TVA looks to expand base of power production

By Knoxville News Sentinel


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In addition to encouraging energy efficiency and tightening its own business operations, TVA is addressing higher fuel costs by moving forward with plans to expand its base of nuclear power generation plants.

In a news teleconference, TVA President and CEO Tom Kilgore said the uranium fuel required to power its nuclear plants is relatively inexpensive compared to coal and natural gas, which this year have risen at an unprecedented clip.

The agency recently has re-started a reactor at Browns Ferry in Athens., Ala., and is currently in the process of deploying an existing unit at its Watts Bar plant near Spring City, Tenn.

TVA is also moving forward with plans to construct two new reactors at the Bellefonte site and filed an application for a construction operation permit last fall.

In a more recent development, the agency also has begun exploring the possibility of restarting two partially completed reactors at the Bellefonte site, although details on the potential project have yet to emerge.

Construction of the two reactors at the site near Scottsboro, Ala., was begun in 1974 and halted in 1988, with the first unit 88 percent complete and the second unit 55 percent finished. TVA invested $4.2 billion in the project.

"What we're doing really is just looking at the feasibility of what we call units one and two, the existing units there," said TVA spokesman John Moulton. "We're just right now exploring the feasibility of what it would take as far as licensing, (construction), the whole ball of wax.Â… We're looking right now, along with our energy efficiency push, (at) what (are the) best ways to meet the needs out there in the future."

Options for the timing of the re-start are being considered with construction schedules for the reactors in mind.

"Our main focus for the site continues to be the new start," he said.

Moulton said he did not have information on when TVA planned to make a decision on the re-start, which would require a construction license from the Nuclear Regulatory Commission. TVA had withdrawn its existing construction permit.

The Huntsville Times of Alabama quoted TVA spokesman Gil Francis as saying that energy forecasts show more power plants may be needed between 2017 and 2019 and that was why the utility is considering finishing Units 1 and 2.

Kilgore said that nuclear generation lies at the heart of the agency's future power production plans.

"TVA is strategically building its nuclear generation portfolio, which will reduce the Valley's exposure to volatile commodity fuel prices," an information slide presented to reporters at the Web and teleconference said.

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Ontario Power Generation's Commitment to Small Modular Reactors

OPG Small Modular Reactors advance clean energy with advanced nuclear, baseload power, renewables integration, and grid reliability; factory built, scalable, and cost effective to support Ontario energy security and net zero goals.

 

Key Points

Factory built nuclear units delivering reliable, low carbon power to support Ontario's grid, renewables, climate goals.

✅ Factory built modules cut costs and shorten schedules

✅ Provides baseload power to balance wind and solar

✅ Enhances grid reliability with advanced safety and waste reduction

 

Ontario Power Generation (OPG) is at the forefront of Canada’s energy transformation, demonstrating a robust commitment to sustainable energy solutions. One of the most promising avenues under exploration is the development of Small Modular Reactors (SMRs), as OPG broke ground on the first SMR at Darlington to launch this next phase. These innovative technologies represent a significant leap forward in the quest for reliable, clean, and cost-effective energy generation, aligning with Ontario’s ambitious climate goals and energy security needs.

Understanding Small Modular Reactors

Small Modular Reactors are advanced nuclear power plants that are designed to be smaller in size and capacity compared to traditional nuclear reactors. Typically generating up to 300 megawatts of electricity, SMRs can be constructed in factories and transported to their installation sites, offering flexibility and scalability that larger reactors do not provide. This modular approach reduces construction time and costs, making them an appealing option for meeting energy demands.

One of the key advantages of SMRs is their ability to provide baseload power—energy that is consistently available—while simultaneously supporting intermittent renewable sources like wind and solar. As Ontario continues to increase its reliance on renewables, SMRs could play a crucial role in ensuring that the energy supply remains stable and secure.

OPG’s Initiative

In its commitment to advancing clean energy technologies, OPG has been a strong advocate for the adoption of SMRs. The province of Ontario has announced plans to develop three additional small modular reactors, part of its plans for four Darlington SMRs that would further enhance the region’s energy portfolio. This initiative aligns with both provincial and federal climate objectives, and reflects a collaborative provincial push on nuclear innovation to accelerate clean energy.

