Power contracts a source of regret

By Orillia Packet & Times


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Like more than a million consumers in Ontario, Dave and Heather Murdock were persuaded by a front-door sales pitch to buy electricity from an energy retailer.

"They let on prices were going to go sky high," Heather Murdock said.

"They were so convincing, we thought, 'Holy crow, we better do something.'"

Now the Murdocks, who live in a new home on Andrew Street built by Habitat for Humanity, are paying 60% more for their electricity than if they had stuck with the Orillia Power Corporation (OPC).

Under the five-year contract signed with a Toronto-based retailer, the Murdocks pay 7.99 cents a kilowatt hour for electricity, three cents more than the five-cent regulated price currently charged by OPC and other municipal utilities across the province.

The leap in prices predicted by the private electricity salesman has not happened.

The Murdocks, who have two children, were living with Heather's parents before they moved into their new house, built as a community project.

"We are the working poor," said Heather, who works for a local household cleaning company.

"We're trying to make ends meet."

The Murdocks also signed up to buy natural gas from the same retailer.

When they got behind in their gas and electric payments, they were forced to seek emergency assistance from the Housing Resource Centre in downtown Orillia.

"Every month our bill was close to $250 to $300."

People on low incomes who get locked into paying far more for electricity than they would through the local utility can quickly get into financial trouble, said Nadine Ritchie, co-ordinator of the resource centre at 33 Mississaga St. E.

"They get into a contract and find their bills have almost doubled. It's a factor, absolutely, in payments becoming unmanageable."

Seniors on fixed incomes are particularly vulnerable to pitches about vaulting electricity costs, Ritchie said.

"They're so afraid because they're on such tight incomes to begin with."

Murdock thinks consumers need to be protected from slick sales people who arrive unbidden at their doors and make dubious claims about the electricity market, disguising exploitation as protection.

"The government should step in," he said.

"These people are taking advantage."

Two retailers, Universal Energy Corporation from Toronto and Summit Energy Management from Mississauga were fined a combined $300,000 earlier this year for making false, misleading or deceptive statements to customers.

But despite the evidence of improper business practices, contracts signed with retailers are still considered valid.

To break their contract, the Murdocks would have to pay a penalty of $500 to $1,000 dollars.

"We're still locked in," Heather Murdock said.

John Mattinson, president of the Orillia Power Corporation, said the municipally owned utility advises customers to read retail electricity contracts very carefully.

"We are aware there has been some misleading information given to some of our customers who have signed up (with retailers)."

Gus Diamantakos, owner of George's Country Restaurant on Colborne Street, said he did well buying natural gas through an energy retailer.

"I was at 28 cents when everybody else was at 42 cents."

But there have been no comparable savings with retail electricity, he said.

"My bills are almost double." Orillia city councillor Maurice McMillan says electricity prices have been regulated since 2002, eliminating the rationale to buy from retailers.

"It's like buying insurance for the moon to fall."

McMillan thinks the electricity retailers should have their licence to peddle their services door-to-door revoked, but the municipality does not have the authority to enact such a ban.

With hundreds of residential consumers in Orillia locked into retail contracts paying $30 more per 1,000 kilowatts of electricity, McMillan estimated $100,000 is being skimmed off local power customers every month.

McMillan did succeed recently in convincing council to pass a resolution asking the Ministry of Energy and Infrastructure to crack down on door-to-door retailing of electricity.

Simcoe North MPP Garfield Dunlop, whose constituency office has received many complaints about aggressive retailers, advises local residents to stay with the local electrical utility.

"At the end of the day, the Ministry of Energy may have to be more forceful with retailers and how business is done by these people," Dunlop said.

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Latvia eyes electricity from Belarus nuclear plant

Latvia Astravets electricity imports weigh AST purchases from the Belarusian nuclear plant, impacting the Baltic grid, Lithuania market, energy security, and cross-border trading as Latvia seeks to mitigate supply risks and stabilize power flows.

