Underground FEMA fuel tanks could leak

By Associated Press


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The government owns hundreds of underground fuel tanks — many designed for emergencies back in the Cold War — that need to be inspected for leaks of hazardous substances that could be making local water undrinkable.

The Federal Emergency Management Agency has known since at least the 1990s that tanks under its supervision around the country could be leaking fuel into soil and groundwater, according to Associated Press interviews and research.

The agency knows of at least 150 underground tanks that need to be inspected for leaks, according to spokeswoman Debbie Wing. FEMA also is trying to determine by September whether an additional 124 tanks are underground or above ground and whether they are leaking.

There has been no documentation of reported leaks or harm to communities from the FEMA tanks, Wing said, although former agency officials and congressional testimony suggest that the federal tanks have long been seen as a problem.

Many of these tanks were built to store 5,000 gallons of diesel fuel and placed around the country at the height of the Cold War back in the 1960s to fuel electric generators that could sustain emergency broadcasts by radio stations in case of a nuclear attack or other catastrophe. Made of steel, the tanks inevitably rust over time and allow fuel to escape.

Steel tanks left in the ground for decades rot like Swiss cheese, said Pat Coyne, director of business development for Environmental Data Resources Inc. Coyne said a joke in the industry is: "What percentage of steel tanks leak? 100 percent!"

In the late 1980s and early 1990s the government insisted on better-made tanks. The underground tanks of today must have safety measures including leak detection and an extra shell made with material resistant to gasoline, diesel and ethanol, Coyne said.

The FEMA tanks are part of a larger problem. More than 500,000 leaking storage tanks — most of which are filled with fuel and oil — are buried across the country, according to Environmental Data Resources, based in Milford, Conn. That's about half of all the underground tanks in the country, the consulting company says. Those tanks are owned privately or by local, state and federal agencies.

Because they're underground, leaking tanks can go undetected for years. If diesel leaks into drinking water, affected people could be at a higher risk of cancer, kidney damage and nervous system disorders, said Rochelle Cardinale, one of the lead coordinators for underground tank cleanup in Iowa. A gallon of fuel can contaminate 1 million gallons of water.

FEMA says the hundreds of federal tanks have not always been its responsibility. The Federal Communications Commission also has had oversight, although FCC spokesman Clyde Ensslin said the commission believed FEMA was responsible for monitoring and maintaining the tanks. FEMA said it spent $8 million in the 1990s removing and repairing some of them.

FEMA now acknowledges that it is the agency responsible for all of the tanks in question. But Senate testimony from 1992 suggests FEMA has long tried to avoid having to deal with the tanks.

"For years FEMA resisted acknowledging the problem or seeking funds for remediation," former FEMA union president Leo Bosner said in 1992 before a Senate Appropriations subcommittee.

He said then there were more than 2,000 underground oil storage tanks that FEMA had paid for or acquired over the years. But FEMA came out with a legal opinion that year concluding that it wasn't responsible for the tanks.

Congress eventually decided it didn't matter which agency owned the tanks — FEMA would fund tank inspection, removal and replacement, said Bill Cumming, who at the time ran FEMA's ethics program.

FEMA did eventually receive reports about leaking tanks, said Jane Bullock, who was the agency's chief of staff in the Clinton administration.

Many of FEMA's out-of-use fuel tanks today have yet to be inspected because officials only recently finished going through decades of paperwork from the different federal agencies that at one point participated in the emergency broadcasting program.

"We are committed to upholding our obligations to remediate, remove or upgrade them as necessary," FEMA spokesman Dan Stoneking told the AP. "We believe in adhering to any relevant environmental rule or law and will do so."

FEMA disclosed the problems to the EPA in August 2007, a step that could lead to reduced penalties against FEMA. In May, the EPA formally requested information about the status of the tanks.

FEMA said it now oversees 1,129 defunct tanks — including the hundreds that could be leaking — many of which were inherited from the FCC and the Civil Defense Preparedness Agency.

Recently FEMA found the location of most of the defunct tanks by looking through old records. To determine the tanks' conditions requires a physical inspection, and agency contractors have been going to each location and searching with hand-held metal detectors and other tools.

