WWF aims for 600,000 electric vehicles in Canada by 2020

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Recently, WWF-Canada World Wildlife Fund announced the launch of Transportation rEVolution, a program aimed at reducing CanadaÂ’s greenhouse gas GHG emissions from transportation by encouraging the use of electric vehicles EVs.

A recent Environics study commissioned by WWF-Canada showed that while Canadians overwhelmingly support EVs 73 percent support government actions to promote electric cars they are unclear on the environmental value of EVs. The research found that just 26 percent of Canadians strongly agree that vehicle emissions in Canada are a major source of climate change, and 36 percent of Canadians are unsure about the impact of an EV on reducing a householdÂ’s GHG emissions. WWFÂ’s Transportation rEVevolution program is expected to provide information to help Canadians make informed decisions about their transportation choices.

Based on modeling completed in WWF’s “Greenhouse Gas Reduction Potential of Electric Vehicles: 2025 Outlook Report”, WWF has set a target of 600,000 EVs--accounting for 10 percent of vehicle sales--on Canada’s roads by 2020. To achieve this goal, WWF will work with governments, businesses and individuals to:

-- Highlight environmental benefits of EVs support improved access to EVs and EV infrastructure

-- Achieve competitive pricing with conventional vehicles expand travel freedom for EV users with infrastructure and travel partnership options provide Canadians with positive EV information and experiences

Electric vehicles are part of a suite of sustainable transportation options necessary to reduce GHG emissions, including improved public transportation and urban design, as well as a shift to increased walking and cycling.

“Emissions from transportation are one of the biggest contributors to climate change, in Canada and around the world,” says Josh Laughren, Director, Climate and Energy Program, WWF-Canada. “Switching from gas-powered to electric vehicles is a critical part of building a sustainable transportation future.”

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Ukraine resumes electricity exports despite Russian attacks

Ukraine Electricity Exports resume to the European grid, starting with Moldova and expanding to Poland, Slovakia, and Romania, signaling energy security, grid resilience, added megawatts, and recovery after Russian strikes with support and renewables.

 

Key Points

Ukraine Electricity Exports are resumed sales of surplus power to EU neighbors, reflecting grid recovery and resilience.

✅ Initial deliveries to Moldova; Poland, Slovakia, Romania to follow.

✅ Extra capacity from repairs, warmer demand, and renewables.

✅ Exports may vary amid ongoing Russian strikes risk.

 

Ukraine began resuming electricity exports to European countries on Tuesday, its energy minister said, a dramatic turnaround from six months ago when fierce Russian bombardment of power stations plunged much of the country into darkness in a bid to demoralize the population.

The announcement by Energy Minister Herman Halushchenko that Ukraine was not only meeting domestic consumption demands but also ready to restart exports to its neighbors was a clear message that Moscow’s attempt to weaken Ukraine by targeting its infrastructure did not work.

Ukraine’s domestic energy demand is “100%” supplied, he told The Associated Press in an interview, and it has reserves to export due to the “titanic work” of its engineers and international partners.

Russia ramped up infrastructure attacks in September, when waves of missiles and exploding drones destroyed about half of Ukraine’s energy system. Power cuts were common across the country as temperatures dropped below freezing and tens of millions struggled to keep warm.

Moscow said the strikes were aimed at weakening Ukraine’s ability to defend itself, and has also moved to reactivate the Zaporizhzhia plant through new power lines, while Western officials said the blackouts that caused civilians to suffer amounted to war crimes. Ukrainians said the timing was designed to destroy their morale as the war marked its first anniversary.

Ukraine had to stop exporting electricity in October to meet domestic needs.

Engineers worked around the clock, often risking their lives to come into work at power plants and keep the electricity flowing. Kyiv’s allies also provided help. In December, U.S. Secretary of State Antony Blinken announced $53 million in bilateral aid to help the country acquire electricity grid equipment, and USAID mobile gas turbine plant support, on top of $55 million for energy sector support.

Much more work remains to be done, Halushchenko said. Ukraine needs funding to repair damaged generation and transmission lines, and revenue from electricity exports would be one way to do that.

The first country to receive Ukraine’s energy exports will be Moldova, he said.

Besides the heroic work by engineers and Western aid, warmer temperatures are enabling the resumption of exports by making domestic demand lower, even as Germany’s coal generation shapes regional power flows.

Renewables like solar and wind power also come into play as temperatures rise, taking some pressure off nuclear and coal-fired power plants.