The deployment of SMRs in Ontario is particularly strategic, given the province’s existing nuclear infrastructure, including the continued operation of Pickering NGS that supports grid reliability. OPG operates a significant portion of Ontario’s nuclear fleet, and leveraging this existing expertise can facilitate the integration of SMRs into the energy mix. By building on established operational frameworks, OPG can ensure that new reactors are deployed safely and efficiently.

Economic and Environmental Benefits

The introduction of SMRs is expected to bring substantial economic benefits to Ontario. The construction and operation of these reactors will create jobs, including work associated with the Pickering B refurbishment across the province, stimulate local economies, and foster innovation in nuclear technology. Additionally, SMRs have the potential to attract investment from both domestic and international stakeholders, positioning Ontario as a leader in advanced nuclear technology.

From an environmental perspective, SMRs are designed with enhanced safety features and lower waste production compared to traditional reactors, complementing life-extension measures at Pickering that bolster system reliability. They can significantly contribute to Ontario’s goal of achieving net-zero emissions by 2050. By providing a reliable source of clean energy, SMRs will help mitigate the impacts of climate change while supporting the province's transition to a sustainable energy future.

Community Engagement and Collaboration

Recognizing the importance of community acceptance and stakeholder engagement, OPG is committed to an open dialogue with local communities and Indigenous groups. This collaboration is essential to addressing concerns and ensuring that the deployment of SMRs is aligned with the values and priorities of the residents of Ontario. By fostering a transparent process, OPG aims to build trust and support for this innovative energy solution.

Moreover, the development of SMRs will involve partnerships with various stakeholders, including government agencies, research institutions, and private industry, such as the OPG-TVA partnership to advance new nuclear technology. These collaborations will not only enhance the technical aspects of SMR deployment but also ensure that Ontario can capitalize on shared expertise and resources.

Looking Ahead

As Ontario Power Generation moves forward with plans for three additional Small Modular Reactors, the province stands at a critical juncture in its energy evolution. The integration of SMRs into Ontario’s energy landscape promises a sustainable, reliable, and economically viable solution to meet growing energy demands while addressing climate change challenges.

With the support of government initiatives, community collaboration, and continued innovation in nuclear technology, Ontario is poised to become a leader in the advancement of Small Modular Reactors. The successful implementation of these projects could serve as a model for other jurisdictions seeking to transition to cleaner energy sources, highlighting the role of nuclear power in a balanced and sustainable energy future.

In conclusion, OPG's commitment to developing Small Modular Reactors not only reinforces Ontario’s energy security but also demonstrates a proactive approach to addressing the pressing challenges of climate change and environmental sustainability. The future of energy in Ontario looks promising, driven by innovation and a commitment to clean energy solutions.

 

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Renewables surpass coal in US energy generation for first time in 130 years

Renewables Overtake Coal in the US, as solar, wind, and hydro expand grid share; EIA data show an energy transition accelerated by COVID-19, slashing emissions, displacing fossil fuels, and reshaping electricity generation and climate policy.

 

Key Points

It refers to the milestone where US renewable energy generation surpassed coal, marking a pivotal energy transition.

✅ EIA data show renewables topped coal consumption in 2019.

✅ Solar, wind, and hydro displaced aging, costly coal plants.

✅ COVID-19 demand drop accelerated the energy transition.

 

Solar, wind and other renewable sources have toppled coal in energy generation in the United States for the first time in over 130 years, with the coronavirus pandemic accelerating a decline in coal that has profound implications for the climate crisis.

Not since wood was the main source of American energy in the 19th century has a renewable resource been used more heavily than coal, but 2019 saw a historic reversal, building on wind and solar reaching 10% of U.S. generation in 2018, according to US government figures.

Coal consumption fell by 15%, down for the sixth year in a row, while renewables edged up by 1%, even as U.S. electricity use trended lower. This meant renewables surpassed coal for the first time since at least 1885, a year when Mark Twain published The Adventures of Huckleberry Finn and America’s first skyscraper was erected in Chicago.

Electricity generation from coal fell to its lowest level in 42 years in 2019, with the US Energy Information Administration (EIA) forecasting that renewables will eclipse coal as an electricity source this year, while a global eclipse by 2025 is also projected. On 21 May, the year hit its 100th day in which renewables have been used more heavily than coal.

“Coal is on the way out, we are seeing the end of coal,” said Dennis Wamsted, analyst at the Institute for Energy Economics and Financial Analysis. “We aren’t going to see a big resurgence in coal generation, the trend is pretty clear.”

