CSA changes 2009 Canadian Electrical Code to align with American counterpart

By Vince Versace, CSA


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Future upgrades to the Canadian Electrical Code will help bring the code closer to its American counterpart and incorporate new safety improvements, states the Canadian Standards Association (CSA).

“There will be greater clarity improvements and harmonization (with the new code),” said Stephen Brown, electrotechnical director at CSA.

CSA recently held a webcast and teleconference to highlight new areas in the CSA 2009 Canadian Electrical Code which will undergo upgrades after a little more consultation. The code is considered a “must-have” safety tool and it has now been moved to a three-year production cycle, similar to the American National Electrical Code, noted Brown. Canada’s code was previously in a four-year cycle.

Brown said the stakeholder consultation, which helped develop the changes, was “the most extensive stakeholder consultation ever” undertaken by the CSA.

Utilities, home builders, product manufacturers, designers, installers and government officials were all involved in the process, he said.

The 10 main areas where code upgrades will occur are: requirements for tamper resistant receptacles; passenger ropeway requirements; new bonding requirements for servicing pools; new requirements for primary seals; equipment requirements for certain class and zone hazardous locations; new cable types; motor overload protection requirements; kitchen microwave and range hood hookups; connection of non-mandatory equipment to emergency power supplies; and electrically connected carbon monoxide alarms.

New technology, immediacy for improving electrical hazard safety and alignment with the American code are the primary drivers for the code review.

However, the proposed upgrades will now go through a further stakeholder engagement process across Canada to help gather more input and rank priorities, noted CSA.

Lance Novak, sales vice president at CSA, said that along with the upgrades to the code CSA will also use new support tools to both provide and understand the code. The tools recognize “the best practices and latest in technology”, he said.

“We will offer the standards in a handy mobile device format,” said Novak.

The format allows users to download a software reader and the 2009 code right to their mobile device. The code will also be available on a “Smart Standard” CD-ROM which contains the guide and a handbook.

CSA will offer a conference series on electrical safety which are specifically designed to provide provincial regulatory bodies the opportunity for input on their issues and concerns. Burnaby, Edmonton, Winnipeg, Toronto and Moncton are the sites for the conference series.

Training via e-learning methods through a Web browser will also be available. This feature allows people access to self-training and assessment anytime, from anywhere, said Novak.

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In a record year for clean energy purchases, Southeast cities stand out

Municipal Renewable Energy Procurement surged as cities contracted 3.7 GW of solar and wind, leveraging green tariffs, community solar, and utility partnerships across the Southeast, led by Houston, RMI, and WRI data.

 

Key Points

The process by which cities contract solar and wind via utilities or green tariffs to meet climate goals.

✅ 3.7 GW procured in 2020, nearly 25% year-over-year growth

✅ Houston runs city ops on 500 MW solar, a record purchase

✅ Southeast cities use green tariffs and community solar

 

Cities around the country bought more renewable energy last year than ever before, reflecting how renewables may soon provide one-fourth of U.S. electricity across the grid, with some of the most remarkable projects in the Southeast, according to new data unveiled Thursday.

Even amid the pandemic, about eight dozen municipalities contracted to buy nearly 3.7 gigawatts of mostly solar and wind energy — enough to power more than 800,000 homes. The figure is almost a quarter higher than the year before.

Half of the cites listed as “most noteworthy” in Thursday’s release —  from research groups Rocky Mountain Institute and World Resources Institute — are in the region that stretches from Texas to Washington, D.C. 

Houston stands out for the sheer enormity of its purchase: In July, it began powering city operations entirely from nearly 500 megawatts of solar power — the largest municipal purchase of renewable energy ever in the United States, as renewable electricity surpassed coal nationwide.

The groups also feature smaller deals in North Carolina and Tennessee, achieved through a utility partnership called a green tariff.

“We wanted to recognize that Nashville and Charlotte were really blazing a new trail,” said Stephen Abbott, principal at the Rocky Mountain Institute.

