Future dim for nuclear waste repository

By New York Times


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President Obama’s proposed budget cuts off most money for the Yucca Mountain nuclear waste project, a decision that fulfills a campaign promise and wins the president political points in Nevada — but raises new questions about what to do with radioactive waste from the nation’s nuclear power plants.

The decision could cost the federal government additional billions in payments to the utility industry, and if it holds up, it would mean that most of the $10.4 billion spent since 1983 to find a place to put nuclear waste was wasted.

A final decision to abandon the repository would leave the nation with no solution to a problem it has struggled with for half a century.

Lawyers are predicting tens of billions of dollars in damage suits from utilities that must pay to store their wastes instead of having the government bury them, with the figure rising by about a half-billion dollars for each year of additional delay.

The courts have already awarded the companies about $1 billion, because the government signed contracts obligating it to begin taking the waste in 1998, but seems unlikely to do so for years. The nuclear industry says it may demand the return of the $22 billion that it has paid to the Energy Department to establish a repository, but that the government has not yet spent.

The spent fuel that emerges from nuclear power plants has been accumulating for decades in steel-lined pools or giant steel-and-concrete casks near the reactors.

Yucca Mountain, a ridge of volcanic rock about 100 miles northwest of Las Vegas, has been the leading candidate site for a repository since the 1980s. But it was not selected by any scientific process of elimination; it was selected from a list in 1987 by Congress, which declared it dry and remote enough.

Scientific concerns have since emerged, including the realization that water flows through Yucca Mountain a lot faster than initially believed. That raises the prospect that the nuclear waste would leach over time, polluting the water table. The scientific merit of the site has not been established by independent judges.

Nevada has fought the project bitterly in court and in Congress. The ascension of Harry Reid, a Nevada Democrat, as Senate majority leader, and President ObamaÂ’s campaign promise to stop the Yucca Mountain depository and look for alternatives may finally settle the question.

In fact, the political wind is blowing so strongly against using Yucca Mountain that the nuclear industry’s trade association is not opposing Mr. Obama head-on. Instead, in response to his budget proposal, it called for creation of an independent panel to study how the government should meet its “legal and moral obligation” to take the waste. Mr. Obama himself is calling for more study.

Mr. Reid does not appear to have the votes to kill the Yucca Mountain depository entirely, because many members of Congress want to stick with the consensus they achieved two decades ago to bury the waste there. If Congress changes the law that designates Yucca Mountain as the prime candidate, said Edward F. Sproat III, who was the Energy Department official in charge of the depository project for the last two and a half years of the Bush administration, “everybody knows their state is going to be back in play.”

The siteÂ’s suitability is supposed to be established in hearings by the Nuclear Regulatory Commission, which must decide whether to license the repository. Now, the Obama administration is proposing to provide only enough money that project officials can answer questions from the hearings. Eliot Brenner, a commission spokesman, said the hearings would proceed.

“What happens once we say yes or no is out of our hands,” Mr. Brenner said.

Opponents of nuclear power contend that the nationÂ’s failure to find a permanent repository for the waste is a reason to shut down nuclear reactors and forget about building more.

Abandonment of the Yucca Mountain depository would be a blow for the nuclear industry, which is hoping to begin work on new reactors for the first time in 30 years.

If the commission does not issue its decision until the next administration, that could keep Yucca Mountain viable.

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Sask. Party pledges 10% rebate on SaskPower electricity bills

SaskPower 10% Electricity Rebate promises one-year bill relief for households, farms, businesses, hospitals, schools, and universities in Saskatchewan, boosting affordability amid COVID-19, offsetting rate hikes, and countering carbon tax impacts under Scott Moe's plan.

 

Key Points

One-year 10% SaskPower rebate lowering bills for residents, farms, and institutions, funded by general revenue.

✅ Applies automatically to all customers for 12 months from Dec 2020.

✅ Average savings: $215 residential; $845 farm; broad sector coverage.

✅ Cost $261.6M, paid from the general revenue fund; separate from carbon tax.

 

Saskatchewan Party leader Scott Moe says SaskPower customers can expect a one-year, 10 per cent rebate on electricity if they are elected government.

Moe said the pledge aims to make life more affordable for people, including through lower electricity rates initiatives seen in other provinces. The rate would apply to everyone, including residential customers, farmers, businesses, hospitals, schools and universities.