The ongoing collapse of coal would have been nearly unthinkable a decade ago, when the fuel source accounted for nearly half of America’s generated electricity, even as a brief uptick in 2021 was anticipated. That proportion may fall to under 20% this year, with analysts predicting a further halving within the coming decade.

A rapid slump since then has not been reversed despite the efforts of the Trump administration, which has dismantled a key Barack Obama-era climate rule to reduce emissions from coal plants and eased requirements that prevent coal operations discharging mercury into the atmosphere and waste into streams.

Coal releases more planet-warming carbon dioxide than any other energy source, with scientists warning its use must be rapidly phased out to achieve net-zero emissions globally by 2050 and avoid the worst ravages of the climate crisis.

Countries including the UK and Germany are in the process of winding down their coal sectors, and in Europe renewables are increasingly crowding out gas as well, although in the US the industry still enjoys strong political support from Trump.

“It’s a big moment for the market to see renewables overtake coal,” said Ben Nelson, lead coal analyst at Moody’s. “The magnitude of intervention to aid coal has not been sufficient to fundamentally change its trajectory, which is sharply downwards.”

Nelson said he expects coal production to plummet by a quarter this year but stressed that declaring the demise of the industry is “a very tough statement to make” due to ongoing exports of coal and its use in steel-making. There are also rural communities with power purchase agreements with coal plants, meaning these contracts would have to end before coal use was halted.

The coal sector has been beset by a barrage of problems, predominantly from cheap, abundant gas that has displaced it as a go-to energy source. The Covid-19 outbreak has exacerbated this trend, even as global power demand has surged above pre-pandemic levels. With plunging electricity demand following the shutting of factories, offices and retailers, utilities have plenty of spare energy to choose from and coal is routinely the last to be picked because it is more expensive to run than gas, solar, wind or nuclear.

Many US coal plants are ageing and costly to operate, forcing hundreds of closures over the past decade. Just this year, power companies have announced plans to shutter 13 coal plants, including the large Edgewater facility outside Sheboygan, Wisconsin, the Coal Creek Station plant in North Dakota and the Four Corners generating station in New Mexico – one of America’s largest emitters of carbon dioxide.

The last coal facility left in New York state closed earlier this year.

The additional pressure of the pandemic “will likely shutter the US coal industry for good”, said Yuan-Sheng Yu, senior analyst at Lux Research. “It is becoming clear that Covid-19 will lead to a shake-up of the energy landscape and catalyze the energy transition, with investors eyeing new energy sector plays as we emerge from the pandemic.”

Climate campaigners have cheered the decline of coal but in the US the fuel is largely being replaced by gas, which burns more cleanly than coal but still emits a sizable amount of carbon dioxide and methane, a powerful greenhouse gas, in its production, whereas in the EU wind and solar overtook gas last year.

Renewables accounted for 11% of total US energy consumption last year – a share that will have to radically expand if dangerous climate change is to be avoided. Petroleum made up 37% of the total, followed by gas at 32%. Renewables marginally edged out coal, while nuclear stood at 8%.

“Getting past coal is a big first hurdle but the next round will be the gas industry,” said Wamsted. “There are emissions from gas plants and they are significant. It’s certainly not over.”
 

 

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Minnesota bill mandating 100% carbon-free electricity by 2040

Minnesota 100% Carbon-Free Electricity advances renewable energy: wind, solar, hydropower, hydrogen, biogas from landfill gas and anaerobic digestion; excludes incineration in environmental justice areas; uses renewable energy credits and streamlined permitting.

 

Key Points

Minnesota's mandate requires utilities to deliver 100% carbon-free power by 2040 with targets and EJ safeguards.

✅ Utilities must hit 90% carbon-free by 2035; 100% by 2040.

✅ Incineration in EJ areas excluded; biogas, wind, solar allowed.

✅ Compliance via renewable credits; streamlined permitting.

 

Minnesota Gov. Tim Walz, D, is expected to soon sign a bill establishing a clean electricity standard requiring utilities in the state to provide electricity from 100% carbon-free sources by 2040. The bill also calls for utilities to generate at least 55% of their electricity from renewable energy sources by 2035, a trajectory similar to New Mexico's clean electricity push underway this decade.

