FPL uses simulations to prepare for hurricane season

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With the 2009 hurricane season almost here, Florida Power & Light Company conducted the final exercise in its annual, company-wide preparations for emergency response and restoration in the event that severe storms make landfall in FPLÂ’s service territory.

While almost three and a half years have passed since a major hurricane inflicted significant damage on the state, FPL continues to take storm season preparation extremely seriously, working to advance its restoration capabilities and continuously investing in improvements to the reliability and resiliency of our infrastructure.

FPL’s comprehensive storm plan focuses on readiness, restoration and recovery in order to respond safely and as quickly as possible if a hurricane strikes our service territory. A key annual component of FPL’s constant preparation for a real storm, the hurricane “dry run” serves as the company’s final major milestone event in advance of the June 1 start of hurricane season.

“Florida Power & Light employees know our customers count on us to restore power and help get their lives back to normal after a destructive storm. While no utility can ever be 100 percent storm proof, FPL has a plan of action, and we train rigorously so we are prepared to implement that plan during storm season,” said Irene White, FPL’s director of customer support. “If a hurricane strikes, FPL will be on the job around the clock to restore service as quickly as possible after the storm to each and every one of our customers.”

Employees from across the company participated in the dry run to practice the companyÂ’s emergency plan, which includes tracking outages, assessing damage, communicating with customers and employees and initiating the service restoration plan. Throughout the simulation, FPL tested its storm plans and tactics, applying lessons learned from previous hurricanes and other extreme weather events.

This year’s virtual hurricane, “Alpha,” was a storm that formed in the Atlantic and made landfall in South Florida near the Broward-Miami-Dade County line as a strong Category 2. The storm moved east to west across the state before exiting near Long Boat Key into the Gulf of Mexico. Shortly after Alpha’s exit, another storm, Hurricane Bravo, threatened the Alabama and Northwest Florida coastal region. Despite being outside FPL’s service area, the second storm created the additional challenge of reduced restoration resources as backup crews were diverted.

To make the exercise as real as possible, FPL computers generated damage estimates for the fictional scenario. These estimates were based on scientific modeling, which included other potential real-life factors such as post-storm weather, gas supplies and school opening goals to test the ability of the team to remain flexible but focused on the ultimate mission: restoring power to customers safely and as quickly as possible.

FPL works year-round to prepare for hurricane season, conducting extensive training to prepare its employees to respond safely and as quickly as possible if a hurricane strikes our service territory and working with suppliers to stock up on poles, wires and other electrical equipment that might be needed in the event of a storm.

FPL reviews its inventory of lodging and food vendors that are called upon to house and feed the thousands of men and women who contribute to a restoration effort that can last weeks. The company coordinates assistance agreements with other utilities for out-of-state support and secures staging sites throughout its 35-county service area in advance, enabling the company to rapidly deploy equipment and crews to storm-damaged communities.

In addition, FPL works closely with emergency operations officials throughout the state to update information on infrastructure and facilities that are critical to the community, such as hospitals, police, fire, communications, water treatment plants and transportation providers.

The company also conducts extensive vegetation clearing, pole inspections and other infrastructure work as part of a comprehensive, multi-year program to increase the resilience of the electrical system so it can better withstand the high winds experienced in specific areas.

When outages occur, FPL knows its customers and their families want and need information about when their power will be restored so they can plan. After a major storm, FPL works to restore power as soon as it is safe to begin and provides its best estimates of when service will be restored.

Immediately following a storm, FPL deploys field teams to conduct neighborhood-by-neighborhood damage assessments. This helps FPL assign the right resources, crews and materials to each effort and provide customers an estimate of when repairs will be finished and power will be restored in their area.

Restoration work is not based on when a customer calls to report an outage, where someone lives or the status of an account. Instead, FPL follows a process that restores power to the largest number of customers first while taking into consideration the welfare and urgent needs of communities:

• FPL initiates the restoration process by repairing damage to power generation plants and lines that carry power from the plants.

• Concurrently, the company focuses on repairing poles and lines that serve critical infrastructure, such as hospitals, police, fire, communications, water, sanitary and transportation services.

• The company works to return service to the largest number of customers in the shortest amount of time – including service to the main thoroughfares that host supermarkets, gas stations and other priority community services.

• This is followed by the next largest number of customers until crews converge in the hardest hit areas.

