AESO receives international recognition for wind integration

By Marketwire


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U.S.-based Utility Wind Integration Group (UWIG) announced John Kehler, a senior technical specialist with the Alberta Electric System Operator (AESO), as one of its 2008 Honorees for Achievement in Wind Integration.

Kehler is part of the team leading the AESO's efforts to address the challenges of integrating wind into the Alberta electricity market and to determine appropriate mitigation measures to ensure system reliability and fair, open and efficient market operation. He has also led and been involved in AESO efforts with stakeholders to develop a clear set of rules to guide participation of wind generators in the market and a wind forecasting pilot project to assist system operators in dealing with the variable nature of wind generation. All of this has resulted in Alberta becoming the Canadian leader in wind power development.

In the citation for the award, UWIG President Henry Durrwachter states that "John Kehler has made a significant contribution to the electric power and wind industries and is to be commended for advancing the integration of wind generation and his work in addressing the challenges of integrating wind into the Alberta electricity market."

"We are very proud of the work the AESO has done in collaboration with stakeholders on wind integration and John has shown great foresight, commitment and leadership," said AESO Vice- President Operations and Reliability Warren Frost. "This amounts to the AESO receiving international recognition for our industry leading efforts in wind integration."

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Experts warn Albertans to lock in gas and electricity rates as prices set to soar

Alberta Energy Price Spike signals rising electricity and natural gas costs; lock in fixed rates as storage is low, demand surged in heat waves, and exports rose after Hurricane Ida, driving volatility and higher futures.

 

Key Points

An anticipated surge in Alberta electricity and natural gas prices, urging consumers to lock fixed rates to reduce risk.

✅ Fixed-rate gas near $3.79/GJ vs futures approaching $6/GJ

✅ Low storage after heat waves and U.S. export demand

✅ Switch providers or plans; UCA comparison tool helps

 

Energy economists are warning Albertans to review their gas and electricity bills and lock in a fixed rate if they haven't already done so because prices are expected to spike in the coming months.

"I have been urging anyone who will listen that every single Albertan should be on a fixed rate for this winter," University of Calgary energy economist Blake Shaffer said Monday. "And I say that for both natural gas and power."

Shaffer said people will rightly point out energy costs make up only roughly a third of their monthly bill. The rest of the costs for such things as delivery fees can't be avoided. 

But, he said, "there is an energy component and it is meaningful in terms of savings." 

For example, Shaffer said, when he checked last week, a consumer could sign a fixed rate gas contract for $3.79 a gigajoule and the current future price for gas is nearly $6 a gigajoule.

A typical household would use about 15 gigajoules a month, he said, so a consumer could save $30 to $45 a month for five months. For people on lower or fixed incomes, "that is a pretty significant saving."

Comparable savings can also be achieved with electricity, he said.

Shaffer said research has shown households that are least able to afford sharp increases in gas and electrical bills are less likely to pick up the phone and call their energy provider and either negotiate a lower fixed rate contract or jump to a new provider. 

But, he said, it is definitely worth the time and effort, particularly as Calgary electricity bills are rising across the city. Alberta's Utilities Consumer Advocate has a handy cost comparison tool on its website that allows consumers to conduct regional price comparisons that will assist in making an informed decision.

"Folks should know that for most providers you can change back to a floating rate any time you want," Shaffer said.

Summer heat wave affected natural gas supply
Why are energy prices set to spike in Alberta, which is a major producer of natural gas?

Sophie Simmonds, managing director of the brokerage firm Anova Energy, said Alberta is now generating the majority of its power using natural gas. 

The heat wave in June and July created record electrical demand. Normally, natural gas is stored in the summer for use in the winter. But this year, there was much greater gas consumption in the summer and so less was stored. 

Alberta also set a new electricity usage record during a recent deep freeze, underscoring system stress.

On top of that, Alberta has been exporting much more natural gas to the United States since August and September because Hurricane Ida knocked out natural gas assets in the Gulf of Mexico.

"So what this means is we are actually going into winter with very, very low storage numbers," Simmonds said.

Why natural gas prices have surged to some of their highest levels in years
Canadians to remain among world's top energy users even as government strives for net zero
Consultant Matt Ayres said he believes rising electricity prices also are being affected by Alberta's transition from carbon-intensive fuel sources to less carbon-intensive fuel sources.

