ABB enters license agreement with RCCS

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ABB has entered into a license agreement with Radio Control Central Stations Inc. RCCS of Boston, Massachusetts, for software solutions related to power quality.

RCCS is best known in the United States for its Volt-Var Optimization VVO solutions, which include complex software algorithms to help utilities improve power quality and voltage fluctuations within the electric grid, in real-time. It enables utility planning, engineering, operations and maintenance functions to monitor and interact with automated capacitor switching systems through centralized control, allowing the grid to operate closer to its theoretical limits.

Smart grid optimization offers significant growth opportunities in this area.

“The RCCS software provides an advanced power quality management solution with features and capabilities consistent with a mature and proven product,” said Pier-André Rancourt, General Manager for ABB High Voltage Capacitors in North America. “We will be offering these products to customers as part of our commitment to increase energy efficiency and strengthen grid reliability.”

ABB will combine its capacitor products and advanced capacitor switching technology with RCCSÂ’ software to offer complete power quality solutions to utility customers, enabling them to deploy optimized power factor and power quality solutions, while at the same time increasing the utilization of the existing distribution automation infrastructure. These solutions will also help improve energy efficiency by reducing line losses and enhancing the network's capability to carry more power.

ABB takes a holistic view of the smart grid, which extends from generation through transmission and distribution to end use. ABB is working to make the grid more intelligent at every level, from the primary equipment that carries the current to the IT systems that monitor and control the flow of power. The smart grid will take full advantage of technologies such as demands response, wide area monitoring, advanced materials and many others. The result will be a grid that improves on our current infrastructure in terms of efficiency, capacity, reliability and long-term sustainability.

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Nine EU countries oppose electricity market reforms as fix for energy price spike

EU Electricity Market Reform Opposition highlights nine states resisting an overhaul of the wholesale power market amid gas price spikes, urging energy efficiency, interconnection targets, and EU caution rather than redesigns affecting renewables.

 

Key Points

Nine EU states reject overhauling wholesale power pricing, favoring efficiency and prudent policy over redesigns.

✅ Nine states oppose redesign of wholesale power market.

✅ Call for efficiency and 15% interconnection by 2030.

✅ Ministers to debate responses amid gas-driven price spikes.

 

Germany, Denmark, Ireland and six other European countries said on Monday they would not support a reform of the EU electricity market, ahead of an emergency meeting of energy ministers to discuss emergency measures and the recent price spike.

European gas and power prices soared to record high levels in autumn and have remained high, prompting countries including Spain and France to urge Brussels to redesign its electricity market rules.

Nine countries on Monday poured cold water on those proposals, in a joint statement that said they "cannot support any measure that conflicts with the internal gas and electricity market" such as an overhaul of the wholesale power market altogether.

"As the price spikes have global drivers, we should be very careful before interfering in the design of internal energy markets," the statement said.

"This will not be a remedy to mitigate the current rising energy prices linked to fossil fuels markets across Europe."

Austria, Germany, Denmark, Estonia, Finland, Ireland, Luxembourg, Latvia and the Netherlands signed the statement, which called instead for more measures to save energy and a target for a 15% interconnection of the EU electricity market by 2030.

European energy ministers meet tomorrow to discuss their response to the price spike, including gas price cap strategies under consideration. Most countries are using tax cuts, subsidies and other national measures to shield consumers against the impact higher gas prices are having on energy bills, but EU governments are struggling to agree on a longer term response.

Spain has led calls for a revamp of the wholesale power market in response to the price spike, amid tensions between France and Germany over reform, arguing that the system is not supporting the EU's green transition.

Under the current system, the wholesale electricity price is set by the last power plant needed to meet overall demand for power. Gas plants often set the price in this system, which Spain said was unfair as it results in cheap renewable energy being sold for the same price as costlier fossil fuel-based power.

The European Commission has said it will investigate whether the EU power market is functioning well, but that there is no evidence to suggest a different system would have better protected countries against the surge in energy costs, and that rolling back electricity prices is tougher than it appears during such spikes.

 

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India’s Kakrapur 3 achieves criticality

Kakrapar Unit 3 700MWe PHWR achieved first criticality, showcasing indigenously designed nuclear power, NPCIL operations, Make in India manufacturing, advanced safety systems, grid integration, and closed-fuel-cycle strategy for India's expansion of pressurised heavy water reactors.

