say the commission “should” adopt them.

Nevertheless, the CPUC has already requested and received nine proposals for how a flat fee should be implemented, as regulators face calls for action amid soaring electricity bills.

The suggestions came from consumer groups, environmentalists, the solar industry and utilities.

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Hydro-Québec $185-Billion Clean Energy Plan accelerates hydroelectric upgrades, wind power expansion, solar and battery storage, pumped storage, and 5,000 km transmission lines to decarbonize Quebec, boost grid resilience, and attract bond financing and Indigenous partnerships.

Key Points

Plan to grow renewables, harden the grid, and fund Quebec's decarbonization with major investments.

✅ $110B new generation, $50B grid resilience by 2035

✅ Triple wind, add solar, batteries, and pumped storage

✅ 5,000 km lines, bond financing, Indigenous partnerships

Hydro-Québec is in the preliminary stages of dialogue with various financiers and potential collaborators to strategize the implementation of a $185-billion initiative aimed at transitioning Quebec away from fossil fuel dependency.

As the leading hydroelectric power producer in Canada, Hydro-Québec is set to allocate up to $110 billion by 2035 towards the development of new clean energy facilities, building on its hydropower capacity expansion in recent years, with an additional $50 billion dedicated to enhancing the resilience of its power grid, as revealed in a strategy announced last November. The remainder of the projected expenditure will cover operational costs.

This ambitious initiative has garnered significant interest from the financial sector, with the province's recent electricity for industrial projects also drawing attention, as noted by CEO Michael Sabia during a conference call with journalists where the utility's annual financial outcomes were discussed. Sabia reported receiving various proposals to fund the initiative, though specific partners were not disclosed. He expressed confidence in securing the necessary capital for the project's success.

Sabia highlighted three immediate strategies to increase power output: identifying new sites for hydroelectric projects while upgrading turbines at existing facilities, such as the Carillon Generating Station upgrade now underway for enhanced efficiency, expanding wind energy production threefold, and promoting energy conservation among consumers to optimize current power usage.

Additionally, Hydro-Québec aims to augment its solar and battery energy production and is planning to establish a pumped-storage hydroelectric plant to support peak demand periods. The utility also intends to construct 5,000 kilometers of new transmission lines, address Quebec-to-U.S. transmission constraints where feasible, and is set to double its capital expenditure to $16 billion annually, a significant increase from the investment levels during the James Bay hydropower project construction in the 1970s and 1980s.

To fund part of this expansive plan, Hydro-Québec will continue to access the bond market, having issued $3.7 billion in notes to investors last year despite facing several operational hurdles due to adverse weather conditions.

For the year 2023, Hydro-Québec reported a net income of $3.3 billion, marking a 28% decrease from the previous year's record of $4.56 billion. Factors such as insufficient snow cover, reduced spring runoff, and higher temperatures resulted in lower water levels in reservoirs, leading to a reduction in power exports and a $547-million decrease in external market sales compared to the previous year.

The utility experienced its lowest export volume in a decade but managed to leverage hedging strategies to secure 10.3 cents per kWh for exported power to markets including New Brunswick via recent NB Power agreements that expand interprovincial deliveries, nearly twice the average market rate, through forward contracts that cover up to half of its export volume for about a year in advance.

The success of Sabia's plan will partly depend on the cooperation of First Nations communities, as the proposed infrastructure developments are likely to traverse their ancestral territories. Relationships with some communities are currently tense, exemplified by the Innu of Labrador's $4-billion lawsuit against Hydro-Québec for damages related to land flooding for reservoir construction, and broader regional tensions in Newfoundland and Labrador that persist in the power sector.

Sabia has committed to involving First Nations and Inuit communities as partners in clean energy ventures, offering them ongoing financial benefits rather than one-off settlements, a principle he refers to as "economic reconciliation."

Recently, the Quebec government reached an agreement with the Innu of Pessamit, pledging $45 million to support local community development. This agreement outlines solutions for managing a nearby hydropower reservoir, such as the La Romaine complex in the region, and includes commitments for wind energy development.

Sabia is optimistic about building stronger, more positive relationships with various Indigenous communities, anticipating significant progress in the coming months and viewing this year as a potential milestone in transforming these relationships for the better.

