Johnvince Foods improves with green power

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The massive power blackouts across Ontario in August, 2003, left millions in the dark. Electricity costs began to soar shortly after, and it became obvious that higher costs would be long-term. The ensuing brownouts and growing bill for power generated a sense of helplessness among businesses and consumers.

Instead of just accepting that new order, Toronto-based Johnvince Foods (Planters Canada), the country's largest importer, processor and distributor of bulk and packaged nuts, dried fruits and confectionary, decided to do something about it.

In 2006, the company retrofitted a warehouse facility rather than demolish it, literally slicing the roof off to add the extra space it needed. It then installed energy-efficient lighting.

Two years later, it switched to more energy-efficient T8 fluorescent lighting in all its warehouse and supermarket facilities and is now doing the same in its offices with the help of Valuelights, a Toronto-based company that will provide Johnvince Foods with T8 fluorescent bulbs. These are not only highly energy-efficient but also have a 46,000-hour life. Valuelight, in fact, offers a six-year onsite service warranty for the bulbs.

As a result, Johnvince Foods has a 20% energy savings each month. "You have to spend money to save money," says John Logarakis, company vice-president of special projects.

You also have to have the vision. "Joe Pulla, the owner, and his family are very committed to environmental responsibility and the environment," says Mr. Logarakis, who is constantly researching new ways to improve the company's sustainability and efficiency, including examining solar energy. Part of that research involves phone calls to Toronto Hydro — which, since 2004, has become a cutting-edge leader in the energy-efficiency movement.

Toronto Hydro has pioneered a variety of conservation programs to help businesses and consumers cut energy consumption, such as the Summer Challenge for Business, which gives a 10% discount to business customers in their fall bill if they reduce their energy consumption by 10% in July and August, and the Business Incentive Program for building energy efficiency into commercial renovations.

The utility is also investing more than $1.2-billion in overhauling the city's electricity infrastructure and adding smart-grid technology that could make power outages a thing of the past.

"This technology makes the grid almost self-heal. It detects outages and does things itself to reroute electricity... to avoid outages," says Dave O'Brien, president and CEO, Toronto Hydro Corp.

As well, the smart-grid system will allow customers to be more in control of their energy costs through Smart Meters and time-of-use rates, so they can save money by shifting some of their usage to less expensive off-peak hours. Already, customers can sell back to the grid any excess electricity they generate by using such technology as solar or wind power.

Advances do not end there. Ontario is undergoing a transformation that is absolutely electrifying. With the passing of the Ontario's Green Energy Act in May, the province is promoting use of renewable energy, reducing greenhouse gas emissions, fostering green industries and jobs — and building a culture of conservation.

"The exciting thing about the future this legislation holds is that the residential and business customer now has an opportunity to become actively engaged in both energy savings for themselves but also helping the overall demand," Mr. O'Brien says.

"This is really about empowerment. It's about saying to the customer, ‘you and your utility can do something here, and we're going to make it reasonably priced.’"

"I believe the Green Act itself, once the regulations have been finalized, can bring about social change in terms of the amount of local jobs that are created as well as a deeper consciousness of sustainability in our society," says Richard Morris, manager of the City of Toronto's Energy Efficiency office. "I've had many conversations with groups and individuals who say, ‘Well, I know there's something I should do but I really don't know what and the how of doing it.’"

With the transformation now underway, those Torontonians — including small business owners — can now turn to their municipal government as well as their utility and find the resources, including financial assistance and tools, that will answer those questions.

"I see the day when we will all be as much a part of the conservation culture as we now are of the recycling culture when we walk our blue, grey and green boxes to the curb each garbage day," Mr. O'Brien says.

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Australia PM rules out taxpayer funded power plants amid energy battle

ACCC energy underwriting guarantee proposes government-backed certainty for new generation, cutting electricity prices and supporting gas, pumped hydro, renewables, batteries, and potentially coal-fired power, addressing market failure without direct subsidies.

 

Key Points

A tech-neutral, government-backed plan underwriting new generation revenue to increase certainty and cut power prices.

✅ Government guarantee provides a revenue floor for new generators.

✅ Technology neutral: coal, gas, renewables, pumped hydro, batteries.

✅ Intended to reduce bills by up to $400 and address market failure.