 

Key Points

India's first indigenous 700MWe PHWR at Kakrapar reached criticality, advancing NPCIL's Make in India nuclear power.

✅ First indigenous 700MWe PHWR achieves criticality

✅ NPCIL-built, Make in India components and contractors

✅ Advanced safety: passive decay heat removal, containment spray

 

Unit 3 of India’s Kakrapar nuclear plant in Gujarat achieved criticality on 22 July, as milestones at nuclear projects worldwide continue to be reached. It is India’s first indigenously designed 700MWe pressurised heavy water reactor (PHWR) to achieve this milestone.

Prime Minister Narendra Modi congratulated nuclear scientists, saying the reactor is a shining example of the 'Make in India' campaign and of the government's steps to get nuclear back on track in recent years, and a trailblazer for many such future achievements. 

India developed its own nuclear power generation technology as it faced sanctions from the international community following its first nuclear weapons test in in 1974. It has not signed the Nuclear Non-Proliferation Treaty, while China's nuclear energy development is on a steady track according to experts. India has developed a three-stage nuclear programme based on a closed-fuel cycle, where the used fuel of one stage is reprocessed to produce fuel for the next stage.

Kakrapar 3 was developed and is operated by state-owned Nuclear Power Corporation of India Ltd (NPCIL), while in Europe KHNP considered for a Bulgarian project as countries weigh options. The first two units are 220MWe PHWRs commissioned in 1993 and 1995. NPCIL said in a statement that the components and equipment for Kakrapur 3 were “manufactured by lndian industries and the construction and erection was undertaken by various lndian contractors”.

The 700MWe PHWRs have advanced safety features such as steel lined inner containment, a passive decay heat removal system, a containment spray system, hydrogen management systems etc, the statement added.

Fuel loading was completed by mid-March, a crucial step in Abu Dhabi during its commissioning as well. “Thereafter, many tests and procedures were carried out during the lockdown period following all COVlD-19 guidelines.”

“As a next step, various experiments / tests will be conducted and power will be increased progressively, a path also followed by Barakah Unit 1 reaching 100% power before commercial operations.” Kakrapur 3 will be connected to the western grid and will be India’s 23rd nuclear power reactor.

Kakrapur 3 “is the front runner in a series of 16 indigenous 700MWe PHWRs which have been accorded administrative approval and financial sanction by the government and are at various stages of implementation”. Five similar units are under construction at Kakarapur 4, Rajasthan 7&8 and Gorakhpur1&2.

DAE said in January 2019 that India planned to put 21 new nuclear units with a combined generating capacity of 15,700MWe into operation by 2031, including ten indigenously designed PHWRs, while Bangladesh develops nuclear power with IAEA assistance. 

 

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UK must start construction of large-scale storage or fail to meet net zero targets.

UK Hydrogen Storage Caverns enable long-duration, low-carbon electricity balancing, storing surplus wind and solar power as green hydrogen in salt formations to enhance grid reliability, energy security, and net zero resilience by 2035 and 2050.

 

Key Points

They are salt caverns storing green hydrogen to balance wind and solar, stabilizing a low-carbon UK grid.

✅ Stores surplus wind and solar as green hydrogen in salt caverns

✅ Enables long-duration, low-carbon grid balancing and security

✅ Complements wind and solar; reduces dependence on flexible CCS

 

The U.K. government must kick-start the construction of large-scale hydrogen storage facilities if it is to meet its pledge that all electricity will come from low-carbon electricity sources by 2035 and reach legally binding net zero targets by 2050, according to a report by the Royal Society.

The report, "Large-scale electricity storage," published Sep. 8, examines a wide variety of ways to store surplus wind and solar generated electricity—including green hydrogen, advanced compressed air energy storage (ACAES), ammonia, and heat—which will be needed when Great Britain's electricity generation is dominated by volatile wind and solar power.

It concludes that large scale electricity storage is essential to mitigate variations in wind and sunshine, particularly long-term variations in the wind, and to keep the nation's lights on. Storing most of the surplus as hydrogen, in salt caverns, would be the cheapest way of doing this.

The report, based on 37 years of weather data, finds that in 2050 up to 100 Terawatt-hours (TWh) of storage will be needed, which would have to be capable of meeting around a quarter of the U.K.'s current annual electricity demand. This would be equivalent to more than 5,000 Dinorwig pumped hydroelectric dams. Storage on this scale, which would require up to 90 clusters of 10 caverns, is not possible with batteries or pumped hydro.