Electricity generated from landfill gas and anaerobic digestion are named as approved renewable energy technologies, but electricity generated from incinerators operating in “environmental justice areas”, reflecting concerns about renewable facilities violating pollution rules in some states, will not be counted toward the goal. Wind, solar, and certain hydropower and hydrogen energy sources are also considered renewable in the bill. 

The bill defines EJ areas as places where at least 40% of residents are not white, 35% of households have an income that’s below 200% of the federal poverty line, and 40% or more of residents over age 5 have “limited” English proficiency. Areas the U.S. state defines as “Indian country” are also considered EJ areas.

Some of the state’s largest electric utilities, like Xcel Energy and Minnesota Power, have already pledged to move to carbon-free energy, and utilities such as Alliant Energy have outlined carbon-neutral plans in the region, but this bill speeds up that goal by 10 years, Minnesota Public Radio reported. The bill calls for public utilities operating in the state to be 80% carbon-free and other electric utilities to be 60% carbon-free by 2030. All utilities must be 90% carbon-free by 2035 before ultimately hitting the 100% mark in 2040, according to the bill.  

The bill gives utilities some leniency if they demonstrate to state regulators that they can’t offer affordable power while working toward the benchmarks, acknowledging reliability challenges seen in places like California's grid during the clean energy transition. It also allows utilities to buy renewable energy credits to meet the standard instead of generating the energy themselves. 

Patrick Serfass, executive director of the American Biogas Council, said the bill will incentivize more biogas-related electricity projects, “which means the recycling of more organic material and more renewable electricity in the state. Those are all good things,” he said. ABC sees significant potential for biogas production in Minnesota, though the federal climate law has delivered mixed results for accelerating clean power deployment.

The bill also aims to streamline the permitting process for new energy projects in the state, even as some states consider limits on clean energy that would constrain utility use, and calls for higher minimum wage requirements for workers.

 

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UK price cap on household energy bills expected to cost 89bn

UK Energy Price Guarantee Cost forecasts from Cornwall Insight suggest an £89bn bill, tied to wholesale gas prices, OBR projections, and fiscal policy, to shield households amid the cost of living crisis.

 

Key Points

It is the projected government spend to cap household bills, driven by wholesale gas prices and OBR market forecasts.

✅ Base case: £89bn over two years, per Cornwall Insight

✅ Range: £72bn to £140bn, volatile wholesale gas costs

✅ Excludes 6-month business support estimated at £22bn-£48bn

 

Liz Truss’s intervention to freeze energy prices for households for two years is expected to cost the government £89bn, according to the first major costing of the policy by the sector’s leading consultancy.

The analysis from Cornwall Insight, seen exclusively by the Guardian, shows the prime minister’s plan to tackle the cost of living crisis could cost as much as £140bn in a worst-case scenario.

Truss announced in early September that the average annual bill for a typical household would be capped at £2,500 to protect consumers from the intensifying cost of living crisis amid high winter energy costs and a scheduled 80% rise in the cap to £3,549.

The ultimate cost of the policy is uncertain as it is highly dependent on the wholesale cost of gas, including UK natural gas prices which have soared since Russia’s invasion of Ukraine put a squeeze on already-volatile international markets. Ballpark projections had put the cost anywhere from £100bn to £150bn.

The Office for Budget Responsibility is expected to give its forecast for the bill when it provides its independent assessment of Kwasi Kwarteng’s medium-term fiscal plan, which the chancellor said on Tuesday would still happen on 23 November despite previous reports that it would be brought forward.

Cornwall Insight analysed projections of wholesale market moves to cost the intervention. In its base case scenario, analysts expect the policy to cost £89bn. That assumes the cost of supporting each household would be just over £1,000 in the first year, and about £2,000 in the second year.

The study’s authors said the wholesale price of gas would be influenced by energy demand, the severity of weather, “geo-political uncertainty” and prices for liquified natural gas as Europe seeks to refill storage facilities, which countries have rushed to fill up this winter but which could be relatively empty by next spring.

In the best-case outcome, the policy would cost £72bn, with some projections pointing to a 16% decrease in energy bills in April for households, while the “extreme high” outlook would see the government shell out £140bn to protect 29m UK households.

Gas prices are expected to push even higher if the Kremlin decides to completely cut off Russian gas exports into Europe.

Cornwall Insight’s projection does not include a separate six-month initiative to cap costs for companies, charities and public sector organisations, which is forecast to cost £22bn to £48bn.