The plan, which would cost government $261.6 million, expects to save the average residential customer $215 over the course of the year and the average farm customer $845.  

“This is a very equitable way to ensure that we are not only providing that opportunity for those dollars to go back into our economy and foster the economic recovery that we are working towards here, in Saskatchewan, across Canada and around the globe, but it also speaks to the affordability for our Saskatchewan families, reducing the dollars a day off to pay for their for their power bill,” Moe said.

The rebate would be applied automatically to all SaskPower bills for 12 months, starting in December 2020. 

Moe said residential customers who are net metering and generating their own power, such as solar power, would receive a $215 rebate over the 12-month period, which is the equivalent of the average residential rebate.

The $261.6 million in costs would be covered by the government’s general revenue fund.   

The Saskatchewan NDP said the proposed reduction is "a big change in direction from the Sask. Party’s long history of making life more expensive for Saskatchewan families." and recently took aim at a SaskPower rate hike approval as part of that critique.

Trent Wotherspoon, NDP candidate for Regina Rosemont and former finance critic, called the pledge criticized the one year time frame and said Saskatchewan people need long term, reliable affordability, noting that the Ontario-Quebec hydro deal has not reduced hydro bills for consumers. Something, he said, is reflected in the NDP plan.

“We've already brought about announcements that bring about affordability, such as the break on SGI auto insurance that'll happen, year after year after year, affordable childcare which has been already announced and committed to things like a decent minimum wage instead of having the lowest minimum wage in Canada,” Wotherspoon said.

The NDP pointed out SaskPower bills have increased by 57 per cent since 2007 for families with an average household income of $75,000, while Nova Scotia's 14% rate hike was recently approved by its regulator.

It said the average bill for such household was $901 in 2007-08 and is now $1,418 in 2019-20, while in neighbouring provinces Manitoba rate increases of 2.5 per cent annually have also been proposed for three years.

"This is on top of the PST increases that the Sask. Party put on everyday families – costing them more than $700 a year," the NDP said.

Moe took aim at the federal Liberal government’s carbon tax, citing concerns that electricity prices could soar under national policies.

He said if the Saskatchewan government wins its court fight against Ottawa, all SaskPower customers can expect to save an additional $150 million per year, and he questioned the federal 2035 net-zero electricity grid target in that context.

“As it stands right now, the Trudeau government plans to raise the carbon tax from $30 to $40 a tonne on Jan. 1,” Moe said. “Trudeau plans to raise taxes and your SaskPower bill, in the middle of a pandemic.  The Saskatchewan Party will give you a break by cutting your power bill.”

 

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Hydro-Québec puts global ambitions on hold as crisis weighs on demand

Hydro-Que9bec COVID-19 M&A Pause signals a halt to international expansion as falling electricity demand, weaker exports, and revenue pressure shift capital to the Quebec economy, prioritizing domestic investment, strategic plan revisions, and risk management.

 

Key Points

Hydro-Que9bec COVID-19 M&A Pause halts overseas deals, shifting investment to Quebec as demand, exports and revenue fall.

✅ International M&A on hold; capital reallocated to Quebec projects

✅ Lower electricity demand reduces exports and spot prices

✅ Strategic plan and 2020 guidance revised downward

 

COVID-19 is forcing Hydro-Québec to pull the plug on its global ambitions — for now, even as its electricity ambitions have reopened old wounds in Newfoundland and Labrador in recent years.

Quebec’s state-owned power generator and distributor has put international mergers and acquisitions on hold for the foreseeable future because of the COVID-19 crisis, chief financial officer Jean-Hugues Lafleur said Friday.

Former chief executive officer Éric Martel, who left last month, had made foreign expansion a key tenet of his growth strategy.

“We’re in revision mode” as pertains to acquisitions, Lafleur told reporters on a conference call, as the company pursues a long-term strategy to wean the province off fossil fuels at home as well. “I don’t see how Hydro-Québec could take $5 billion now and invest it in Chile because we have an investment opportunity there. Instead, the $5 billion will be invested here to support the Quebec economy. We’re going to make sure the Quebec economy recovers the right way before we go abroad.”

Lafleur spoke after Hydro-Québec reported a 14-per-cent drop in first-quarter profit and warned full-year results will fall short of expectations as COVID-19 weighs on power demand.