Storage requirements on this scale are not currently foreseen by the government, and the U.K.'s energy transition faces supply delays. Work on constructing these caverns should begin immediately if the government is to have any chance of meeting its net zero targets, the report states.

Sir Chris Llewellyn Smith FRS, lead author of the report, said, "The need for long-term storage has been seriously underestimated. Demand for electricity is expected to double by 2050 with the electrification of heat, transport, and industrial processing, as well as increases in the use of air conditioning, economic growth, and changes in population.

"It will mainly be met by wind and solar generation. They are the cheapest forms of low-carbon electricity generation, but are volatile—wind varies on a decadal timescale, so will have to be complemented by large scale supply from energy storage or other sources."

The only other large-scale low-carbon sources are nuclear power, gas with carbon capture and storage (CCS), and bioenergy without or with CCS (BECCS). While nuclear and gas with CCS are expected to play a role, they are expensive, especially if operated flexibly.

Sir Peter Bruce, vice president of the Royal Society, said, "Ensuring our future electricity supply remains reliable and resilient will be crucial for our future prosperity and well-being. An electricity system with significant wind and solar generation is likely to offer the lowest cost electricity but it is essential to have large-scale energy stores that can be accessed quickly to ensure Great Britain's energy security and sovereignty."

Combining hydrogen with ACAES, or other forms of storage that are more efficient than hydrogen, could lower the average cost of electricity overall, and would lower the required level of wind power and solar supply.

There are currently three hydrogen storage caverns in the U.K., which have been in use since 1972, and the British Geological Survey has identified the geology for ample storage capacity in Cheshire, Wessex and East Yorkshire. Appropriate, novel business models and market structures will be needed to encourage construction of the large number of additional caverns that will be needed, the report says.

Sir Chris observes that, although nuclear, hydro and other sources are likely to play a role, Britain could in principle be powered solely by wind power and solar, supported by hydrogen, and some small-scale storage provided, for example, by batteries, that can respond rapidly and to stabilize the grid. While the cost of electricity would be higher than in the last decade, we anticipate it would be much lower than in 2022, he adds.

 

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Electric vehicles to transform the aftermarket … eventually

Heavy-Duty Truck Electrification is disrupting the aftermarket as diesel declines: fewer parts, regenerative braking, emissions rules, e-drives, gearboxes, and software engineering needs reshape service demand, while ICE fleets persist for years.

 

Key Points

Transition of heavy trucks to EV systems, reducing parts and emissions while reshaping aftermarket service and skills.

✅ 33% fewer parts; regenerative braking slashes brake wear

✅ Diesel share declines; EVs and natural gas slowly gain

✅ Aftermarket shifts to e-drives, gearboxes, software and service

 

Those who sell parts and repair trucks might feel uneasy when reports emerge about a coming generation of electric trucks.

There are reportedly about 33% fewer parts to consider when internal combustion engines and transmissions are replaced by electric motors. Features such as regenerative braking are expected to dramatically reduce brake wear. As for many of the fluids needed to keep components moving? They can remain in their tanks and drums.

Think of them as disruptors. But presenters during the annual Heavy Duty Aftermarket Dialogue are stressing that the changes are not coming overnight. Chris Patterson, a consultant and former Daimler Trucks North America CEO, noted that the Daimler electrification plan underscores the shift as he counts just 50 electrified heavy trucks in North America.

About 88% of today’s trucks run on diesel, with the remaining 12% mostly powered by gasoline, said John Blodgett, MacKay and Company’s vice-president of sales and marketing. Five years out, even amid talk of an EV inflection point, he expects 1% to be electric, 2% to be natural gas, 12% to be gasoline, and 84% on diesel.

But a decade from now, forecasts suggest a split of 76% diesel, 11% gasoline, 7% electric, and 5% natural gas, with a fraction of a percent relying on hydrogen-electric power. Existing internal combustion engines will still be in service, and need to be serviced, but aftermarket suppliers are now preparing for their roles in the mix, especially as Canada’s EV opportunity comes into focus for North American players.

“This is real, for sure,” said Delphi Technologies CEO Rick Dauch.

Aftermarket support is needed
“As programs are launched five to six years from now, what are the parts coming back?” he asked the crowd. “Braking and steering. The fuel injection business will go down, but not for 20-25 years.” The electric vehicles will also require a gear box and motor.

“You still have a business model,” he assured the crowd of aftermarket professionals.

