EU takes aim at OntarioÂ’s policies

By Globe and Mail


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European Union trade negotiators are taking aim at the provinces' renewable energy policies - notably Ontario's Green Energy Act - as they seek to open up provincial procurement markets under a proposed Canada and EU comprehensive trade deal.

Canadian and European negotiators are meeting in Ottawa, and federal Trade Minister Peter Van Loan said they are now focusing on the most difficult issues, including Europe's desire to gain access for its corporations to the lucrative provincial and municipal purchasing budgets.

The Europeans are particularly keen to head off protectionist policies in Canada in order to supply the manufactured products and services that will fuel the country's growing appetite for renewable power - a goal that represents a direct challenge to Premier Dalton McGuinty's ambition to make Ontario an export-oriented hub for renewable energy manufacturing.

In an interview, Mr. Van Loan said the provinces - which are at the negotiating table for the first time in international trade talks - have committed to open their procurement markets. He said they all see the benefits that would accompany a free-trade deal, even as they to seek to negotiate protection for politically sensitive sectors, including procurement.

"They have gains they want to make and [making tradeoffs] is the nature of free-trade negotiations," Mr. Van Loan said.

He noted that Canadian companies and workers were harmed when they were shut out of U.S. government projects under President Barack Obama's massive stimulus effort, and says it was a mistake to leave provincial and municipal procurement out of the North American free-trade agreement. Ottawa and the provinces eventually negotiated a deal that gave Canadian companies limited access to U.S. government stimulus projects in exchange for access to provincial purchasing programs, but Ontario exempted its renewable energy policies from that deal.

Other provinces, notably Quebec and Prince Edward Island, also have policies that reward renewable energy producers that purchase goods and equipment locally, but none are as aggressive as Ontario's feed-in-tariff program, which pays high rates for wind and solar electricity but requires up to 60 per cent local content. Japan has already complained to the World Trade Organization that the Green Energy Act violates trade rules, and both the EU and the United States have joined the action as third parties.

Behind much of the push for liberalized trade rules are multinational companies that are eager to keep costs down and locate their manufacturing facilities where it makes the most business sense. They include U.S.-based General Electric Co. and First Solar Inc., Denmark's Vestas Wind System AS German solar manufacturers Solon AG and Schott Solar GmbH, and a growing number of Chinese manufacturers.

The United States increased the growing tensions over trade in green energy products when it launched an investigation into union complaints that China is illegally subsidizing its wind turbine and solar manufacturers by offering cheap land and low-interest loans. Chinese officials rejected the complaints, saying they have more to do with election politicking in the U.S. than real trade action.

Governments around the world - including Ontario and Quebec - have justified their support for expensive renewable power both in terms of environmental benefit and industrial strategy, noted Mark Winfield, an environmental studies professor at York University. The renewable sector is widely supported through subsidies, targets for generation capacity and premium prices paid by government-owned utilities.

"It's hard to make the case for spending taxpayers dollars - or ratepayers dollars - if most of the benefit is going to China or some other foreign manufacturer," Mr. Winfield said.

Trade experts say the green energy trade is just one of several hurdles that negotiators face as they aim to complete a deal by the end of 2011. Others include agriculture, including Canada's quota-based dairy system the broader provincial and municipal procurement markets and Canada's desire to have its service sector be treated on an equal footing with companies from European countries.

"The provinces' renewable energy protectionism "isn't a deal breaker but it certainly doesn't help," said Jason Langrish of the Canada-Europe Roundtable for Business.

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What's at stake if Davis-Besse and other nuclear plants close early?

FirstEnergy Nuclear Plant Closures threaten Ohio and Pennsylvania jobs, tax revenue, and grid stability, as Nuclear Matters and Brattle Group warn of higher carbon emissions and market pressures from PJM and cheap natural gas.

 

Key Points

Planned shutdowns of Davis-Besse, Perry, and Beaver Valley, with regional economic and carbon impacts.

