GREENWASHING

EDF secures 'green' financing for extended operation of reactors

French utility EDF has signed green bank loans for a total amount of about EUR5.8 billion (USD6.3 billion), which will be used to finance the life extension of its existing nuclear power plant fleet in France.

The Tricastin plant comprises four 900 MWe PWRs (Image: EDF/Toma/M Hake)

The loans - which have maturities of between 3 and 5 years - have been arranged with major international banks, including BNP Paribas, Bank of America, Crédit Agricole CIB, ING, Natixis CIB, Société Générale and Wells Fargo.

EDF announced its Grand Carénage life extension programme for the existing fleet in France in 2011. Under this investment programme, the company planned to spend around EUR55 billion by 2025 on upgrading its plants to improve their performance and enable their continued operation beyond 40 years. The programme also includes safety upgrades in response to the Fukushima Daiichi accident in Japan.

The investment was optimised and revised to EUR45 billion in 2018, and in 2020 EDF adjusted the programme's cost to EUR49.4 billion.

A green bilateral loan worth EUR1 billion was announced by EDF and Credit Agricole CIB in November 2022.

EDF noted that the investments in the extension of the operation of its reactors "are aligned with the European taxonomy".

In July 2022, the European Parliament voted to include certain nuclear and gas activities within the European Union's list of officially approved "green" investments.

In February 2021, the country's nuclear safety regulator, the Autorité de Sûreté Nucléaire (ASN), set the conditions for the continued operation of EDF's 900 MWe reactors beyond 40 years. The regulator said it considered the measures planned by EDF combined with those prescribed by ASN will ensure the safety of the units for a further 10 years of operation.

In August 2023, unit 1 of the Tricastin nuclear power plant in southern France became the first French power reactor licensed to operate beyond 40 years.

EDF operates three pressurised water reactor designs, known as the 900 MWe, the 1300 MWe and the 1450 MWe N4. Its 32 operating 900 MWe reactors came into commercial operation between 1977 and 1988, and include the oldest of the country's current nuclear fleet. Such reactors are in operation at EDF's Blayais, Bugey, Chinon, Cruas-Meysse, Dampierre, Gravelines, Saint-Laurent and Tricastin nuclear power plants.

ASN said the improvements and measures will be applied to each reactor individually during their fourth periodic safety reviews, scheduled to run until 2031. These reviews will take the particularities of each facility into account, it said. The measures planned by EDF for each reactor will be subject to a public inquiry.

13 May 2024

Authorisation issued for Flamanville EPR commissioning

08 May 2024

France's nuclear regulator has authorised the commissioning of the Flamanville EPR reactor, which has a summer 2024 target for connection to the grid.

Flamanville (Image: Screengrab from EDF/Youtube)

The authorisation from the Autorité de Sûreté Nucléaire (ASN) means EDF can now load nuclear fuel into the reactor and carry out start-up tests and then operation of the reactor. Within hours of the authorisation being announced EDF said it had begun to load nuclear fuel assemblies into the reactor vessel - adding that it would take several days to load the 241 fuel assemblies.

The ASN decision follows a public consultation which ran from 27 March until 17 April.

ASN issued technical requirements alongside the authorisation saying it would supervise the performance and monitoring of installation start-up tests after fuel loading and also specify methods for acting on feedback from other EPR-type reactors around the world. The first EPR units came online at Taishan in China, where unit 1 became the first EPR to enter commercial operation in 2018 followed by Taishan 2 in September 2019. In Europe, Olkiluoto 3 in Finland entered commercial operation in 2023 and two units are under construction at Hinkley Point C in the UK.

Construction work began in December 2007 on the 1650 MWe unit at the Flamanville site in Normandy - where two reactors have been operating since 1986 and 1987. The dome of the reactor building was put in place in July 2013 and the reactor vessel was installed in January 2014. The reactor was originally expected to start commercial operation in 2013. In December 2022 the total cost at completion of the project was estimated by EDF to be EUR13.2 billion (USD14.2 billion).

China and France aim to strengthen nuclear energy cooperation

09 May 2024

China's CGN and France's EDF have signed a Letter of Intent on deepening and expanding cooperation on nuclear energy - it came as President Emmanuel Macron hosted a visit to France by Chinese President Xi Jinping.

(Image: China Xinhua News/X)

Acording to the Chinese Foreign Ministry report on the talks, President Xi said the two countries should step up cooperation in a number of areas, including "nuclear energy, innovation and finance", with President Macron responding that France was "ready to step up cooperation with China" in areas including "nuclear energy for civilian use".

