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Nova Scotia Energy Training Program connects students and recent graduates to energy sector internships, wage subsidies, and specialized training, helping SMEs create youth employment, paid work terms, and career pathways across the province.

 

Key Points

A provincial wage-support initiative funding student and graduate placements in the energy sector with paid work terms and training.

✅ 50% wage support up to $7.50/hour for eligible employers

✅ 12-17 week work terms between May and August

✅ Supports SMEs hiring post-secondary students and graduates

 

Young Nova Scotians will again be connected to opportunities in the energy sector, including electricity careers, through government's Energy Training Program. 

Applications are now available to employers for the 2017 program which supports opportunities for students and recent graduates to gain specialized training in a rapidly changing electricity sector and work experience.

"Across government we're helping hundreds of young people find opportunities that will lead to rewarding careers here in Nova Scotia," said Energy Minister Michel Samson. "There is tremendous potential in our energy sector, with initiatives like the offshore wind job fair illustrating demand, and this program helps businesses create momentum by giving some of our brightest young minds the chance to get a foot in the door."

Through the program small and medium-sized companies in the energy sector can apply for wage support to hire post-secondary students and recent graduates.

The program provides eligible employers with 50 per cent of a student's salary, up to $7.50 per hour, during a student's employment with the company. Work terms run from 12 to 17 weeks between May and August. The application deadline is Feb. 24. 

Since 2002 the Energy Training Program has funded about 420 student placements at more than 100 companies, while other provinces have supported energy workforce transitions through coal transition funding as needed. 

National labour statistics indicate that Nova Scotia made more progress on reducing youth unemployment than any other province in Canada in 2015, though later events such as COVID-19 impacts in Saskatchewan reshaped labour markets nationwide.

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Power Co-Op Gets Bond Rating Upgrade After Exiting Kemper Deal

Cooperative Energy bond rating upgrade signals lower debt costs as Fitch lifts GO Zone Bonds to A, reflecting Kemper exit, shift to owned generation, natural gas, and renewable energy for co-op members and borrowing rates.

 

Key Points

Fitch raised Cooperative Energy's GO Zone Bonds to A, cutting debt costs after Kemper exit and shift to natural gas.

✅ Fitch upgrades 2009A GO Zone Bonds from A- to A.

✅ Kemper divestment reduced risk and exposure to coal.

✅ Shift to owned generation, natural gas, renewables lowers costs.

 

Cooperative Energy and its 11 co-op members will see lower debt costs on $35.4 million bond; similar to regional utilities offering one-time bill decreases for customers recently.

Bailing out of its 15 percent ownership stake in Mississippi Power’s Kemper gasification plant, amid debates over coal and nuclear subsidies in federal policy, has helped Hattiesburg-based Cooperative Energy gain a ratings upgrade on a $35.4 million bond issue.

The electric power co-op, which changed its name to Cooperative Energy from South Mississippi Electric Power Association in November, received a ratings upgrade from A- to A for its 2009 2009A Mississippi Business Finance Corporation Gulf Opportunity Zone Bonds, even as other utilities announced bill reductions for customers during 2020.

“This rating upgrade reflects the success of our strategy to move from purchased power to owned generation resources, and from coal to natural gas and renewable energy as clean energy priorities gain traction,” said Cooperative Energy President/CEO Jim Compton in a press release.  “The result for our members is lower borrowing costs and more favorable rates.”

An “A” rating from Fitch designates the bond issue as “near premium quality,” a status noted as utilities adapted to pandemic-era electricity demand trends nationwide.

 

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Illinois electric utility publishes online map of potential solar capacity

ComEd Hosting Capacity Map helps Illinois communities assess photovoltaic capacity, distributed energy resources, interconnection limits, and grid planning needs, guiding developers and policymakers on siting solar, net metering feasibility, and RPS-aligned deployment by circuit.

 

Key Points

An online tool showing circuit-level DER capacity, PV limits, and interconnection readiness across ComEd.

