New Toronto plant will deliver power to the people

By Toronto Sun


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A monster under construction on Toronto's waterfront threatens our city.

But if you like air conditioning, it's the key to keeping the lights on in the next sweltering heat wave.

Technically it's the Portlands Energy Centre. A $730-million, 550-megawatt natural gas energy plant that will bring power to the City of Toronto's electricity grid.

That's the good news. The bad news is it's an environmentalist's and a waterfront planner's worst nightmare.

This is really about industrializing Toronto's waterfront, critics like Mayor David Miller say.

The optics are brutal, with the plant going up next door to the now-shuttered Hearn generating plant.

Yes, it's near the water. It's also at the end of the portlands where the "concrete campus," as it's being called, will be built. A new Canadian Tire opens nearby this fall.

So why build it here? Convenience. Because there are already power lines and a hydro substation built to move power from the old hydro plant which can be adapted for this one.

Most importantly, it doesn't use the existing, maxed-out power lines. Toronto has two circuits into the city, one from the east, one from the west, and that's it.

On a hot, humid day, with air conditioners around the city blowing full blast, Toronto's power grid operates at full tilt. On June 26, the Independent Electricity Service Operator (IESO) begged Torontonians to ease off on the A/C because the transmission lines couldn't bring any more power into the city.

With three Pickering nuclear plant units out of service, there was no way to generate extra power locally, either.

"All the power for Toronto - with all due respect to the windmill - is produced outside the city," the IESO's Terry Young said.

Toronto's transmission system is aging and Young said it's important to find ways to take the stress off.

Putting power where it's needed helps reduce stress on the entire grid.

Toronto is the only major city in North America not producing power within its city limits, Young said.

(New York City requires 75% of its electricity generation to occur within its five boroughs.)

We'd be in the dark already without the incredible efforts of Torontonians, Toronto Hydro and the Ontario Power Authority to conserve energy, taking hundreds of megawatts of demand off the system.

The problem is that at the same time, dozens of new condo buildings have been constructed, bringing with them massive air conditioning demands.

"Air conditioning is one of the biggest draws of power," Young said. "Ontario used to use the highest amount of energy in the winter. Now, it's the summer."

Toronto is adding a city the size of Peterborough to its population every four years. It takes a lot of power to keep up.

The IESO projects without new power generation in the city, there would be brownouts and possibly blackouts by next summer.

"There are very few options," Young said. "Newly-generated power can't make it into the city because the transmission lines are overloaded. The only way is to reduce demand, but sometimes demand spikes in the blink of an eye."

When that happens, either the hydro companies cut the voltage or there are blackouts. That doesn't mean you have to like the new power plant.

Just ask Coun. Paula Fletcher. She detests the view emerging from Commissioners St., across the turning basin. It used to be just the Hearn.

"If you look across, it's blocked off the view of a beautiful waterfront," Fletcher says. "It could have been in the Hearn."

That "beautiful view" line is a bit rich. But why not in the Hearn?

Well, the engineers took us inside the old building, pointed up at a bunch of things and said, "See?"

(It would take a smarter person than me to figure it out, but the technical mumbo jumbo sounded good.)

Fletcher says the power seekers believe there's a supply problem. She believes there's a demand problem.

She advocates green buildings and smart technology, such as having buildings store power overnight, then use it to help the power grid during peak hours.

Still, Fletcher and her cronies need to know, as much as we conserve, our thirst for energy doesn't seem to end. And as our population grows, I'll take another power plant over blackouts any day.

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Ontario's electricity 'recovery rate' could lead to higher hydro bills

Ontario Hydro Flat Rate sets a single electricity rate at 12.8 cents per kWh, replacing time-of-use pricing for Ontario ratepayers, affecting hydro bills this summer, alongside COVID-19 Energy Assistance Program support.

 

Key Points

A fixed 12.8 cents per kWh electricity price replacing time-of-use rates across Ontario from June to November.

✅ Single rate applies 24/7, replacing time-of-use pricing

✅ May slightly raise bills versus pre-pandemic usage patterns

✅ COVID-19 aid offers one-time credits for households, small firms

 

A new provincial COVID-19 measure, including a fixed COVID-19 hydro rate designed to give Ontario ratepayers "stability" on their hydro bills this summer, could result in slightly higher hydro costs over the next four months.