 

Key Points

Proposed AST purchases of power from Belarus's Astravets plant to bolster Baltic grid supply via Lithuania.

✅ AST evaluates imports to mitigate supply risk

✅ Energy could enter Lithuania via existing trading route

✅ Debate centers on nuclear safety and Baltic grid impacts

 

Latvia’s electricity transmission system operator, AST, is looking at the possibility of purchasing electricity from the soon-to-be completed Belarusian nuclear power plant in Astravets, at a time when Ukraine's electricity exports have resumed in the region, long criticised by the Lithuanian government, Belsat TV has reported.

According to the Latvian media, the Latvian government is seeking to mitigate the risk of a possible drop in electricity supplies amid price spikes in Ireland highlighting dispatchable power concerns, given that energy trading between the Baltic states and third parties is currently carried out only through the Belarusian-Lithuanian border, including Latvian imports from Lithuania.

If AST starts importing electricity from the Belarusian plant to Latvia, in a pattern similar to Georgia's electricity imports during peak demand, the energy is expected to enter the Lithuanian market as well.

Such cross-border flows also mirror responses to Central Asia's electricity shortages seen recently.

The Lithuanian government has repeatedly criticised the nuclear power over national security and environmental safety concerns, as well as a number of emergencies that took place during construction, particularly as Europe is losing nuclear power and confronting energy security challenges.

Debates over infrastructure and safety have also intensified by projects like power lines to reactivate Zaporizhzhia in Ukraine.

The first Astravets reactor, which is being built close to the Lithuanian border in the Hrodno region, is expected to be operational by the end of 2019, a year that saw Belgium's nuclear exports rise across Europe.

 

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Duke Energy Florida to build its largest battery storage projects yet

Duke Energy Florida battery storage will add 22 MW across Trenton, Cape San Blas and Jennings, improving grid reliability, outage resilience, enabling peak shaving and deferring distribution upgrades to increase efficiency and customer value.

 

Key Points

Three lithium battery projects totaling 22 MW to improve Florida grid reliability, outage resilience and efficiency.

✅ 22 MW across Trenton, Cape San Blas and Jennings sites

✅ Enhances outage resilience and grid reliability

✅ Defers costly distribution upgrades and improves efficiency

 

Duke Energy Florida (DEF) has announced three battery energy storage projects, totaling 22 megawatts, that will improve overall reliability and support critical services during power outages.

Duke Energy, the nation's largest electric utility, unveils its new logo. (PRNewsFoto/Duke Energy) (PRNewsfoto/Duke Energy)

Collectively, the storage facilities will enhance grid operations, increase efficiencies and improve overall reliability for surrounding communities, with virtual power plant programs offering a model for coordinating distributed resources.

They will also provide important backup generation during power outages, a service that is becoming increasingly important with the number and intensity of storms that have recently impacted the state.

As the grid manager and operator, DEF can maximize the versatility of battery energy storage systems (BESS) to include multiple customer and electric system benefits such as balancing energy demand, managing intermittent resources, increasing energy security and deferring traditional power grid upgrades.

These benefits help reduce costs for customers and increase operational efficiencies.

The 11-megawatt (MW) Trenton lithium-based battery facility will be located 30 miles west of Gainesville in Gilchrist County. The energy storage project will continue to improve power reliability using newer technologies.

The 5.5-MW Cape San Blas lithium-based battery facility will be located approximately 40 miles southeast of Panama City in Gulf County. The project will provide additional power capacity to meet our customers' rising energy demand in the area. This project is an economical alternative to replacing distribution equipment necessary to accommodate local load growth.

The 5.5-MW Jennings lithium-based battery facility will be located 1.5 miles south of the Florida-Georgia border in Hamilton County. The project will continue to improve power reliability through energy storage as an alternative solution to installing new and more costly distribution equipment.

Currently the company plans to complete all three projects by the end of 2020.