"That transition is not always smooth," said Ayres, who is also an adjunct assistant professor at the University of Calgary's School of Public Policy. 

"It is my view that at least some of the price increases we are seeing on electricity comes down to difficulties imposed by that transition and also by a reduction in competition amongst generators, as well as power market overhaul debates shaping policy." 

In 2019, under the leadership of Premier Jason Kenney the UCP government removed the former NDP government's rate cap on electricity at the time.

The NDP has called for the government to reinstate the cap but the UCP government has dismissed that as unsustainable and unrealistic.

 

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Nuclear plant workers cite lack of precautions around virus

Millstone COVID-19 safety concerns center on a nuclear refueling outage in Connecticut, temporary workers, OSHA complaints, PPE shortages, and disinfecting protocols, as Dominion Energy addresses virus precautions, staffing, and cybersecurity for safe voting infrastructure.

 

Key Points

Employee and union claims about PPE, cleaning, and OSHA compliance during a refueling outage at the nuclear plant.

✅ 10 positive cases; 750 temporary workers during refueling outage

✅ Union cites PPE gaps, partitions, and disinfectant effectiveness

✅ Dominion Energy notes increased cleaning, communication, staffing

 

Workers at Connecticut's only nuclear power plant worry that managers are not taking enough precautions against the coronavirus, as some utilities weigh on-site staffing measures to maintain operations, after 750 temporary employees were brought in to help refuel one of the two active reactors.

Ten employees at the Millstone Power Station in Waterford have tested positive for the virus, and, amid a U.S. grid pandemic warning, the arrival of the temporary workers alarms some of the permanent employees, The Day newspaper reported Sunday.

"Speaking specifically for the guard force, there's a lot of frustration, there's a lot of concern, and I would say there's anger," said Millstone security officer Jim Foley.

Foley, vice president of the local chapter of the United Government Security Officers of America, noted broader labor concerns such as unpaid wages for Kentucky miners while saying security personnel have had to fight for personal protective equipment and for partitions at access points to separate staff from security.

Foley also has filed a complaint with the Occupational Safety and Health Administration saying Millstone staff are using ineffective cleaning materials and citing a lack of cleaning and sanitizing, as telework limits at the EPA drew scrutiny during the pandemic, he said.

Officials at Millstone, owned by Dominion Energy, have not heard internal criticism about the plant's virus precautions, Millstone spokesman Kenneth Holt said.

"We've actually gotten a lot of compliments from employees on the steps we've taken," he said. "We've stepped up communications with employees to let them know what's going on."

As another example of communication efforts, COVID-19 updates at Site C have been published to keep workers informed.

Millstone recently increased cleaning staff on the weekends, Holt said, and there is regular disinfecting at the plant.

Separately, utility resilience remains a concern, as extended outages for tornado survivors in Kentucky may last weeks, affecting essential services.

Responding to the complaint about ineffective cleaning materials, Holt said staff members early in the pandemic went to a Home Depot and got a bottle of disinfectant that wasn't approved by the federal government as effective against the coronavirus. An approved disinfectant was brought in the next day, he said.

The deaths of nearly 2,500 Connecticut residents have been linked to COVID-19, the disease caused by the virus. More than 29,000 state residents have tested positive. As of Sunday, hospitalizations had declined for 11 consecutive days, to over 1,480.

With more people working remotely, utilities have reported higher residential electricity use during the pandemic, affecting household bills.

For most people, the coronavirus causes mild or moderate symptoms, such as fever and cough, that clear up in two to three weeks. For some, especially older adults and people with existing health problems, it can cause more severe illness, including pneumonia, and death.

In other developments related to the coronavirus:

SAFE VOTING

Secretary of the State Denise Merrill released a plan Monday aimed at making voting safe during the Aug. 11 primary and Nov. 3 general election.

Merrill said her office is requiring all cities and towns in the state to submit plans for the two elections that include a list of cleaning and safety products to be used, a list of polling locations, staffing levels at each polling location, and the names of polling workers and moderators.

Municipalities will be eligible for grants to cover the extra costs of holding elections during a pandemic, including expenses for cleaning products and increased staffing.

Merrill also announced her office and the Connecticut National Guard will perform a high-level cybersecurity assessment of the election infrastructure of all 169 towns in the state to guard against malicious actors.