Shifting emissions standards are largely responsible for the transformation that is occurring. In Europe, Volkswagen’s diesel emissions scandal and future emissions rules of Euro 7 will essentially sideline diesel-powered cars, even as electric buses have yet to take over transit systems. Delphi’s light-duty diesel business has dropped 70% in just five years, leading to plant closures in Spain, France and England.

“We’ve got a billion-dollar business in electrification, last year down $200 million because of the downturn in light-duty diesel controllers,” Dauch said. “We think we’re going to double our electrification business in five years.”

That has meant opening five new plants in Eastern European markets like Turkey, Romania and Poland alone.

Deciding when the market will emerge is no small task, however. One new plant in China offered manufacturing capacity in July 2019, but it has yet to make any electric vehicle parts, highlighting mainstream EV challenges tied to policy shifts, because the Chinese government changed the incentive plans for electric vehicles.

‘All in’ on electric vehicles
Dana has also gone “all in” on electrification, said chairman and CEO Jim Kamsickas, referring to Dana’s work on e-drives with Kenworth and Peterbilt. Its gasket business is focusing on the needs of battery cooling systems and enclosures.

But he also puts the demand for new electric vehicle systems in perspective. “The mechanical piece is still going to be there.”

The demand for the new components and systems, however, has both companies challenged to find enough capable software engineers. Delphi has 1,600 of them now, and it needs more.

“Just being a motor supplier, just being an inverter supplier, just being a gearbox supplier itself, yes you’ll get value out of that. But in the longhaul you’re going to need to have engineers,” Kamsickas said of the work to develop systems.

Dauch noted that Delphi will leave the capital-intensive work of producing batteries to other companies in markets like China and Korea. “We’re going to make the systems that are in between – inverters, chargers, battery management systems,” he said.

Difficult change
But people working for European companies that have been built around diesel components are facing difficult days. Dauch refers to one German village with a population of 1,200, about 800 of whom build diesel engine parts. That business is working furiously to shift to producing gasoline parts.

Electrification will face hurdles of its own, of course. Major cities around the world are looking to ban diesel-powered vehicles by 2050, but they still lack the infrastructure needed to charge all the cars and truck fleet charging at scale, he added.

Kamsickas welcomes the disruptive forces.

“This is great,” he said. “It’s making us all think a little differently. It’s just that business models have had to pivot – for you, for us, for everybody.”

They need to be balanced against other business demands, including evolving cross-border EV collaboration dynamics, too.

Said Kamsickas: “Working through the disruption of electrification, it’s how do you financially manage that? Oh, by the way, the last time I checked there are [company] shareholders and stakeholders you need to take care of.”

“It’s going to be tough,” Dauch agreed, referring to the changes for suppliers. “The next three to four years are really going to be game changes. “There’ll be some survivors and some losers, that’s for sure.”

 

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Electric Motor Testing Training

Electric Motor Testing Training covers on-line and off-line diagnostics, predictive maintenance, condition monitoring, failure analysis, and reliability practices to reduce downtime, optimize energy efficiency, and extend motor life in industrial facilities.

 

Key Points

An instructor-led course teaching on-line/off-line tests to diagnose failures, improve reliability, and cut downtime.

✅ On-line and off-line test methods and tools

✅ Failure modes, root cause analysis, and KPIs

✅ Predictive maintenance, condition monitoring, ROI

 

Our 12-Hour Electric Motor Testing Training live online instructor-led course introduces students to the basics of on-line and off-line motor testing techniques, with context from VFD drive training principles applicable to diagnostics.

September 10-11 , 2020 - 10:00 am - 4:30 pm ET

Our course teaches students the leading cause of motor failure. Electric motors fail. That is a certainty. And unexpectded motor failures cost a company hundreds of thousands of dollars. Learn the techniques and obtain valuable information to detect motor problems prior to failure, avoiding costly downtime, with awareness of lightning protection systems training that complements plant surge mitigation. This course focuses electric motor maintence professionals to achieve results from electrical motor testing that will optimize their plant and shop operations.

Our comprehensive Electric Motor Testing course emphasizes basic and advanced information about electric motor testing equipment and procedures, along with grounding practices per NEC 250 for safety and compliance. When completed, students will have the ability to learn electric motor testing techniques that results in increased electric motor reliability. This always leads to an increase in overall plant efficiency while at the same time decreasing costly motor repairs.