"These battery projects provide electric system benefits that will help improve local reliability for our customers and provide significant energy services to the power grid," said Catherine Stempien, Duke Energy Florida state president. "Duke Energy Florida will continue to identify opportunities in battery storage technology which will deliver efficiency improvements to our customers."

 

Additional renewables projects

As part of DEF's commitment to renewables, the company is investing an estimated $1 billion to construct or acquire a total of 700 MW of cost-effective solar power facilities and 50 MW of battery storage through 2022.

Duke Energy is leading the industry deployment of battery technology, with SDG&E's Emerald Storage project underscoring broader adoption across the sector today. Last fall, the company and University of South Florida St. Petersburg unveiled a Tesla battery storage system that is connected to a 100-kilowatt (kW) solar array – the first of its kind in Florida.

This solar-battery microgrid system manages the energy captured by the solar array, situated on top of the university's parking garage, and similar low-income housing microgrid financing efforts are expanding access. The solar array was constructed three years ago through a $1 million grant from Duke Energy. The microgrid provides a backup power source during a power outage for the parking garage elevator, lights and electric vehicle charging stations. Click here to learn more.

In addition to expanding its battery storage technology and solar investments, DEF is investing in transportation electrification to support the growing U.S. adoption of electric vehicles (EV), including EV charging infrastructure, 530 EV charging stations and a modernized power grid to deliver the diverse and reliable energy solutions customers want and need.

 

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Cost of US nuclear generation at ten-year low

US Nuclear Generating Costs 2017 show USD33.50/MWh for nuclear energy, the lowest since 2008, as capital expenditures, fuel costs, and operating costs declined after license renewals and uprates, supporting a reliable, low-carbon grid.

 

Key Points

The 2017 US nuclear average was USD33.50/MWh, lowest since 2008, driven by reduced capital, fuel, and operating costs.

✅ Average cost USD33.50/MWh, lowest since 2008

✅ Capital, fuel, O&M costs fell sharply since 2012 peak

✅ License renewals, uprates, market reforms shape competitiveness

 

Average total generating costs for nuclear energy in 2017 in the USA were at their lowest since 2008, according to a study released by the Nuclear Energy Institute (NEI), amid a continuing nuclear decline debate in other regions.

The report, Nuclear Costs in Context, found that in 2017 the average total generating cost - which includes capital, fuel and operating costs - for nuclear energy was USD33.50 per megawatt-hour (MWh), even as interest in next-generation nuclear designs grows among stakeholders. This is 3.3% lower than in 2016 and more than 19% below 2012's peak. The reduction in costs since 2012 is due to a 40.8% reduction in capital expenditures, a 17.2% reduction in fuel costs and an 8.7% reduction in operating costs, the organisation said.

The year-on-year decline in capital costs over the past five years reflects the completion by most plants of efforts to prepare for operation beyond their initial 40-year licence. A few major items - a series of vessel head replacements; steam generator replacements and other upgrades as companies prepared for continued operation, and power uprates to increase output from existing plants - caused capital investment to increase to a peak in 2012. "As a result of these investments, 86 of the [USA's] 99 operating reactors in 2017 have received 20-year licence renewals and 92 of the operating reactors have been approved for uprates that have added over 7900 megawatts of electricity capacity. Capital spending on uprates and items necessary for operation beyond 40 years has moderated as most plants are completing these efforts," it says.

Since 2013, seven US nuclear reactors have shut down permanently, with the Three Mile Island debate highlighting wider policy questions, and another 12 have announced their permanent shutdown. The early closure for economic reasons of reliable nuclear plants with high capacity factors and relatively low generating costs will have long-term economic consequences, the report warns: replacement generating capacity, when needed, will produce more costly electricity, fewer jobs that will pay less, and, for net-zero emissions objectives, more pollution, it says.