Ontario Premier Doug Ford's government announced over the weekend that consumers would be charged a single around-the-clock electricity rate between June and November, before a Nov. 1 rate increase takes effect, replacing the much-derided time-of-use model ratepayers have complained about for years.

Instead of being charged between 10 to 20 cents per kilowatt hour, depending on the time of day electricity is used, including ultra-low TOU rates during off-peak hours, hydro users will be charged a blanket rate of 12.8 cents per kWh.

"The new rate will simply show up on your bill," Premier Doug Ford said at a Monday afternoon news conference.

While the government said the new fixed rate would give customers "greater flexibility" to use their home appliances without having to wait for the cheapest rate -- and has tabled legislation to lower rates as part of its broader plan -- the new policy also effectively erases a pandemic-related hydro discount for millions of consumers.

For example, a pre-pandemic bill of $59.90 with time-of-use rates, will now cost $60.28 with the government's new recovery rate, as fixed pricing ends across the province, before delivery charges, rebates and taxes.

That same bill would have been much cheaper -- $47.57 -- if the government continued applying the lowest tier of time-of-use 24/7 under an off-peak price freeze as it had been doing since March 24.

The government also introduced support for electric bills with two new assistance programs to help customers struggling to pay their bills.

The COVID-19 Energy Assistance Program will provide a one-time payment consumers to help pay off electricity debt incurred during the pandemic -- which will cost the government $9 million.

The government will spend another $8 million to provide similar assistance to small businesses hit hard by the pandemic.

 

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More Managers Charged For Price Fixing At Ukraine Power Producer

DTEK Rotterdam+ price-fixing case scrutinizes alleged collusion over coal-based electricity tariffs in Ukraine, with NABU probing NERC regulators, market manipulation, consumer overpayment, and wholesale pricing tied to imported coal benchmarks.

 

Key Points

NABU probes alleged DTEK-NERC collusion to inflate coal power tariffs via Rotterdam+; all suspects deny wrongdoing.

✅ NABU alleges tariff manipulation tied to coal import benchmarks.

✅ Four DTEK execs and four NERC officials reportedly charged.

✅ Probe centers on 2016-2017 overpayments; defendants contest.

 

Two more executives of DTEK, Ukraine’s largest private power and coal producer and recently in energy talks with Octopus Energy, have been charged in a criminal case on August 14 involving an alleged conspiracy to fix electricity prices with the state energy regulator, Interfax reported.

They are Ivan Helyukh, the CEO of subsidiary DTEK Grid, which operates as Ukraine modernizes its network alongside global moves toward a smart electricity grid, and Borys Lisoviy, a top manager of power generation company Skhidenergo, according to Kyiv-based Concorde Capital investment bank.

Ukraine’s Anti-Corruption Bureau (NABU) alleges that now four DTEK managers “pressured” and colluded with four regulators at the National Energy and Utilities Regulatory Commission to manipulate tariffs on electricity generated from coal that forced consumers to overpay, reflecting debates about unjustified profits in the UK, $747 million in 2016-2017.

 

DTEK allegedly benefited $560 million in the scheme.

All eight suspects are charged with “abuse of office” and deny wrongdoing, similar to findings in a B.C. Hydro regulator report published in Canada.

There is “no legitimate basis for suspicions set out in the investigation,” DTEK said in an August 8 statement.

Suspect Dmytro Vovk, the former head of NERC, dismissed the investigation as a “wild goose chase” on Facebook.

In separate statements over the past week, DTEK said the managers who are charged have prematurely returned from vacation to “fully cooperate” with authorities in order to “help establish the truth.”

A Kyiv court on August 14 set bail at $400,000 for one DTEK manager who wasn’t named, as enforcement actions like the NT Power penalty highlight regulatory consequences.

The so-called Rotterdam+ pricing formula that NABU has been investigating since March 2017, similar to federal scrutiny of TVA rates, was in place from April 2016 until July of this year.

It based the wholesale price of electricity by Ukrainian thermal power plants on coal prices set in the Rotterdam port plus delivery costs to Ukraine.