✅ Circuit-level estimates of solar hosting capacity

✅ Guides siting, interconnection, and net metering

✅ Supports RPS goals with grid planning insights

 

As the Illinois solar market grows from the Future Energy Jobs Act, the largest utility in the state has posted a planning tool to identify potential PV capacity in their service territory. ComEd, a Northern Illinois subsidiary of Exelon, has a hosting capacity website for its communities indicating how much photovoltaic capacity can be sited in given areas, based on the existing electrical infrastructure, as utilities pilot virtual power plant programs that leverage distributed resources.

According to ComEd’s description, “Hosting Capacity is an estimate of the amount of DER [distributed energy resources] that may be accommodated under current configurations at the overall circuit level without significant system upgrades to address adverse impacts to power quality or reliability.” This website will enable developers and local decision makers to estimate how much solar could be installed by township, sections and fractions of sections as small as ½ mile by ½ mile and to gauge EV charging impacts with NREL's projection tool for distribution planning. The map sections indicate potential capacity by AC kilowatts with a link to to ComEd’s recently upgraded Interconnection and Net Metering homepage.

The Hosting Map can provide insight into how much solar can be installed in which locations in order to help solar reach a significant portion of the Illinois Renewable Portfolio Standard (RPS) of 25% electricity from renewable sources by 2025, and to plan for transportation electrification as EV charging infrastructure scales across utility territories. For example, the 18 sections of Oak Park Township capacity range from 612 to 909 kW, and total 13,260 kW of photovoltaic power. That could potentially generate around 20 million kWh, and policy actions such as the CPUC-approved PG&E EV program illustrate how electrification initiatives may influence future demand. Oak Park, according to the PlanItGreen Report Card, a joint project of the Oak Park River Forest Community Foundation and Seven Generations Ahead, uses about 325 million kWh.

Based on ComEd’s Hosting Capacity, Oak Park could generate about 6% of its electricity from solar power located within its borders. Going significantly beyond this amount would likely require a combination of upgrades by ComEd’s infrastructure, potentially higher interconnection costs and deployment of technologies like energy storage solutions. What this does indicate is that a densely populated community like Oak Park would most likely have to get the majority of its solar and renewable electricity from outside its boundaries to reach the statewide RPS goal of 25%. The Hosting Capacity Map shows a considerable disparity among communities in ½ mile by ½ mile sections with some able to host only 100-200 kWs to some with capacities of over 3,000 kW.

 

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Electric Utilities Plot Bullish Course for EV Charging Infrastructure

EV Charging Infrastructure Incentives are expanding as utilities fund public chargers, Level 2 networks, DC fast charging, grid-managed off-peak programs, and equitable access across Ohio, New Jersey, and Florida to accelerate clean transportation.

 

Key Points

Utility-backed programs funding Level 2 and DC fast chargers, managing grid demand, and expanding EV equity.

✅ Incentives for Level 2 and DC fast public charging stations.

✅ Grid-friendly off-peak charging to balance demand.

✅ Equity targets place chargers in low-income communities.

 

Electric providers in Florida, Ohio and New Jersey recently announced plans to expand electric vehicle charging networks and infrastructure through various incentive programs that could add thousands of new public chargers in the next several years.

Elsewhere, utilities are advancing similar efforts, with Michigan EV programs proposing more than $20 million for charging infrastructure to accelerate adoption.

American Electric Power in Ohio will offer nearly $10 million in incentives toward the build out of 375 EV charging stations throughout the company's service territory, which largely includes Columbus.

Meanwhile, the Public Service Electric and Gas Company (PSE&G), an electric utility provider in New Jersey, has proposed a six-year plan to support the development of nearly 40,000 electric vehicle chargers across a wide range of customers and sectors, said Francis Sullivan, a spokesperson for PSE&G.

And Duke Energy in Florida is installing up to 530 EV charging stations across its service area, as part of its Park and Plug pilot program, which will be making the charging ports available in multifamily housing complexes, workplaces and other high traffic areas.

"We are bringing cleaner energy to Florida through 700 megawatts of new universal solar, and we are helping our customers to bring clean transportation to the state as well," Catherine Stempien, Duke Energy Florida president, said in a statement. "We are committed to providing smarter, cleaner energy alternatives for all our customers."