But it’s unclear if Ukraine can keep up exports amid the constant threat of Russian bombardment, with any potential agreement on power plant attacks still uncertain.

“Unfortunately now a lot of things depend on the war,” Halushchenko said. “I would say we feel quite confident now until the next winter.”

Exports to Poland, Slovakia and Romania are also on schedule to resume, he said.

“Today we are starting with Moldova, and we are talking about Poland, we are talking about Slovakia and Romania,” Halushchenko added, noting that how much will depend on their needs.

“For Poland, we have only one line that allows us to export 200 megawatts, but I think this month we will finish another line which will increase this to an additional 400 MW, so these figures could change,” he said.

Export revenue will depend on fluctuating electricity prices in Europe, where stunted hydro and nuclear output may affect recovery. In 2022, while Ukraine was still able to export energy, Ukrainian companies averaged 40 million to 70 million euros a month depending on prices, Halushchenko said.
 

 

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Electricity prices rise more than double EU average in first half of 2021

Estonia energy prices 2021 show sharp electricity hikes versus the EU average, mixed natural gas trends, kWh tariffs on Nord Pool spiking, and VAT, taxes, and support measures shaping household bills.

 

Key Points

EU-high electricity growth, early gas dip, then Nord Pool spikes; taxes, VAT, and subsidies shaped energy bills.

✅ Electricity up 7% on year; EU average 2.8% in H1 2021.

✅ Gas fell 1% in H1; later spiked with global market.

✅ VAT, taxes, excise and aid impacted household costs.

 

Estonia saw one of the highest rates in growth of electricity prices in the first half of 2021, compared with the same period in key trends in 2020 across Europe. These figures were posted before the more recent, record level of electricity and natural gas prices; the latter actually dropped slightly in Estonia in the first half of the year.

While electricity prices rose 7 percent on year in the first half of 2021 in Estonia, the average for the EU as a whole, where energy prices drove inflation across the bloc, stood at 2.8 percent over the same period, BNS reports.

Hungary (€10 per 100 Kwh) and Bulgaria (€10.20 per 100 Kwh) saw the lowest electricity prices EU-wide, while at €31.9 per KWH, Germany's power prices posted the most expensive rate, while Denmark, Belgium and Ireland also had high prices, in excess of €25 per Kwh.

Slovenia saw the highest electricity price rise, at 15 percent, and even the United States' electricity prices saw their steepest rise in decades during the same era, while Estonia was in third place, joint with Romania at 7 percent as noted, and behind Poland (8 percent).

Lithuania, on the other hand, experienced the third highest electricity price fall over the first half of 2021, compared with the same period in 2020, at 6 percent, behind only Cyprus (7 percent) and the Netherlands (10 percent, largely due to a tax cut).

Urmas Reinsalu: VAT on electricity, gas and heating needs to be lowered
The EU average price of electricity was €21.9 percent per Kwh, with taxes and excise accounting for 39 percent of this, even as prices in Spain surged across the day-ahead market.

Estonia has also seen severe electricity price rises in the second half of the year so far, with records set and then promptly broken several times earlier in October, while an Irish electricity provider raised prices amid similar pressures, and a support package for low income households rolled out for the winter season (October to March next year). The price on the Nord Pool market as of €95.01 per Kwh; a day earlier it had stood at €66.21 per Kwh, while on October 19 the price was €140.68 per Kwh.

Gas prices
Natural gas prices to household, meanwhile, dropped in Estonia over the same period, at a sharper rate (1 percent) than the EU average (0.5 percent), according to Eurostat.

Gas prices across the EU were lowest in Lithuania (€2.8 per 100 Kwh) and highest in the Netherlands (€9.6 per KWH), while the highest growth was seen in Denmark (19 percent), in the first half of 2021.

Natural gas prices dropped in 20 member states, however, with the largest drop again coming in Lithuania (23 percent).

The average price of natural gas EU-side in the first half of 2021 was €6.4, and taxes and excise duties accounted on average for 36 percent of the total.

The second half of the year has seen steep gas price rises in Estonia, largely the result of increases on the world market, though European gas benchmarks later fell to pre-Ukraine war levels.

 

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Australia's energy transition stalled by stubbornly high demand

Australia Renewable Energy Transition: solar capacity growth, net-zero goals, rising electricity demand, coal reliance, EV adoption, grid decarbonization, heat waves, air conditioning loads, and policy incentives shaping clean power, efficiency, and emissions reduction.

 

Key Points

Australia targets net-zero by 2050 by scaling renewables, curbing demand, and phasing down coal and gas.