And the nation’s capital shows how renewable energy can be a source of revenue: It’s leasing out its public transit station rooftops for 10 megawatts of community solar.

All of these strategies will be necessary for scores of U.S. cities to meet their ambitious climate goals, researchers believe. An interactive clean energy targets tracker shows all 95 clean energy procurements from the year in detail.


Tracker 
Even before former President Donald Trump promised to remove the United States from the Paris Climate Accord, a lack of federal action on climate left a void that some cities and counties were beginning to fill, as renewables hit a record 28% in a recent month. In 2015, the first year tracked by researchers at the Rocky Mountain Institute and the World Resources Institute, municipalities contracted to buy more than 1 gigawatt of wind, solar and other forms of clean energy. 

But when Trump officially set in motion the withdrawal from the climate agreement, the ranks of municipalities dedicated to 100% clean energy multiplied. Today there are nearly 200 of them. The growth in activity last year reflects, in part, that surge of new pledges.

“It takes a while to get city staff up to speed and understand the options, and create the roadmap and then start executing,” Abbott said. “There is a bit of a lag, but we’re starting to see the impact.”

Even in Houston — one of the earliest to begin procuring renewable energy — there has been a steep learning curve as market forces change and prices drop, including cheaper solar batteries shaping procurement strategies, said Lara Cottingham, Houston’s chief of staff and chief sustainability officer.

No matter how well resourced and educated their staff, cities have to clear a thicket of structural, political and economic challenges to procure renewable energy. Most don’t own their own sources of power. Nearly all face budget constraints. Few have enough land or government rooftops to meet their goals within city limits.

“Cities face a situation where it’s a square peg in a round hole,” Cottingham said.

The hurdles are especially steep in much of the Southeast, where only publicly regulated utilities can sell electricity to retail customers, even large ones such as major cities. That’s where a green tariff regime comes in: Cities can purchase clean energy from a third party, such as a solar company, using the utility as a go-between.

Early last year, Charlotte became the largest city to use such a program, partnering with Duke Energy and two North Carolina solar developers to build a solar farm 50 miles north in Iredell County. At first, the city will pay a premium for the energy, but in the latter half of the 20-year contract, as gas prices rise, it will save money compared to business as usual.

“Over the course of 20 years, it’s projected we would save about $2 million,” Katie Riddle, sustainability analyst with Charlotte, told the Energy News Network last year.

The growing size of projects, innovative partnerships like green tariff programs, and the improving economics all give Abbott hope that renewable energy investments from cities will only grow — even with the Trump presidency over and the country back in the Paris agreement.

And when cities meet their goals for procuring renewable energy for their own operations, they must then turn to an even bigger task: reducing the carbon footprint of every person in their jurisdiction with broader decarbonization strategies and community engagement.

“The city needs to do its part for sure,” said Houston’s Cottingham. “Then we have this challenge of how do we get everyone else to.”

 

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Hydro One bends to government demands, caps CEO pay at $1.5M

Hydro One CEO Pay Cap sets executive compensation at $1.5 million under Ontario's provincial directive, linking incentives to transmission and distribution cost reductions, governance improvements, and board pay limits at the electricity utility.

 

Key Points

The Hydro One CEO Pay Cap limits pay to $1.5M, linking incentives to cost reductions and defined targets.

✅ Base salary set at $500,000 per year.

✅ Incentives capped at $1,000,000, tied to cost cuts.

✅ Board pay capped: chair $120,000; members $80,000.

 

Hydro One has agreed to cap the annual compensation of its chief executive at $1.5 million, the provincial utility said Friday, acquiescing to the demands of the Progressive Conservative government.

The CEO's base salary will be set at $500,000 per year, while short-term and long-term incentives are limited to $1 million. Performance targets under the pay plan will include the CEO's contributions to reductions in transmission and distribution costs, even as Hydro One has pursued a bill redesign to clarify charges for customers.

The framework represents a notable political victory for Premier Doug Ford, who vowed to fire Hydro One's CEO and board during the campaign and promised to reduce the annual earnings of Hydro One's board members.

