Nuclear planning to the year 1,002,008

By Reuters


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Will this barren mountain rising up to 4,950 feet from the Mojave desert look roughly the same in the year 1,002,008? ThatÂ’s a million years into the future.

The question may sound bizarre but its answer is key to the future of a decades-old, controversial project to store America’s nuclear waste in the belly of Yucca Mountain, on the edge of a nuclear test site and 95 miles from Las Vegas. The narrow road from there winds through a desolate landscape of sparse vegetation — creosote scrub, cactus and gnarled Joshua trees.

“This is probably the world’s most intensely studied mountain,” says Michael Voegele, one of the senior engineers on the project, standing beside the “Yucca Mucker”, a 720-ton cylinder-shaped machine that has drilled a five-mile tunnel into the mountain. “And yet, there will be even more study.”

Indeed. In September, the U.S. Environmental Protection Agency (EPA) revised its original safety standards for what would be the worldÂ’s first deep underground nuclear mausoleum. Those standards were meant to protect the health of people living near Yucca Mountain for 10,000 years from the time the mountain is filled with 70,000 tons of radioactive nuclear waste.

Ten thousand years is roughly twice mankind’s recorded history. But a court in Washington ruled in 2004 that protection should reach farther into the future. The new standards “will protect public health and the environment for 1 million years,” according to the EPA. “The Yucca Mountain facility will open only if it meets EPA’s standards….”

The standards specify that for the first 10,000 years, future residents should not be exposed to more than 15 millirem of radioactivity per year. From year 10,001 to one million, the dose limit is now set at 100 millirem a year.

To put those limits into context: Princeton University estimates that the average American is exposed to 350 millirems per year, from sources that range from X-rays to food. Bananas, for example. (They contain potassium and a radioactive potassium isotope. Eating one or two a day adds up to the radioactivity of a chest x-ray a year).

So is a U.S. government agency engaging in scientific fantasy that sets impossible hurdles to building up nuclear power?

“Our fundamental problem is our strict adherence to this number which is given to us by the EPA,” Allison Macfarlane, one of America’s leading experts on the Yucca Mountain project told a panel on nuclear waste in Washington a few days after the U.S. election. (America’s energy mix and the country’s dependence on foreign oil were major campaign topics.)

“This… number created these huge machinations of making incredibly complex computer models, simulations of what will happen at Yucca Mountain over time. And you know what? Those models are meaningless. We’ve set up this process where we want to say a million years from now we know that Yucca Mountain won’t give anyone a dose of more than 100 millirems a year. And we can’t know that. So we need to rethink that whole process of how we re-evaluate that site.”

Like many other experts, Macfarlane does not consider Yucca Mountain an ideal site for a nuclear cemetery. It is in a seismically active zone, complete with extinct volcanoes. Critics say an earthquake could damage the canisters in which nuclear waste will be kept and release highly toxic radioactive emissions.

Up on the mountain, that prospect is not rated probable. Says Voegele, pointing to large boulders that look as if they are balancing on the ridge: “There’s been no quake strong enough in the past 500,000 years to topple them over. Difficult to see how a quake could shake the mountain.”

At the dawn of the nuclear age, scientists discussed a range of options for the storage of the nuclear waste that began piling up from the military — much of the U.S. naval fleet is powered by nuclear reactors — and civilian power plants. They included burying the material in the ocean floor, placing it in polar ice sheets, and even blasting it into space.

No country has completely solved the problem but there is consensus that “deep geological disposal” is a better option than the present system of storing the waste in above-the-ground containers. In the U.S., radioactive waste is kept at 121 sites in 39 states, all awaiting eventual storage inside the mountain here.

Whether that will ever happen is not clear. Apart from technical considerations, Yucca Mountain faces fierce political opposition, not least from president-elect Barack Obama who has described the project as a multi-billion-dollar mistake and said no U.S. state should be “unfairly burdened with waste from other states.”

That came during the election campaign in a letter to a newspaper in Nevada, a fiercely contested state whose people are almost uniformly opposed to Yucca Mountain.

ObamaÂ’s encouragement of an attitude also known as Nimbyism (from Not in My Backyard) helped him beat his pro-Yucca, pro-nuclear energy Republican rival John McCain.