Merrill's office also will provide network upgrades to the election infrastructures of 20 towns that have had chronic problems with connecting to the elections system.

 

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Annual U.S. coal-fired electricity generation will increase for the first time since 2014

U.S. coal-fired generation 2021 rose as higher natural gas prices, stable coal costs, and a recovering power sector shifted the generation mix; capacity factors rebounded despite low coal stocks and ongoing plant retirements.

 

Key Points

Coal output rose 22% on high gas prices and higher capacity factors; a 5% decline is expected in 2022.

✅ Natural gas delivered cost averaged $4.93/MMBtu, more than double 2020

✅ Coal capacity factor rose to ~51% from 40% in 2020

✅ 2022 coal generation forecast to fall about 5%

 

We expect 22% more U.S. coal-fired generation in 2021 than in 2020, according to our latest Short-Term Energy Outlook (STEO). The U.S. electric power sector has been generating more electricity from coal-fired power plants this year as a result of significantly higher natural gas prices and relatively stable coal prices, even as non-fossil sources reached 40% of total generation. This year, 2021, will yield the first year-over-year increase in coal generation in the United States since 2014, highlighted by a January power generation jump earlier in the year.

Coal and natural gas have been the two largest sources of electricity generation in the United States. In many areas of the country, these two fuels compete to supply electricity based on their relative costs and sensitivity to policies and gas prices as well. U.S. natural gas prices have been more volatile than coal prices, so the cost of natural gas often determines the relative share of generation provided by natural gas and coal.

Because natural gas-fired power plants convert fuel to electricity more efficiently than coal-fired plants, record natural gas generation has at times underscored that advantage, and natural gas-fired generation can have an economic advantage even if natural gas prices are slightly higher than coal prices. Between 2015 and 2020, the cost of natural gas delivered to electric generators remained relatively low and stable. This year, however, natural gas prices have been much higher than in recent years. The year-to-date delivered cost of natural gas to U.S. power plants has averaged $4.93 per million British thermal units (Btu), more than double last year’s price.

The overall decline in electricity demand in 2020 and record-low natural gas prices led coal plants to significantly reduce the percentage of time that they generated power. In 2020, the utilization rate (known as the capacity factor) of U.S. coal-fired generators averaged 40%. Before 2010, coal capacity factors routinely averaged 70% or more. This year’s higher natural gas prices have increased the average coal capacity factor to about 51%, which is almost the 2018 average, a year when wind and solar reached 10% nationally.

Although rising natural gas prices have resulted in more U.S. coal-fired generation than last year, this increase in coal generation will most likely not continue as solar and wind expand in the generation mix. The electric power sector has retired about 30% of its generating capacity at coal plants since 2010, and no new coal-fired capacity has come online in the United States since 2013. In addition, coal stocks at U.S. power plants are relatively low, and production at operating coal mines has not been increasing as rapidly as the recent increase in coal demand. For 2022, we forecast that U.S. coal-fired generation will decline about 5% in response to continuing retirements of generating capacity at coal power plants and slightly lower natural gas prices.

 

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Miami Valley Expands EV Infrastructure with 24 New Chargers

Miami Valley EV Chargers Expansion strengthens Level 2 charging infrastructure across Dayton, with Ohio EPA funding and Volkswagen settlement support, easing range anxiety and promoting sustainable transportation at Austin Landing and high-traffic destinations.

 

Key Points

An Ohio initiative installing 24 Level 2 stations to boost EV adoption, reduce range anxiety, and expand access in Dayton.

✅ 24 new Level 2 chargers at high-traffic regional sites

✅ Ohio EPA and VW settlement funds support deployment

✅ Reduces range anxiety, advancing sustainable mobility

 

The Miami Valley region in Ohio is accelerating its transition to electric vehicles (EVs) with the installation of 24 new Level 2 EV chargers, funded through a $1.1 million project supported by the Ohio Environmental Protection Agency (EPA). This initiative aims to enhance EV accessibility and alleviate "range anxiety" among drivers as the broader U.S. EV boom tests grid readiness.