✅ Over 3,000 direct jobs and local tax revenue at risk

✅ Emissions may rise until renewables scale, possibly into 2034

✅ Debate over subsidies, market design, and PJM capacity rules

 

A national nuclear lobby wants to remind people what's at stake for Ohio and Pennsylvania if FirstEnergy Solutions follows through with plans to shut down three nuclear plants over the next three years, including its Davis-Besse nuclear plant east of Toledo.

A report issued Monday by Nuclear Matters largely echoes concerns raised by FES, a subsidiary of FirstEnergy Corp., and other supporters of nuclear power about economic and environmental hardships and brownout risks that will likely result from the planned closures.

Along with Davis-Besse, Perry nuclear plant east of Cleveland and the twin-reactor Beaver Valley nuclear complex west of Pittsburgh are slated to close.

#google#

"If these plants close, the livelihoods of thousands of Ohio and Pennsylvania residents will disappear. The over 3,000 highly skilled individuals directly employed by these sites will leave to seek employment at other facilities still operating around the country," Lonnie Stephenson, International Brotherhood of Electrical Workers president, said in a statement distributed by Nuclear Matters. Mr. Stephenson also serves on the Nuclear Matters advocacy council.

This new report and others like it are part of an extensive campaign by nuclear energy advocates to court state and federal legislators one more time for tens of millions of dollars of financial support or at least legislation that better suits the nuclear industry. Critics allege such pleas amount to a request for massive government bailouts, arguing that deregulated electricity markets should not subsidize nuclear.

The latest report was prepared for Nuclear Matters by the Brattle Group, a firm that specializes in analyzing economic, finance, and regulatory issues for corporations, law firms, and governments.

"These announced retirements create a real urgency to learn what would happen if these plants are lost," Dean Murphy, the Brattle report's lead author, said.

More than 3,000 jobs would be lost, as would millions of dollars in tax revenue. It also could take as long as 2034 for the region's climate-altering carbon emissions to be brought back down to existing levels, based on current growth projections for solar- and wind-powered projects, and initiatives such as ending coal by 2032 by some utilities, Mr. Murphy said.

His group's report only takes into account nuclear plant operations, though. Many of those who oppose nuclear power have long pointed out that mining uranium for nuclear plant fuel generates substantial emissions, as does the process of producing steel cladding for fuel bundles and the enrichment-production of that fuel. Still, nuclear has ranked among the better performers in reports that have taken such a broader look at overall emissions.

FES has accused the regional grid operator, PJM Interconnection, of creating market conditions that favor natural gas and, thus, make it almost impossible for nuclear to compete throughout its 13-state region, a debate intensified by proposed electricity pricing changes at the federal level.

PJM has strongly denied those accusations, and has said it anticipates no shortfalls in energy distribution if those nuclear plants close prematurely, even as a recent FERC decision on grid policy drew industry criticism.

FES, citing massive losses, has filed for Chapter 11 bankruptcy. The target dates for closures of the FES properties are May 31, 2020 for Davis-Besse; May 31, 2021 for Perry and Beaver Valley Unit 1, and Oct. 31, 2021 for Beaver Valley Unit 2.

In addition to the three FES sites, the report includes information about the Three Mile Island Unit 1 plant near Harrisburg, Pa., which Chicago-based Exelon Generation Corp. has previously announced will be shut down in 2019. That plant and others are experiencing similar difficulties the FES plants face by competing in a market radically changed by record-low natural gas prices.

 

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It's CHEAP but not necessarily easy: Crosbie introduces PCs' Newfoundland electricity rate reduction strategy

Crosbie Hydro Energy Action Plan outlines rate mitigation for Muskrat Falls, leveraging Nalcor oil revenues, export sales, Holyrood savings, and potential Hydro-Quebec taxation to keep Newfoundland and Labrador electricity rates near 14.67 cents/kWh.

 

Key Points

PC plan to cap post-Muskrat rates by using Nalcor revenues, exports, and savings, with optional Accord funds.