But the project, based on legislation dating back to 1982, canÂ’t be stopped by presidential fiat. The U.S. Department of Energy submitted an application to the Nuclear Regulatory Commission in September to license Yucca Mountain. That process is expected to last three to four years and includes passing judgment on the one-million-year safety standard.

If all goes well, the facility will open in 2020 at the earliest, more than 20 years behind schedule — a blink of an eye on the geological time scale.

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Yukon receives funding for new wind turbines

Yukon Renewable Energy Funding backs wind turbines, grid-scale battery storage, and transmission line upgrades, cutting diesel dependence, lowering greenhouse gas emissions, and strengthening Yukon Energy's isolated grid for remote communities, local jobs, and future growth.

 

Key Points

Federal support for Yukon projects adding wind, battery storage, and grid upgrades to cut diesel use and emissions.

✅ Three 100 kW wind turbines will power Destruction Bay.

✅ 8 MW battery storage smooths peaks and reduces diesel.

✅ Mayo-McQuesten 138 kV line upgrade boosts reliability.

 

Kluane First Nation in Yukon will receive a total of $3.1 million in funding from the federal government to install and operate wind turbines that will help reduce the community’s diesel reliance.

According to a release, the community will integrate three 100-kilowatt turbines in Destruction Bay, Yukon, providing a renewable energy source for their local power grid that will reduce greenhouse gas emissions and create local jobs in the community.

A $2-million investment from Natural Resources Canada came from the Clean Energy for Rural and Remote Communities Program, part of the Government of Canada’s Investing in Canada infrastructure plan, which supports green energy solutions across jurisdictions. Crown-Indigenous Relations’ and Northern Affairs Canada also contributed a $1.1-million investment from the Northern REACHE Program.

Also, the Government of Canada announced more than $39.2 million in funding for two Yukon Energy projects that will increase the reliability of Yukon’s electrical grid, including exploration of a potential connection to the B.C. grid to bolster resiliency, and help build the robust energy system needed to support future growth. The investment comes from the government’s Green Infrastructure Stream (GIS) of the Investing in Canada infrastructure plan.

 

Project 1: Grid-scale battery storage

The federal government is investing $16.5 million in Yukon Energy’s construction of a new battery storage system in Yukon. Once completed, the 8 MW battery will be the largest grid-connected battery in the North, and one of the largest in Canada, alongside major Ontario battery projects underway.

The new battery is a critical investment in Yukon Energy’s ability to meet growing demands for power and securing Yukon’s energy future. As an isolated grid, one of the largest challenges Yukon Energy faces is meeting peak demands for power during winter months, as electrification grows with EV adoption in the N.W.T. and beyond.

When complete, the new system will store excess electricity generated during off-peak periods, complementing emerging vehicle-to-grid integration approaches, and provide Yukoners with access to more power during peak periods. This new energy storage system will create a more reliable power supply and help reduce the territory’s reliance on diesel fuel. Over the 20-year life of project, the new battery is expected to reduce carbon emissions in Yukon by more than 20,000 tonnes.

A location for the new battery energy storage system has not been identified. Yukon Energy will begin permitting of the project in 2020 with construction targeted to be complete by mid-2023.

 

Project 2: Replacing and upgrading the Mayo to McQuesten Transmission Line

Yukon Energy has received $22.7 million in federal funding to proceed with Stage 1 of the Stewart to Keno City Transmission Project – replacing and upgrading the 65 year-old transmission line between Mayo and McQuesten. The project also includes the addition of system protection equipment at the Stewart Crossing South substation. The Yukon government, through the Yukon Development Corporation, has already provided $3.5 million towards planning for the project.

Replacing the Mayo to McQuesten transmission line is critical to Yukon Energy’s ability to deliver safe and reliable electricity to customers in the Mayo and Keno regions, mirroring broader regional transmission initiatives that enhance grid resilience, and to support economic growth in Yukon. The transmission line has reached end-of-life and become increasingly unreliable for customers in the area.

The First Nation of Na-Cho Nyak Dun has expressed their support of this project. The project has also been approved by the Yukon Environmental and Socio-Economic Assessment Board.