NEI Vice President of Policy Development and Public Affairs John Kotek said the "hardworking men and women of the nuclear industry" had done an "amazing job" reducing costs through the institute's Delivering the Nuclear Promise campaign and other initiatives, in line with IAEA low-carbon lessons from the pandemic. "As we continue to face economic headwinds in markets which do not properly compensate nuclear plants, the industry has been doing its part to reduce costs to remain competitive," he said.

"Some things are in urgent need of change if we are to keep the nation's nuclear plants running and enjoy their contribution to a reliable, resilient and low-carbon grid. Namely, we need to put in place market reforms that fairly compensate nuclear similar to those already in place in New York, Illinois and other states," Kotek added.

Cost information in the study was collected by the Electric Utility Cost Group with prior years converted to 2017 dollars for accurate historical comparison.

 

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Canada Invests Over $960-Million in Renewable Energy and Grid Modernization Projects

Smart Renewables and Electrification Pathways Program enables clean energy and grid modernization across Canada, funding wind, solar, hydro, geothermal, tidal, and storage to cut GHG emissions and accelerate electrification toward a net-zero economy.

 

Key Points

A $964M Canadian program funding clean power and grid upgrades to cut emissions and build net-zero electrified economy.

✅ Funds wind, solar, hydro, geothermal, tidal, and storage projects

✅ Modernizes grids for reliability, digitalization, and resilience

✅ Supports net-zero by 2050 with Indigenous and utility partners

 

Harnessing Canada's immense clean energy resources requires transformational investments to modernize our electricity grid. The Government of Canada is investing in renewable energy and upgrading the electricity grid, moving toward an electric, connected and clean economy, to make clean, affordable electricity options more accessible in communities across Canada.

The Honourable Seamus O'Regan Jr., Minister of Natural Resources, today launched a $964-million program, alongside a recent federal green electricity contract in Alberta that underscores momentum, to support smart renewable energy and grid modernization projects that will lower emissions by investing in clean energy technologies, like wind, solar, storage, hydro, geothermal and tidal energy across Atlantic Canada.

The Smart Renewables and Electrification Pathways Program (SREPs) supports building Canada's low-emissions energy future and a renewable, electrified economy through projects that focus on non-emitting, cleaner energy technologies, such as storage, and modernizing electricity system operations.

Investing in these technologies reduces greenhouse gas emissions by creating a cleaner, more connected electrical system, supporting progress toward zero-emissions electricity by 2035 goals, while helping Canada reach net-zero emissions by 2050.

Minister O'Regan launched the program during the Canadian Electricity Association's (CEA) virtual regulatory forum on Electricity Regulation & the Four Disruptors – Decarbonization, Decentralization, Digitalization and Democratization, highlighting evolving regulatory approaches as B.C. streamlines clean energy approvals to support deployment nationwide. The launch also coincides with Canadian Environment Week, which celebrates Canada's environmental accomplishments and encourages Canadians to contribute to conserving and protecting the environment.

Through SREPs and other programming, the government is working with provinces and territories, with the Prairie Provinces leading renewable growth in the years ahead, utilities, Indigenous partners and others, including diverse businesses and communities, to deliver these clean and reliable energy initiatives. With Canadian innovation, technology and skilled energy workers, we can provide more communities, households and businesses with an increased supply of clean electricity and a cleaner electrical grid.

To help interested stakeholders find information on SREPs, a new webpage has been launched, which includes a comprehensive guide for eligible projects.

This supports Canada's strengthened climate plan, A Healthy Environment and a Healthy Economy. Canada is advancing projects that support the clean grid of the future and seize opportunities in the global electricity market to boost competitiveness. Collectively with investments from the Fall Economic Statement 2020 and Budget 2021, Canada will achieve our climate change commitments and ensure a healthier environment and more prosperous economy for future generations.