✅ $575.4M yearly to hold rates near 14.67 cents/kWh

✅ Sources: Nalcor oil $231M, Holyrood $150M, rates/dividends $123.4M

✅ Options: export sales, restructuring, Atlantic Accord, HQ tax

 

Newfoundland and Labrador PC Leader Ches Crosbie says Muskrat Falls won't drive up electricity rates, a goal consistent with an agreement to shield ratepayers from cost overruns, if he's elected premier.

According to Crosbie, who presented the party's Crosbie Hydro Energy Action Plan — acronym CHEAP — at a press conference Monday, $575.4 million is needed per year in order to keep rates from ballooning past 14.67 cents per kilowatt hour.

Here's where he thinks the money could come from:

  • Hydro rates and dividends — $123.4 million
  • Export sales — $40.1 million
  • Nalcor restructuring — $30 million
  • Holyrood savings — $150  million
  • Nalcor oil revenue — $231 million

The oil money, Crosbie said, isn't going into government coffers but being invested into the offshore which, he said, is a good place for it.

"But the plan from the beginning around Muskrat Falls was that if there was need for it — for mitigation for rates — that those revenues and operating cash flows from Nalcor oil and gas would be available to be recycled into rate mitigation, as reflected in a recent financial update on the pandemic's impact. and that's what we're going to have to do," he said.

According to Crosbie, his numbers come from the preliminary stage of the Public Utilities Board process, even as rate mitigation talks have lacked public details.

This is a recent aerial view of the Muskrat Falls project in central Labrador. The project is more than 90 per cent complete, with first power forecast for late 2019, alongside Ottawa's $5.2B support for the project. (Nalcor)

"I'm telling you this is the best information available to anyone outside of government," he said. "We're working on what we can."

The PUB estimated Nalcor restructuring could save between $10 million and $15 million, according to Crosbie, but he figures there's "enough duplication and overpayment involved in the way things are now set up that we can find $30 million there."

Currently, provincial ratepayers pay about 12 cents per kilowatt hour as electricity users have started paying for Muskrat Falls costs.

Crosbie's $575.4-million figure would put rates at 14.67 cents per kilowatt-hour in 2021, where his plan pledges to keep them.

A recent Public Utilities Board Report says there's a potential $10 million to $15 million in savings from Nalcor, but Crosbie says he can find $30 million. (CBC)

"The promise is that Muskrat Falls, when it comes online — comes in service — will not increase your rates. Between now and when that happens there are rate increases already in the pipeline up to that level of [14.67 cents per kilowatt-hour] … so that is the baseline target rate at which rates will be kept.

"In other words, Muskrat will not drive up prices for electricity to consumers beyond that point."

In addition to those savings, Crosbie's plan outlined two further steps.

"We think it could be done out of the resources that I've just identified now, but if there's a problem with that, and as a temporary measure, we can use a modest amount of the Atlantic Accord review, fiscal review, revenues," he said.

 

Plan 'nothing new'

Premier Dwight Ball slammed the plan at the House of Assembly on Monday, saying it lacked insight.

"It was a copy and paste exercise," he told reporters. "There's nothing new in that plan. Not at all."

"We're not leaving any stone unturned of where the opportunity would be to actually generate revenue," he said.  "We are genuinely concerned about rate mitigation and we've got to get a plan in place."

 

Potential to tax Hydro-Québec

Crosbie also said there's potential to tax Hydro-Québec.

According to Crosbie, tax exemptions that expired in 2016 allow the province to tax exports from the Upper Churchill, which, he said, could result in "hundreds of millions or billions" in revenue.

"It's not my philosophy to immediately go and do that because that would generate litigation — who needs more of that? — but we do need to let Quebec know that we're very aware of that, and aware of that opportunity, and invite them to come talk about a whole host of issues," Crosbie said.

Crosbie said the tax would also have to be applied to domestic consumption.

"But so massive is the potential revenue from the Upper Churchill export that there would be ways to mitigate that and negate the effect of that on consumers in the province."

Crosbie said with the Atlantic Accord revenue, he could still present a balanced budget by 2022.

 

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Ontario Provides Stable Electricity Pricing for Industrial and Commercial Companies

Ontario ICI Electricity Pricing Freeze helps Industrial Conservation Initiative (ICI) participants by stabilizing Global Adjustment charges, suspending peak hours curtailment, and reducing COVID-19-related electricity cost volatility to support large employers returning operations to full capacity.