Strategic Locations Across the Region

The newly installed chargers are strategically located in high-traffic areas to maximize their utility as national charging networks compete to expand coverage across travel corridors. Notable sites include Austin Landing, the Dayton Art Institute, the Oregon District, Caesar Creek State Park, and the Rose Music Center. These locations were selected to ensure that EV drivers have convenient access to charging stations throughout the region, similar to how Ontario streamlines station build-outs to place chargers where drivers already travel.

Funding and Implementation

The project is part of Ohio's broader effort to expand EV infrastructure, reflecting the evolution of U.S. charging infrastructure while utilizing funds from the Volkswagen Clean Air Act settlement. The Ohio EPA awarded approximately $3.25 million statewide for the installation of Level 2 EV chargers, with the Miami Valley receiving a significant portion of this funding, while Michigan utility programs advance additional investments to scale regional infrastructure.

Impact on the Community

The expansion of EV charging infrastructure is expected to have several positive outcomes. It will provide greater convenience for current EV owners and encourage more residents to consider electric vehicles as a viable transportation option, including those in apartments and condos who benefit from expanded access. Additionally, the increased availability of charging stations supports the state's environmental goals by promoting the adoption of cleaner, more sustainable transportation.

Looking Ahead

As the adoption of electric vehicles continues to grow, the Miami Valley's investment in EV infrastructure positions the region as a leader in sustainable transportation as utilities pursue ambitious charging strategies to meet demand. The success of this project may serve as a model for other regions looking to expand their EV charging networks. This initiative reflects a significant step towards a more sustainable and accessible transportation future for the Miami Valley.

 

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Is Ontario embracing clean power?

Ontario Clean Energy Expansion signals IESO-backed renewables, energy storage, and low-CO2 power to meet EV-driven demand, offset Pickering nuclear retirement, and balance interim gas-fired generation while advancing grid reliability, decarbonization, and net-zero targets.

 

Key Points

Ontario Clean Energy Expansion plans to grow renewables and storage, manage short-term gas, and meet rising demand.

✅ IESO long-term procurements for renewables and storage

✅ Interim reliance on gas to replace Pickering capacity

✅ Targets align with net-zero grid reliability goals

 

After cancelling hundreds of renewable power projects four years ago, the Doug Ford government appears set to expand clean energy to meet a looming electricity shortfall across the province.

Recent announcements from Ontario Energy Minister Todd Smith and the province’s electric grid management agency suggest the province plans to expand low-CO2 electricity with new wind and solar plans in the long-term, even as it ramps up gas-fired power over the next five years.

The moves are in response to an impending electricity shortfall as climate-conscious drivers switch to electric vehicles, farmers replace field crops with greenhouses and companies like ArcelorMittal Dofasco in Hamilton switch from CO2-heavy manufacturing to electricity-based production. Forecasters predict Canada will need to double its power supply by 2050.

While Ontario has a relatively low-CO2 power system, the province’s electricity supply will be reduced in 2025 when Ontario Power Generation closes the 50-year-old Pickering nuclear station, now near the end of its operating life. This will remove 3,100 megawatts of low-CO2 generation, about eight per cent of the province’s 40,000-megawatt total.

The impending closure has created a difficult situation for the Independent Electricity System Operator (IESO), the provincial agency managing Ontario’s grid. Last year, it forecasted it would need to sharply increase CO2-polluting natural gas-fired power to avoid widespread blackouts.

This would mean drivers switching to electric vehicles or companies like Dofasco cutting CO2 through electrification would end up causing higher power system emissions.

It would also fly in the face of the federal government’s ambition to create a net-zero national electricity system by 2035, a critical part of Canada’s pledge to reduce CO2 emissions to zero by 2050.

Yet the Ford government has appeared reluctant to expand clean energy. In the 2018 election, clean electricity was a key issue as it appealed to anti-turbine voters in rural Ontario and cancelled more than 700 renewable energy contracts shortly after taking office, taking 400 megawatts out of the system.

But there are signs the government is having a change of heart. IESO recently released a list of 55 companies approved to submit bids for 3,500 megawatts of long-term electricity contracts starting between 2025 and 2027, and the energy minister has outlined a plan to address growing energy needs as well.

The companies include a variety of potential producers, ranging from Canadian and global renewable companies to local utilities and small startups. Most are renewable power or energy storage companies specializing in low- or zero-emission power. IESO plans additional long-term bid offerings in the future.