In February, the province issued a directive to the board, ordering it to pay the utility's CEO no more than the $1.5 million figure it has now agreed to, as part of a broader push to lower electricity rates across Ontario.

Hydro One and the government had been at loggerheads over executive compensation, with the company refusing repeated requests to slash the CEO pay below $2,775,000. The board argued it would have difficulty recruiting suitable leaders for anything less, even as customers contend with a recovery rate that could raise hydro bills.

Further, the company agreed to pay the board chair no more than $120,000 annually and board members no more than $80,000 — figures Energy Minister Greg Rickford had outlined in his directive last month, amid calls for cleaning up Ontario's hydro mess from policy commentators.

"Hydro One's compliance with this directive allows us to move forward as a province. It sets the company on the right course for the future, proving that it can operate as a top-class electricity utility while reining in executive compensation and increasing public transparency," Rickford said in a statement issued Friday morning.

 

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Minnesota Power energizes Great Northern Transmission Line

Great Northern Transmission Line delivers 250 MW of carbon-free hydropower from Manitoba Hydro, strengthening Midwest grid reliability, enabling wind storage balancing, and advancing Minnesota Power's EnergyForward strategy for cleaner, renewable energy across the region.

 

Key Points

A 500 kV cross-border line delivering 250 MW of carbon-free hydropower, strengthening reliability and enabling renewables.

✅ 500 kV, 224-mile line from Manitoba to Minnesota

✅ Delivers 250 MW hydropower via ALLETE-Minnesota Power

✅ Enables wind storage and grid balancing with Manitoba Hydro

 

Minnesota Power, a utility division of ALLETE Inc. (NYSE:ALE), has energized its Great Northern Transmission Line, bringing online an innovative delivery and storage system for renewable energy that spans two states and one Canadian province, similar to the Maritime Link project in Atlantic Canada.

The 500 kV line is now delivering 250 megawatts of carbon-free hydropower from Manitoba, Canada, to Minnesota Power customers.

Minnesota Power completed the Great Northern Transmission Line (GNTL) in February 2020, ahead of schedule and under budget. The 224-mile line runs from the Canadian border in Roseau County to a substation near Grand Rapids, Minnesota. It consists of 800 tower structures which were fabricated in the United States and used 10,000 tons of North American steel. About 2,200 miles of wire were required to install the line's conductors. The GNTL also is contributing significant property tax revenue to local communities along the route.

"This is such an incredible achievement for Minnesota Power, ALLETE, and our region, and is the culmination of a decade-long vision brought to life by our talented and dedicated employees," said ALLETE President and CEO Bethany Owen. "The GNTL will help Minnesota Power to provide our customers with 50 percent renewable energy less than a year from now. As part of our EnergyForward strategy, it also strengthens the grid across the Midwest and in Canada, enhancing reliability for all of our customers."

With the GNTL energized and connected to Manitoba Hydro's recently completed Manitoba-Minnesota Transmission Project at the border, the companies now have a unique "wind storage" mechanism that quickly balances energy supply and demand in Minnesota and Manitoba, and enables a larger role for renewables in the North American energy grid.

The GNTL and its delivery of carbon-free hydropower are important components of Minnesota Power's EnergyForward strategy to transition away from coal and add renewable power sources while maintaining reliable and affordable service for customers, echoing interties like the Maritime Link that facilitate regional power flows. It also is part of a broader ALLETE strategy to advance and invest in critical regional transmission and distribution infrastructure, such as the TransWest Express transmission project, to ensure grid integrity and enable cleaner energy to reduce carbon emissions.

"The seed for this renewable energy initiative was planted in 2008 when Minnesota Power proposed purchasing 250 megawatts of hydropower from Manitoba Hydro. Beyond the transmission line, it also included a creative asset swap to move wind power from North Dakota to Minnesota, innovative power purchase agreements, and a remarkable advocacy process to find an acceptable route for the GNTL," said ALLETE Executive Chairman Al Hodnik. "It marries wind and water in a unique connection that will help transform the energy landscape of North America and reduce carbon emissions related to the existential threat of climate change."