The project in Ohio is making incentive funding available to government organizations, multifamily housing developments and workplaces, covering from 50 percent to all of the costs. The plan, to be rolled out in the next four years, aims to incentivize the development of 300 level-two chargers and 75 "fast chargers" capable of charging a car's battery in minutes rather than hours.

"I think what's interesting about what we're seeing now in the industry is that electric vehicles and electric vehicle charging are expanding beyond California, and like other Pacific Coast states," said Scott Fisher, vice president of marketing at Greenlots, maker of car chargers and software. Greenlots has been selected as one of the companies to provide the chargers for the AEP project.

California has occupied the lion's share of the electric vehicle market, making up about 5 percent of the cars on the state's highways. The U.S. market sits at about 1.5 percent. However, indications show the EV boom may be set to take off as more models are being rolled out, and prices are making the electric cars more competitive with their gas-powered counterparts. The group Securing America's Future Energy (SAFE) announced the one-millionth electric vehicle is on course to be sold in the United States this month.

In a statement, Ben Prochazka, vice president of the Electrification Coalition, an EV advocacy group, called this "a major milestone and brings us one step closer to reducing our transportation system's dependence on oil. This is a direct result of the tireless efforts by communities and advocates throughout the 'EV ecosystem.'"

In New Jersey, PSE&G's efforts -- which are part of the company's proposed Clean Energy Future program -- will not only focus on building out the charging infrastructure, but structure car recharging to control charging and encourage residents to charge their cars during off-peak times.

"For now, with a modest number of charging stations in the market, it's not a huge problem. But over time, as you're putting in many thousands of these stations, what you want to make sure is that those stations are operating in sync with state power grids, where you don't have people all charging at the same time at like 5 p.m. on a hot summer day," said Fisher.

PSE&G also plans to offer incentives to encourage the development of level-two chargers and DC fast-chargers, as well as "provide grants and incentives for 100 electric school buses and EV charging infrastructure at school districts in PSE&G's service territory," said Sullivan.

"PSE&G will also help fund electrification projects at customer locations such as ports, airports and transit facilities," Sullivan added, via email.

Utilities and transportation planners are also keeping the concept of equity in mind -- to ensure EVs are adopted by more than just the Tesla owner -- and will also focus on placing infrastructure in low-income areas.

"Ten percent of the stations will be in low income areas, defined by census blocks," said Scott Blake, a communications consultant at AEP in Columbus.

Duke Energy also announced 10 percent of the chargers it is installing in Florida will be in "income-qualified communities," according to a company press release.

 

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'Electricity out of essentially nothing': Invention creates power from falling snow

Snow-powered nanogenerator harvests static electricity from falling snow using a silicone triboelectric design, enabling energy harvesting, solar panel support during snowfall, and dual-use sensing for weather monitoring and wearable winter sports analytics.

 

Key Points

A silicone triboelectric device that harvests snowDcharge to generate power and enable sensing.

✅ Triboelectric silicone layer captures charge from falling snow.

✅ Integrates with solar arrays to maintain power during snowfall.

✅ Functions as weather and motion sensor for winter sports.

 

Scientists from University of California, Los Angeles and McMaster University have invented a nanogenerator that creates electricity from falling snow.

Most Canadians have already seen a mini-version of this, McMaster Prof. Ravi Selvaganapathy told CTV’s Your Morning. “We find that we often get shocked in the winter when it’s dry when we come in into contact with a conductive surface like a doorknob.”

The thin device works by harnessing static electricity: positively-charged, falling snow collides with the negatively-charged silicone device, which produces a charge that’s captured by an electrode.

“You separate the charges and create electricity out of essentially nothing,” Richard Kaner, who holds UCLA’s Dr. Myung Ki Hong Endowed Chair in Materials Innovation and whose lab has explored turning waste into graphene, said in a press release.