Yukon Energy will begin replacing and upgrading the 31 km transmission line between Mayo and McQuesten in 2020. Construction is expected to be complete in late 2020. When finished, the new 138 kV transmission line will provide more reliable electricity to customers in the Mayo and Keno regions and be equipped to support industrial growth and development in the area, including the Victoria Gold Mine, with renewable power from the Yukon grid.

Planning work for the remainder of the Stewart to Keno City Transmission Project has been completed. Yukon Energy continues to explore funding opportunities that are needed to proceed with other stages of the project.

 

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Berlin Geothermal Plant in El Salvador Set to Launch This Year

El Salvador Geothermal Expansion boosts renewable energy with a 7 MW Berlin binary ORC plant, upgrades at Ahuachapan, and pipeline projects, strengthening clean power capacity, grid reliability, and sustainable growth in Central America.

 

Key Points

A national push adding binary-cycle capacity at Berlin and Ahuachapan, boosting geothermal supply and advancing sites.

✅ 7 MW Berlin binary ORC plant entering service.

✅ Ahuachapan upgrade adds 2 MW, total geothermal 204 MW.

✅ Next: Chinameca, San Miguel, San Vicente, World Bank backed.

 

El Salvador is set to expand its renewable energy capacity with the inauguration of the 7-MW Berlin binary geothermal power plant, slated to go online later this year. This new addition marks a significant milestone in the country’s geothermal energy development, highlighting its commitment to sustainable energy solutions. The plant, which has already been installed and is currently undergoing testing, is expected to boost the nation’s geothermal capacity, contributing to its growing renewable energy portfolio.

The Role of Geothermal Energy in El Salvador’s Energy Mix

Geothermal energy plays a pivotal role in El Salvador's energy landscape. With the combined output from the Ahuachapan and Berlin geothermal plants, geothermal energy now accounts for about 21% of the country's net electricity supply. This makes geothermal the second-largest source of energy generation in El Salvador, underscoring its importance as a reliable and sustainable energy resource alongside emerging options like advanced nuclear microreactor technologies in the broader low-carbon mix.

In addition to the Berlin plant, El Salvador has made significant improvements to its Ahuachapan geothermal power plant. Recent upgrades have increased its generation capacity by 2 MW, further enhancing the country’s geothermal energy output. Together, the Ahuachapan and Berlin plants bring the total installed geothermal capacity to 204 MW, positioning El Salvador as a regional leader in geothermal energy development.

The Berlin Binary Geothermal Plant: A Technological Milestone

The Berlin binary geothermal power plant is especially noteworthy for several reasons. It is the first geothermal power plant to be constructed in El Salvador since 2007, marking a significant step in the country's ongoing efforts to expand its renewable energy infrastructure while reinforcing attention to risk management in light of Hawaii geothermal safety concerns reported elsewhere. The plant utilizes a binary cycle geothermal system, which is known for its efficiency in extracting energy from lower temperature geothermal resources, making it an ideal solution for regions like Berlin, where geothermal resources are abundant but at lower temperatures.

The plant was built by Turboden, an Italian company specializing in organic Rankine cycle (ORC) technology. The binary cycle system operates by transferring heat from the geothermal fluid to a secondary fluid, which then drives a turbine to generate electricity. This system allows for the efficient use of geothermal resources that might otherwise be too low in temperature for traditional geothermal plants, enabling pairing with thermal storage demonstration solutions to optimize output.

Future Geothermal Developments in El Salvador

El Salvador is not stopping with the Berlin geothermal plant. The country is actively working on other geothermal projects, including those in Chinameca, San Miguel, and San Vicente. These developments are expected to add 50 MW of additional capacity in their first phase, reflecting a broader shift as countries pursue hydrogen-ready power plants to reduce emissions, with a second phase, supported by the World Bank, planned to add another 100 MW.

The Chinameca, San Miguel, and San Vicente projects represent the next wave of geothermal development in El Salvador. When completed, these plants will significantly increase the country’s geothermal capacity, further diversifying its energy mix and reducing reliance on fossil fuels, and will require ongoing grid upgrades, a task complicated elsewhere by Germany grid expansion challenges highlighted in Europe.