✅ Solar capacity up 200% since 2018, yet coal remains dominant.

✅ Transport leads energy use; EV uptake lags global average.

✅ Heat waves boost AC load, stressing grids and emissions goals.

 

A more than 200% increase in installed solar power generation capacity since 2018 helped Australia rank sixth globally in terms of solar capacity last year and emerge as one of the world's fastest-growing major renewable energy producers, aligning with forecasts that renewables to surpass coal in global power generation by 2025.

However, to realise its goal of becoming a net-zero carbon emitter by 2050, Australia must reverse the trajectory of its energy use, which remains on a rising path, even as Asia set to use half of electricity underscores regional demand growth, in contrast with several peers that have curbed energy use in recent years.

Australia's total electricity consumption has grown nearly 8% over the past decade, amid a global power demand surge that has exceeded pre-pandemic levels, compared with contractions over the same period of more than 7% in France, Germany and Japan, and a 14% drop in the United Kingdom, data from Ember shows.

Sustained growth in Australia's electricity demand has in turn meant that power producers must continue to heavily rely on coal for electricity generation on top of recent additions in supply of renewable energy sources, with low-emissions generation growth expected to cover most new demand.

Australia has sharply boosted clean energy capacity in recent years, but remains heavily reliant on coal & natural gas for electricity generation
To accomplish emissions reduction targets on time, Australia's energy use must decline while clean energy supplies climb further, as that would give power producers the scope to shut high-polluting fossil-powered energy generation systems ahead of the 2050 deadline.

DEMAND DRIVERS
Reducing overall electricity and energy use is a major challenge in all countries, where China's electricity appetite highlights shifting consumption patterns, but will be especially tough in Australia which is a relative laggard in terms of the electrification of transport systems and is prone to sustained heat waves that trigger heavy use of air conditioners.

The transport sector uses more energy than any other part of the Australian economy, including industry, and accounted for roughly 40% of total final energy use as of 2020, according to the International Energy Agency (IEA.)

Transport energy demand has also expanded more quickly than other sectors, growing by over 5% from 2010 to 2020 compared to industry's 1.3% growth over the same period.

Transport is Australia's main energy use sector, and oil products are the main source of energy type
To reduce energy use, and cut the country's fuel import bill which topped AUD $65 billion in 2022 alone, according to the Australian Bureau of Statistics, the Australian government is keen to electrify car fleets and is offering large incentives for electric vehicle purchases.

Even so, electric vehicles accounted for only 5.1% of total Australian car sales in 2022, according to the International Energy Agency (IEA).

That compares to 13% in New Zealand, 21% in the European Union, and a global average of 14%.

More incentives for EV purchases are expected, but any rapid adoption of EVs would only serve to increase overall electricity demand, and with surging electricity demand already straining power systems worldwide, place further pressure on power producers to increase electricity supplies.

Heating and cooling for homes and businesses is another major energy demand driver in Australia, and accounts for roughly 40% of total electricity use in the country.

Australia is exposed to harsh weather conditions, especially heat waves which are expected to increase in frequency, intensity and duration over the coming decades due to climate change, according to the New South Wales government.

To cope, Australians are expected to resort to increased use of air conditioners during the hottest times of the year, and with reduced power reserves flagged by the market operator, adding yet more strain to electricity systems.

 

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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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Was there another reason for electricity shutdowns in California?

PG&E Wind Shutdown and Renewable Reliability examines PSPS strategy, wildfire risk, transmission line exposure, wind turbine cut-out speeds, grid stability, and California's energy mix amid historic high-wind events and supply constraints across service areas.

 

Key Points

An overview of PG&E's PSPS decisions, wildfire mitigation, and how wind cut-out limits influence grid reliability.

✅ Wind turbines reach cut-out near 55 mph, reducing generation.

✅ PSPS mitigates ignition from damaged transmission infrastructure.

✅ Baseload diversity improves resilience during high-wind events.

 

According to the official, widely reported story, Pacific Gas & Electric (PG&E) initiated power shutoffs across substantial portions of its electric transmission system in northern California as a precautionary measure.

Citing high wind speeds they described as “historic,” the utility claims that if it didn’t turn off the grid, wind-caused damage to its infrastructure could start more wildfires.

Perhaps that’s true. Perhaps. This tale presumes that the folks who designed and maintain PG&E’s transmission system are unaware of or ignored the need to design it to withstand severe weather events, and that the Federal Energy Regulatory Commission (FERC) and North American Electric Reliability Corp. (NERC) allowed the utility to do so.