Students will also learn how to acquire motor test results that result in fact-based, proper motor maintenance management. Students will understand the reasons that electric motors fail, including grounding deficiencies highlighted in grounding guidelines for disaster prevention, and how to find problems quickly and return motors to service.

 

COURSE OBJECTIVE:

This course is designed to enable participants to:

  • Describe Various Equipment Used For Motor Testing And Maintenance.
  • Recognize The Cause And Source Of Electric Motor Problems, including storm-related hazards described in electrical safety tips for seasonal preparedness.
  • Explain How To Solve Existing And Potential Motor Problems, integrating substation maintenance practices to reduce upstream disruptions, Thereby Minimizing Equipment Disoperation And Process Downtime.
  • Analyze Types Of Motor Loads And Their Energy Efficiency Considerations, including insights relevant to hydroelectric projects in utility settings.

 

Complete Course Details Here

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Ontario Providing Electricity Relief to Families, Small Businesses and Farms During COVID-19

Ontario TOU Electricity Rate Relief offers 24/7 fixed off-peak pricing at 10.1¢/kWh, suspending time-of-use tiers to support residential customers, small businesses, and farms, coordinated by the Ontario Energy Board during COVID-19.

 

Key Points

A 45-day policy fixing TOU power at 10.1¢/kWh 24/7 off-peak to ease costs for residents, small businesses, and farms.

✅ Applies 24/7 off-peak 10.1¢/kWh to all TOU electricity customers.

✅ Automatic bill credit; no application or enrollment required.

✅ Covers residential, small businesses, and farms; OEB coordination.

 

To support Ontarians through the rapidly evolving COVID-19 situation, the Government of Ontario is providing immediate electricity rate relief for families, small businesses and farms paying time-of-use (TOU) rates.

For a 45-day period, the government is working to suspend time-of-use electricity rates, holding electricity prices to the off-peak rate of 10.1 cents-per-kilowatt-hour. This reduced price will be available 24 hours per day, seven days a week to all time-of-use customers, who make up the majority of electricity consumers in the province. By switching to a fixed off-peak rate, time-of-use customers will see rate reductions of over 50 per cent compared to on-peak rates now in effect.

To deliver savings as quickly and conveniently as possible, this discount will be applied automatically to electricity bills without the need for customers to fill out an application form.

"During this unprecedented time, we are providing much-needed relief to Ontarians, specifically helping those who are doing the right thing by staying home and small businesses that have closed or are seeing fewer customers," said Premier Doug Ford. "By adopting a fixed, 24/7 off-peak rate, aligned with ultra-low overnight pricing options, we are making things a little easier during these difficult times and putting more money in people's pockets for other important priorities and necessities."

The Government of Ontario issued an Emergency Order under the Emergency Management and Civil Protection Act to apply the off-peak TOU electricity rate for residential, small businesses, and farm customers who currently pay TOU rates.

"Ontario is fortunate to have a strong electricity system we can rely on during these exceptional times, even as Ottawa's electricity consumption decreased during the pandemic, and our government is proud to provide additional relief to Ontarians who are doing their part to stay home," said Greg Rickford, Minister of Energy, Northern Development and Mines.

"We thank the Ontario Energy Board and our partners at local distribution companies across the province, including initiatives like Hydro One's Ultra-Low Overnight Price Plan that support customers, for taking quick action to make this change and provide immediate support for hardworking people of Ontario," said Bill Walker, Associate Minister of Energy.

Visit Ontario's website to learn more about how the province continues to protect Ontarians from COVID-19.

Quick Facts

  • The Ontario Energy Board sets time-of-use electricity rates for residential and small business customers through the Regulated Price Plan, and provides stable electricity pricing for industrial and commercial companies through separate programs.
  • Time-of-use prices as of November, 2019 ― Off-Peak: 10.1₵/kWh, Mid-Peak: 14.4₵/kWh, On-Peak: 20.8₵/kWh
  • Depending on billing cycles, some customers will see these changes on their next electricity bill. TOU customers whose billing cycle ended before their local distribution company implemented this change will receive the reduced rate as a credit on a future bill.
  • The Ontario Electricity Rebate (OER) will continue to provide a 31.8 per cent rebate on the sub-total bill amount for all existing Regulated Price Plan (RPP) consumers.
  • There are approximately five million residential consumers, farms and some small businesses billed using time-of-use (TOU) electricity prices under the RPP.
  • The Ontario Energy Board has extended the winter ban on disconnections to July 31st.

 

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