The consultancy’s chief executive, Gareth Miller, said the £70bn range in its forecasts reflected “a febrile wholesale market continuing to be beset by geopolitical instability, sensitivity to demand, weather and infrastructure resilience”.

He said: “Fortune befriends the bold, but it also favours the prepared. The large uncertainties around commodity markets over the next two years means that the government could get lucky with costs coming out at the low end of the range, but the opposite could also be true.

“In each case, the government may find itself passengers to circumstances outside its control, having made policy that is a hostage to surprises, events and volatile factors. That’s a difficult position to be in.”

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The government has faced criticism, as some British MPs urge tighter limits on prices, that the policy is effectively a “blank cheque” and is not targeted at the most vulnerable in society.

Concerns over how Truss and Kwarteng intend to fund a series of measures, including the price guarantee, have spooked financial markets.

The EU, which has outlined possible gas price cap strategies in recent proposals, said last week it planned to cap the revenues of low-carbon electricity generators at €180 a megawatt hour, which is less than half current market prices. Truss has so far resisted calls to extend a levy on North Sea oil and gas operators to electricity generators, who have benefited from a link between gas and electricity prices in Britain.

Truss hopes to strike voluntary long-term deals with generators including Centrica and EDF, alongside the government’s Energy Security Bill measures, to bring down wholesale prices.

The Financial Times reported on Tuesday that the government has threatened companies with legislation to cap their revenues if voluntary deals cannot be agreed.

 

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Egypt Plans Power Link to Saudis in $1.6 Billion Project

Egypt-Saudi Electricity Interconnection enables cross-border power trading, 3,000 MW capacity, and peak-demand balancing across the Middle East, boosting grid stability, reliability, and energy security through an advanced electricity network, interconnector infrastructure, and GCC grid integration.

 

Key Points

A 3,000 MW grid link letting Egypt and Saudi Arabia trade power, balance peak demand, and boost regional reliability.

✅ $1.6B project; Egypt invests ~$600M; 2-year construction timeline

✅ 3,000 MW capacity; peak-load shifting; cross-border reliability

✅ Links GCC grid; complements Jordan and Libya interconnectors

 

Egypt will connect its electricity network to Saudi Arabia, joining a system in the Middle East that has allowed neighbors to share power, similar to the Scotland-England subsea project that will bring renewable power south.

The link will cost about $1.6 billion, with Egypt paying about $600 million, Egypt’s Electricity Minister Mohamed Shaker said Monday at a conference in Cairo, as the country pursues a smart grid transformation to modernize its network. Contracts to build the network will be signed in March or April, and construction is expected to take about two years, he said. In times of surplus, Egypt can export electricity and then import power during shortages.

"It will enable us to benefit from the difference in peak consumption,” Shaker said. “The reliability of the network will also increase.”

Transmissions of electricity across borders in the Gulf became possible in 2009, when a power grid connected Qatar, Kuwait, Saudi Arabia and Bahrain, a dynamic also seen when Ukraine joined Europe's grid under emergency conditions. The aim of the grid is to ensure that member countries of the Gulf Cooperation Council can import power in an emergency. Egypt, which is not in the GCC, may have been able to avert an electricity shortage it suffered in 2014 if the link with Saudi Arabia existed at the time, Shaker said.

The link with Saudi Arabia should have a capacity of 3,000 megawatts, he said. Egypt has a 450-megawatt link with Jordan and one with Libya at 200 megawatts, the minister said. Egypt will seek to use its strategic location to connect power grids in Asia, where the Philippines power grid efforts are raising standards, and elsewhere in Africa, he said.

In 2009, a power grid linked Qatar, Kuwait, Saudi Arabia and Bahrain, allowing the GCC states to transmit electricity across borders, much like proposals for a western Canadian grid that aim to improve regional reliability. 

 

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Old meters giving away free electricity to thousands of N.B. households

NB Power Smart Meters will replace aging analog meters, boosting billing accuracy, reducing leakage, and modernizing distribution as the EUB considers a $92 million rollout of 360,000 advanced meters for residential and commercial customers.

 

Key Points

NB Power Smart Meters replace analog meters, improving billing accuracy and reducing leakage in the electricity network.