FEMA will determine what to do with the defunct tanks — such as remove them or fill them with sand — on a case-by-case basis, because of varying state laws.

FEMA would not provide the exact location of the tanks, and it has not contacted all the states about the tanks in question. Florida officials, for instance, did not know about these out-of-use tanks in their state.

A 2005 law required all federal agencies to submit an inventory to Congress and the EPA of all the tanks they owned or operated, and whether the tanks were in compliance with the law.

The inventory was pushed by private gasoline retailers who long have argued that they were being targeted for violations by a government that wasn't following its own rules.

In the 1960s the federal government gave fuel tanks and generators to radio stations across the country so that vital information could be broadcast during an emergency. The program was managed by the FCC in some parts of the country, and elsewhere by the former Civil Defense Preparedness Agency. Broadcast stations volunteered for the program, and by 1979 about 700 stations participated.

When FEMA was created in 1979 it took over programs run by the civil defense agency. Broadcast stations began to drop out of the program and funding was slowly eliminated between 1987 and 1994.

FEMA manages fewer tanks now because of new broadcast technology and a realignment of oversight responsibilities to states. Now FEMA oversees only 38 in-use underground tanks that are being maintained to comply with EPA rules. These tanks are used for broadcast stations and to fuel generators to keep emergency operations centers running during a disaster.

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Trump's Order Boosts U.S. Uranium and Nuclear Energy

Uranium Critical Mineral Reclassification signals a US executive order directing USGS to restore critical status, boosting nuclear energy, domestic uranium mining, streamlined permitting, federal support, and energy security amid import reliance and supply chain risks.

 

Key Points

A policy relisting uranium as a critical mineral to unlock funding, speed permits, and strengthen U.S. nuclear security.

✅ Directs Interior to have USGS reconsider uranium classification

✅ Speeds permits for domestic uranium mining projects

✅ Targets import dependence and strengthens energy security

 

In a strategic move to bolster the United States' nuclear energy sector, former President Donald Trump issued an executive order on January 20, 2025, directing the Secretary of the Interior to instruct the U.S. Geological Survey (USGS) to reconsider classifying uranium as a critical mineral. This directive aims to enhance federal support and streamline permitting processes for domestic uranium projects, thereby strengthening U.S. energy security objectives.

Reclassification of Uranium as a Critical Mineral

The USGS had previously removed uranium from its critical minerals list in 2022, categorizing it as a "fuel mineral" that did not qualify for such designation. The recent executive order seeks to reverse this decision, recognizing uranium's strategic importance in the context of the nation's energy infrastructure and geopolitical considerations.

Implications for Domestic Uranium Production

Reclassifying uranium as a critical mineral is expected to unlock federal funding and expedite the permitting process for uranium mining projects within the United States. This initiative is particularly pertinent given the significant decline in domestic uranium production over the past two decades. According to the U.S. Energy Information Administration, domestic production has decreased by 96%, from 4.8 million pounds in 2014 to approximately 121,296 pounds in the third quarter of 2024.

Current Uranium Supply Dynamics

Despite the push for increased domestic production, the U.S. remains heavily reliant on uranium imports. In 2022, 27% of U.S. uranium purchases were sourced from Canada, with an additional 57% imported from countries including Kazakhstan, Uzbekistan, Australia, and Russia; a recent ban on Russian uranium could further disrupt these supply patterns and heighten risks. This reliance on foreign sources has raised concerns about energy security, especially in light of recent geopolitical tensions.

Challenges and Considerations

While the executive order represents a significant step toward revitalizing the U.S. nuclear energy sector, several challenges persist, and energy dominance faces constraints that will shape implementation:

  • Regulatory Hurdles: Accelerating the permitting process for uranium mining projects involves navigating complex environmental and regulatory frameworks, though recent permitting reforms for geothermal hint at potential pathways, which can be time-consuming and contentious.

  • Market Dynamics: The uranium market is subject to global supply and demand fluctuations, and domestic producers may face competition from established international suppliers.

  • Infrastructure Development: Expanding domestic uranium production necessitates substantial investment in mining infrastructure and workforce development, areas that have been underfunded in recent years.