Net income in the three-month period ended March 31 was $1.53 billion, down from $1.77 billion a year ago, Hydro-Québec said in a statement. Revenue fell about six per cent to $4.37 billion.

“Due to the economic downturn resulting from the current crisis, we’re anticipating lower electricity sales in all of our markets,” Lafleur said. “Consequently, the financial outlook for 2020 set out in the strategic plan 2020–2024, which also reflects the province’s no-nuclear stance, will be revised downward.”

It’s still too early to determine the scope of the revision, the company said in its quarterly report. Hydro-Québec was targeting net income of between $2.8 billion and $3 billion in 2020, according to its strategic plan.

The first quarter was the utility’s last under Martel, who quit to take over at jetmaker Bombardier Inc. Quebec appointed former Énergir CEO Sophie Brochu to replace him, effective April 6.

First-quarter results “weren’t significantly affected” by the pandemic, Lafleur said on a conference call with reporters. Electricity sales generated $294 million less than a year ago due primarily to milder temperatures, he said.

Results will start to reflect COVID-19’s impact in the second quarter, though NB Power has signed three deals to bring more Quebec electricity into the province that could cushion some exports.

Electricity consumption in Quebec has fallen five per cent in the past two months, paced by an 11-per-cent plunge for commercial and institutional clients, and cities such as Ottawa saw a demand plunge during closures.

Industrial customers such as pulp and paper producers have also curbed power use, and it’s hard to see demand rebounding this year, Lafleur said.

“What we’ve lost since the start of the pandemic is not coming back,” he said.

Demand on export markets, meanwhile, has shrunk between six per cent and nine per cent since mid-March. The drop has been particularly steep in Ontario, reaching as much as 12 per cent, after the province chose not to renew its electricity deal with Quebec earlier this year, compared with declines of up to five per cent in New England and eight per cent in New York.

Spot prices in the U.S. have retreated in tandem, falling this week to as low as 1.5 U.S. cents per kilowatt-hour, Lafleur said. Hydro-Québec’s hedging strategy — which involves entering into fixed-price sales contracts about a year ahead of time — allowed the company to export power for an average of 4.9 U.S. cents per kilowatt-hour in the first quarter, compared with the 2.2 cents it would have otherwise made.

Investments will decline this year as construction activity proceeds at reduced speed, Lafleur said. Hydro-Québec was initially planning to invest about $4 billion in the province, he said, as it works to increase hydropower capacity to more than 37,000 MW across its fleet.

Physical distancing measures “are having an impact on productivity,” Lafleur said. “We can’t work the way we wanted, and project costs are going to be affected. Anytime we send workers north on a plane, we need to leave an empty seat beside them.”

 

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Saudis set to 'boost wind by over 6GW'

Saudi Arabia Wind Power Market set to lead the Middle East, driven by Vision 2030 renewables goals, REPDO tenders, and PIF backing, adding 6.2GW wind capacity by 2028 alongside solar PV diversification.

 

Key Points

It is the emerging national segment leading Middle East wind growth, targeting 6.2GW by 2028 under Vision 2030 policies.

✅ Adds 6.2GW, 46% of regional wind capacity by 2028

✅ REPDO tenders and PIF funding underpin pipeline

✅ Targets: 16GW wind, 40GW solar under Vision 2030

 

Saudi Arabia will become a regional heavyweight in the Middle East's wind power market adding over 6GW in the next 10 years, according to new research by Wood Mackenzie Power & Renewables.

The report – 'Middle East Wind Power Market Outlook, 2019-2028’ – said developers will build 6.2GW of wind capacity in the country or 46% of the region’s total wind capacity additions between 2019 and 2028.

Wood Mackenzie Power & Renewables senior analyst Sohaib Malik said: “The integration of renewables in Vision 2030’s objectives underlines strong political commitment within Saudi Arabia.

“The level of Saudi ambition for wind and solar PV varies significantly, despite the cost parity between both technologies during the first round of tenders in 2018.”

Saudi Arabia has set a 16GW target for wind by 2030 and 40GW for solar, plans to solicit 60 GW of clean energy over the next decade, Wood Mackenzie added.

“Moving forward, the Renewable Energy Project Development Office will award 850MW of wind capacity in 2019, which is expected to be commissioned in 2021-2022, and increase the local content requirement in future tendering rounds,” Malik said.