International Support and Collaboration

El Salvador’s geothermal development efforts are supported by various international partners, including the World Bank, which has been instrumental in financing the expansion of geothermal projects, as utilities such as SaskPower geothermal plans in Canada explore comparable pathways. This collaboration highlights the global recognition of El Salvador’s potential in geothermal energy and its efforts to position itself as a hub for geothermal energy development in Central America.

Additionally, the country’s expertise in geothermal energy, especially in binary cycle technology, has attracted international attention. El Salvador’s progress in the geothermal sector could serve as a model for other countries in the region that are looking to harness their geothermal resources to reduce energy costs and promote sustainable energy development.

The upcoming launch of the Berlin binary geothermal power plant is a testament to El Salvador’s commitment to sustainable energy. As the country continues to expand its geothermal capacity, it is positioning itself as a leader in renewable energy in the region. The binary cycle technology employed at the Berlin plant not only enhances energy efficiency but also demonstrates El Salvador’s ability to adapt and innovate within the renewable energy sector.

With the continued development of projects in Chinameca, San Miguel, and San Vicente, and ongoing international collaboration, El Salvador’s geothermal energy sector is set to play a crucial role in the country’s energy future. As global demand for clean energy grows, exemplified by U.S. solar capacity additions this year, El Salvador’s investments in geothermal energy are helping to build a more sustainable, resilient, and energy-independent future.

 

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Operating record for Bruce Power as Covid-19 support Council announced

Bruce Power Life-Extension Programme advances Ontario nuclear capacity through CANDU Major Component Replacement, reliable operation milestones, supply chain retooling for COVID-19 recovery, PPE production, ventilator projects, and medical isotope supply security.

 

Key Points

A program to refurbish CANDU reactors, extend asset life, and mobilize Ontario nuclear supply chain and isotopes.

✅ Extends CANDU units via Major Component Replacement

✅ Supports COVID-19 recovery with PPE and ventilator projects

✅ Boosts Ontario energy reliability and medical isotopes

 

Canada’s Bruce Power said on 1 May that unit 1 at the Bruce nuclear power plant had set a record of 624 consecutive days of reliable operation – the longest since it was returned to service in 2012.

It exceeded Bruce 8’s run of 623 consecutive days between May 2016 and February 2018. Bruce 1, a Candu reactor, was put into service in 1977. It was shut down and mothballed by the former Ontario Hydro in 1997, and was refurbished and returned to service in 2012 by Bruce Power.

Bruce units 3 and 4 were restarted in 2003 and 2004. They are part of Bruce Power’s Life-Extension Programme, and future planning such as Bruce C project exploration continues across the fleet, with units 3 and 4 to undergo Major Component Replacement (MCR) Projects from 2023-28, adding about 30 years of life to the reactors.

The refurbishment of Bruce 6 has begun and will be followed by MCR Unit 3 which is scheduled to begin in 2023. Nuclear power accounts for more than 60% of Ontario’s supply, with Bruce Power providing more than 30%   of the province’s electricity.

Set up of Covid recovery council
On 30 April, Bruce Power announced the establishment of the Bruce Power Retooling and Economic Recovery Council to leverage the province’s nuclear supply chain to support Ontario’s fight against Covid-19 and to help aid economic recovery.

Bruce Power’s life extension programme is Canada’s second largest infrastructure project and largest private sector infrastructure programme. It is creating 22,000 direct and indirect jobs, delivering economic benefits that are expected to contribute $4 billion to Ontario’s GDP and $8-$11 billion to Canada’s gross domestic product (GDP), Bruce Power said.

“With 90% of the investment in manufactured goods and services coming from 480 companies in Ontario and other provinces, including recent manufacturing contracts with key suppliers, we can harness these capabilities in the fight against Covid-19, and help drive our economic recovery,” the company said.

“An innovative and dynamic nuclear supply chain is more important than ever in meeting this new challenge while successfully implementing our mission of providing clean, reliable, flexible, low-cost nuclear energy and a global supply of medical isotopes,” said Bruce Power president and CEO Mike Rencheck. “We are mobilising a great team with our extended supply chain, which spans the province, to assist in the fight against Covid-19 and to help drive our economic recovery in the future.”