In 2009, FPL will aim to provide the public with restoration information in the following timeframes, depending on the severity of a storm:

• Within hours after the storm passes, FPL will provide a preliminary estimate of how long it will take to restore service based on its models and historical information from similar storms.

• Within 24 hours after a storm, based on the information available at the time, FPL will provide an initial estimate of how long it will take for the entire restoration to be completed.

• Within 48 hours, FPL will provide restoration information on a county-by-county basis.

• Within 72 to 96 hours, FPL will work to provide information on a sub-county level.

As the restoration gets under way following a storm, customers are advised to monitor local media and www.FPL.com for specific reports on progress assessing and repairing damage to the electric system in their areas.

• Area Command Center – From this location, FPL manages the restoration efforts throughout its 35-county service area to get the power back on for its customers. The Area Command Center provides instruction to personnel at staging sites and service centers on the best plan for restoring power to communities.

• Work Bases – These are the staging sites and service centers that house the thousands of restoration crews and support personnel who are executing the restoration plan. Potential sites across the state are pre-selected before storm season.

• Logistics – The logistics team provides support to the staging sites, securing services such as materials, food, water and housing.

Safety is FPLÂ’s first priority before, during and after a storm. FPL advises its customers to learn all they can about how to prepare for a storm, what to do during a storm, and how to make safety a priority after a storm when utilities and community services may be interrupted.

• Residents are advised to be self-sufficient for three to 14 days and to keep a battery-operated radio on hand with a two-week supply of fresh batteries. A battery-operated radio may be the only way to receive emergency public information if a devastating storm strikes.

• Prior to storm season, put your FPL account number and FPL’s phone number (1-800-4-OUTAGE or 1-800-468-8243) in a secure location that will be readily available in case you need to call. By knowing your account number, you will be able to quickly access your account and receive important information through FPL’s automated system.

• If you plan to operate a portable generator in the event of an outage at your home, wait until the storm has passed and be sure to set the generator up outside and connect appliances directly to it. Do not wire your generator directly to your breaker or fuse box because the power you generate can flow back into power lines and cause injuries. Only a licensed electrician should connect a generator to a main electrical panel. Never operate a generator inside your home or even in the garage, and keep it well away from open windows so exhaust does not enter your home or a neighbor’s home.

• Stay away from downed lines, flooding and debris. Don’t walk in standing water, and don’t venture out in the dark because you might not see a power line that could still be energized and dangerous. If you see a downed power line, call 911 or 1-800-4-OUTAGE.

• For additional safety tips, visit www.FPL.com/storm, and remember to always follow the advice of your local emergency management officials.

Right after a storm, weÂ’ll know if damage to large power lines has interrupted your service. Stay tuned to local radio, TV and newspapers for specific reports on FPLÂ’s progress in assessing and repairing damage to the electrical system in your area.

Please help us keep the phone lines open for emergencies by calling FPL only to report dangerous situations such as downed power lines or sparking electrical equipment.

If power has been restored to your neighborhood but your home is still without power, please visually inspect the following before calling FPL:

• all circuit breakers and fuses – if you have significant water damage that might make it unsafe to check these, call a licensed electrician for assistance.

• the area outside your home or office near the meter – if the meter, piping or wires appear missing or damaged, call a licensed electrician for advice.

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Ukraine has electricity reserves, no more outages planned if no new strikes

Ukraine Electricity Outages may pause as the grid stabilizes, with energy infrastructure repairs, generators, and reserves supporting supply; officials cite no rationing absent new Russian strikes, while Odesa networks recover and Ukrenergo completes restoration works.

 

Key Points

Planned power cuts in Ukraine paused as grid capacity, repairs, and reserves improve, barring new strikes.

✅ No rationing if Russia halts strikes on energy infrastructure

✅ Grid repairs and reserves meet demand for third straight week

✅ Odesa networks restored; Ukrenergo crews redeploy to repairs

 

Ukraine plans no more outages to ration electricity if there are no new strikes and has been able to amass some power reserves, the energy minister said on Saturday, as it continues to keep the lights on despite months of interruptions caused by Russian bombings.

"Electricity restrictions will not be introduced, provided there are no Russian strikes on infrastructure facilities," Energy Minister Herman Halushchenko said in remarks posted on the ministry's Telegram messaging platform.

"Outages will only be used for repairs."

After multiple battlefield setbacks and scaling down its troop operation to Ukraine's east and south, Russia in October began bombing the country's energy infrastructure, as winter loomed over the battlefront, leaving millions without power and heat for days on end.