Broader Implications for Nuclear Energy Policy

The executive order aligns with a broader strategy to revitalize the U.S. nuclear energy industry, where ongoing nuclear innovation is critical to delivering stable, low-emission power. The increasing demand for nuclear energy is driven by the global push for zero-emissions energy sources and the need to support power-intensive technologies, such as artificial intelligence servers.

Former President Trump's executive order to reclassify uranium as a critical mineral, aligning with his broader energy agenda and a prior pledge to end the 'war on coal', signifies a pivotal moment for the U.S. nuclear energy sector. By potentially unlocking federal support, including programs advanced by the Nuclear Innovation Act, and streamlining permitting processes, this initiative aims to reduce dependence on foreign uranium sources and enhance national energy security. However, realizing these objectives will require addressing regulatory challenges, market dynamics, and infrastructure needs to ensure the successful revitalization of the domestic uranium industry.

 

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Ontario unveils new tax breaks, subsidized hydro plan to spur economic recovery from COVID-19

Ontario COVID-19 Business Tax Relief outlines permanent Employer Health Tax exemptions, lower Business Education Tax rates, optional municipal property tax cuts, and hydro bill subsidies to support small businesses, industrial and commercial recovery.

 

Key Points

A provincial package of tax breaks and hydro subsidies to help small, industrial, and commercial businesses recover.

✅ Permanent Employer Health Tax exemption to $1M payroll

✅ Lower Business Education Tax rates for 94% of firms

✅ Hydro subsidies cut medium-large rates by 14-16%

 

The Ontario government's latest plan to help businesses survive and recover from the COVID-19 pandemic includes a suite of new tax breaks for small businesses and $1.3 billion to subsidize electricity bills for industrial and commercial operations.

The new measures were announced Thursday as part of Ontario's 2020 budget, which sets new provincial records for both spending and deficit projections.

The government of Premier Doug Ford says the budget will address barriers impeding long-term growth, ensuring the province forges a path to a full recovery from the pandemic.

"When the pandemic is over, Ontario will come back with a vengeance, stronger and more prosperous than ever before," Ford said at an afternoon news conference.

Small businesses with payrolls under $1 million will no longer have to pay the Employer Health Tax. The province temporarily raised the exemption from $490,000 to $1 million earlier this year, but the government is now making the change permanent.

The higher exemption means that about 90 per cent of Ontario businesses will no longer have to pay the tax, amounting to about $360 million by 2022, according to the province.

"We have heard from employers across Ontario that this measure helped them keep workers on the job during COVID-19," Finance Minister Rod Phillips told the legislature.

The 2020 budget lowers rates for the Business Education Tax (BET), a property tax earmarked for public education. More than 200,000 Ontario businesses, or 94 per cent, will see a lower rate.

"I believe this budget takes some significant initial steps to help stabilize the economy and help businesses, especially small businesses," said Toronto Mayor John Tory in a statement. Tory's office estimates that reductions to the BET will result in $117 million in lower taxes for commercial properties in Canada's largest city.

Municipal governments will also be permitted to reduce property taxes for small businesses, should they choose to do so. The province says it will "consider matching these reductions," which could amount to $385 million in tax relief by 2023.

Finance Minister Rod Phillips tabled the largest spending plan in Ontario history on Thursday afternoon. (Frank Gunn/The Canadian Press)
Municipalities currently have few options to provide targeted relief to local businesses. Guelph Mayor Cam Guthrie, chair of Ontario's Big City Mayors, said the prospect of lowering property taxes will likely be welcomed by local governments across the province.

"I really am looking forward to looking into that because it would give targeted relief to these businesses that have been asking for something from local governments for the past nine months," he said in an interview.

Tax cuts 'won't help a boarded up business,' NDP says
The 2020 budget does not contain any new direct funding for small businesses or their employees. NDP leader Andrea Horwath, who has proposed to make hydro public again, said those types of funding would help businesses more than potential tax reductions.

"A future hydro or tax cut won't help a boarded up business and it certainly won't help the folks that used to work there," Horwath said.

"Those measures are great if you're a company that's doing really well ... but let's face it, main streets across Ontario are crumbling."

Ontario did reveal on Thursday more details about a previously announced $300-million fund to support businesses in Toronto, Ottawa, Peel Region and York Region, which were placed under modified Stage 2 restrictions this fall. The money can be used to cover property taxes and energy bills for eligible businesses.