“The device can work in remote areas because it provides its own power and does not need batteries or reliance on home storage systems such as the Tesla Powerwall, which store energy for later use,” he said, explaining that the device was 3D printed, flexible and inexpensive to make because of the low cost of silicone.

“It’s also going to be useful in places like Canada, where we get a lot of snow and are pursuing a net-zero grid by 2050 to cut emissions. We can extract energy from the environment,” Selvaganapathy added.

The team, which also included scientists from the University of Toronto, published their findings in Nano Energy journal last year, but a few weeks ago, they revealed the device’s more practical uses.

About 30 per cent of the Earth’s surface is covered by snow each winter, which can significantly limit the energy generated by solar panels, including rooftop solar grids in cold climates.

So the team thought: why not simply harness electricity from the snow whenever the solar panels were covered?

Integrating their device into solar panel arrays could produce a continuous power supply whenever it snows, potentially as part of emerging virtual power plants that aggregate distributed resources, study co-author and UCLA assistant researcher Maher El-Kady explained.

The device also serves as a weather-monitoring station by recording how much snow is falling and from where; as well as the direction and speed of the wind.

The team said they also want to incorporate their device into weather sensors to help them better acquire and transmit electronic signals, supporting initiatives to use AI for energy savings across local grids. They said several Toronto-based companies -- which they couldn’t name -- have expressed interest in partnering with them.

Selvaganapathy said the device would hop on the trend of “sensors being incorporated into what we wear, into our homes and even to detect electricity theft in some markets in order to monitor a lot of the things that are important to us”

But the device’s arguably larger potential use is being integrated into technology to monitor athletes and their performances during winter sports, such as hiking, skiing and cross-country skiing.

Up to now, the movement patterns used during cross-country skiing couldn’t be detected by a smart watch, but this device may be able to.

Scientists such as Kaner believe the technology could usher in a new era of self-monitoring devices to assess an athlete’s performance while they’re running, walking or jumping.

The device is simply a proof of concept and the next step would be figuring out how to generate more electricity and integrate it into all of these potential devices, Selvaganapathy said.

 

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Hydro One wants to spend another $6-million to redesign bills

Hydro One Bill Redesign Spending sparks debate over Ontario Energy Board regulation, rate applications, privatization, and digital billing upgrades, as surveys cite confusing invoices under the Fair Hydro Plan for residential, commercial, and industrial customers.

 

Key Points

$15M project to simplify Hydro One bills, upgrade systems, and improve digital billing for commercial customers.

✅ $9M spent; $6M proposed for C&I and large-account changes.

✅ OEB to rule amid rate application and privatization scrutiny.

✅ Survey: 40% of customers struggled to understand bills.

 

Ontario's largest and recently privatized electricity utility has spent $9-million to redesign bills and is proposing to spend an additional $6-million on the project.

Hydro One has come under fire for spending since the Liberal government sold more than half of the company, notably for its CEO's $4.5-million pay.

Now, the NDP is raising concerns with the $15-million bill redesign expense contained in a rate application from the formerly public utility.

"I don't think the problem we face is a bill that people can't understand, I think the problem is rates that are too high," said energy critic Peter Tabuns. "Fifteen million dollars seems awfully expensive to me."

But Hydro One says a 2016 survey of its customers indicated about 40 per cent had trouble understanding their bills.

Ferio Pugliese, the company's executive vice-president of customer care and corporate affairs, said the redesign was aimed at giving customers a simpler bill.

"The new format is a format that when tested and put in front of our customers has been designed to give customers the four or five salient items they want to see on their bill," he said.

About $9-million has already gone into redesigning bills, mostly for residential customers, Pugliese said. Cosmetic changes to bills account for about 25 per cent of the cost, with the rest of the money going toward updating information systems and improving digital billing platforms, he said.

The additional $6-million Hydro One is looking to spend would go toward bill changes mostly for its commercial, industrial and large distribution account customers.

Energy Minister Glenn Thibeault noted in a statement that the Ontario Energy Board has yet to decide on the expense, but he suggested he sees the bill redesign as necessary alongside legislation to lower electricity rates introduced by the province.