However, Saudi Arabia will fall short of its current 2030 renewables target, despite growth projections and regional leadership, the report said.

Some 70% of the renewables capacity target is to be supported by the Public Investment Fund (PIF), the Saudi sovereign wealth fund, while the remaining capacity is to be awarded through REPDO.

“A central concern is the PIF’s lack of track record in the renewables sector and its limited in-house sectoral expertise,” said Malik

“REPDO, on the other hand, completed two renewables request for proposals after pre-developing the sites,” he said.

PIF is estimated to have $230bn of assets – targeted to reach $2 trillion under Vision 2030 – driven by investments in a variety of sectors ranging from electric vehicles to public infrastructure, Wood Mackenzie said.

“There is little doubt about the fund’s financial muscle, however, its past investment strategy focused on established firms in traditional industries,” Malik added.

“Aspirations to develop a value chain for wind and PV technologies locally is a different ball game and requires the PIF to acquire new capabilities for effective oversight of these ventures,” he said.

The report noted that regional volatility is expected to remain, with strong positive growth, driven by Jordan and Iran in 2018 expected to reverse in 2019, and policy shifts, as in Canada’s scaled-back projections, can influence outcomes.

Post-2020 Wood Mackenzie Power & Renewables sees regional demand returning to steady growth as global renewables set more records elsewhere.

“In 2018, developers added 185MW and 63MW of wind capacity in Jordan and Iran, respectively, compared to 53MW of capacity across the entire region in 2017, following a record year for renewables in 2016,” said Malik.

“The completion of the 89MW Al Fujeij and the 86MW Al Rajef projects in 2018 indicates that Jordan has 375MW of the region’s operational 675MW wind capacity.

“Iran followed with 278MW of installed capacity at the end of 2018. A slowdown in 2019 is expected, as project development activity softens in Iran.

“Additionally, delays in awarding the 400MW Dumat Al Jandal project in Saudi Arabia will limit annual capacity additions to 184MW.”

He added that a maturing project pipeline in the region supports the 2020-2021 outlook, even as wind power grew despite Covid-19 globally.

“Saudi Arabian demand serves as the foundation for regional demand. Regional demand diversification is also occurring, with Lebanon set to add 200-400MW to its existing permitted capacity pipeline of 202MW in 2019,” he said

“These developments pave the way for the addition of 2GW of wind capacity between 2019 and 2021.”

Wood Mackenzie Power & Renewables added that the outlook for solar in the region is “much more positive” than wind.

“Compared to only 6GW of wind power capacity, developers will add 53GW of PV capacity through 2024,” said Malik.

He added: “Solar PV, supported by trends such as China’s rapid PV growth in 2016, has become a natural choice for many countries in the region, which is endowed with world class solar energy resources.

“The increased focus on solar energy is demonstrated by ambitious PV targets across the region.”

 

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Power customers in British Columbia, Quebec have faced fees for refusing the installation of smart meters

NB Power Smart Meter Opt-Out Fees reflect cost causation principles set before the Energy and Utilities Board, covering meter reading charges, transmitter-disable options, rollout targets, and education plans across New Brunswick's smart metering program.

 

Key Points

Fees NB Power may apply to customers opting out of smart meters, reflecting cost causation and meter-reading costs.

✅ Based on cost causation and meter reading expenses

✅ BC and Quebec charge monthly opt-out surcharges

✅ Policy finalized during rollout after EUB review

 

NB Power customers who do not want a smart meter installed on their home could be facing a stiff fee for that decision, but so far the utility is not saying how much it might be.  

"It will be based on the principles of cost causation, but we have not gotten into the detail of what that fee would be at this point," said NB Power Senior Vice President of Operations Lori Clark at Energy and Utilities Board hearings on Friday.

In other jurisdictions that have already adopted smart meters, customers not wanting to participate have faced hundreds of dollars in extra charges, while Texas utilities' pullback from smart-home networks shows approaches can differ.

In British Columbia, power customers are charged a meter reading fee of $32.40 per month if they refuse a smart meter, or $20 per month if they accept a smart meter but insist its radio transmitter be turned off. That's a cost of between $240 and $388.80 per year for customers to opt out.

In Quebec, smart meters were installed beginning in 2012. Customers who refused the devices were initially charged $98 to opt out plus a meter reading fee of $17 per month. That was eventually cut by Quebec's energy board in 2014 to a $15 refusal fee and a $5 per month meter reading surcharge.