In a similar move, B.C. provided a three-month break on electricity bills for residents and businesses during the pandemic.

An undetermined amount of the $300 million will also be made available to businesses that are placed under "control" and "lockdown" rules, which are the two most severe restrictions in the province's updated reopening guidelines announced in October.

No regions are currently under these restrictions.

Elsewhere, B.C. saw commercial electricity consumption plummet during the COVID-19 pandemic.

Government to subsidize hydro bills for industrial businesses
The Ford government, which earlier oversaw a Hydro One leadership overhaul, is also taking aim at what it calls "job-killing electricity prices" in Ontario's industrial and commercial sectors.

The budget includes a $1.3 billion investment over three years to subsidize their hydro bills, a move praised by Canadian Manufacturers & Exporters as supportive of industry, which the province says have been inflated due to contracts signed by the previous Liberal government to purchase electricity generated by wind, solar and bioenergy.

"This is the legacy that is making our businesses uncompetitive," Phillips told reporters Thursday afternoon.

Ontario says its $1.3-billion investment to subsidize electricity bills will offset expensive contracts for green energy signed by the previous Liberal government. (Patrick Pleul/dpa via Associated Press)
The investment will lower rates for medium- and large-sized business by between 14 and 16 per cent, and follows an OEB decision on Hydro One rates that affects transmission and distribution costs, according to Ontario's calculations. Phillips said those rates will be among the lowest of any jurisdiction in the Great Lakes region.

The provincial government said the investment is necessary for Ontario to recover from the COVID-19 downturn. The Ford government expects that no further subsidies will be required by around 2040.

 

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Learn how fees and usage impacts your electricity bill in new online CER tool

CER Interactive Electricity Bill Tool compares provincial electricity prices, fees, taxes, and usage. Explore household appliance costs, hydroelectric generation, and consumption trends across Canada with interactive calculators and a province-by-province breakdown.

 

Key Points

An online CER report with calculators comparing electricity prices, fees, and usage to explain household energy costs.

✅ Province-by-province bill, price, and consumption comparison

✅ Calculator for appliance and electronics energy costs

✅ Explains fees, taxes, regulation, and generation sources

 

Canadians have a new way to assess their electricity bill in a new, interactive online report released by the Canada Energy Regulator (CER).

The report titled What is in a residential electricity bill? features a province-to-province comparison of electricity bills, generation and consumption. It also explains electricity prices across the country, including how Calgary electricity prices have changed, allowing people to understand why costs vary depending on location, fees, regulation and taxes.  

Learn how fees and usage impacts your electricity bill in new online CER tool
Interactive tools allow people to calculate the cost of household appliances and electronic use for each province and territory, and to understand how Ontario rate increases may affect monthly bills. For example, an individual can use the tools to find out that leaving a TV on for 24-hours in Quebec costs $5.25 per month, while that same TV on for a whole day would cost $12.29 per month in Saskatchewan, $20.49 per month in the Northwest Territories, and $15.30 per month in Nova Scotia.

How Canadians use energy varies as much as how provinces and territories produce it, especially in regions like Nunavut where unique conditions influence costs. Millions of Canadians rely on electricity to power their household appliances, charge their electronics, and heat their homes. Provinces with abundant hydro-electric resources like Quebec, B.C., Manitoba, and Newfoundland and Labrador use electricity for home heating and tend to consume the most electricity.

By gathering data from various sources, this report is the first Canadian publication that features interactive tools to allow for a province-by-province comparison of electricity bills while highlighting different elements within an electricity bill, a helpful context as Canada faces a critical supply crunch in the years ahead.

The CER monitors energy markets and assesses Canadian energy requirements and trends, including clean electricity regulations developments that shape pricing. This report is part of a portfolio of publications on energy supply, demand and infrastructure that the CER publishes regularly as part of its ongoing market monitoring.

"No matter where you go in the country, Canadians want to know how much they pay for power and why, especially amid price spikes in Alberta this year," says lead author Colette Craig. "This innovative, interactive report really explains electricity bills to help everyone understand electricity pricing and consumption across Canada."