The temperature in winter months often stays below freezing across most of Ukraine. Halushchenko said this heating season has been extremely difficult.

"But our power engineers managed to maintain the power system, and for the third week in a row, electricity generation has ensured consumption needs, we have reserves," Halushchenko said.

Ukraine, which does not produce power generators itself, has imported and received thousands of them over the past few years, with the U.S. pledging a further $10 billion on Friday to aid Kyiv's energy needs, despite ended grid restoration support reported earlier.

Separately, the chief executive of state grid operator Ukrenergo, Volodymyr Kudrytskyi, said that repair works on the damaged infrastructure in the city of Odesa suffered earlier this month, has been finished, highlighting how Ukraine has even helped Spain amid blackouts while managing its own network challenges.

"Starting this evening, there is more light in Odesa," Kudrytskyi wrote on his Facebook page. "The crews that worked on restoring networks are moving to other facilities."

A Feb. 4 fire that broke out at an overloaded power station left hundreds of thousands of residents without electricity, prompting many to adopt new energy solutions to cope with outages.

 

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Ontario explores possibility of new, large scale nuclear plants

Ontario Nuclear Expansion aims to meet rising electricity demand and decarbonization goals, complementing renewables with energy storage, hydroelectric, and SMRs, while reducing natural gas reliance and safeguarding grid reliability across the province.

 

Key Points

A plan to add large nuclear capacity to meet demand, support renewables, cut gas reliance, and maintain grid reliability

✅ Adds firm, low-carbon baseload to complement renewables

✅ Reduces reliance on natural gas during peak and outages

✅ Requires public and Indigenous engagement on siting

 

Ontario is exploring the possibility of building new, large-scale nuclear plants in order to meet increasing demand for electricity and phase out natural gas generation.

A report late last year by the Independent Electricity System Operator found that the province could fully eliminate natural gas from the electricity system by 2050, starting with a moratorium in 2027, but it will require about $400 billion in capital spending and more generation including new, large-scale nuclear plants.

Decarbonizing the grid, in addition to new nuclear, will require more conservation efforts, more renewable energy sources and more wind and solar power sources and more energy storage, the report concluded.

The IESO said work should start now to assess the reliability of new and relatively untested technologies and fuels to replace natural gas, and to set up large, new generation sources such as nuclear plants and hydroelectric facilities.

The province has not committed to a natural gas moratorium or phase-out, or to building new nuclear facilities other than its small modular reactor plans, but it is now consulting on the prospect.

A document recently posted to the government’s environmental registry asks for input on how best to engage the public and Indigenous communities on the planning and location of new generation and storage facilities.

Building new nuclear plants is “one pathway” toward a fully electrified system, Energy Minister Todd Smith said in an interview.

“It’s a possibility, for sure, and that’s why we’re looking for the feedback from Ontarians,” he said. “We’re considering all of the next steps.”

Environmental groups such as Environmental Defence oppose new nuclear builds, as well as the continued reliance on natural gas.

“The IESO’s report is peddling the continued use of natural gas under the guise of a decarbonization plan, and it takes as a given the ramping up of gas generation and continues to rely on gas generated electricity until 2050, which is embarrassingly late,” said Lana Goldberg, Environmental Defence’s Ontario climate program manager.

“Building new nuclear is absurd when we have safe and much cheaper alternatives such as wind and solar power.”

The IESO has said the flexibility natural gas provides, alongside new gas plants, is needed to keep the system stable while new and relatively untested technologies are explored and new infrastructure gets built, but also as an electricity supply crunch looms.

Ontario is facing a shortfall of electricity with the Pickering nuclear station set to be retired, others being refurbished, and increasing demands including from electric vehicles, new electric vehicle and battery manufacturing, electric arc furnaces for steelmaking, and growth in the greenhouse and mining industries.

The government consultation also asks whether “additional investment” should be made in clean energy in the short term in order to decrease reliance on natural gas, “even if this will increase costs to the electricity system and ratepayers.”

But Smith indicated the government isn’t keen on higher costs.

“We’re not going to sacrifice reliability and affordability,” he said. “We have to have a reliable and affordable system, otherwise we won’t have people moving to electrification.”

The former Liberal government faced widespread anger over high hydro bills _ highlighted often by the Progressive Conservatives, then in Opposition — driven up in part by long-term contracts at above-market rates with clean power producers secured to spur a green energy transition.