NABU alleges that at certain times it has not seen documented proof that the purchased coal originated in Rotterdam, insisting that there was no justification for the price hikes, echoing issues around paying for electricity in India in some markets.

Ukraine started facing thermal-coal shortages after fighting between government forces and Russia-backed separatists in the eastern part of the country erupted in April 2014. A vast majority of the anthracite-coal mines on which many Ukrainian plants rely are located on territory controlled by the separatists.

Overnight, Ukraine went from being a net exporter of coal to a net importer and started purchasing coal from as far away as South Africa and Australia.

 

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B.C. government freezes provincial electricity rates

BC Hydro Rate Freeze delivers immediate relief on electricity rates in British Columbia, reversing a planned 3% hike, as BCUC oversight, a utility review, and Site C project debates shape provincial energy policy.

 

Key Points

A one-year provincial policy halting BC Hydro electricity rate hikes while a utility review finds cost savings.

✅ Freeze replaces planned 3% hike approved by BCUC.

✅ Government to conduct comprehensive BC Hydro review.

✅ Critics warn $150M revenue loss impacts capital projects.

 

British Columbia's NDP government has announced it will freeze BC Hydro rates effective immediately, fulfilling a key election promise.

Energy, Mines and Petroleum Resources Minister Michelle Mungall says hydro rates have gone up by more than 24 per cent in the last four years and by more than 70 per cent since 2001, reflecting proposals such as a 3.75% increase over two years announced previously.

"After years of escalating electricity costs, British Columbians deserve a break on their bills," Mungall said in a news release.

BC Hydro had been approved by the B.C. Utilities Commission to increase the rate by three per cent next year, but Mungall said it will pull back its request in order to comply with the freeze.

In the meantime, the government says it will undertake a comprehensive review of the utility meant to identify cost-savings measures for customers often asked to pay an extra $2 a month on electricity bills.

The Liberal critic, Tracy Redies, says the one year rate freeze is going to cost BC Hydro, calling it a distraction from the bigger issue of the future of the Site C project and the oversight of a BC Hydro fund surplus as well.

"A one year rate freeze costs Hydro $150 million," Redies said. "That means there's $150 million less to invest in capital projects and other investments that the utility needs to make."

"This is putting off decisions that should be made today to the future."

Recommendations from the review — including possible new rates — will be implemented starting in April 2019.

 

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ABL Secures Contract for UK Subsea Power

ABL has secured a contract for the UK Subsea Power Link, highlighting ABL Group’s marine warranty role in Eastern Green Link 2, a 2 GW offshore electricity superhighway connecting Scotland and England to enhance grid reliability and renewable energy transmission.

 

Key Points: ABL Group’s contract for the UK Subsea Power Link

ABL Group has been appointed to provide marine warranty survey services for the 2 GW Eastern Green Link 2 subsea interconnector between Scotland and England.

✅ Manages vessel suitability checks, installation oversight, and DP assurance

✅ Strengthens UK grid reliability and advances the clean energy transition

✅ Sizeable contract valued between USD 1 million and 3 million

 

Energy and marine consultancy ABL, a subsidiary of ABL Group, has been awarded a contract by Eastern Green Link 2 (EGL2) to provide marine warranty survey (MWS) services for the installation of a new 2 GW subsea power connection between Scotland and England.

EGL2 is one of the United Kingdom’s most significant energy-infrastructure projects, involving the creation of a 505-kilometre “electricity superhighway” that will enable simultaneous power transfer between Peterhead in Aberdeenshire and Drax in North Yorkshire, mirroring a renewable power link announced for the same corridor recently. The project is designed to strengthen grid resilience, integrate renewable energy from Scotland’s offshore resources, and advance the UK’s broader energy transition goals.

Under the terms of the contract, ABL will be responsible for the technical review and approval of the project and procedural documentation, as well as conducting suitability surveys of the proposed fleet for marine transportation and installation operations. The company will also provide dynamic positioning (DP) assurance where required and will review and approve all warranted operations through on-site attendances, reflecting practices used on projects like the Great Northern Transmission Line in North America.

Cable-laying operations for the link are scheduled to take place between January and September 2028, amid wider efforts to fast-track grid connections across the UK. According to ABL, the engagement represents a “sizeable” contract, valued between USD 1 million and 3 million.