 

Key Points

A two-year policy stabilizing GA costs and pausing peak-hour cuts to aid industrial and commercial recovery.

✅ GA cost share frozen for two years

✅ No peak-hour curtailment obligations

✅ Supports industrial and commercial restart

 

The Ontario government is helping large industrial and commercial companies return to full levels of operation without the fear of electricity costs spiking by providing more stable electricity pricing for two years. Effective immediately, companies that participate in the Industrial Conservation Initiative (ICI) will not be required to reduce their electricity usage during peak hours or shift some load to ultra-low overnight pricing where applicable, as their proportion of Global Adjustment (GA) charges for these companies will be frozen.

"Ontario's industrial and commercial electricity consumers continue to experience unprecedented economic challenges during COVID-19, with electricity relief for households and small businesses introduced to help," said Greg Rickford, Minister of Energy, Northern Development and Mines. "Today's announcement will allow large industrial employers to focus on getting their operations up and running and employees back to work, instead of adjusting operations in response to peak electricity demand hours."

Due to COVID-19, electricity consumption in Ontario has been below average as fall in demand as people stayed home across the province, and the province is forecast to have a reliable supply of electricity, supported by the system operator's staffing contingency plans during the pandemic, to accommodate increased usage. Peak hours generally occur during the summer when the weather is hot and electricity demand from cooling systems is high.

"Today's action will reduce the burden of anticipating and responding to peak hours for more than 1,300 ICI participants with 2,000 primarily industrial facilities in Ontario," said Bill Walker, Associate Minister of Energy. "Now these large employers can focus on getting their operations back up and running at full tilt and explore new energy-efficiency programs to manage costs."

The government previously announced it was providing temporary relief for industrial and commercial electricity consumers that do not participate in the Regulated Price Plan (RPP) by deferring a portion of GA charges for April, May and June 2020 and by extending off-peak rates for many customers, as well as a disconnect moratorium extension for residential electricity users.

 

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Quebec premier inaugurates La Romaine hydroelectric complex

La Romaine Hydroelectric Complex anchors Quebec's hydropower expansion, showcasing Hydro-Québec ingenuity, clean energy, electrification, and grid capacity gains along the North Shore's Romaine River to power industry and nearly 470,000 homes.

 

Key Points

A four-station, $7.4B hydro project on Quebec's Romaine River producing 8 TWh a year for electrification and industry.

✅ Generates 8 TWh yearly, powering about 470,000 homes

✅ Largest Quebec hydro build since James Bay project

✅ Key to clean energy, grid capacity, and electrification

 

Quebec Premier François Legault has inaugurated the la Romaine hydroelectric complex on the province's North Shore.

The newly inaugurated Romaine hydroelectric complex could serve as a model for future projects, such as the Carillon Generating Station investment now planned in the province, Legault said.

"It brings me a lot of pride. It is truly the symbol of Quebec ingenuity," he said as he opened the vast power plant.

Legault was accompanied at today's event by Jean Charest, who was Quebec premier when construction began in 2009, as well as Hydro-Québec president and CEO Michael Sabia. 

La Romaine is comprised of four power stations and is the largest hydro project constructed in the province since the Robert Bourassa generation facility, which was commissioned in 1979. It is the biggest hydro installation since the James Bay project, bolstering Hydro-Québec's hydropower capacity across the grid today.

The construction work for Romaine-4 was supposed to finish in 2020, but it was delayed the COVID-19 pandemic, the death of four workers due to security flaws and soil decomposition problems. 

The $7.4-billion la Romaine complex can produce eight terawatt hours of electricity per year, enough to power nearly 470,000 homes.

It generates its power from the Romaine River, located north of Havre-St-Pierre, Que., near the Labrador border, where long-standing Newfoundland and Labrador tensions over Quebec's projects sometimes resurface today.