 

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Alberta's Last Coal Plant Closes, Embracing Clean Energy

Alberta Coal Phase-Out signals a clean energy transition, replacing coal with natural gas and renewables, cutting greenhouse gas emissions, leveraging a carbon levy, and supporting workers in Alberta's evolving electricity market.

 

Key Points

Alberta Coal Phase-Out moves power from coal to lower-emission natural gas and renewables to reduce grid emissions.

✅ Last coal plant closed: Genesee Generating Station, Sept 30, 2023

✅ Shift to natural gas and renewables lowers emissions

✅ Carbon levy and incentives accelerated clean power build-out

 

The closure of the Genesee Generating Station on September 30, 2023, marked a significant milestone in Alberta's energy history, as the province moved to retire coal power by 2023 ahead of its 2030 provincial deadline. The Genesee, located near Calgary, was the province's last remaining coal-fired power plant. Its closure represents the culmination of a multi-year effort to transition Alberta's electricity sector away from coal and towards cleaner sources of energy.

For decades, coal was the backbone of Alberta's electricity grid. Coal-fired plants were reliable and relatively inexpensive to operate. However, coal also has a significant environmental impact. The burning of coal releases greenhouse gases, including carbon dioxide, a major contributor to climate change. Coal plants also produce air pollutants such as sulfur dioxide and nitrogen oxide, which can cause respiratory problems and acid rain, and in some regions electricity is projected to get dirtier as gas use expands.

In recognition of these environmental concerns, the Alberta government began to develop plans to phase out coal-fired power generation in the early 2000s. The government implemented a number of policies to encourage the shift from coal to cleaner energy such as natural gas and renewable energy. These policies included providing financial incentives for the construction of new natural gas plants and renewable energy facilities, as well as imposing a carbon levy on coal-fired generation.

The phase-out of coal was also driven by economic factors. The cost of natural gas has declined significantly in recent years, making it a more competitive fuel source for electricity generation as producers switch to gas under evolving market conditions. Additionally, the Alberta government faced increasing pressure from the federal government to reduce greenhouse gas emissions.

The transition away from coal has not been without its challenges. Coal mining and coal-fired power generation have long been important parts of Alberta's economy. The closure of coal plants has resulted in job losses in the affected communities. The government has implemented programs to help workers transition to new jobs in the clean energy sector.

Despite these challenges, the closure of the Genesee Generating Station is a positive development for Alberta's environment and climate. Coal-fired power generation is one of the largest sources of greenhouse gas emissions in Alberta, and recent wind generation outpacing coal underscores the sector's transformation. The closure of the Genesee is expected to result in a significant reduction in emissions, helping Alberta to meet its climate change targets.

The transition away from coal also presents opportunities for Alberta. The province has vast natural gas resources, which can be used to generate electricity with lower emissions than coal. Alberta is also well-positioned to develop renewable energy sources, such as wind power and solar power. These renewable energy sources can help to further reduce emissions and create new jobs in the clean energy sector.

The closure of the Genesee Generating Station is a significant milestone in Alberta's energy history. It represents the end of an era for coal-fired power generation in the province, a shift mirrored by the UK's last coal station going offline earlier this year. However, it also marks the beginning of a new era for Alberta's energy sector. By transitioning to cleaner sources of energy, Alberta can reduce its environmental impact and create a more sustainable energy future.

 

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Setbacks at Hinkley Point C Challenge UK's Energy Blueprint

Hinkley Point C delays highlight EDF cost overruns, energy security risks, and wholesale power prices, complicating UK net zero plans, Sizewell C financing, and small modular reactor adoption across the grid.

 

Key Points

Delays at EDF's 3.2GW Hinkley Point C push operations to 2031, lift costs to £46bn, and risk pricier UK electricity.

✅ First unit may slip to 2031; second unit date unclear.

✅ LSEG sees 6% wholesale price impact in 2029-2032.

✅ Sizewell C replicates design; SMR contracts expected soon.

 

Vincent de Rivaz, former CEO of EDF, confidently announced in 2016 the commencement of the UK's first nuclear power station since the 1990s, Hinkley Point C. However, despite milestones such as the reactor roof installation, recent developments have belied this optimism. The French state-owned utility EDF recently disclosed further delays and cost overruns for the 3.2 gigawatt plant in Somerset.