Quick Facts

  • Quebec ranks first in electricity consumption per capita at 21.0 MW.h, followed by Saskatchewan at 20.0 MW.h, Newfoundland and Labrador at 19.3 MW.h.
  • About 95% of Quebec's electricity is produced from hydroelectricity.
  • Provinces that use electricity for home heating tend to consume the most electricity.
  • Canada's largest consuming sector for electricity was industrial at 238 TW.h. The residential and commercial sectors consumed 168 TW.h and 126 TW.h, respectively.
  • In 2018, Canada produced 647.7 terawatt hours (TW.h) of electricity. More than half of the electricity in Canada (61%) is generated from hydro sources. The remainder is produced from a variety of sources, such as fossil fuels (natural gas and petroleum), nuclear, wind, coal, biomass, solar.
  • Canada is a net exporter of electricity. In 2019, net exports to the U.S. electricity market totaled 47.0 TW.h.
  • The total value of Canada's electricity exports was $2.5 billion Canadian dollars and the value of imports was $0.6 billion Canadian dollars, resulting in 2019 net exports of $1.9 billion.
  • All regions in Canada are reflected in this report but it does not include data that reflects the COVID-19 lockdown and its effects on residential electricity bills.
     

 

 

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IAEA Warns of Nuclear Risks from Russian Attacks on Ukraine Power Grids

Ukraine nuclear safety risks escalate as IAEA warns of power grid attacks threatening reactor cooling, diesel generators, and Zaporizhzhia oversight, prompting UN calls for demilitarized zones to prevent radioactive releases and accidents.

 

Key Points

Escalating threats from grid attacks and outages that jeopardize reactor cooling, IAEA oversight, and public safety.

✅ Power grid strikes threaten reactor cooling systems.

✅ Emergency diesel generators are last defense lines.

✅ Calls grow for demilitarized zones around plants.

 

In early February 2025, Rafael Grossi, Director General of the International Atomic Energy Agency (IAEA), expressed grave concerns regarding the safety of Ukraine's nuclear facilities amid ongoing Russian attacks on the country's power grids, as Kyiv warned of a difficult winter without power after deadly strikes on energy infrastructure. Grossi's warnings highlight the escalating risks to nuclear safety and the potential for catastrophic accidents.

The Threat to Nuclear Safety

Ukraine's nuclear infrastructure, including the Zaporizhzhia Nuclear Power Plant—the largest in Europe—relies heavily on a stable power supply to maintain critical cooling systems and other safety measures. Russian military operations targeting Ukraine's energy infrastructure have led to power outages, and created hazards akin to those highlighted in downed power line safety guidance during emergency repairs, jeopardizing the safe operation of these facilities. Grossi emphasized that such disruptions could result in severe nuclear accidents if cooling systems fail.

IAEA's Response and Actions

In response to these threats, the IAEA has been actively involved in monitoring and assessing the situation. Grossi visited Kyiv to inspect electrical substations and discuss safety measures with Ukrainian officials. He underscored the necessity of ensuring uninterrupted power to nuclear plants and the critical role of emergency diesel generators as a last line of defense, and noted that maintaining staffing continuity, including measures such as staff living on site at critical facilities, may be necessary. The IAEA has also postponed the rotation of its mission at the Zaporizhzhia plant due to security concerns, as reported by Reuters.

International Concerns and Diplomatic Efforts

The international community has expressed deep concern over the potential for nuclear accidents in Ukraine, echoing earlier grid overseer warnings about systemic risks in other crises that stress energy systems. The United Nations and various countries have called for the establishment of a demilitarized zone around nuclear facilities to prevent military activities that could compromise their safety. Diplomatic efforts are ongoing to facilitate dialogue between Russia and Ukraine, aiming to ensure the protection of nuclear sites and the safety of surrounding populations.

The Zaporizhzhia Nuclear Power Plant

The Zaporizhzhia Nuclear Power Plant, located in southeastern Ukraine, has been under Russian control since early in the conflict, with Rosatom cooperation agreements reflecting broader nuclear policy priorities that frame Moscow's approach to the sector. The plant consists of six reactors and has been a focal point of international concern due to its size and the potential consequences of any incident. The IAEA has been working to maintain oversight and ensure the plant's safety amid the ongoing conflict.