Greg Rickford, the Minister of Energy, Mines, Northern Development, and Minister of Indigenous Affairs, said the launch of the council is consistent with Ontario’s focus to fight Covid-19 as a top priority and a look ahead to economic recovery, and initiatives like Pickering life extensions supporting long-term system reliability.

The creation of the Council was announced during a live event on Bruce Power's Facebook page, in which Rencheck was joined by Associate Minister of Energy Bill Walker and Rocco Rossi, the president and CEO of the Ontario Chamber of Commerce.

Walker reiterated the Government of Ontario’s commitment to nuclear power over the long term and to the life extension programme, including the Pickering B refurbishment as part of this strategy.

The Council, which will be formed for the duration of the pandemic and will include of all of Bruce Power’s Ontario-based suppliers, will focus on the continued retooling of the supply chain to meet front-line Covid-19 needs to contribute to the province’s economy recovery in the short, medium and long term.

New uses for nuclear medical applications will be explored, including isotopes for the sterilisation of medical equipment and long-term supply security.

The supply chain will be leveraged to support the health care sector through the rapid production of medical Personal Protection Equipment for front line-workers and large-scale PPE donations to communities as well as participation in pilot projects to make ventilators within the Bruce Power supply chain or help identify technology to better utilise existing ventilators;

“Buy Local” tools and approaches will be emphasised to ensure small businesses are utilised fully in communities where nuclear suppliers are located.

The production of hand sanitiser and other cleaning products will be facilitated for distribution to communities.

 

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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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First Nuclear Reactors Built in 30 Years Take Shape at Georgia Power Plant

Vogtle Units 3 and 4 are Westinghouse AP1000 nuclear reactors under construction in Waynesboro, Georgia, led by Southern Nuclear, Georgia Power, and Bechtel, adding 2,234 MWe of carbon-free baseload power with DOE loan guarantees.

 

Key Points

Vogtle Units 3 and 4 are AP1000 reactors in Georgia delivering 2,234 MWe of low-carbon baseload electricity.

✅ Each unit: Westinghouse AP1000, 1,117 MWe capacity.

✅ Managed by Southern Nuclear, built by Bechtel.

✅ DOE loan guarantees support financing and risk.

 

Construction is ongoing for two new nuclear reactors, Units 3 and 4, at Georgia Power's Alvin W. Vogtle Electric Generating Plant in Waynesboro, Ga. the first new nuclear reactors to be constructed in the United Stated in 30 years, mirroring a new U.S. reactor startup that will provide electricity to more than 500,000 homes and businesses once operational.

Construction on Unit 3 started in March 2013 with an expected completion date of November 2021. For Unit 4, work began in November 2013 with a targeted delivery date of November 2022. Each unit houses a Westinghouse AP1000 (Advanced Passive) nuclear reactor that can generate about 1,117 megawatts (MWe). The reactor pressure vessels and steam generators are from Doosan, a South Korean firm.

The pouring of concrete was delayed to 2013 due to the United States Nuclear Regulatory Commission issuing a license amendment which permitted the use of higher-strength concrete for the foundations of the reactors, eliminating the need to make additional modifications to reinforcing steel bar.

The work is occurring in the middle of an operational nuclear facility, and the construction area contains many cranes and storage areas for the prefabricated parts being installed. Space also is needed for various trucks making deliveries, especially concrete.

The reactor buildings, circular in shape, are several hundred feet apart from one another and each one has an annex building and a turbine island structure. The estimated total price for the project is expected in the $18.7 billion range. Bechtel Corporation, which built Units 1 and 2, was brought in January 2017 to take over the construction that is being overseen by Southern Nuclear Operating Company (SNOC), which operates the plant.

The project will require the equivalent of 3,375 miles of sidewalk; the towers for Units 3 and 4 are 60 stories high and have two million pound CA modules; the office space for both units is 300,000 sq. ft.; and there are more than 8,000 construction workers over 30 percent being military veterans. The new reactors will create 800 permanent jobs.