 

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In North Carolina, unpaid electric and water bills are driving families and cities to the financial brink

North Carolina Utility Arrears Crisis strains households and municipal budgets as COVID-19 cuts jobs; unpaid utility bills mount, shutoffs loom, and emergency aid, unemployment benefits, and CARES Act relief lag behind rising arrears across cities.

 

Key Points

A COVID-19 driven spike in unpaid utility bills, threatening households and municipal budgets as federal aid lapses.

✅ 1 million families behind on power, water, sewage bills

✅ $218M arrears accrued April to June, double last year

✅ Municipal utilities face shutoffs, budget shortfalls

 

As many as 1 million families in North Carolina have fallen behind on their electric, water and sewage bills, a sign of energy insecurity threatening residents and their cities with severe financial hardship unless federal lawmakers act to approve more emergency aid.

The trouble stems from the widespread economic havoc wrought by the coronavirus, which has left millions of workers out of a job and struggling to cover their monthly costs as some states moved to suspend utility shut-offs to provide relief. Together, they’ve been late or missed a total of $218 million in utility payments between April 1 and the end of June, according to data released recently by the state, nearly double the amount in arrears at this time last year.

In some cases, cities that own or operate their own utilities have been forced to absorb these losses, as some utilities reconnected customers to prevent harm, creating a dire situation in which the government’s attempt to save people from the financial brink instead has pushed municipal coffers to their own breaking point.

In Elizabeth City, N.C., for example, about 2,500 residents haven’t paid their electric bills on time, according to Richard Olson, the city manager. The late payments at one point proved so problematic that Olson said he calculated Elizabeth City wouldn’t have enough money to pay for its expenses in July. In response, city leaders requested and obtained a waiver from a statewide order, similar to New York’s disconnection moratorium, issued in March, that protects people from being penalized for their past-due utility bills.

The predicament has presented unique budget challenges throughout North Carolina, while illustrating the consequences of a cash crunch plaguing the entire country, where proposals such as a Texas electricity market bailout surfaced following severe grid stress. State and federal leaders have extended a range of coronavirus relief programs since March to try to help people through the pandemic. But the money is limited and restricted — and it’s not clear whether more help from Congress is on the way — creating a crisis in which the nation’s economic woes are outpacing some of the aid programs adopted to combat them.

“We are entering a phase where the utilities [may] be able to shut off power, but what was propping up people’s economic lives, the unemployment benefits and Cares Act support, won’t be there,” said Paul Meyer, the executive director of the North Carolina League of Municipalities.

White House, GOP in disarray over coronavirus spending plan as deadline nears on expiring emergency aid

The future of that safety-net support — and other federal aid — hangs in the balance as lawmakers returned to work this week in their final sprint ahead of the August recess. The White House and congressional leaders are split over the contours of the next coronavirus relief package, including the need to extend more aid to cities and states as some utilities have waived fees to help customers, and reauthorize an extra $600 in weekly unemployment payments that were approved as part of the Cares Act in March.

Outside Washington, workers, businesses and government officials nationwide have pleaded with federal lawmakers to renew or expand those programs. Last week, Roy Cooper, the Democratic governor of North Carolina, urged Congress to act swiftly and adopt a wide array of new federal spending, including proposals for DOE nuclear cleanup funding, stressing in a letter that the “actions you take in the next few weeks are vital to our ability to emerge from this crisis. ”

 

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BMW boss says hydrogen, not electric, will be "hippest thing" to drive

BMW Hydrogen Fuel Cell Strategy positions iX5 and eDrive for zero-emission mobility, leveraging fuel cells, fast refueling, and hydrogen infrastructure as an alternative to BEVs, diversifying drivetrains across premium segments globally, rapidly.

 

Key Points

BMW's plan to commercialize hydrogen fuel-cell drivetrains like iX5 eDrive for scalable, zero-emission mobility.

✅ Fuel cells enable fast refueling and long range with water vapor only.

✅ Reduces reliance on lithium and cobalt via recyclable materials.

✅ Targets premium SUV iX5; limited pilots before broader rollout.