“This appointment reflects ABL's reputation as a trusted MWS partner for major power transmission infrastructure development and reinforces our position at the forefront of supporting the UK's energy transition,” said Hege Norheim, CEO of ABL Group. “We look forward to contributing to this strategic initiative.”

The subsea interconnector, known as Eastern Green Link 2, will transmit up to 2 gigawatts of electricity—enough to power approximately 2 million homes. It forms part of the Great Grid Upgrade, National Grid’s nationwide program to modernize and expand the transmission network in preparation for a low-carbon future, alongside a recent 2 GW substation milestone.

By linking renewable-rich northern Scotland with high-demand regions in England, EGL2 is expected to reduce congestion on the existing grid by leveraging HVDC technology to improve transfer efficiency, enhance security of supply, and facilitate the more efficient flow of surplus renewable energy south. The connection will also support the UK government’s target of decarbonizing the electricity system by 2035.

ABL’s appointment follows a period of intensive marine and geotechnical surveys along the proposed cable route to assess seabed conditions and environmental sensitivities. The company’s marine warranty oversight will ensure that transportation and installation operations meet strict safety, technical, and environmental standards demanded by insurers and project partners, as seen in a recent cross-border transmission approval in North America.

For ABL Group, which provides engineering and risk services to the offshore energy and marine industries worldwide, the contract marks another milestone in its expanding portfolio of subsea power and transmission projects across Europe. With operations set to begin in 2028, the Eastern Green Link 2 initiative represents both a major engineering challenge and a key enabler of the UK’s offshore energy ambitions, echoing a recent offshore wind power milestone in the U.S.

 

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Recommendations from BC Hydro review to keep electricity affordable

BC Hydro Review Phase 2 Recommendations advance affordable electricity rates, clean energy adoption, electrification, and demand response, supporting heat pumps, EV charging, and low-income programs to cut emissions and meet CleanBC climate targets.

 

Key Points

Policies to keep rates affordable and accelerate clean electrification via heat pump, EV, and demand response incentives.

✅ Optional rates, heat pump and EV charging incentives

✅ Demand response via controllable devices lowers peak loads

✅ Expanded support for lower-income customers and affordability

 

The Province and BC Hydro have released recommendations from Phase 2 of the BC Hydro Review to keep rates affordable, including through a provincial rate freeze initiative that supported households, and encourage greater use of clean, renewable electricity to reduce emissions and achieve climate targets.

“Keeping life affordable for people is a key priority of our government,” said Bruce Ralston, Minister of Energy, Mines and Low Carbon Innovation. “Affordable electricity rates not only help British Columbians, they help ensure the price of electricity remains competitive with other forms of energy, supporting the transition away from fossil fuels to clean electricity in our homes and buildings, vehicles and businesses.”

While affordable rates have always been important to BC Hydro customers, amid proposals such as a modest rate increase under review, expectations are also changing as customers look to have more choice and control over their electricity use and opportunities to save money.

Guided by input from a panel of external energy industry experts, government and BC Hydro have developed recommendations under Phase 2 of the BC Hydro Review to reduce electricity costs for individuals and businesses, even as a 3.75% increase has been discussed, as envisioned by the CleanBC climate strategy. This is also in alignment with TogetherBC, the Province’s poverty reduction strategy, and its guiding principle of affordability.

“As we promote increased use of electricity in B.C. to achieve our climate targets, we need to continue to focus on keeping electricity rates affordable, especially for lower-income families,” said Nicholas Simons, Minister of Social Development and Poverty Reduction. “Through the BC Hydro Review, and continuing engagement with stakeholders and organizations to follow, we are committed to finding ways to keep rates affordable, so everyone has access to the benefits of B.C.’s clean, reliable electricity.”

Recommendations include having BC Hydro consider providing more support for lower-income BC Hydro customers, informed by a recent surplus report that highlighted funding opportunities. These include incentives and exploring optional rates for customers to adopt electric heat pumps, and facilitating customer adoption of controllable energy devices that provide BC Hydro the ability to offer incentives in return for helping to manage a customer’s electricity use. 