Minnesota Power and Manitoba Hydro, a provincial Crown Corporation, coordinated on the project from the beginning, navigating National Energy Board reviews along the way. It is based on the companies' shared values of integrity, environmental stewardship and community engagement.

"The completion of Minnesota Power's Great Northern Transmission Line and our Manitoba-Minnesota Transmission Project is a testament to the creativity, perseverance, cooperation and skills of hundreds of people over so many years on both sides of the border," said Jay Grewal, president and CEO of Manitoba Hydro. "Perhaps even more importantly, it is a testament to the wonderful, longstanding relationship between our two companies and two countries. It shows just how much we can accomplish when we all work together toward a common goal."

Minnesota Power engaged federal, state and local agencies; the sovereign Red Lake Nation and other tribes, reflecting First Nations involvement in major transmission planning; and landowners along the proposed routes beginning in 2012. Through 75 voluntary meetings and other outreach forums, a preferred route was selected with strong support from stakeholders that was approved by the Minnesota Public Utilities Commission in April 2016.

A four-year state and federal regulatory process culminated in late 2016 when the federal Department of Energy approved a Presidential Permit for the GNTL, similar to the New England Clean Power Link process, needed because of the international border crossing. Construction of the line began in early 2017.

"A robust stakeholder process is essential to the success of any project, but especially when building a project of this scope," Owen said. "We appreciated the early engagement and support from stakeholders, local communities and tribes, agencies and regulators through the many approval milestones to the completion of the GNTL."

 

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British Columbians can access more in EV charger rebates

B.C. EV Charging Rebates boost CleanBC incentives as NRCan and ZEVIP funding covers up to 75% of Level 2 and DC fast-charger purchase and installation costs for homes, workplaces, condos, apartments, and fleet operators.

 

Key Points

Incentives in B.C. cover up to 75% of Level 2 and DC fast charger costs for homes, workplaces, and fleets.

✅ Up to 75% back; Level 2 max $5,000; DC fast max $75,000 for fleets.

✅ Eligible sites: homes, workplaces, condos, apartments, fleet depots.

✅ Funded by CleanBC with NRCan ZEVIP; time-limited top-up.

 

The Province and Natural Resources Canada (NRCan) are making it more affordable for people to install electric vehicle (EV) charging stations in their homes, businesses and communities, as EV demand ramps up across the province.

B.C. residents, businesses and municipalities can receive higher rebates for EV charging stations through the CleanBC Go Electric EV Charger Rebate and Fleets programs. For a limited time, funding will cover as much as 75% of eligible purchase and installation costs for EV charging stations, which is an increase from the previous 50% coverage.

“With electric vehicles representing 13% of all new light-duty vehicles sold in B.C. last year, our province has the strongest adoption rate of electric vehicles in Canada. We’re positioning ourselves to become leaders in the EV industry,” said Bruce Ralston, B.C.’s Minister of Energy, Mines and Low Carbon Innovation. “We’re working with our federal partners to increase rebates for home, workplace and fleet charging, and making it easier and more affordable for people to make the switch to electric vehicles.”

With a $2-million investment through NRCan’s Zero-Emission Vehicle Infrastructure Program (ZEVIP) to top up the Province’s EV Charger Rebate program, workplaces, condominiums and apartments can get a rebate for a Level 2 charging station for as much as 75% of purchase and installation costs to a maximum of $5,000. As many as 360 EV chargers will be installed through the program.

“We’re making electric vehicles more affordable and charging more accessible where Canadians live, work and play,” said Jonathan Wilkinson, federal Minister of Natural Resources. “Investing in more EV chargers, like the ones announced today in British Columbia, will put more Canadians in the driver’s seat on the road to a net-zero future and help achieve our climate goals.”