Ignorance and incompetence happens, to be sure, but there’s much about this story that doesn’t smell right—and it’s disappointing that most journalists and elected officials are apparently accepting it without question.

Take, for example, this statement from a Fox News story about the Kincade Fires: “A PG&E meteorologist said it’s ‘likely that many trees will fall, branches will break,’ which could damage utility infrastructure and start a fire.”

Did you ever notice how utilities cut wide swaths of trees away when transmission lines pass through forests? There’s a reason for that: When trees fall and branches break, the grid can still function, and even as the electric rhythms of New York City shifted during COVID-19, operators planned for variability.

So, if badly designed and poorly maintained infrastructure isn’t the reason PG&E cut power to millions of Californians, what might have prompted them to do so? Could it be that PG&E’s heavy reliance on renewable energy means they don’t have the power to send when a “historic” weather event occurs, especially as policymakers weigh the postponed closure of three power plants elsewhere in California?

 

Wind Speed Limits

The two most popular forms of renewable energy come with operating limitations, which is why some energy leaders urge us to keep electricity options open when planning the grid. With solar power, the constraint is obvious: the availability of sunlight. One doesn’t generate solar power at night and energy generation drops off with increasing degrees of cloud cover during the day.

The main operating constraint of wind power is, of course, wind speed, and even in markets undergoing 'transformative change' in wind generation, operators adhere to these technical limits. At the low end of the scale, you need about a 6 or 7 miles-per-hour wind to get a turbine moving. This is called the “cut-in speed.” To generate maximum power, about a 30 mph wind is typically required. But, if the wind speed is too high, the wind turbine will shut down. This is called the “cut-out speed,” and it’s about 55 miles per hour for most modern wind turbines.

It may seem odd that wind turbines have a cut-out speed, but there’s a very good reason for it. Each wind turbine rotor is connected to an electric generator housed in the turbine nacelle. The connection is made through a gearbox that is sized to turn the generator at the precise speed required to produce 60 Hertz AC power.

The blades of the wind turbine are airfoils, just like the wings of an airplane. Adjusting the pitch (angle) of the blades allows the rotor to maintain constant speed, which, in turn, allows the generator to maintain the constant speed it needs to safely deliver power to the grid. However, there’s a limit to blade pitch adjustment. When the wind is blowing so hard that pitch adjustment is no longer possible, the turbine shuts down. That’s the cut-out speed.

Now consider how California’s power generation profile has changed. According to Energy Information Administration data, the state generated 74.3 percent of its electricity from traditional sources—fossil fuels and nuclear, amid debates over whether to classify nuclear as renewable—in 2001. Hydroelectric, geothermal, and biomass-generated power accounted for most of the remaining 25.7 percent, with wind and solar providing only 1.98 percent of the total.

By 2018, the state’s renewable portfolio had jumped to 43.8 percent of total generation, with clean power increasing and wind and solar now accounting for 17.9 percent of total generation. That’s a lot of power to depend on from inherently unreliable sources. Thus, it wouldn’t be at all surprising to learn that PG&E didn’t stop delivering power out of fear of starting fires, but because it knew it wouldn’t have power to deliver once high winds shut down all those wind turbines

 

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Court reinstates constitutional challenge to Ontario's hefty ‘global adjustment’ electricity charge

Ontario Global Adjustment Charge faces constitutional scrutiny as a regulatory charge vs tax; Court of Appeal revives case over electricity pricing, feed-in tariff contracts, IESO policy, and hydro rate impacts on consumers and industry.

 

Key Points

A provincial electricity fee funding generator contracts, now central to a court fight over tax versus regulatory charge.

✅ Funds gap between market price and contracted generator rates

✅ At issue: regulatory charge vs tax under constitutional law

✅ Linked to feed-in tariff, IESO policy, and hydro rate hikes

 

Ontario’s court of appeal has decided that a constitutional challenge of a steep provincial electricity charge should get its day in court, overturning a lower-court judgment that had dismissed the legal bid.

Hamilton, Ont.-based National Steel Car Ltd. launched the challenge in 2017, saying Ontario’s so-called global adjustment charge was unconstitutional because it is a tax — not a valid regulatory charge — that was not passed by the legislature.

The global adjustment funds the difference between the province’s hourly electricity price and the price guaranteed under contracts to power generators. It is “the component that covers the cost of building new electricity infrastructure in the province, maintaining existing resources, as well as providing conservation and demand management programs,” the province’s Independent Electricity System Operator says.