These complications at Hinkley Point C, which is expected to power 6 million homes, have sparked new concerns about the UK's energy strategy and its ambition to decarbonize the grid by 2050.

The UK government's plan to achieve net zero by 2050 includes a significant role for nuclear energy, reflecting analyses that net-zero may not be possible without nuclear and aiming to increase capacity from the current 5.88GW to 24GW by mid-century.

Simon Virley, head of energy at KPMG in the UK, stressed the importance of nuclear energy in transitioning to a net zero power system, echoing industry calls for multiple new stations to meet climate goals. He pointed out that failing to build the necessary capacity could lead to increased reliance on gas.

Hinkley Point C is envisioned as the pioneer in a new wave of nuclear plants intended to augment and replace Britain's existing nuclear fleet, jointly managed by EDF and Centrica. Nuclear power contributed about 14 percent of the UK's electricity in 2022, even as Europe is losing nuclear power across the continent. However, with the planned closure of four out of five plants by March 2028 and rising electricity demand, there is concern about potential power price increases.

Rob Gross, director of the UK Energy Research Centre, emphasized the link between energy security and affordability, highlighting the risk of high electricity prices if reliance on expensive gas increases.

The first 1.6GW reactor at Hinkley Point C, initially set for operation in 2027, may now face delays until 2031, even after first reactor installation milestones were reported. The in-service date for the second unit remains uncertain, with project costs possibly reaching £46bn.

LSEG analysts predict that these delays could increase wholesale power prices by up to 6 percent between 2029 and 2032, assuming the second unit becomes operational in 2033.

Martin Young, an analyst at Investec, warned of the price implications of removing a large power station from the supply side.

In response to these delays, EDF is exploring the extension of its four oldest plants. Jerry Haller, EDF’s former decommissioning director, had previously expressed skepticism about extending the life of the advanced gas-cooled reactor fleet, but EDF has since indicated more positive inspection results. The company had already decided to keep the Heysham 1 and Hartlepool plants operational until at least 2026.

Nevertheless, the issues at Hinkley Point C raise doubts about the UK's ability to meet its 2050 nuclear build target of 24GW.

Previous delays at Hinkley were attributed to the COVID-19 pandemic, but EDF now cites engineering problems, similar to those experienced at other European power stations using the same technology.

The next major UK nuclear project, Sizewell C in Suffolk, will replicate Hinkley Point C's design, aligning with the UK's green industrial revolution agenda. EDF and the UK government are currently seeking external investment for the £20bn project.

Compared with Hinkley Point C, Sizewell C's financing model involves exposing billpayers to some risk of cost overruns. This, coupled with EDF's track record, could affect investor confidence.

Additionally, the UK government is supporting the development of small modular reactors, while China's nuclear program continues on a steady track, with contracts expected to be awarded later this year.

 

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UK windfarms generate record amount of electricity during Storm Malik

UK Wind Power Record as Storm Malik boosts renewable electricity, with National Grid reporting 19,500 megawatts in Scotland, cutting fossil fuel use and easing market prices on the path toward net zero targets.

 

Key Points

An all-time peak in UK wind generation, reaching 19,500 MW during Storm Malik, supplying over half of electricity.

✅ Peak: 19,500 MW, over 50% of UK electricity.

✅ Driven by Storm Malik; strongest winds in Scotland.

✅ Lowered market prices; reduced fossil fuel generation.

 

The UK’s windfarms generated a new record for wind power generation over the weekend as Storm Malik battered parts of Scotland and northern England.

Wind speeds of up to 100 miles an hour recorded in Scotland's wind farms helped wind power generation to rise to a provisional all-time high of more than 19,500 megawatts – or more than half the UK’s electricity – according to data from National Grid.

National Grid’s electricity system operator said that although it recognised the new milestone towards the UK’s ‘net zero’ carbon future, where wind is leading the power mix according to recent analyses, it was “also thinking of those affected by Storm Malik”.

The deadly storm caused widespread disruption over the weekend, leaving thousands without electricity and killing two people.

Many of the areas affected by Storm Malik were also hit in December by Storm Arwen, which caused the most severe disruption to power supplies since 2005, leaving almost a million homes without power for up to 12 days.

The winter storms have followed a summer of low wind power generation across the UK and Europe, even though wind produced more electricity than coal for the first time in 2016, which caused increased use of gas power plants during a global supply shortfall.