Through the CleanBC Go Electric Fleets program and in support of B.C. businesses that own and operate fleet vehicles, NRCan has invested $1.54 million through ZEVIP to top up rebates. Fleet operators can get combined rebates from NRCan and the Province for a Level 2 charging station as much as 75% to a maximum of $5,000 of purchase and installation costs, and 75% to a maximum of $75,000 for a direct-current, fast-charging station. As many as 450 EV chargers will be installed through the program.

CleanBC is a pathway to a more prosperous, balanced and sustainable future. It supports government’s commitment to climate action to meet B.C.’s emission targets and build a cleaner, stronger economy.

Quick Facts:

  • A direct-current fast charger on the BC Electric Highway allows an EV to get 100-300 kilometres of range from 30 minutes of charging.
  • Faster chargers, which give more range in less time, are coming out every year.
  • A Level 2 charger allows an EV to get approximately 30 kilometres of range per hour of charging.
  • It uses approximately the same voltage as a clothes dryer and is usually installed in homes, workplaces or for fleets to get a faster charge than a regular outlet, or in public places where people might park for a longer time.
  • A key CleanBC action is to strengthen the Zero-Emission Vehicles Act to require light-duty vehicle sales to be 26% zero-emission vehicles (ZEVs) by 2026, 90% by 2030 and 100% by 2035, five years ahead of the original target.
  • At the end of 2021, B.C. had more than 3,000 public EV charging stations and almost 80,000 registered ZEVs.

Learn More:

To learn more about home and workplace EV charging-station rebates, eligibility and application processes, visit: https://goelectricbc.gov.bc.ca/   

To learn more about the Fleets program, visit: https://pluginbc.ca/go-electric-fleets/    

To learn more about Natural Resources Canada’s Zero-Emission Vehicle Infrastructure Program, visit:
https://www.nrcan.gc.ca/energy-efficiency/transportation-alternative-fuels/zero-emission-vehicle-infrastructure-program/21876

 

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Electricity Regulation With Equity & Justice For All

Energy equity in utility regulation prioritizes fair rates, clean energy access, and DERs, addressing fixed charges and energy burdens on low-income households through stakeholder engagement and public utility commission reforms.

 

Key Points

Fairly allocates clean energy benefits and rate burdens, ensuring access and protections for low-income households.

✅ Reduces fixed charges that burden low-income households

✅ Funds community participation in utility proceedings

✅ Prioritizes DERs, energy efficiency, and solar in impacted areas

 

By Kiran Julin

Pouring over the line items on your monthly electricity bill may not sound like an enticing way to spend an afternoon, but the way electricity bills are structured has a significant impact on equitable energy access and distribution. For example, fixed fees can have a disproportionate impact on low-income households. And combined with other factors, low-income households and households of color are far more likely to report losing home heating service, with evidence from pandemic power shut-offs highlighting these disparities, according to recent federal data.

Advancing Equity in Utility Regulation, a new report published by the U.S. Department of Energy’s (DOE’s) Lawrence Berkeley National Laboratory (Berkeley Lab), makes a unifying case that utilities, regulators, and stakeholders need to prioritize energy equity in the deployment of clean energy technologies and resources, aligning with a people-and-planet electricity future envisioned by advocacy groups. Equity in this context is the fair distribution of the benefits and burdens of energy production and consumption. The report outlines systemic changes needed to advance equity in electric utility regulation by providing perspectives from four organizations — Portland General Electric, a utility company; the National Consumer Law Center, a consumer advocacy organization; and the Partnership for Southern Equity and the Center for Biological Diversity, social justice and environmental organizations.
 
“While government and ratepayer-funded energy efficiency programs have made strides towards equity by enabling low-income households to access energy-efficiency measures, that has not yet extended in a major way to other clean-energy technologies,” said Lisa Schwartz, a manager and strategic advisor at Berkeley Lab and technical editor of the report. “States and utilities can take the lead to make sure the clean-energy transition does not leave behind low-income households and communities of color. Decarbonization and energy equity goals are not mutually exclusive, and in fact, they need to go hand-in-hand.”