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Alberta wind power surpasses coal as AESO reports record renewable energy feeding the grid, with natural gas conversions, solar growth, energy storage, and decarbonization momentum lowering carbon intensity across Alberta's electricity system.

Key Points

AESO data shows wind surpassing coal in Alberta, driven by coal retirements, gas conversions, and growing renewables.

✅ AESO reports wind output above coal several times this week

✅ Coal units retire or convert to natural gas, boosting renewables

✅ Carbon intensity falls; storage and solar improve grid reliability

Marking a significant shift in Alberta energy history, wind generation trends provided more power to the province's energy grid than coal several times this week.

According to data from the Alberta Energy System Operator (AESO) released this week, wind generation units contributed more energy to the grid than coal at times for several days. On Friday afternoon, wind farms contributed more than 1,700 megawatts of power to the grid, compared to around 1,260 megawatts from coal stations.

"The grid is going through a period of transformative change when we look at the generation fleet, specifically as it relates to the coal assets in the province," Mike Deising, AESO spokesperson, told CTV News in an interview.

The shift in electricity generation comes as more coal plants come offline in Alberta, or transition to cleaner energy through natural gas generation, including the last of TransAlta's units at the Keephills Plant west of Edmonton.

Only three coal generation stations remain online in the province, at the Genesee plant southwest of Edmonton, as the coal phase-out timeline advances. Less available coal power, means renewable energy like wind and solar make up a greater portion of the grid.

EVOLUTION OF THE GRID
"Our grid is changing, and it's evolving," Deising said, adding that more units have converted to natural gas and companies are making significant investments into solar and wind energy.

For energy analyst Kevin Birn with IHS Markit, that trend is only going to continue.

"What we've seen for the last 24 to 36 months is a dramatic acceleration in ambition, policy, and projects globally around cleaner forms of energy or lower carbon forms of energy," Birn said.

Birn, who is also chief analyst of Canadian Oil Markets, added that not only has the public appetite for cleaner energy helped fuel the shift, but technological advancements have made renewables like wind and solar more cost-efficient.

"Alberta was traditionally heavily coal-reliant," he said. "(Now) western Canada has quite a diverse energy base."

LESS CARBON-INTENSIVE
According to Birn, the shift in energy production marks a significant reduction in carbon emissions as Alberta progresses toward its last coal plant closure milestone.

Ten years ago, IHS Markit estimates that Alberta's grid contributed about 900 kilograms of carbon dioxide equivalent per megawatt-hour of energy generation.

"That (figure is) really representing the dominance and role of coal in that grid," Birn said.

Current estimates show that figure is closer to 600 kilograms of CO2 equivalent.

"That means the power you and I are using is less carbon-intensive," Birn said, adding that figure will continue to fall over the next couple of years.

RENEWABLES HERE TO STAY
While many debate whether Alberta's energy is getting clean enough fast enough, Birn believes change is coming.

"It's been a half-decade of incredible price volatility in the oil market which had really dominated this sector and region," the analyst said.

"When I think of the future, I see the power sector building on large-scale renewables, which means decarbonization, and that provides an opportunity for those tech companies looking for clean energy places to land facilities."

Coal and natural gas are considered baseline assets by the AESO, where generation capacity does not shift dramatically, though some utilities report declining coal returns in other markets.

"Wind is a variable resource. It will generate when the wind is blowing, and it obviously won't when the wind is not," Deising said. "Wind and solar can ramp quickly, but they can drop off quite quickly, and we have to be prepared.

"We factor that into our daily planning and assessments," he added. "We follow those trends and know where the renewables are going to show up on the system, how many renewables are going to show up."

Deising says one wind plant in Alberta currently has an energy storage capacity to preserve renewably generated electricity during summer demand records and peak hours as needed. As the technology becomes more affordable, he expects more plants to follow suit.

"As a system operator, our job is to make sure as (the grid) is evolving we can continue to provide reliable power to Albertans at every moment every day," Deising said. "We just have to watch the system more carefully." 

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Ontario Electricity Export Retaliation signals tariff-fueled trade tensions as Doug Ford leverages cross-border energy flows to the U.S., risking grid reliability, higher power prices, and escalating a Canada-U.S. trade war over protectionist policies.