Gas markets around the world reached record highs due to rising demand for gas, and UK electricity prices hit a 10-year high as economies have rebounded from the economic shock of the Covid-19 pandemic. In the UK, electricity market prices reached an all-time high of more than £424.60 a megawatt-hour in September, compared with an average price of £44/MWh in the same month the year before.

The UK’s weekend surge in renewable electricity helped to provide a temporary reprieve from its heavy reliance on fossil fuel generation in recent months, and on some days wind has been the main source of UK electricity, which has caused market prices to reach record highs.

The market price for electricity on Saturday fell to £150.59 pounds a megawatt-hour, the lowest level since 3 January, while UK peak power prices have risen with the price for power on Sunday, when wind was expected to fall, jumping to more than £193.50/MWh.

The new wind generation record bettered a high recorded last year when the gusty May bank holiday weekend recorded 17.6GW.

 

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Report call for major changes to operation of Nova Scotia's power grid

Nova Scotia Energy Modernization Act proposes an independent system operator, focused energy regulation, coal phase-out by 2030, renewable integration, transmission upgrades, and competitive market access to boost consumer trust and grid reliability across the province.

 

Key Points

Legislation to create an independent system operator and energy regulator, enabling coal phase-out and renewable integration.

✅ Transfers grid control from Nova Scotia Power to an ISO

✅ Establishes a focused energy regulator for multi-sector oversight

✅ Accelerates coal retirement, renewables build-out, and grid upgrades

 

Nova Scotia is poised for a significant overhaul in how its electricity grid operates, with the electricity market headed for a reshuffle as the province vows changes, following a government announcement that will strip the current electric utility of its grid access control. This move is part of a broader initiative to help the province achieve its ambitious energy objectives, including the cessation of coal usage by 2030.

The announcement came from Tory Rushton, the Minister of Natural Resources, who highlighted the recommendations from the Clean Electricity Task Force's report to make the electricity system more accountable to Nova Scotians according to the authors. The report suggests the creation of two distinct entities: an autonomous system operator for energy system planning and an independent body for energy regulation.

Minister Rushton expressed the government's agreement with these recommendations, while the premier had earlier urged regulators to reject a 14% rate hike to protect customers, stating plans to introduce a new Energy Modernization Act in the next legislative session.

Under the proposed changes, Nova Scotia Power, a privately-owned entity, will retain its operational role but will relinquish control over the electricity grid. This responsibility will shift to an independent system operator, aiming to foster competitive practices essential for phasing out coal—currently a major source of the province’s electricity.

Additionally, the existing Utility and Review Board, which recently approved a 14% rate increase despite political opposition, will undergo rebranding to become the Nova Scotia Regulatory and Appeals Board, reflecting a broader mandate beyond energy. Its electricity-related duties will be transferred to the newly proposed Nova Scotia Energy Board, which will oversee various energy sectors including electricity, natural gas, and retail gasoline.

The task force, led by Alison Scott, a former deputy energy minister, and John MacIsaac, an ex-executive of Nalcor Energy, was established by the province in April 2023 to determine the needs of the electrical system in meeting Nova Scotia's environmental goals.

Minister Rushton praised the report for providing a clear direction towards achieving the province's 2030 environmental targets and beyond. He estimated that establishing the recommended bodies would take 18 months to two years, and noted the government cannot order the utility to cut rates under current law, promising job security for current employees of Nova Scotia Power and the Utility and Review Board throughout the transition.

The report advocates for the new system operator to improve consumer trust by distancing electricity system decisions from Nova Scotia Power's corporate interests. It also critiques the current breadth of the Utility and Review Board's mandate as overly extensive for addressing the energy transition's long-term requirements.

Nova Scotia Power's president, Peter Gregg, welcomed the recommendations, emphasizing their role in the province's shift towards renewable energy, as neighboring jurisdictions like P.E.I. explore community generation to build resilience, he highlighted the importance of a focused energy regulator and a dedicated system operator in advancing essential projects for reliable customer service.

The task force's 12 recommendations also include the requirement for Nova Scotia Power to submit an annual asset management plan for regulatory approval and to produce reports on vegetation and wood pole management. It suggests the government assess Ontario's hydro policies for potential adaptation in Nova Scotia and calls for upgrades to the transmission grid infrastructure, with projected costs detailed by Stantec.

Alison Scott remarked on the comparative expense of coal power against renewable sources like wind, suggesting that investments in the grid to support renewables would be economically beneficial in the long run.

 

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