This doesn’t mean gas generation will be turned off. IESO will contract yearly production from existing gas plants until 2028 (the annual contract in 2023 will be for about 2,000 megawatts). As well, IESO has issued contracts to four gas-fired producers, a small wind company and a storage company to begin production of about 700 megawatts to boost gas plant output starting between 2024 and 2026.

While this represents an expansion of existing gas-fired generation, Smith has asked IESO to report on a gas moratorium, saying he doesn’t believe new gas plants will be needed over the long term.

The NDP and Greens criticized the government for relying on gas in the near term. But clean energy advocates greeted the long-term plans positively.

The IESO process “will contribute to a clean, reliable and affordable grid,” said the Canadian Renewable Energy Association.

Rachel Doran, director of policy and strategy at Clean Energy Canada, said in an email the potential gas generation moratorium “is an encouraging step forward,” although she criticized the “unfortunate decision to replace near-term nuclear power capacity with climate-change-causing natural gas.”

There will have to be a massive clean energy expansion to green Ontario’s grid well beyond what has been announced in recent days for Ontario to meet its future energy needs (think a doubling of Ontario’s current 40,000-megawatt capacity by 2050).

But these first steps hold promise that Ontario is at least starting on the path to that goal, rather than scrambling to keep the lights on with CO2-polluting natural gas.

 

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Community-generated green electricity to be offered to all in UK

Community Power Tariff UK delivers clean electricity from community energy projects, sourcing renewable energy from local wind and solar farms, with carbon offset gas, transparent provenance, fair pricing, and reinvestment in local generators across Britain.

 

Key Points

UK energy plan delivering 100% community renewable power with carbon-offset gas, sourced from local wind and solar.

✅ 100% community-generated electricity from UK wind and solar

✅ Fair prices with profits reinvested in local projects

✅ Carbon-offset gas and verified, transparent provenance

 

UK homes will soon be able to plug into community wind and solar farms from anywhere in the country through the first energy tariff to offer clean electricity exclusively from community projects.

The deal from Co-op Energy comes as green energy suppliers race to prove their sustainability credentials amid rising competition for eco-conscious customers and “greenwashing” in the market.

The energy supplier will charge an extra £5 a month over Co-op’s regular tariff to provide electricity from community energy projects and gas which includes a carbon offset in the price.

Co-op, which is operated by Octopus Energy after it bought the business from the Midcounties Co-operative last year, will source the clean electricity for its new tariff directly from 90 local renewable energy generation projects across the UK, including the Westmill wind and solar farms in Oxfordshire. It plans to use all profits to reinvest in maintaining the community projects and building new ones.

Phil Ponsonby, the chief executive of Midcounties Co-operative, said the tariff is the UK’s only one to be powered by 100% community-generated electricity and would ensure a fair price is paid to community generators too, amid a renewable energy auction boost that supports wider deployment.

Customers on the Community Power tariff will be able to “see exactly where it is being generated at small scale sites across the UK, and, with new rights to sell solar power back to energy firms, they know it is benefiting local communities”, he said.

Co-op, which has about 300,000 customers, has set itself apart from a rising number of energy supply deals which are marked as 100% renewable, but are not as green as they seem, even as many renewable projects are on hold due to grid constraints.

Consumer group Which? has found that many suppliers offer renewable energy tariffs but do not generate renewable electricity themselves or have contracts to buy any renewable electricity directly from generators.

Instead, the “pale green” suppliers exploit a loophole in the energy market by snapping up cheap renewable energy certificates, without necessarily buying energy from renewables projects.

The certificates are issued by the regulator to renewable energy developers for each megawatt generated, but these can be sold separately from the electricity for a fraction of the price.

A survey conducted last year found that one in 10 people believe that a renewables tariff means that the supplier generates at least some of its electricity from its own renewable energy projects.

Ponsonby said the wind and solar schemes that generate electricity for the Community Power tariff “plough the profits they make back into their neighbourhoods or into helping other similar projects get off the ground”.

Greg Jackson, the chief executive of Octopus Energy, said being able to buy locally-sourced clean, green energy is “a massive jump in the right direction” which will help grow the UK’s green electricity capacity nationwide.

“Investing in more local energy infrastructure and getting Britain’s homes run by the sun when it’s shining and wind energy when it’s blowing can end our reliance on dirty fossil fuels sooner than we hoped,” he said.

 

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