Southern Nuclear and Georgia Power took over management of the construction project in 2017 after Westinghouse's Chapter 11 bankruptcy. The plant, built in the late 1980s with Unit 1 becoming operational in 1987 and Unit 2 in 1989, is jointly owned by Georgia Power (45.7 percent), Oglethorpe Power Corporation (30 percent), Municipal Electric Authority of Georgia (22.7 percent) and Dalton Utilities (1.6 percent).

"Significant progress has been made on the construction of Vogtle 3 and 4 since the transition to Southern Nuclear following the Westinghouse bankruptcy," said Paul Bowers, Chairman, President and CEO of Georgia Power. "While there will always be challenges in building the first new nuclear units in this country in more than 30 years, we remain focused on reducing project risk and maintaining the current project momentum in order to provide our customers with a new carbon-free energy source that will put downward pressure on rates for 60 to 80 years."

The Vogtle and Hatch nuclear plants currently provide more than 20 percent of Georgia's annual electricity needs. Vogtle will be the only four-unit nuclear facility in the country. The energy is needed to meet the rising demand for electricity as the state expects to have more than four million new residents by 2030.

The plant's expansion is the largest ongoing construction project in Georgia and one of the largest in the state's history, while comparable refurbishments such as the Bruce reactor overhaul progress in Canada. Last March an agreement was signed to secure approximately $1.67 billion in additional Department of Energy loan guarantees. Georgia Power previously secured loan guarantees of $3.46 billion.

The signing highlighted the placement of the top of the containment vessel for Unit 3, echoing the Hinkley Point C roof lift seen in the U.K., which signified that all modules and large components had been placed inside it. The containment vessel is a high-integrity steel structure that houses critical plant components. The top head is 130 ft. in diameter, 37 ft. tall, and weighs nearly 1.5 million lbs. It is comprised of 58 large plates, welded together with each more than 1.5 in. thick.

"From the very beginning, public and private partners have stood with us," said Southern Company Chairman, President and CEO Tom Fanning. "Everyone involved in the project remains focused on sustaining our momentum."

Bechtel has completed more than 80 percent of the project, and the major milestones for 2019 have been met, aligning with global nuclear milestones reported across the industry, including setting the Unit 4 pressurizer inside the containment vessel last February, which will provide pressure control inside the reactor coolant system. More specialized construction workers, including craft labor, have been hired via the addition of approximately 300 pipefitters and 350 electricians since November 2018. Another 500 to 1,000 craft workers have been more recently brought in.

A key accomplishment occurred last December when 1,300 cu. yds. of concrete were poured inside the Unit 4 containment vessel during a 21-hour operation that involved more than 100 workers and more than 120 truckloads of concrete. In 2018 alone, more than 23,000 cu. yds. of concrete were poured part of the nearly 600,000 cu. yds. placed since construction started, and the installation of more than 16,200 yds. of piping.

Progress also has been solid for Unit 3. Last January the integrated head package (IHP) was set inside the containment vessel. The IHP, weighing 475,000 lbs. and standing 48 ft. tall, combines several separate components in one assembly and allows the rapid removal of the reactor vessel head during a refueling outage. One month earlier, the placement of the third and final ring for containment vessel, and the placement of the fourth and final reactor coolant pump (RCP, 375,000 lbs.), were executed.

"Weighing just under 2 million pounds, approximately 38 feet high and with a diameter of 130 feet, the ring is the fourth of five sections that make up the containment vessel," stated a Georgia Power press release. "The RCPs are mounted to the steam generator and serve a critical part of the reactor coolant system, circulating water from the steam generator to the reactor vessel, allowing sufficient heat transfer for safe plant operation. In the same month, the Unit 3 shield building with additional double-decker panels, was placed.

According to a construction update from Georgia Power, a total of eight six-panel sections have been placed, with each one measuring 20 ft. tall and 114 ft. wide, weighing up to 300,000 lbs. To date, more than half of the shield building panels have been placed for Unit 3. The shield building panels, fabricated in Newport News, Va., provide structural support to the containment cooling water supply and protect the containment vessel, which houses the reactor vessel.

Building the reactors is challenging due to the design, reflecting lessons from advanced reactors now being deployed. Unit 3 will have 157 fuel assemblies, with each being a little over 14 ft. long. They are crucial to fuelling the reactor, and once the initial fueling is completed, nearly one-third of the fuel assemblies will be replaced for each re-fuelling operation. In addition to the Unit 3 containment top, placement crews installed three low-pressure turbine rotors and the generator rotor inside the unit's turbine building.