 

Australian Taxpayers won't directly fund any new power plants despite some Coalition MPs seizing on a new report to call for a coal-fired power station.

The Australian Competition and Consumer Commission recommended the government give financial certainty to new power plants, guaranteeing energy will be bought at a cheap price if it can't be sold, as part of an electricity market plan to avoid threats to supply.

It's part of a bid to cut up to $400 a year from average household power prices.

Prime Minister Malcolm Turnbull said the finance proposal had merit, but he ruled out directly funding specific types of power generation.

"We are not in the business of subsidising one technology or another," he told reporters in Queensland today.

"We've done enough of that. Frankly, there's been too much of that."

Renewable subsidies, designed in the 1990s to make solar and wind technology more affordable, have worked and will end in 2020.

Some Coalition MPs claim the ACCC's recommendation to underwrite power generation is vindication for their push to build new coal-fired power plants.

But ACCC chair Rod Sims said no companies had proposed building new coal plants - instead they're trying to build new gas projects, pumped hydro or renewable projects.

Opposition Leader Bill Shorten said Mr Turnbull was offering solutions years away, having overseen a rise in power prices over the past year.

"You don't just go down to K-Mart and get a coal-fired power station off the shelf," Mr Shorten told reporters, admitting he had not read the ACCC report.

Energy Minister Josh Frydenberg said the recommendation to underwrite new power generators had a lot of merit, as it would address a market failure highlighted by AEMO warnings about reduced reserves.

"What they're saying is the government needs to step in here to provide some sort of assurance," Mr Frydenberg told 9NEWS today.

He said that could include coal, gas, renewable energy or battery storage.

Deputy Nationals leader Bridget McKenzie said science should determine which technology would get the best outcomes for power bills, with a scrapping coal report suggesting it can be costly.

Mr Turnbull said there was strong support for the vast majority of the ACCC's 56 recommendations, but the government would carefully consider the report, which sets out a blueprint to cut electricity bills by 25 percent.

Acting Greens leader Adam Bandt said Australia should exit coal-fired power in favour of renewable energy to cut pollution.

In contrast, Canada has seen the Stop the Shock campaign advocate a return to coal power in some provinces.

The Australian Energy Council, which represents 21 major energy companies, said the government should consult on changes to avoid "unintended consequences".

 

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EU outlines $300 billion plan to dump Russian energy

REPowerEU Plan accelerates the EU's shift from Russian fossil fuels with renewable energy, energy efficiency, solar, wind, heat pumps, faster permits, and energy security measures by 2027, backed by grants, loans, and grid investments.

 

Key Points

EU plan to quit Russian fossil fuels via renewables and efficiency, with faster permits, by 2027.

✅ €300bn in grants and loans for efficiency and renewables

✅ Streamlined permits; solar mandate on new buildings

✅ Targets 2027 independence; cuts Russian gas, oil, coal

 

The European Union’s executive arm moved Wednesday to jump-start plans for the 27-nation bloc to abandon Russian energy amid the Kremlin’s war in Ukraine, proposing a nearly 300 billion-euro ($315 billion) package that includes more efficient use of fuels and faster rollout of renewable power, even as rolling back electricity prices remains challenging.

The European Commission’s investment initiative is meant to help the 27 EU countries start weaning themselves off Russian fossil fuels this year, a move many see as a wake-up call to ditch fossil fuels across Europe. The goal is to deprive Russia, the EU’s main supplier of oil, natural gas and coal, of tens of billions in revenue and strengthen EU climate policies.

“We are taking our ambition to yet another level to make sure that we become independent from Russian fossil fuels as quickly as possible,” European Commission President Ursula von der Leyen said in Brussels when announcing the package, dubbed REPowerEU.

With no end in sight to Russia’s war in Ukraine and European energy security shaken, amid what some describe as an energy nightmare for the region, the EU is rushing to align its geopolitical and climate interests for the coming decades. It comes amid troubling signs that have raised concerns about energy supplies that the EU relies on and have no quick replacements for, including Russia cutting off member nations Poland and Bulgaria after they refused a demand to pay for natural gas in rubles.

The bloc’s dash to ditch Russian energy stems from a combination of voluntary and mandatory actions. Both reflect the political discomfort of helping fund Russia’s military campaign in a country that neighbors the EU and wants to join the bloc.