Potential Consequences of Nuclear Accidents

A nuclear accident at any of Ukraine's nuclear facilities could have catastrophic consequences, including the release of radioactive materials, displacement of populations, and long-term environmental damage, with communities potentially facing weeks without electricity and basic services in the aftermath. The proximity of these plants to densely populated areas further amplifies the risks. The international community continues to monitor the situation closely, emphasizing the need for immediate action to safeguard nuclear facilities.

The ongoing conflict in Ukraine has introduced unprecedented challenges to nuclear safety. The IAEA's warnings and actions underscore the critical need for international cooperation to protect nuclear facilities from the dangers posed by military activities. Ensuring the safety of these sites is paramount to prevent potential disasters that could have far-reaching humanitarian and environmental impacts, and sustained attention to nuclear workers' safety concerns helps maintain operational readiness under strain.

 

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Doug Ford's New Stance on Wind Power in Ontario

Ontario Wind Power Policy Shift signals renewed investment in renewable energy, wind farms, and grid resilience, aligning with climate goals, lower electricity costs, job creation, and turbine technology for cleaner, diversified power.

 

Key Points

A provincial pivot to expand wind energy, meet climate goals, lower costs, and boost jobs across Ontario’s power system.

✅ Diversifies Ontario's grid with scalable renewable capacity.

✅ Targets emissions cuts while stabilizing electricity prices.

✅ Spurs rural investment, supply chains, and skilled jobs.

 

Ontario’s energy landscape is undergoing a significant transformation as Premier Doug Ford makes a notable shift in his approach to wind power. This change represents a strategic pivot in the province’s energy policy, potentially altering the future of Ontario’s power generation, environmental goals, and economic prospects.

The Backdrop: Ford’s Initial Stance on Wind Power

When Doug Ford first assumed the role of Premier in 2018, his administration was marked by a strong stance against renewable energy projects, including wind power, with Ford later saying he was proud of tearing up contracts as part of this shift. Ford’s government inherited a legacy of ambitious renewable energy commitments from the previous Liberal administration under Kathleen Wynne, which had invested heavily in wind and solar energy. The Ford government, however, was critical of these initiatives, arguing that they resulted in high energy costs and a surplus of power that was not always needed.

In 2019, Ford’s government began rolling back several renewable energy projects, including wind farms, and was soon tested by the Cornwall wind farm ruling that scrutinized a cancellation. This move was driven by a promise to reduce electricity bills and cut what was perceived as wasteful spending on green energy. The cancellation of several wind projects led to frustration among environmental advocates and the renewable energy sector, who viewed the decision as a setback for Ontario’s climate goals.

The Shift: Embracing Wind Power

Fast forward to 2024, and Premier Ford’s administration is taking a markedly different approach. The recent policy shift, which moves to reintroduce renewable projects, indicates a newfound openness to wind power, reflecting a broader acknowledgment of the changing dynamics in energy needs and environmental priorities.

Several factors appear to have influenced this shift:

  1. Rising Energy Demands and Climate Goals: Ontario’s growing energy demands, coupled with the pressing need to address climate change, have necessitated a reevaluation of the province’s energy strategy. As Canada commits to reducing greenhouse gas emissions and transitioning to cleaner energy sources, wind power is increasingly seen as a crucial component of this strategy. Ford’s change in direction aligns with these national and global goals.

  2. Economic Considerations: The economic landscape has also evolved since Ford’s initial opposition to wind power. The cost of wind energy has decreased significantly over the past few years, making it a more competitive and viable option compared to traditional energy sources, as competitive wind power gains momentum in markets worldwide. Additionally, the wind energy sector promises substantial job creation and economic benefits, which are appealing in the context of post-pandemic recovery and economic growth.

  3. Public Opinion and Pressure: Public opinion and advocacy groups have played a role in shaping policy. There has been a growing demand from Ontarians for more sustainable and environmentally friendly energy solutions. The Ford administration has been responsive to these concerns, recognizing the importance of addressing public and environmental pressures.

  4. Technological Advancements: Advances in wind turbine technology have improved efficiency and reduced the impact on wildlife and local communities. Modern wind farms are less intrusive and more effective, addressing some of the concerns that were previously associated with wind power.