Legault said that Quebec still doesn't have enough electricity to meet demand from industry, including recent allocations of electricity for industrial projects across the province, and Quebecers need to consider more ways to boost the province's ability to power future projects. The premier has said previously that demand is expected to surge by an additional 100 terawatt-hours by 2050 — half the current annual output of the provincially owned utility.

Legault's environmental plan of reducing greenhouse gases and achieving carbon neutrality by 2050 hinges on increased electrification and a strategy to wean off fossil fuels provincewide, so the electricity needs for transport and industry will be massive.

An updated strategic plan from Hydro-Quebec will be presented in November outlining those needs, president and CEO Michael Sabia told reporters on Thursday, after recent deals with NB Power underscored interprovincial demand.

Legault said the report will trigger a broader debate on energy transition and how the province can be a leader in the green economy. He said he wasn't ruling out any potential power sources — except for a return to nuclear power at this stage.

 

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Physicists Just Achieved Conduction of Electricity at Close to The Speed of Light

Attosecond Electron Transport uses ultrafast lasers and single-cycle light pulses to drive tunneling in bowtie gold nanoantennas, enabling sub-femtosecond switching in optoelectronic nanostructures and surpassing picosecond silicon limits for next-gen computing.

 

Key Points

A light-driven method that manipulates electrons with ultrafast pulses to switch currents within attoseconds.

✅ Uses single-cycle light pulses to drive electron tunneling

✅ Achieves 600 attosecond current switching in nano-gaps

✅ Enables optoelectronic, plasmonic devices beyond silicon

 

When it comes to data transfer and computing, the faster we can shift electrons and conduct electricity the better – and scientists have just been able to transport electrons at sub-femtosecond speeds (less than one quadrillionth of a second) in an experimental setup.

The trick is manipulating the electrons with light waves that are specially crafted and produced by an ultrafast laser. It might be a long while before this sort of setup makes it into your laptop, but similar precision is seen in noninvasive interventions where targeted electrical stimulation can boost short-term memory for limited periods, and the fact they pulled it off promises a significant step forward in terms of what we can expect from our devices.

Right now, the fastest electronic components can be switched on or off in picoseconds (trillionths of a second), a pace that intersects with debates over 5G electricity use as systems scale, around 1,000 times slower than a femtosecond.

With their new method, the physicists were able to switch electric currents at around 600 attoseconds (one femtosecond is 1,000 attoseconds).

"This may well be the distant future of electronics," says physicist Alfred Leitenstorfer from the University of Konstanz in Germany. "Our experiments with single-cycle light pulses have taken us well into the attosecond range of electron transport."

Leitenstorfer and his colleagues were able to build a precise setup at the Centre for Applied Photonics in Konstanz. Their machinery included both the ability to carefully manipulate ultrashort light pulses, and to construct the necessary nanostructures, including graphene architectures, where appropriate.

The laser used by the team was able to push out one hundred million single-cycle light pulses every single second in order to generate a measurable current. Using nanoscale gold antennae in a bowtie shape (see the image above), the electric field of the pulse was concentrated down into a gap measuring just six nanometres wide (six thousand-millionths of a metre).

As a result of their specialist setup and the electron tunnelling and accelerating it produced, the researchers could switch electric currents at well under a femtosecond – less than half an oscillation period of the electric field of the light pulses.

Getting beyond the restrictions of conventional silicon semiconductor technology has proved a challenge for scientists, but using the insanely fast oscillations of light to help electrons pick up speed could provide new avenues for pushing the limits on electronics, as our power infrastructure is increasingly digitized and integrated with photonics.

And that's something that could be very advantageous in the next generation of computers: scientists are currently experimenting with the way that light and electronics could work together in all sorts of different ways, from noninvasive brain stimulation to novel sensors.

Eventually, Leitenstorfer and his team think that the limitations of today's computing systems could be overcome using plasmonic nanoparticles and optoelectronic devices, using the characteristics of light pulses to manipulate electrons at super-small scales, with related work even exploring electricity from snowfall under specific conditions.

"This is very basic research we are talking about here and may take decades to implement," says Leitenstorfer.