"With Ontarians wanting clearer bills that are easier to understand, Hydro One's bill redesign project is a necessary improvement that will help customers," he wrote.

"Reductions from the Fair Hydro Plan (the government's 25 per cent cut to bills last year) are important information for both households and businesses, and it's our job to provide clear, helpful answers whenever possible."

The OEB recently ordered Hydro One to lower a rate increase it had been seeking for this year to 0.2 per cent down from 4.8 per cent.

The regulator also rejected a Hydro One proposal to give shareholders all of the tax savings generated by the IPO in 2015 when the Liberal government first began partially privatizing the utility. The OEB instead mandated shareholders receive 62 per cent of the savings while ratepayers receive the remaining 38 per cent.

 

 

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Coal CEO blasts federal agency's decision on power grid

FERC Rejects Trump Coal Plan, denying subsidies for coal-fired and nuclear plants as energy policy shifts toward natural gas and renewables, citing no grid reliability threat and warning about electricity prices and market impacts.

 

Key Points

FERC unanimously rejected subsidies for coal and nuclear plants, finding no grid reliability risk from retirements.

✅ Unanimous FERC vote rejects coal and nuclear compensation

✅ Cites no threat to grid reliability from plant retirements

✅ Opponents warned subsidies would distort power markets and prices

 

A decision by an independent energy agency to reject the Trump administration’s electricity pricing plan to bolster the coal industry could lead to more closures of coal-fired power plants and the loss of thousands of jobs, a top coal executive said Tuesday.

Robert Murray, CEO of Ohio-based Murray Energy Corp., called the action by the Federal Energy Regulatory Commission “a bureaucratic cop-out” that will raise the cost of electricity and jeopardize the reliability and security of the nation’s electric grid.

“While FERC commissioners sit on their hands and refuse to take the action directed by Energy Secretary Rick Perry and President Donald Trump, the decommissioning of more coal-fired and nuclear plants could result, further jeopardizing the reliability, resiliency and security of America’s electric power grids,” Murray said. “It will also raise the cost of electricity for all Americans.”

The five-member energy commission voted unanimously Monday to reject Trump’s plan to reward nuclear and coal-fired power plants for adding reliability to the nation’s power grid. The plan would have made the plants eligible for billions of dollars in government subsidies and help reverse a tide of bankruptcies and loss of market share suffered by the once-dominant coal industry as utilities' shift to natural gas and renewable energy continues.

The Republican-controlled commission said there’s no evidence that any past or planned retirements of coal-fired power plants pose a threat to reliability of the nation’s electric grid.

Murray disputed that and said the recent cold snap that hit the East Coast showed coal’s value, as power users in the Southeast were asked to cut back on electricity usage because of a shortage of natural gas. “If it were not for the electricity generated by our nation’s coal-fired and nuclear power plants, we would be experiencing massive brownouts risk and blackouts in this country,” he said.

Murray Energy is the largest privately owned coal company in the United States, with mining operations in Ohio, Illinois, Kentucky, Utah and West Virginia. Robert Murray, a Trump friend and political supporter, has been pushing hard for federal assistance for his industry. The Associated Press reported last year that Murray asked the Trump administration to issue an emergency order protecting coal-fired power plants from closing. Murray warned that failure to act could cause thousands of coal miners to be laid off and force his largest customer, Ohio-based FirstEnergy Solutions, into bankruptcy.

Perry ultimately rejected Murray’s request, but later asked energy regulators to boost coal and nuclear plants as the administration moved to replace the Clean Power Plan with a more limited approach.

The plan drew widespread opposition from business and environmental groups that frequently disagree with each other, even as some coal and business interests backed the EPA's Affordable Clean Energy rule in court.

Jack Gerard, president and CEO of the American Petroleum Institute, said Tuesday that the Trump plan was “far too narrow” in its focus on power sources that maintain a 90-day fuel supply.

API, the largest lobbying group for oil and gas industry, supports coal and other energy sources, Gerard said, “but we should not put our eggs in an individual basket defined as a 90-day fuel supply (while) unnecessarily intervening in private markets.”

 

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