Implications of the Policy Shift

The implications of Ford’s shift towards wind power are far-reaching. Here are some key areas affected by this change:

  1. Energy Portfolio Diversification: By reembracing wind power, Ontario will diversify its energy portfolio, reducing its reliance on fossil fuels and increasing the proportion of renewable energy in the mix. This shift will contribute to a more resilient and sustainable energy system.

  2. Environmental Impact: Increased investment in wind power will contribute to Ontario’s efforts to combat climate change. Wind energy is a clean, renewable source that produces no greenhouse gas emissions during operation. This aligns with broader environmental goals and helps mitigate the impact of climate change.

  3. Economic Growth and Job Creation: The wind power sector has the potential to drive significant economic growth and create jobs. Investments in wind farms and associated infrastructure can stimulate local economies, particularly in rural areas where many wind farms are located.

  4. Energy Prices: While the initial shift away from wind power was partly motivated by concerns about high energy costs, including exposure to costly cancellation fees in some cases, the decreasing cost of wind energy could help stabilize or even lower electricity prices in the long term. As wind power becomes a larger component of Ontario’s energy supply, it could contribute to a more stable and affordable energy market.

Moving Forward: Challenges and Opportunities

Despite the positive aspects of this policy shift, there are challenges to consider, and other provinces have faced setbacks such as the Alberta wind farm scrapped by TransAlta that illustrate potential hurdles. Integrating wind power into the existing grid requires careful planning and investment in grid infrastructure. Additionally, addressing local concerns about wind farms, such as their impact on landscapes and wildlife, will be crucial to gaining broader acceptance.

Overall, Doug Ford’s shift towards wind power represents a significant and strategic change in Ontario’s energy policy. It reflects a broader understanding of the evolving energy landscape and the need for a sustainable and economically viable energy future. As the province navigates this new direction, the success of this policy will depend on effective implementation, ongoing stakeholder engagement, and a commitment to balancing environmental, economic, and social considerations, even as the electricity future debate continues among party leaders.

 

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Can the Electricity Industry Seize Its Resilience Moment?

Hurricane Grid Resilience examines how utilities manage outages with renewables, microgrids, and robust transmission and distribution systems, balancing solar, wind, and batteries to restore service, harden infrastructure, and improve storm response and recovery.

 

Key Points

Hurricane grid resilience is a utility approach to withstand storms, reduce outages, and speed safe power restoration.

✅ Focus on T&D hardening, vegetation management, remote switching

✅ Balance generation mix; integrate solar, wind, batteries, microgrids

✅ Plan 12-hour shifts; automate forecasting and outage restoration

 

When operators of Duke Energy's control room in Raleigh, North Carolina wait for a hurricane, the mood is often calm in the hours leading up to the storm.

“Things are usually fairly quiet before the activity starts,” said Mark Goettsch, the systems operations manager at Duke. “We’re anxiously awaiting the first operation and the first event. Once that begins, you get into storm mode.”

Then begins a “frenzied pace” that can last for days — like when Hurricane Florence parked over Duke’s service territory in September.

When an event like Florence hits, all eyes are on transmission and distribution. Where it’s available, Duke uses remote switching to reconnect customers quickly. As outages mount, the utility forecasts and balances its generation with electricity demand.

The control center’s four to six operators work 12-hour shifts, while nearby staff members field thousands of calls and alarms on the system. After it’s over, “we still hold our breath a little bit to make sure we’ve operated everything correctly,” said Goettsch. Damage assessment and rebuilding can only begin once a storm passes.

That cycle is becoming increasingly common in utility service areas like Duke's.

A slate of natural disasters that reads like a roll call — Willa, Michael, Harvey, Irma, Maria, Florence and Thomas — has forced a serious conversation about resiliency. And though Goettsch has heard a lot about resiliency as a “hot topic” at industry events and meetings, those conversations are only now entering Duke’s control room.

Resilience discussions come and go in the energy industry. Storms like Hurricane Sandy and Matthew can spur a nationwide focus on resiliency, but change is largely concentrated in local areas that experienced the disaster. After a few news cycles, the topic fades into the background.