An EU ban on coal from Russia is due to start in August, and the bloc has pledged to try to reduce demand for Russian gas by two-thirds by year's end, while debating gas price cap strategies to curb volatility. Meanwhile, a proposed EU oil embargo has hit a roadblock from Hungary and other landlocked countries that worry about the cost of switching to alternative sources.

In a bid to swing Hungary behind the oil phaseout, the REPowerEU package expects oil investment funding of around 2 billion euros for member nations highly dependent on Russian oil.

Energy savings and renewables form the cornerstones of the package, which would be funded mainly by an economic stimulus program put in place to help member countries overcome the slump triggered by the coronavirus pandemic.

The European Commission said the price tag for abandoning Russian fossil fuels completely by a 2027 target date is 210 billion euros. Its package includes 56 billion euros for energy efficiency and 86 billion euros for renewables.

Von der Leyen cited a total funding pot of 72 billion euros in grants and 225 billion euros for loans.

The European Commission also proposed ways to streamline the approval processes in EU countries for renewable projects, which can take up to a decade to get through red tape, as part of a broader effort to revamp the electricity market across Europe. The commission said approval times need to fall to as little as a year or less.

It put forward a specific plan on solar energy, seeking to double photovoltaic capacity by 2025 and pushing for a phased-in obligation to install solar panels on new buildings.

Simone Tagliapietra, an energy expert at the Bruegel think tank in Brussels, called REPowerEU a “jumbo package” whose success will ultimately depend on political will in the bloc’s national capitals, with examples such as Germany’s 200 billion euro energy price shield illustrating the scale of national responses.

“Most of the actions entailed in the plan require either national implementation or strong coordination among member states,” Tagliapietra said. “The extent to which countries really engage is going to be defining.”

The German energy think tank Agora Energiewende said the EU’s plan “gives too little attention to concrete initiatives that reduce fossil fuel demand in the short term and thereby misses the opportunity to simultaneously enhance Europe’s energy security and meet Europe’s climate objectives.”

The group's research shows rapidly expanding solar, wind parks and use of heat pumps for low-temperature heat in industry and buildings could be done faster than constructing new liquefied natural gas terminals or gas infrastructure, said Matthias Buck, its director for Europe.

The European Commission’s recommendations on short-term national actions to cut demand for Russian energy, which include potential emergency measures to limit electricity prices as well, coincide with deliberations underway in the bloc since last year on setting more ambitious EU energy-efficiency and renewable targets for 2030.

Those targets, being negotiated by the European Parliament and national governments, are part of the bloc’s commitments to a 55% cut in greenhouse gases by decade's end, compared with 1990 emissions, and to climate neutrality by 2050.

Von der Leyen urged the European Parliament and national governments to deepen the commission’s July proposal for an energy efficiency target of 9% and renewable energy goal of 40% by 2030. She said those objectives should be 13% and 45%, respectively.

Belgium, the Netherlands, Germany and Denmark plan to build North Sea wind farms to help cut carbon emissions.

 

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Demand for electricity in Yukon hits record high

Yukon Electricity Demand Record underscores peak load growth as winter cold snaps drive heating, lighting, and EV charging, blending hydro, LNG, and diesel with renewable energy and planned grid-scale battery storage in Whitehorse.

 

Key Points

It is the territory's new peak electricity load, reflecting winter demand, electric heating, EVs, and mixed generation.

✅ New peak: 104.42 MW, surpassing 2020 record of 103.84 MW

✅ Winter peaks met with hydro, LNG, diesel, and renewables mix

✅ Customers urged to shift use off peak hours and use timers

 

A new record for electricity demand has been set in Yukon. The territory recorded a peak of 104.42 megawatts, according to a news release from Yukon Energy.

The new record is about a half a megawatt higher than the previous record of 103.84 megawatts recorded on Jan. 14, 2020.

While in general, over 90 per cent of the electricity generated in Yukon comes from renewable resources each year, with initiatives such as new wind turbines expanding capacity, during periods of high electricity use each winter, Yukon Energy has to use its hydro, liquefied natural gas and diesel resources to generate the electricity, the release says.

But when it comes to setting records, Andrew Hall, CEO of Yukon Energy, says it's not that unusual.