Key Points

A policy threat by Ontario to cut power exports to U.S. states in response to tariffs, leveraging grid dependence.

✅ Powers about 1.5M U.S. homes in NY, MI, and MN

✅ Risks price spikes, shortages, and legal challenges

✅ Part of Canada's CAD 30B retaliatory tariff package

In a move that underscores the escalating trade tensions between Canada and the United States, Ontario Premier Doug Ford has threatened to halt electricity exports to U.S. states in retaliation for the Trump administration's recent tariffs. This bold stance highlights Ontario's significant role in powering regions across the U.S. and serves as a warning about the potential consequences of trade disputes.

The Leverage of Ontario's Electricity

Ontario's electricity exports are not merely supplementary; they are essential to the energy supply of several U.S. states. The province provides power to approximately 1.5 million homes in states such as New York, Michigan, and Minnesota, even as it eyes energy independence through domestic initiatives. This substantial export positions Ontario as a key player in the regional energy market, giving the province considerable leverage in trade negotiations.

Premier Ford's Ultimatum

Responding to the Trump administration's imposition of a 25% tariff on Canadian imports, Premier Ford, following a Washington meeting, declared, "If they want to play tough, we can play tough." He further emphasized his readiness to act, stating, "I’ll cut them off with a smile on my face." This rhetoric underscores Ontario's willingness to use its energy exports as a bargaining chip in the trade dispute.

Economic and Political Ramifications

The potential cessation of electricity exports to the U.S. would have profound economic implications. U.S. states that rely on Ontario's power could face energy shortages, leading to increased prices, particularly New York energy prices, and potential disruptions. Such an action would not only strain the energy supply but also escalate political tensions, potentially affecting other areas of bilateral cooperation.

Canada's Retaliatory Measures

Ontario's threat is part of a broader Canadian strategy to counteract U.S. tariffs. Prime Minister Justin Trudeau has announced retaliatory tariffs on U.S. goods worth approximately CAD 30 billion, targeting products such as food, textiles, and furniture. These measures aim to pressure the U.S. administration into reconsidering its trade policies.

The Risk of Escalation

While leveraging energy exports provides Ontario with a potent tool, it also carries significant risks, as experts warn against cutting Quebec's energy exports amid tariff tensions. Such actions could lead to a full-blown trade war, with both countries imposing tariffs and export restrictions. The resulting economic fallout could affect various sectors, from manufacturing to agriculture, and lead to job losses and increased consumer prices.

International Trade Relations

The dispute also raises questions about the stability of international trade agreements and the rules governing cross-border energy transactions. Both Canada and the U.S. are signatories to various trade agreements that promote the free flow of goods and services, including energy. Actions like export bans could violate these agreements and lead to legal challenges.

Public Sentiment and Nationalism

The trade tensions have sparked a surge in Canadian nationalism, with public sentiment largely supporting tariffs on energy and minerals as retaliatory measures. This sentiment is evident in actions such as boycotting American products and expressing discontent at public events. However, while national pride is a unifying force, it does not mitigate the potential economic hardships that may result from prolonged trade disputes.

The Path Forward

Navigating this complex situation requires careful diplomacy and negotiation. Both Canada and the U.S. must weigh the benefits of trade against the potential costs of escalating tensions. Engaging in dialogue, seeking compromise, and adhering to international trade laws are essential steps to prevent further deterioration of relations and to ensure the stability of both economies.

Ontario's threat to cut off electricity exports to the U.S. serves as a stark reminder of the interconnectedness of global trade and the potential consequences of protectionist policies. While such measures can be effective in drawing attention to grievances, they also risk significant economic and political fallout. As the situation develops, it will be crucial to monitor the responses of both governments and the impact on industries and consumers alike, including growing support for Canadian energy projects among stakeholders.

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Wall Street Fossil Fuel Pivot signals banks reassessing ESG, net-zero, and decarbonization goals, reviving oil, gas, and coal financing while recalibrating clean energy exposure amid policy shifts, regulatory rollbacks, and investment risk realignment.

Key Points

A shift as major U.S. banks ease ESG limits to fund oil, gas, coal while rebalancing alongside renewables.

✅ Banks revisit lending to oil, gas, and coal after policy shifts.

✅ ESG and net-zero commitments face reassessment amid returns.