✅ EUB reviewing $92M plan for 360,000 advanced meters

✅ Replaces 98,000 analog units; curbs unbilled kWh

✅ Improves billing accuracy and reduces system leakage

 

Home and business owners with old power meters in New Brunswick have been getting the equivalent of up to 10 days worth of electricity a year or more for free, a multi million dollar perk that will end quickly if the Energy and Utilities Board approves the adoption of smart meters, a move that in other provinces has prompted refusal fees for some holdouts.

Last week the EUB began deliberations over whether to allow NB Power to purchase and install 360,000 new generation smart meters for its residential and commercial customers as part of a $92 million upgrade of its distribution system, even as regulators elsewhere approve major rate changes that affect customer bills.

If approved, that will spell the end to about 98,000 aging electromagnetic or analog meters still used by about one quarter of NB Power customers.  Those are the kind with a horizontal spinning silver disc and clock-face style dials that record consumption 

NB Power lawyer John Furey told the energy and utilities board last week that the utility suspects it loses several million dollars a year to electricity consumed by customers that is not properly recorded by their old meters. It was a central issue in Furey's argument for smart meters amid broader debates over industrial subsidies and debt. (Roger Cosman/CBC)
The analog units, some more than 50 years old and installed back when the late Louis Robichaud and Richard Hatfield were premiers in the 1960's and 1970's - are suspected of doling out millions of kilowatt hours of free power to customers by failing to register all of the current that moves through them.   

"Over time, analog meters slow down and they register lower consumption of electricity than is actually occurring," said NB Power lawyer John Furey last week about the widespread freeloading of power in New Brunswick caused by the old meters.

3 per cent missed
A 2010 report by the independent non-profit Electric Power Research Institute in Palo Alto, California and entered into evidence during NB Power's smart meter hearing said old spinning disc meters generally degrade over time and after 20 years typically fail to register nearly 3 per cent of the power that flows through them.

The average age of analog meters in New Brunswick is much older than that - 31 years - and more than 11,000 of the units are over the age of 40.

"Worn gears, corrosion, moisture, dust, and insects can all cause drag and result in an electromagnetic meter that does not capture the full consumption of the premises," said the report.

The sudden correction to full accounting and billing could naturally surprise these homeowners and even trigger consumer backlash in some cases

- Electric Power Research Institute report
About 94,000 NB residential customers and 3,900 commercial customers have an old meter, according to NB Power records. The group would receive about 40 million kilowatt hours of electricity for free this year  ($5.1 million worth including HST)  if the average unit failed to register 2 percent of the electricity flowing through it, while elsewhere some customers are receiving lump-sum credits on electricity bills.  

That is about $41 in free power for the average residential customer and $322 for the average business.

But, according to the research, there would also be hundreds of customers with meters that have slowed considerably more than the average with 0.3 percent - or close to 300 in NB Power's case -  not counting between 10 and 20 percent of the electricity customers are using. 

NB Power senior Vice President Lori Clark told the EUB stopping the freeloading of power in New Brunswick caused by older meters is in everyone's interest. (Roger Cosman/CBC)
That's potentially $400 in free electricity in a year for a residential customer with average consumption.

"While the average meter might be only slightly slow a few could be significantly so," said the report.

"The sudden correction to full accounting and billing could naturally surprise these homeowners and result in questioning of a new meter, as seen in a shocking $666 bill reported by a Nova Scotia senior." 

The report made the point analog meters can also run fast but called that "less common" meaning that if the EUB approves smart meters, tens of thousands of customers who lose an old meter to a new accurate model will experience higher bills.

'Leakage' reduction
NB Power acknowledges it does not know precisely how much power its older meters give away but said whether it is a little or a lot, ending the freebies is to everyone's benefit. 

"It reduces our inefficiencies, reduces our leakage that we have in the system, so that we are  picking up those unbilled kilowatt hours," said NB Power senior vice president Lori Clark about ending the free power many customers unknowingly enjoy.

Smart meter critics change tone on NB Power's new business case
NB Power's smart meter plan gets major boost with critical endorsements
"Customers benefit from reduced inefficiencies in our system. They benefit from reduced leakage in our system and the fact that those kilowatt hours are being properly billed to the customers that have consumed the kilowatt hours."   

NB Power hopes to win approval of its plan to acquire smart meters by this spring to allow installation beginning in mid 2021, even as some utilities elsewhere have backed away from smart home network projects.

 

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