The next step is to experiment with a variety of different setups using the same principle. This approach might even offer insights into quantum computing, the researchers say, although there's a lot more work to get through yet - we can't wait to see what they'll achieve next.

 

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Biggest offshore windfarm to start UK supply this week

Hornsea One Offshore Wind Farm delivers first power to the UK grid, scaling renewable energy with 1.2GW capacity, giant offshore turbines, and Yorkshire coast infrastructure to replace delayed nuclear and cut fossil fuel emissions.

 

Key Points

Hornsea One Offshore Wind Farm is a 1.2GW UK project delivering offshore renewable power to about 1 million homes.

✅ 174 turbines over 407 km2; Siemens Gamesa supply chain in the UK

✅ 1.2GW capacity can power ~1m homes; phases scale with 10MW+ turbines

✅ Supports UK grid, replaces delayed nuclear, cuts fossil generation

 

An offshore windfarm on the Yorkshire coast that will dwarf the world’s largest when completed is to supply its first power to the UK electricity grid this week, mirroring advances in tidal electricity projects delivering to the grid as well.

The Danish developer Ørsted, which has installed the first of 174 turbines at Hornsea One, said it was ready to step up its plans and fill the gap left by failed nuclear power schemes.

The size of the project takes the burgeoning offshore wind power sector to a new scale, on a par with conventional fossil fuel-fired power stations.

Hornsea One will cover 407 square kilometres, five times the size of the nearby city of Hull. At 1.2GW of capacity it will power 1m homes, making it about twice as powerful as today’s biggest offshore windfarm once it is completed in the second half of this year.

“The ability to generate clean electricity offshore at this scale is a globally significant milestone at a time when urgent action needs to be taken to tackle climate change,” said Matthew Wright, UK managing director of Ørsted, the world’s biggest offshore windfarm builder.

The power station is only the first of four planned in the area, with a green light and subsidies already awarded to a second stage due for completion in the early 2020s, and interest from Japanese utilities underscoring growing investor appetite.

The first two phases will use 7MW turbines, which are taller than London’s Gherkin building.

But the latter stages of the Hornsea development could use even more powerful, 10MW-plus turbines. Bigger turbines will capture more of the energy from the wind and should lower costs by reducing the number of foundations and amount of cabling firms need to put into the water, with developers noting that offshore wind can compete with gas in the U.S. as costs fall.

Henrik Poulsen, Ørsted’s chief executive, said he was in close dialogue with major manufacturers to use the new generation of turbines, some of which are expected to approach the height of the Shard in London, the tallest building in the EU.

The UK has a great wind resource and shallow enough seabed to exploit it, and could even “power most of Europe if it [the UK] went to the extreme with offshore”, he said.

Offshore windfarms could help ministers fill the low carbon power gap created by Hitachi and Toshiba scrapping nuclear plants, the executive suggested. “If nuclear should play less of a role than expected, I believe offshore wind can step up,” he said.

New nuclear projects in Europe had been “dramatically delayed and over budget”, he added, in comparison to “the strong track record for delivering offshore [wind]”.

The UK and Germany installed 85% of new offshore wind power capacity in the EU last year, according to industry data, with wind leading power across several markets. The average power rating of the turbines is getting bigger too, up 15% in 2018.

The turbines for Hornsea One are built and shipped from Siemens Gamesa’s factory in Hull, part of a web of UK-based suppliers that has sprung up around the growing sector, such as Prysmian UK's land cables supporting grid connections.

Around half of the project’s transition pieces, the yellow part of the structure that connects the foundation to the tower, are made in Teeside. Many of the towers themselves are made by a firm in Campbeltown in the Scottish highlands. Altogether, about half of the components for the project are made in the UK.

Ørsted is not yet ready to bid for a share of a £60m pot of further offshore windfarm subsidies, to be auctioned by the government this summer, but expects the price to reach even more competitive levels than those seen in 2017.

Like other international energy companies, Ørsted has put in place contingency planning in event of a no-deal Brexit – but the hope is that will not come to pass. “We want a Brexit deal that will facilitate an orderly transition out of the union,” said Poulsen.

 

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