NB Power said it may be a year or more before it settles on its own fee.

"The opt out policy will be developed and implemented as part of the roll out.  It will be one of the last things we do," said Clark.

 

Customers need to be on board

NB Power is in front of the New Brunswick Energy and Utilities Board seeking permission to spend $122.7 million to install 350,000 smart meters province wide, as neighboring markets grapple with major rate increases that heighten affordability concerns.  

The meters are capable of transmitting consumption data of customers back to NB Power in real time, which the utility said will allow for a number of innovations in pricing and service, and help address old meter inaccuracies that affected some households.

The meters require near universal adoption by customers to maximize their financial benefit — like eliminating more than $20 million a year NB Power currently spends to read meters manually. The utility has said the switch will not succeed if too many customers opt out.

"We certainly wouldn't be looking at making an investment of this size without having the customer with us," said Clark.

On Thursday, Kent County resident Daniel LeBlanc, who along with Roger Richard, is opposing the introduction of smart meters for health reasons, predicted a cool reception for the technology in many parts of the province, given concerns that include health effects and billing disputes in Nova Scotia reported elsewhere.

"If one were to ask most of the people in the rural areas, I'm not sure you would get a lot of takers for this infrastructure," said LeBlanc, who is concerned with the long-term effect microwave frequencies used by the meters to transmit data may have on human health.

That issue is before the EUB next week.

 

Haven't tested the waters

NB Power acknowledged it has not measured public opinion on adopting smart meters but is confident it can convince customers it is a good idea for them and the utility, even as seasonal rate proposals in New Brunswick have prompted consumer backlash.

"People don't understand what the smart meter is," said Clark. "We need to educate our customers first to allow them to make an informed decision so that will be part of the roll out plan."

Clark noted that smart meters, helped by stiff opting out penalties, were eventually accepted by 98 per cent of customers in British Columbia and by 97.4 per cent of customers in Quebec.

"We will check and adjust along the way if there are issues with customer uptake," said Clark.

 

"This is very similar to what has been done in other jurisdictions and they haven't had those challenges."

 

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Washington State Ferries' Hybrid-Electric Upgrade

Washington State Hybrid-Electric Ferries advance green maritime transit with battery-diesel propulsion, lower emissions, and fleet modernization, integrating charging infrastructure and reliable operations across WSF routes to meet climate goals and reduce fuel consumption.

 

Key Points

New WSF vessels using diesel-battery propulsion to cut emissions, improve efficiency, and sustain reliable ferry service.

✅ Hybrid diesel-battery propulsion reduces fuel use and CO2

✅ Larger vessels with efficient batteries and charging upgrades

✅ Compatible with WSF docks, maintenance, and safety standards

 

Washington State is embarking on an ambitious update to its ferry fleet, introducing hybrid-electric boats that represent a significant leap toward greener and more sustainable transportation. The state’s updated plans reflect a commitment to reducing carbon emissions and enhancing environmental stewardship while maintaining the efficiency and reliability of its vital ferry services.

The Washington State Ferries (WSF) system, one of the largest in the world, has long been a critical component of the state’s transportation network, linking various islands and coastal communities with the mainland. Traditionally powered by diesel engines, the ferries are responsible for significant greenhouse gas emissions. In response to growing environmental concerns and legislative pressure, WSF is now turning to hybrid-electric technology similar to battery-electric high-speed ferries seen elsewhere to modernize its fleet and reduce its carbon footprint.

The updated plans for the hybrid-electric boats build on earlier efforts to introduce cleaner technologies into the ferry system. The new designs incorporate advanced hybrid-electric propulsion systems that combine traditional diesel engines with electric batteries. This hybrid approach allows the ferries to operate on electric power during certain segments of their routes, reducing reliance on diesel fuel and cutting emissions as electric ships on the B.C. coast have demonstrated during similar operations.

One of the key features of the updated plans is the inclusion of larger and more capable hybrid-electric ferries, echoing BC Ferries hybrid ships now entering service in the region. These vessels are designed to handle the demanding operational requirements of the Washington State Ferries system while significantly reducing environmental impact. The new boats will be equipped with state-of-the-art battery systems that can store and utilize electric power more efficiently, leading to improved fuel economy and lower overall emissions.