However, experts agree that resilience is becoming much more important to year-round utility planning and operations as utilities pursue decarbonization goals across their fleets. It's not a fad.

“If you look at the whole ecosystem of utilities and vendors, there’s a sense that there needs to be a more resilient grid,” said Miki Deric, Accenture’s managing director of utilities, transmission and distribution for North America. “Even if they don’t necessarily agree on everything, they are all working with the same objective.”

Can renewables meet the challenge?

After Hurricane Florence, The Intercept reported on coal ash basins washed out by the storm’s overwhelming waters. In advance of that storm, Duke shut down one nuclear plant to protect it from high winds. The Washington Post also recently reported on a slowly leaking oil spill, which could surpass Deepwater Horizon in size, caused by Hurricane Ivan in 2004.

Clean energy boosters have seized on those vulnerabilities.They say solar and wind, which don’t rely on access to fuel and can often generate power immediately after a storm, provide resilience that other electricity sources do not.

“Clearly, logistics becomes a big issue on fossil plants, much more than renewable,” said Bruce Levy, CEO and president at BMR Energy, which owns and operates clean energy projects in the Caribbean and Latin America. “The ancillaries around it — the fuel delivery, fuel storage, water in, water out — are all as susceptible to damage as a renewable plant.”

Duke, however, dismissed the notion that one generation type could beat out another in a serious storm.

“I don’t think any generation source is immune,” said Duke spokesperson Randy Wheeless. “We’ve always been a big supporter of a balanced energy mix, reflecting why the grid isn't 100% renewable in practice today. That’s going to include nuclear and natural gas and solar and renewables as well. We do that because not every day is a good day for each generation source.”

In regard to performance, Wade Schauer, director of Americas Power & Renewables Research at Wood Mackenzie, said the situation is “complex.” According to him, output of solar and wind during a storm depends heavily on the event and its location.

While comprehensive data on generation performance is sparse, Schauer said coal and gas generators could experience outages at 25 percent while stormy weather might cut 95 percent of output from renewables, underscoring clean energy's dirty secret about variability under stress. Ahead of last year’s “bomb cyclone” in New England, WoodMac data shows that wind dropped to less than 1 percent of the supply mix.

“When it comes to resiliency, ‘average performance’ doesn't cut it,” said Schauer.

In the future, he said high winds could impact all U.S. offshore wind farms, since projects are slated for a small geographic area in the Northeast. He also pointed to anecdotal instances of solar arrays in New England taken out by feet of snow. During Florence, North Carolina’s wind farms escaped the highest winds and continued producing electricity throughout. Cloud cover, on the other hand, pushed solar production below average levels.

After Florence passed, Duke reported that most of its solar came online quickly, although four of its utility-owned facilities remained offline for weeks afterward. Only one was because of damage; the other three remained offline due to substation interconnection issues.

“Solar performed pretty well,” said Wheeless. “But did it come out unscathed? No.”

According to installer reports, solar systems fared relatively well in recent storms, even as the Covid-19 impact on renewables constrained projects worldwide. But the industry has also highlighted potential improvements. Following Hurricanes Maria and Irma, the Federal Emergency Management Agency published guidelines for installing and maintaining storm-resistant solar arrays. The document recommended steps such as annual checks for bolt tightness and using microinverters rather than string inverters.

Rocky Mountain Institute (RMI) also assembled a guide for retrofitting and constructing new installations. It described attributes of solar systems that survived storms, like lateral racking supports, and those that failed, like undersized and under-torqued bolts.

“The hurricanes, as much as no one liked them, [were] a real learning experience for folks in our industry,” said BMR’s Levy. “We saw what worked, and what didn’t.”          

Facing the "800-pound gorilla" on the grid

Advocates believe wind, solar, batteries and microgrids offer the most promise because they often rely less on transmitting electricity long distances and could support peer-to-peer energy models within communities.

Most extreme weather outages arise from transmission and distribution problems, not generation issues. Schauer at WoodMac called storm damage to T&D the “800-pound gorilla.”

“I'd be surprised if a single customer power outage was due to generators being offline, especially since loads where so low due to mild temperatures and people leaving the area ahead of the storm,” he said of Hurricane Florence. “Instead, it was wind [and] tree damage to power lines and blown transformers.”

 

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