✅ Renewables compete for capital as risk models are updated.

The global energy finance sector, worth a staggering $1.4 trillion, is undergoing a significant transformation, largely due to former President Donald Trump's renewed support for the oil, gas, and coal industries. Wall Street, which had previously aligned itself with global climate initiatives and the energy transition and net-zero goals, is now reassessing its strategy and pivoting toward a more fossil-fuel-friendly stance.

This shift represents a major change from the earlier stance, where many of the largest U.S. banks and financial institutions took a firm stance on decarbonization push, including limiting their exposure to fossil-fuel projects. Just a few years ago, these institutions were vocal supporters of the global push for a sustainable future, with many committing to support clean energy solutions and abandon investments in high-carbon energy sources.

However, with the change in administration and the resurgence of support for traditional energy sectors under Trump’s policies, these same banks are now rethinking their strategies. Financial institutions are increasingly discussing the possibility of lifting long-standing restrictions that limited their investments in controversial fossil-fuel projects, including coal mining, where emissions drop as coal declines, and offshore drilling. The change reflects a broader realignment within the energy finance sector, with Wall Street reexamining its role in shaping the future of energy.

One of the most significant developments is the Biden administration’s policy reversal, which emphasized reducing the U.S. carbon footprint in favor of carbon-free electricity strategies. Under Trump, however, there has been a renewed focus on supporting the traditional energy sectors. His administration has pushed to reduce regulatory burdens on fossil-fuel companies, particularly oil and gas, while simultaneously reintroducing favorable tax incentives for the coal and gas industries. This is a stark contrast to the Biden administration's efforts to incentivize the transition toward renewable energy and zero-emissions goals.

Trump's policies have, in effect, sent a strong signal to financial markets that the fossil-fuel industry could see a resurgence. U.S. banks, which had previously distanced themselves from financing oil and gas ventures due to the pressure from environmental activists and ESG (Environmental, Social, and Governance) investors, as seen in investor pressure on Duke Energy, are now reconsidering their positions. Major players like JPMorgan Chase and Goldman Sachs are reportedly having internal discussions about revisiting financing for energy projects that involve high carbon emissions, including controversial oil extraction and gas drilling initiatives.

The implications of this shift are far-reaching. In the past, a growing number of institutional investors had embraced ESG principles, with the goal of supporting the transition to renewable energy sources. However, Trump’s pro-fossil fuel stance appears to be emboldening Wall Street’s biggest players to rethink their commitment to green investing. Some are now advocating for a “balanced approach” that would allow for continued investment in traditional energy sectors, while also acknowledging the growing importance of renewable energy investments, a trend echoed by European oil majors going electric in recent years.

This reversal has led to confusion among investors and analysts, who are now grappling with how to navigate a rapidly changing landscape. Wall Street's newfound support for the fossil-fuel industry comes amid a backdrop of global concerns about climate change. Many investors, who had previously embraced policies aimed at curbing the effects of global warming, are now finding it harder to reconcile their environmental commitments with the shift toward fossil-fuel-heavy portfolios. The reemergence of fossil-fuel-friendly policies is forcing institutional investors to rethink their long-term strategies.

The consequences of this policy shift are also being felt by renewable energy companies, which now face increased competition for investment dollars from traditional energy sectors. The shift towards oil and gas projects has made it more challenging for renewable energy companies to attract the same level of financial backing, even as demand for clean energy continues to rise and as doubling electricity investment becomes a key policy call. This could result in a deceleration of renewable energy projects, potentially delaying the progress needed to meet the world’s climate targets.

Despite this, some analysts remain optimistic that the long-term shift toward green energy is inevitable, even if fossil-fuel investments gain a temporary boost. As the world continues to grapple with the effects of climate change, and as technological advancements in clean energy continue to reduce costs, the transition to renewables is likely to persist, regardless of the political climate.

The shift in Wall Street’s approach to energy investments, spurred by Trump’s pro-fossil fuel policies, is reshaping the $1.4 trillion global energy finance market. While the pivot towards fossil fuels may offer short-term gains, the long-term trajectory for energy markets remains firmly in the direction of renewables. The next few years will be crucial in determining whether financial institutions can balance the demand for short-term profitability with their long-term environmental responsibilities.

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