Energy bills and electricity rates are governed by state laws and utility regulators, whose mission is to ensure that utility services are reliable, safe, and fairly priced. Public utility commissions also are increasingly recognizing equity as an important goal, tool, and metric, and some customers face major changes to electric bills as reforms advance. While states can use existing authorities to advance equity in their decision-making, several, including Illinois, Maine, Oregon, and Washington, have enacted legislation over the last couple of years to more explicitly require utility regulators to consider equity.

“The infrastructure investments that utility companies make today, and regulator decisions about what goes into electricity bills, including new rate design steps that shape customer costs, will have significant impacts for decades to come,” Schwartz said.

Solutions recommended in the report include considering energy justice goals when determining the “public interest” in regulatory decisions, allocating funding for energy justice organizations to participate in utility proceedings, supporting utility programs that increase deployment of energy efficiency and solar for low-income households, and accounting for energy inequities and access in designing electricity rates, while examining future utility revenue models as technologies evolve.

The report is part of the Future of Electric Utility Regulation series that started in 2015, led by Berkeley Lab and funded by DOE, to encourage informed discussion and debate on utility trends and tackling the toughest issues related to state electric utility regulation. An advisory group of utilities, public utility commissioners, consumer advocates, environmental and social justice organizations, and other experts provides guidance.

 

Taking stock of past and current energy inequities

One focus of the report is electricity bills. In addition to charges based on usage, electricity bills usually also have a fixed basic customer charge, which is the minimum amount a household has to pay every month to access electricity. The fixed charge varies widely, from $5 to more than $20. In recent years, utility companies have sought sizable increases in this charge to cover more costs, amid rising electricity prices in some markets.

This fixed charge means that no matter what a household does to use energy more efficiently or to conserve energy, there is always a minimum cost. Moreover, low-income households often live in older, poorly insulated housing. Current levels of public and utility funding for energy-efficiency programs fall far short of the need. The combined result is that the energy burden – or percent of income needed to keep the lights on and their homes at a healthy temperature – is far greater for lower-income households.

“While all households require basic lighting, heating, cooling, and refrigeration, low-income households must devote a greater proportion of income to maintain basic service,” explained John Howat and Jenifer Bosco from the National Consumer Law Center and co-authors of Berkeley Lab’s report. Their analysis of data from the most recent U.S. Energy Information Administration’s Residential Energy Consumption Survey shows households with income less than $20,000 reported losing home heating service at a pace more than five times higher than households with income over $80,000. Households of color were far more likely than those with a white householder to report loss of heating service. In addition, low-income households and households of color are more likely to have to choose between paying their energy bill or paying for other necessities, such as healthcare or food.

Based on the most recent data (2015) from the U.S. Energy Information Administration (EIA), households with income less than $20,000 reported losing home heating service at a rate more than five times higher than households with income over $80,000. Households of color were far more likely than those with a white householder to report loss of heating service. Click on chart for larger view. (Credit: John Howat/National Consumer Law Center, using EIA data)

Moreover, while many of the infrastructure investment decisions that utilities make, such as whether and where to build a new power plant, often have long-term environmental and health consequences, impacted communities often are not at the table. “Despite bearing an inequitable proportion of the negative impacts of environmental injustices related to fossil fuel-based energy production and climate change, marginalized communities remain virtually unrepresented in the energy planning and decision-making processes that drive energy production, distribution, and regulation,” wrote Chandra Farley, CEO of ReSolve and a co-author of the report.


Engaging impacted communities
Each of the perspectives in the report identify a need for meaningful engagement of underrepresented and disadvantaged communities in energy planning and utility decision-making. “Connecting the dots between energy, racial injustice, economic disinvestment, health disparities, and other associated equity challenges becomes a clarion call for communities that are being completely left out of the clean energy economy,” wrote Farley, who previously served as the Just Energy Director at Partnership for Southern Equity. “We must prioritize the voices and lived experiences of residents if we are to have more equity in utility regulation and equitably transform the energy sector.”