The transition to hybrid-electric ferries is driven by both environmental and economic considerations. On the environmental side, the move aligns with Washington State’s broader goals to combat climate change and reduce greenhouse gas emissions, including programs like electric vehicle rebate program that encourage cleaner travel across the state. The state has set ambitious targets for reducing carbon emissions across various sectors, and upgrading the ferry fleet is a crucial component of achieving these goals.

From an economic perspective, hybrid-electric ferries offer the potential for long-term cost savings. Although the initial investment in new technology can be substantial, with financing models like CIB support for B.C. electric ferries helping spur adoption and reduce barriers for agencies, the reduced fuel consumption and lower maintenance costs associated with hybrid-electric systems are expected to lead to significant savings over the lifespan of the vessels. Additionally, the introduction of greener technology aligns with public expectations for more sustainable transportation options.

The updated plans also emphasize the importance of integrating hybrid-electric technology with existing infrastructure. Washington State Ferries is working to ensure that the new vessels are compatible with current docking facilities and maintenance practices. This involves updating docking systems, as seen with Kootenay Lake electric-ready ferry preparations, to accommodate the specific needs of hybrid-electric ferries and training personnel to handle the new technology.

Public response to the hybrid-electric ferry initiative has been largely positive, with many residents and environmental advocates expressing support for the move towards greener transportation. The new boats are seen as a tangible step toward reducing the environmental impact of one of the state’s most iconic transportation services. The project also highlights Washington State’s commitment to innovation and leadership in sustainable transportation, alongside global examples like Berlin's electric flying ferry that push the envelope in maritime transit.

However, the transition to hybrid-electric ferries is not without its challenges. Implementing new technology requires careful planning and coordination, including addressing potential technical issues and ensuring that the vessels meet all safety and operational standards. Additionally, there may be logistical challenges associated with integrating the new ferries into the existing fleet and managing the transition without disrupting service.

Despite these challenges, the updated plans for hybrid-electric boats represent a significant advancement in Washington State’s efforts to modernize its transportation system. The initiative reflects a growing trend among transportation agencies to embrace sustainable technologies and address the environmental impact of traditional transportation methods.

In summary, Washington State’s updated plans for hybrid-electric ferries mark a crucial step towards a more sustainable and environmentally friendly transportation network. By incorporating advanced hybrid-electric technology, the state aims to reduce carbon emissions, improve fuel efficiency, and align with its broader climate goals. While challenges remain, the initiative demonstrates a commitment to innovation and underscores the importance of transitioning to greener technologies in the quest for a more sustainable future.

 

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Hot Houston summer and cold winter set new electricity records

US Electricity Demand 2018-2050 projects slower growth as energy consumption, power generation, air conditioning, and electric heating shift with efficiency standards, commercial floor space, industrial load, and household growth across the forecast horizon.

 

Key Points

A forecast of US power use across homes, commercial space, industrial load, and efficiency trends from 2018 to 2050.

✅ 2018 generation hit record; residential sales up 6%.

✅ Efficiency curbs demand; growth lags population and floor space.

✅ Commercial sales up 2%; industrial demand fell 3% in 2018.

 

Last year's Houston cold winter and hot summer drove power use to record levels, especially among households that rely on electricity for air conditioning during extreme weather conditions.

Electricity generation increased 4 per cent nationwide in 2018 and produced 4,178 million megawatt hours, driven in part by record natural gas generation across the U.S., surpassing the previous peak of 4,157 megawatt hours set in 2007, the Energy Department reported.

U.S. households bought 6 percent more electricity in 2018 than they did the previous year, despite longer-term declines in national consumption, reflecting the fact 87 percent of households cool their homes with air conditioning and 35 percent use electricity for heating.

Electricity sales to the commercial sector increased 2 percent in 2018 compared to the previous year while the industrial sector bought 3 percent less last year.

Going forward, the Energy Department forecasts that electricity consumption will grow at a slower pace than in recent decades, aligning with falling sales projections as technology improves and energy efficiency standards moderate consumption.

The economy and population growth are primary drivers of demand and the government predicts the number of households will grow at 0.7 percent per year from now until 2050 but electricity demand will grow only by 0.4 percent annually.

Likewise, commercial floor space is expected to increase 1 percent per year from now until 2050 but electricity sales will increase only by half that amount.

Globally, surging electricity demand is putting power systems under strain, providing context for these domestic trends.

 

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