Electrification of B.C.’s economy helps customers reduce their carbon footprint and supports the Province’s CleanBC climate strategy, and is an important part of keeping electricity affordable even amid higher BC Hydro rates in recent periods. As more customers make the switch from fossil fuels to using clean electricity in their homes, vehicles and businesses, BC Hydro’s electricity sales will increase, providing more revenue that helps keep rates affordable for everyone.

“We’re making the transition to a cleaner future more affordable for people and businesses across British Columbia through our CleanBC plan,” said George Heyman, Minister of Environment and Climate Change Strategy. “By working with BC Hydro and other partners, we’re making sure everyone has access to clean, affordable electricity to power technologies like high-efficiency heat pumps and electric vehicles that will reduce harmful pollution and improve our homes, buildings and communities.”

Chris O’Riley, president and CEO, BC Hydro, said: “Given the impact of COVID-19 on British Columbians, affordability is more important than ever. That’s why we are committed to continuing to keep rates affordable and offering customers more options that allow them to save on their bills while using clean electricity.”

In July 2021, the Province announced a first set of recommendations from Phase 2 of the BC Hydro Review amid a 3% rate increase approved by regulators. The next announcement from Phase 2 will include recommendations to increase the number of electric vehicles on the road.

In addition, as part of the Draft Action Plan to advance the Declaration on the Rights of Indigenous Peoples Act, the Province is proposing to engage with Indigenous peoples to identify and support new clean energy opportunities related to CleanBC, the BC Hydro Review and the British Columbia Utilities Commission Indigenous Utilities Regulation Inquiry, and to consider lessons from Ontario's hydro policy experiences as appropriate.

B.C. is the cleanest electricity-generation jurisdiction in western North America, with an average of 98% of its electricity generation coming from clean or renewable resources.

 

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Poland’s largest power group opts to back wind over nuclear

Poland Offshore Wind Energy accelerates as PGE exits nuclear leadership, PKN Orlen steps in, and Baltic Sea projects expand to cut coal reliance, meet EU emissions goals, attract investors, and bridge the power capacity gap.

 

Key Points

A shift from coal and nuclear to Baltic offshore wind to add capacity, cut EU emissions, and attract investment.

✅ PGE drops lead in nuclear; pivots $10bn to offshore wind.

✅ PKN Orlen may assume nuclear role; projects await approval.

✅ 6 GW offshore could add 60b zlotys and 77k jobs by 2030.

 

PGE, Poland’s biggest power group has decided to abandon a role in building the country’s first nuclear power plant and will instead focus investment on offshore wind energy.

Reuters reports state-run refiner PKN Orlen (PKN.WA) could take on PGE’s role, while the latter announces a $10bn offshore wind power project.

Both moves into renewables and nuclear represent a major change in Polish energy policy, diversifying away from the country’s traditional coal-fired power base, as regional efforts like the North Sea wind farms initiative expand, in a bid to fill an electricity shortfall and meet EU emission standards.

An unnamed source told the news agency, PGE could not fund both projects and cheap technology had swung the decision in favour of wind, with offshore wind competing with gas in some markets. PGE could still play a smaller role in the nuclear project which has been delayed and still needs government approval.

#google#

A proposed law is currently before the Polish parliament aiming at facilitating easy construction of wind turbines, mindful of Germany’s grid expansion challenges that have hindered rollout.

If the law is passed, as expected, several other wind farm projects could also proceed.

Polenergia has said it would like to build a wind farm in the Baltic by 2022. PKN Orlen is also considering building one.

PGE said in March that it wants to build offshore windfarms with a capacity of 2.5 gigawatts (GW) by 2030.

Analysts and investors say that offshore wind farms are the easiest and fastest way for Poland to fill the expected capacity gap from coal, with examples like the largest UK offshore wind farm coming online underscoring momentum, and reduce CO2 emissions in line with EU’s 2030 targets as Poland seeks improved ties with Brussels.

The decision to open up the offshore power industry could also draw in investors, as shown by Japanese utilities’ UK offshore investment attracting cross-border capital. Statoil said in April it would join Polenergia’s offshore project which has drawn interest from other international wind companies. “

The Polish Wind Energy Association (PWEA) estimates that offshore windfarms with a total capacity of 6 GW would help create around 77,000 new jobs and add around 60 billion zlotys to economic growth.

 

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