"Typically, during the winter, when the weather is cold, demand for electricity in the Yukon reaches its maximum. And that's because folks use more electricity for heating their homes, for cooking meals, there's more lighting demand, because the days are shorter," he said.

"It usually happens either in December or sometimes in January, when we get a cold snap."

He said generally over the years, electricity demand has grown.

"We get new home construction, construction of new apartment buildings. And typically, those new homes are all heated by electricity, maybe not all of them but the majority," Hall said.

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In taking action on climate, this Arctic community wants to be a beacon to the world

Efforts to curb climate change add to electricity demand
There are also other reasons, ones that are "in the name of climate change," Hall added.

That includes people trying to limit fossil fuel heating by swapping to electric heating. And, he said some Yukoners are switching to electric vehicles as incentives expand across the North.

"Over time, those two new demands, in the name of climate change, will also contribute to growing demand for electricity," he said.

While Yukon did reach this new all time high, Hall said the territory still hadn't hit the maximum capacity for the week, which was 118 megawatts, and discussions about a potential connection to the B.C. grid are part of long-term planning.


Yukon Energy's hydroelectric dam in Whitehorse. Yukon Energy's CEO, Andrew Hall, said demand of 104 megawatts wasn't unexpected, nor was it an emergency. The corporation has the ability to generate 118 megawatts. (Paul Tukker/CBC)
Tips to curve demand
"When we plan our system, we actually plan for a scenario, guided by the view that sustainability is key to the grid's future, where we actually lose our largest hydro generating facility," Hall said.

"We had plenty of generation available so it wasn't an emergency situation, and, even as other provinces face electricity shortages, it was more just an observation that hey, our peaks are growing."

He also said it was an opportunity to reach out to customers on ways to curve their demand for electricity around peak times, drawing on energy efficiency insights from other provinces, which is typically between 7 a.m. and 9 a.m., and between 5 p.m. and 7 p.m., Monday to Friday.

For example, he said, people should consider running major appliances, like dishwashers, during non-peak hours, such as in the afternoon rather than in the morning or evening.

During winter peaks, people can also use a block heater timer on vehicles and turn down the thermostat by one or two degrees.

'We plan for each winter'
Hall said Yukon Energy is working to increase its peak output, including working on a large grid scale battery to be installed in Whitehorse, similar to Ontario's energy storage push now underway. 

When it comes to any added load from people working from home due to COVID-19, Hall said they haven't noticed any identifiable increase there.

"Presumably, if someone's working from home, you know, their computer is at home, and they're not using the computer at the office," he said.

Yukon Energy one step closer to having largest battery storage site in the North
He said there shouldn't be any concern for maxing out the capacity of electricity demand as Yukon moves into the colder winter months, since those days are forecast for.

"This number of 104 megawatts wasn't unexpected," he said, adding how much electricity is needed depends on the weather too.

"We plan for each winter."

 

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Congressional Democrats push FERC to act on aggregated DERs

FERC DER Aggregation advances debates over distributed energy resources as Congress presses action on Order 841, grid resilience, and wholesale market access, including rooftop solar, storage, and virtual power plant participation across PJM and ISO-NE.

 

Key Points

FERC DER Aggregation enables grouped distributed resources to join wholesale markets, providing capacity and flexibility.

? Opens wholesale market access for aggregated DER portfolios

? Aligns with Order 841, storage, and grid resilience goals

? Raises jurisdictional questions between FERC and state regulators

 

The Monday letter from Congressional Democrats illustrates growing frustration in Washington over the lack of FERC action on multiple power sector issues, including the aging U.S. grid and related challenges.

Last May, after the FERC technical conference, 16 Democratic Senators wrote to then-Chairman Kevin McIntyre urging him to develop guidance for grid operators on aggregated DERs.

In July, McIntyre responded, saying that FERC was "diligently reviewing the record," but the commission has taken no action since.

Since then, "DER adoption and renewable energy aggregation have continued to grow," House and Senate lawmakers wrote in their identical Monday letters, "driven not only by state and federal policies, but consumer interest in choosing cost-competitive technologies such as rooftop solar, smart thermostats and customer-sited energy generation and storage, reflecting key utility trends in the sector."

The lawmakers wrote they were "encouraged" by FERC Chairman Neil Chatterjee's comments in June 2018, writing that he "specifically cited the role DERs will play in our continued grid transition."