In another essay in the report, Nidhi Thaker and Jake Wise from Portland General Electric identify the importance of collaborating directly with the communities they serve. In 2021, the Oregon Legislature passed Oregon HB 2475, which allows the Oregon Public Utility Commission to allocate ratepayer funding for organizations representing people most affected by a high energy burden, enabling them to participate in utility regulatory processes.

The report explains why energy equity requires correcting inequities resulting from past and present failures as well as rethinking how we achieve future energy and decarbonization goals. “Equity in energy requires adopting an expansive definition of the ‘public interest’ that encompasses energy, climate, and environmental justice. Energy equity also means prioritizing the deployment of distributed energy resources and clean energy technologies in areas that have been hit first and worst by the existing fossil fuel economy,” wrote Jean Su, energy justice director and senior attorney at the Center for Biological Diversity.

This report was supported by DOE’s Grid Modernization Laboratory Consortium, with funding from the Office of Energy Efficiency and Renewable Energy and the Office of Electricity.

 

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Uzbekistan Looks To Export Electricity To Afghanistan

Surkhan-Pul-e-Khumri Power Line links Uzbekistan and Afghanistan via a 260-kilometer transmission line, boosting electricity exports, grid reliability, and regional trade; ADB-backed financing could open Pakistan's energy market with 24 million kWh daily.

 

Key Points

A 260-km line to expand Uzbekistan power exports to Afghanistan, ADB-funded, with possible future links to Pakistan.

✅ 260 km Surkhan-Pul-e-Khumri transmission link

✅ +70% electricity exports; up to 24M kWh daily

✅ ADB $70M co-financing; $32M from Uzbekistan

 

Senior officials with Uzbekistan’s state-run power company have said work has begun on building power cables to Afghanistan that will enable them to increase exports by 70 per cent, echoing regional trends like Ukraine resuming electricity exports after grid repairs.

Uzbekenergo chief executive Ulugbek Mustafayev said in a press conference on March 24 that construction of the Afghan section of the 260-kilometer Surkhan-Pul-e-Khumri line will start in June.

The Asian Development Bank has pledged $70 million toward the final expected $150 million bill of the project. Another $32 million will come from Uzbekistan.

Mustafayev said the transmission line would give Uzbekistan the option of exporting up to 24 million kilowatt hours to Afghanistan daily, similar to Ukraine's electricity export resumption amid shifting regional demand.

“We could potentially even reach Pakistan’s energy market,” he said, noting broader regional ambitions like Iran's bid to be a power hub linking regional grids.

#google#

This project was given fresh impetus by Afghan President Ashraf Ghani’s visit to Tashkent in December, mirroring cross-border energy cooperation such as Iran-Iraq energy talks in the region. His Uzbek counterpart, Shavkat Mirziyoyev, had announced at the time that work was set to begin imminently on the line, which will run from the village of Surkhan in Uzbekistan’s Surkhandarya region to Pul-e-Khumri, a town in Afghanistan just south of Kunduz.

In January, Mirziyoyev issued a decree ordering that the rate for electricity deliveries to Afghanistan be dropped from $0.076 to $0.05 per kilowatt.

Mustafayev said up to 6 billion kilowatt hours of electricity could eventually be sent through the power lines. More than 60 billion kilowatt hours of electricity was produced in Uzbekistan in 2017.

According to Tulabai Kurbonov, an Uzbek journalist specializing in energy issues, the power line will enable the electrification of the the Hairatan-Mazar-i-Sharif railroad joining the two countries. Trains currently run on diesel. Switching over to electricity will help reduce the cost of transporting cargo.

There is some unhappiness, however, over the fact that Uzbekistan plans to sell power to Afghanistan when it suffers from significant shortages domestically and wider Central Asia electricity shortages persist.

"In the villages of the Ferghana Valley, especially in winter, people are suffering from a shortage of electricity,” said Munavvar Ibragimova, a reporter based in the Ferghana Valley. “You should not be selling electricity abroad before you can provide for your own population. What we clearly see here is the favoring of the state’s interests over those of the people.”

 

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