 

BMW is hanging in there with hydrogen, a stance mirrored in power companies' hydrogen outlook today. That’s what Oliver Zipse, the chairperson of BMW, reiterated during an interview last week in Goodwood, England. 

“After the electric car, which has been going on for about 10 years and scaling up rapidly, the next trend will be hydrogen,” he says. “When it’s more scalable, hydrogen will be the hippest thing to drive.”

BMW has dabbled with the idea of using hydrogen for power for years, even though it is obscure and niche compared to the current enthusiasm surrounding vehicles powered by electricity. In 2005, BMW built 100 “Hydrogen 7” vehicles that used the fuel to power their V12 engines. It unveiled the fuel cell iX5 Hydrogen concept car at the International Motor Show Germany in 2021. 

In August, the company started producing fuel-cell systems for a production version of its hydrogen-powered iX5 sport-utility vehicle. Zipse indicated it would be sold in the United States within the next five years, although in a follow-up phone call a spokesperson declined to confirm that point. Bloomberg previously reported that BMW will start delivering fewer than 100 of the iX5 hydrogen vehicles to select partners in Europe, the U.S., and Asia, where Asia leads on hydrogen fuel cells today, from the end of this year.

All told, BMW will eventually offer five different drivetrains to help diversify alternative-fuel options within the group, as hybrids gain renewed momentum in the U.S., Zipse says.

“To say in the U.K. about 2030 or the U.K. and in Europe in 2035, there’s only one drivetrain, that is a dangerous thing,” he says. “For the customers, for the industry, for employment, for the climate, from every angle you look at, that is a dangerous path to go to.” 

Zipse’s hydrogen dreams could even extend to the group’s crown jewel, Rolls-Royce, which BMW has owned since 1998. The “magic carpet ride” driving style that has become Rolls-Royce’s signature selling point is flexible enough to be powered by alternatives to electricity, says Rolls-Royce CEO Torsten Müller-Ötvös. 

“To house, let’s say, fuel cell batteries: Why not? I would not rule that out,” Müller-Ötvös told reporters during a roundtable conversation in Goodwood on the eve of the debut of the company’s first-ever electric vehicle, Spectre. “There is a belief in the group that this is maybe the long-term future.”

Such a vehicle would contain a hydrogen fuel-cell drivetrain combined with BMW’s electric “eDrive” system. It works by converting hydrogen into electricity to reach an electrical output of up to 125 kW/170 horsepower and total system output of nearly 375hp, with water vapor as the only emission, according to the brand.

Hydrogen’s big advantage over electric power, as EVs versus fuel cells debates note, is that it can supply fuel cells stored in carbon-fiber-reinforced plastic tanks. “There will [soon] be markets where you must drive emission-free, but you do not have access to public charging infrastructure,” Zipse says. “You could argue, well you also don’t have access to hydrogen infrastructure, but this is very simple to do: It’s a tank which you put in there like an old [gas] tank, and you recharge it every six months or 12 months.”

Fuel cells at BMW would also help reduce its dependency on raw materials like lithium and cobalt, because the hydrogen-based system uses recyclable components made of aluminum, steel, and platinum. 

Zipse’s continued commitment to prioritizing hydrogen has become an increasingly outlier position in the automotive world. In the last five years, electric-only vehicles have become the dominant alternative fuel — as the age of electric cars dawns ahead of schedule — if not yet on the road, where fewer than 3% of new cars have plugs, at least at car shows and new-car launches.

Rivals Mercedes-Benz and Audi scrapped their own plans to develop fuel cell vehicles and instead have poured tens of billions of dollars into developing pure-electric vehicle, including Daimler's electrification plan initiatives. Porsche went public to finance its own electric aspirations. 

BMW will make half of all new-car sales electric by 2030 across the group, with many expecting most drivers to go electric within a decade, which includes MINI and Rolls-Royce. 
 

 

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