In that speech at the S&P Global Platts 2018 Transmission Planning and Development Conference, Chatterjee noted "growing interest" in non-transmission alternatives, including "DERs and storage."

"How the Commission treats filings associated with those first-of-kind projects could prove an important factor in investors’ assessments of whether similar non-traditional projects are bankable or not — and more broadly signal whether FERC is open to innovation in the transmission sector,” he said.

In addition to the DER order and rehearing decision on Order 841, FERC has multiple other power sector initiatives that have not seen official action in months, even as major changes to electricity pricing are debated by stakeholders.

The highest profile is its open proceeding on grid resilience, set up last January after FERC rejected a coal and nuclear bailout proposal from the Department of Energy. In October, the CEO of the PJM Interconnection, the nation’s largest wholesale power market, urged FERC to issue a final order in the docket, calling for "leadership" from the commission.

Chatterjee, however, has not indicated when FERC could decide on the case. In December, Commissioner Rich Glick told a Washington audience he is "not entirely sure where the chairman wants to go with that proceeding yet."

Outside of resilience, FERC also has open reviews of both its pipeline certificate policy and implementation of the Public Utilities Regulatory Policy Act, a key law supporting renewable energy. McIntrye set those reviews in motion during his tenure as chairman, but after his death in January the timing of both remains unclear.

In recent months, Chatterjee has also delayed FERC votes on major export facilities for liquefied natural gas and a political spending case involving PJM after impasses between Republicans and Democrats on FERC.

Two members from each party currently sit on the commission. That allows Democrats to deadlock commission votes on natural gas facilities and other issues — a partisan divide on display this week when they clashed with the chairman over offshore wind.

As the commission considers final guidance on DERs, the boundaries of federal jurisdiction are likely to be a key issue. At the technical conference, states from the Midcontinent ISO argued FERC should allow them to choose whether to let aggregated DERs participate in retail and wholesale markets. Other states argued the value proposition of distributed resources may rely on that sort of dual participation.

Despite the lack of action from FERC, some grid operators are moving forward with aggregated distributed resources in New England market reform efforts and elsewhere, demonstrating momentum. Last week, a residential solar-plus-storage aggregation cleared the ISO-NE capacity auction for the first time, committing to provide 20 MW of capacity beginning in 2022.

On the Senate side, Sens. Sheldon Whitehouse, R.I., and Ed Markey, Mass., led the letter to FERC. In the House, Reps. Peter Welch, Vt., and Mike Levin, Calif., led the signatories.

 

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Peterborough Distribution sold to Hydro One for $105 million.

Peterborough Distribution Inc. Sale to Hydro One delivers a $105 million deal pending Ontario Energy Board approval, a 1% distribution rate cut, five-year rate freeze, job protections, and a new operations centre and fleet facility.

 

Key Points

A $105M acquisition of PDI by Hydro One, with OEB review, rate freeze, job protections, and a new operations centre.

✅ $105 million purchase; Ontario Energy Board approval required

✅ 1% distribution rate cut and a five-year rate freeze

✅ New operations centre; PDI employees offered roles at Hydro One

 

The City of Peterborough said Wednesday it has agreed to sell Peterborough Distribution Inc. to Hydro One for $105 million, amid a period when Hydro One shares fell after leadership changes.

The deal requires approval from the Ontario Energy Board before it can proceed.

According to the city, the deal includes a one per cent distribution rate reduction and a five-year freeze in distribution rates for customers, plus:

  • A second five-year period with distribution rate increases limited to inflation and an earnings sharing mechanism to offset rates in year 11 and onward
  • Protections for PDI employees with employees receiving employment offers to move to Hydro One
  • A sale price of $105 million
  • An agreement to develop a regional operations centre and new fleet maintenance facility in Peterborough

“Hydro One was unique in its ability to offer new investment and job creation in our community through the addition of a new operations centre to serve customers throughout the broader region,” Mayor Daryl Bennett said.

“We’re surrounded by Hydro One territory — in fact, we already have Hydro One customers within the City of Peterborough and new subdivisions will be in Hydro One territory. Hydro One will be able to create efficiencies by better utilizing its existing infrastructure, benefiting customers and supporting growth.”