However, the global adjustment now makes up most of the commodity portion of a household electricity bill, and its costs have ballooned, as regulators elsewhere consider a proposed 14% rate hike in Nova Scotia.

Ontario’s auditor general said in 2015 that global adjustment fees had increased from $650 million in 2006 to more than $7 billion in 2014. She added that consumers would pay $133 billion in global adjustment fees from 2015 to 2032, after having already paid $37 billion from 2006 to 2014.

National Steel Car, which manufactures steel rail cars and faces high electricity rates that hurt Ontario factories, said its global adjustment costs went from $207,260 in 2008 to almost $3.4 million in 2016, according to an Ontario Court of Appeal decision released on Wednesday.

The company claimed the global adjustment was a tax because one of its components funds electricity procurement contracts under a “feed-in tariff” program, or FIT, which National Steel Car called “the main culprit behind the dramatic price increases for electricity,” the decision said.

Ontario’s auditor general said the FIT program “paid excessive prices to renewable energy generators.” The program has been ended, but contracts awarded under it remain in place.


National Steel Car claimed the FIT program “was actually designed to accomplish social goals unrelated to the generation of electricity,” such as helping rural and indigenous communities, and was therefore a tax trying to help with policy goals.

“The appellant submits that the Policy Goals can be achieved by Ontario in several ways, just not through the electricity pricing formula,” the decision said.

National Steel Car also argued the global adjustment violated a provincial law that requires the government to hold a referendum for new taxes.

“The appellant’s principal claim is that the Global Adjustment was a ‘colourable attempt to disguise a tax as a regulatory charge with the purpose of funding the costs of the Policy Goals,’” the decision said. “The appellant pressed this argument before the motion judge and before this court. The motion judge did not directly or adequately address it.”

The Ontario government applied to have the challenge thrown out for having “no reasonable cause of action,” and a Superior Court judge did so in 2018, saying the global adjustment is not a tax.

National Steel Car appealed the decision, and the decision published Wednesday allowed the appeal, set aside the lower-court judgment, and will send the case back to Superior Court, where it could get a full hearing.

“The appellant’s claim is sufficiently plausible on the evidentiary record it put forward that the applications should not have been dismissed on a pleadings motion before the development of a full record,” wrote Justice Peter D. Lauwers. “It is not plain, obvious and beyond doubt that the Global Adjustment, and particularly the challenged component, is properly characterized as a valid regulatory charge and not as an impermissible tax.”

Jerome Morse of Morse Shannon LLP, one of National Steel Car’s lawyers, said the Ontario government would now have 60 days to decide whether to seek permission to appeal to the Supreme Court of Canada.

“What the court has basically said is, ‘this is a plausible argument, here are the reasons why it’s plausible, there was no answer to this,’” Morse told the Financial Post.

Ontario and the IESO had supported the lower-court decision, but there has been a change in government since the challenge was first launched, with Progressive Conservative Premier Doug Ford replacing the Liberals and Kathleen Wynne in power. The Liberals had launched a plan aimed at addressing hydro costs before losing in a 2018 election, the main thrust of which had been to refinance global adjustment costs.

Wednesday’s decision states that “Ontario’s counsel advised the court that the current Ontario government ‘does not agree with the former government’s electricity procurement policy (since-repealed).’

“The government’s view is that: ‘The solution does not lie with the courts, but instead in the political arena with political actors,’” it adds.

A spokesperson for Ontario Energy Minister Greg Rickford said in an email that they are reviewing the decision but “as this matter is in the appeal period, it would be inappropriate to comment.” 

Ontario had also requested to stay the matter so a regulator, the Ontario Energy Board, could weigh in, while the Nova Scotia regulator approved a 14% hike in a separate case.

“However, Ontario only sought this relief from the motion judge in the alternative, and given the motion judge’s ultimate decision, she did not rule on the stay,” Thursday’s decision said. “It would be premature for this court to rule on the issue, although it seems incongruous for Ontario to argue that the Superior Court is the convenient forum in which to seek to dismiss the applications as meritless, but that it is not the convenient forum for assessing the merits of the applications.”

National Steel Car’s challenge bears a resemblance to the constitutional challenges launched by Ontario and other provinces over the federal government’s carbon tax, but Justice Lauwers wrote “that the federal legislative scheme under consideration in those cases is distinctly different from the legislation at issue in this appeal.”

“Nothing in those decisions impacts this appeal,” the judge added.
 

 

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