Last November, major systems testing got underway at Unit 3 as the site continues to transition from construction toward system operations. The Open Vessel Testing will demonstrate how water flows from the key safety systems into the reactor vessel ensuring the paths are not blocked or constricted.

"This is a significant step on our path towards operations," said Glen Chick, Vogtle 3 & 4 construction executive vice president. "[This] will prepare the unit for cold hydro testing and hot functional testing next year both critical tests required ahead of initial fuel load."

It also confirms that the pumps, motors, valves, pipes and other components function as designed, a reminder of how issues like the South Carolina plant leak can disrupt operations when systems falter.

"It follows the Integrated Flush process, which began in August, to push water through system piping and mechanical components that feed into the Unit 3 reactor vessel and reactor coolant loops for the first time," stated a press release. "Significant progress continues ... including the placement of the final reinforced concrete portion of the Unit 4 shield building. The 148-cubic yard placement took eight hours to complete and, once cured, allows for the placement of the first course of double-decker panels. Also, the upper inner casing for the Unit 3 high-pressure turbine has been placed, signifying the completion of the centerline alignment, which will mean minimal vibration and less stress on the rotors during operations, resulting in more efficient power generation."

The turbine rotors, each weighing approximately 200 tons and rotating at 1,800 revolutions per-minute, pass steam through the turbine blades to power the generator.

The placement of the middle containment vessel ring for Unit 4 was completed in early July. This required several cranes to work in tandem as the 51-ft. tall ring weighed 2.4 million lbs. and had dozens of individual steel plates that were fabricated on site.

A key part of the construction progress was made in late July with the order of the first nuclear fuel load for Unit 3, which consists of 157 fuel assemblies with each measuring 14 ft. tall.

On May 7, Unit 3 was energized (permanently powered), which was essential to perform the testing for the unit. Prior to this, the plant equipment had been running on temporary construction power.

"[This] is a major first step in transitioning the project from construction toward system operations," Chick said.

Construction of the north side of the Unit 3 Auxiliary Building (AB) has progressed with both the floor and roof modules being set. Substantial work also occurred on the steel and concrete that forms the remaining walls and the north AB roof at elevation.

 

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Alberta Carbon tax is gone, but consumer price cap on electricity will remain

Alberta Electricity Rate Cap stays despite carbon tax repeal, keeping the Regulated Rate Option at 6.8 cents/kWh. Levy funds cover market gaps as the UCP reviews NDP policies to maintain affordable utility bills.

 

Key Points

Program capping RRO power at 6.8 cents/kWh, using levy funds to offset market prices while the UCP reviews policy.

✅ RRO cap fixed at 6.8 cents/kWh for eligible customers

✅ Levy funds pay generators when market prices exceed the cap

✅ UCP reviewing NDP policies to ensure affordable rates

 

Alberta's carbon tax has been cancelled, but a consumer price cap on electricity — which the levy pays for — is staying in place for now.

June electricity rates are due out on Monday, about four days after the new UCP government did away with the carbon charge on natural gas and vehicle fuel.

Part of the levy's revenue was earmarked by the previous NDP government to keep power prices at or below 6.8 cents per kilowatt hour under new electricity rules set by the province.

"The Regulated Rate Option cap of 6.8 cents/kWh was implemented by the previous government and currently remains in effect. We are reviewing all policies put in place by the former government and will make decisions that ensure more affordable electricity rates for job-creators and Albertans," said a spokesperson for Alberta's energy ministry in an emailed statement.

Albertans with regulated rate contracts and all City of Medicine Hat utility customers only pay that amount or less, though some Alberta ratepayers have faced deferral-related arrears.

If the actual market price rises above that, the difference is paid to generators directly from levy funds, a buffer that matters as experts warn prices are set to soar later this year.

The government has paid more than $55 million to utilities over the past year ending in March 2019, due to that electricity price cap being in place.

Alberta Energy says the price gap program will continue, at least for the time being, amid electricity policy changes being considered.

 

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