The sale comes after months of negotiations amid investor concerns about Hydro One’s uncertainties. At one point, it looked like the sale wouldn’t go through, after it was announced that Hydro One had walked away from the bargaining table.

City council approved the sale of PDI in December 2016, despite a strong public opposition and debate over proposals to make hydro public again among some parties.

Elsewhere in Canada, political decisions around utilities have also sparked debate, as seen when Manitoba Hydro faced controversy over policy shifts.

 

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Smaller, cheaper, safer: Next-gen nuclear power, explained

MARVEL microreactor debuts at Idaho National Laboratory as a 100 kW, liquid-metal-cooled, zero-emissions generator powering a nuclear microgrid, integrating wind and solar for firm, clean energy in advanced nuclear applications research.

 

Key Points

A 100 kW, liquid-metal-cooled INL reactor powering a nuclear microgrid and showcasing zero-emissions clean energy.

✅ 100 kW liquid-metal-cooled microreactor at INL

✅ Powers first nuclear microgrid for applications testing

✅ Integrates with wind and solar for firm clean power

 

Inside the Transient Reactor Test Facility, a towering, windowless gray block surrounded by barbed wire, researchers are about to embark on a mission to solve one of humanity’s greatest problems with a tiny device.

Next year, they will begin construction on the MARVEL reactor. MARVEL stands for Microreactor Applications Research Validation and EvaLuation. It’s a first-of-a-kind nuclear power generator with a mini-reactor design that is cooled with liquid metal and produces 100 kilowatts of energy. By 2024, researchers expect MARVEL to be the zero-emissions engine of the world’s first nuclear microgrid at Idaho National Laboratory (INL).

“Micro” and “tiny,” of course, are relative. MARVEL stands 15 feet tall, weighs 2,000 pounds, and can fit in a semi-truck trailer. But it's minuscule compared to conventional nuclear power plants, which span acres, produces gigawatts of electricity to power whole states, and can take more than a decade to build.

For INL, where scientists have tested dozens of reactors over the decades across an area three-quarters the size of Rhode Island, it’s a radical reimagining of the technology. This advanced reactor design could help overcome the biggest obstacles to nuclear energy: safety, efficiency, scale, cost, and competition. MARVEL is an experiment to see how all these pieces could fit together in the real world.

“It’s an applications test reactor where we’re going to try to figure out how we extract heat and energy from a nuclear reactor and apply it — and combine it with wind, solar, and other energy sources,” said Yasir Arafat, head of the MARVEL program.

The project, however, comes at a time when nuclear power is getting pulled in wildly different directions, from phase-outs to new strategies like the UK’s green industrial revolution that shapes upcoming reactors.

Germany just shut down its last nuclear reactors. The U.S. just started up its first new reactor in 30 years, underscoring a shift. France, the country with the largest share of nuclear energy on its grid, saw its atomic power output decline to its lowest since 1988 last year. Around the world, there are currently 60 nuclear reactors under construction, with 22 in China alone.

But the world is hungrier than ever for energy. Overall electricity demand is growing: Global electricity needs will increase nearly 70 percent by 2050 compared to today’s consumption, according to the Energy Information Administration. At the same time, the constraints are getting tighter. Most countries worldwide, including the U.S., have committed to net-zero goals by the middle of the century, even as demand rises.

To meet this energy demand without worsening climate change, the U.S. Energy Department’s report on advanced nuclear energy released in March said, “the U.S. will need ~550–770 [gigawatts] of additional clean, firm capacity to reach net-zero; nuclear power is one of the few proven options that could deliver this at scale.”

The U.S. government is now renewing its bets on nuclear power to produce steady electricity without emitting greenhouse gases. The Bipartisan Infrastructure Law included $6 billion to keep existing nuclear power plants running. In addition, the Inflation Reduction Act, the U.S. government’s largest investment in countering climate change, includes several provisions to benefit atomic power, including tax credits for zero-emissions energy.

“It’s a game changer,” said John Wagner, director of INL.

The tech sector is jumping in, too, as atomic energy heats up across startups and investors. In 2021, venture capital firms poured $3.4 billion into nuclear energy startups. They’re also pouring money into even more far-out ideas, like nuclear fusion power. Public opinion has also started moving. An April Gallup poll found that 55 percent of Americans favour and 44 percent oppose using atomic energy, the highest levels of support in 10 years.

 

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