During the visit there were a number of business cooperation agreements outlined, with the Letter of Intent on Deepening Related Cooperation in the Nuclear Energy Field signed by Yang Changli, Chairman of China General Nuclear (CGN), and EDF Chairman and CEO Luc Raymond.

According to CGN the letter of intent means "the two parties will further expand and strengthen cooperation in aspects such as nuclear power engineering construction, talent training, EPR operations and leadership training in the field of nuclear power operations to achieve common development".

CGN and EDF have worked together over many years, dating back to the Daya Bay nuclear power plant's construction, which began in the 1980s, and CGN said that deepening and expanding cooperation areas "is of great significance to the development of civil nuclear energy in both countries and the business development of the two groups".

China and France are two of the world's biggest generators of nuclear energy, with both having large-scale plans to expand capacity in the coming years. According to World Nuclear Association figures, both countries currently have 56 operable reactors. China's have a capacity of 54 GW and it has 27 more reactors under construction which would provide 28.9 GW more capacity. France currently has 61 GW nuclear energy capacity, with one more 1.6 GW reactor under construction. 

Researched and written by World Nuclear News

UK

In Pictures: Hinkley Point C receives heaviest delivery yet

13 May 2024

The first of eight steam generators manufactured by Framatome in France has been delivered to the Hinkley Point C construction site in Somerset, England.

The steam generator making its final approach to Hinkley Point C (Image: EDF Energy)

Measuring 25 metres in length and weighing 520 tonnes, the steam generator was transported by sea and road. The component travelled the final four miles by road transporter after arriving from Avonmouth at Combwich Wharf on the River Parrett in Somerset.

The steam generator travelling by barge to Combwich Wharf (Image: EDF Energy)

"The generator's arrival is in time for the fit-out of the new power station, which will see the first nuclear reactor installed later this year," EDF Energy said.

The steam generator getting ready to leave Combwich Wharf (Image: EDF Energy)

(Image: EDF Energy)
The first of two 13-metre, 500-tonne reactor pressure vessels for Hinkley Point C - which was built by Framatome at its Le Creusot facility in Burgundy, central France - was delivered to the site in February 2023.

Construction of Hinkley Point C - composed of two EPR reactors of 1630 MWe each - began in December 2018, with unit 1 of the plant originally scheduled to start up by the end of 2025, before that was revised to 2027 in May 2022. In January EDF announced that the "base case" was now for unit 1 being operational in 2030, with the cost revised from GBP26 billion to between GBP31-34 billion, in 2015 prices. When operational, the plant is expected to provide enough power for 6 million homes for at least 60 years.

UK aims for Urenco-built HALEU facility by 2031

08 May 2024

The UK government is awarding GBP196 million (USD245 million) to Urenco to build a uranium enrichment facility with the capacity to produce up to 10 tonnes of high-assay low-enriched uranium (HALEU) per year by 2031.

The Capenhurst site (Image: Urenco)

The Department for Energy Security and Net Zero says the new facility will be built at Urenco's Capenhurst site in northwest England, will support around 400 jobs and "will put an end to Russia's reign as the only commercial producer" of HALEU fuel in Europe.

HALEU - uranium enriched to between 5% and 20% uranium-235 - will be used in the advanced nuclear fuel required for most of the next-generation reactor designs currently under development. At present, only Russia and China have the infrastructure to produce HALEU at scale. The first advanced reactors are scheduled to be operational in the early 2030s.

UK Prime Minister Rishi Sunak said that building the uranium enrichment plant was essential for guaranteeing the country's nuclear and energy security.

Urenco CEO Boris Schucht said: "The responsibility the nuclear industry has to help governments and customers to achieve climate change and energy security goals is clear. We welcome this government investment, which will help accelerate the development of a civil HALEU commercial market and in turn the development of the next generation of nuclear power plants. These plants will have even higher safety standards and lend themselves to quicker licensing and construction processes."

The GBP195 million funding is part of the GBP300 million HALEU programme announced in January, with the energy department saying that the remaining funding would be allocated later this year to other parts of the programme including to support deconversion capability (converting the enriched uranium into a form to be made into fuel).

Tom Greatrex, Chief Executive of the Nuclear Industry Association, said: "This investment will enable the UK to fuel advanced reactors around the world, building on our existing capabilities to strengthen energy security for our allies."

Zara Hodgson, Director of the Dalton Nuclear Institute, which is also based in the northwest of England, said: "This is the biggest single investment in UK nuclear fuel production capability in decades, and it is especially welcome as it will accelerate the supply of the next generation of fuels that are vital for this new net zero nuclear era. Urenco Capenhurst's HALEU Enrichment capability will help hugely to unlock the deliverability of advanced nuclear projects, opening the door to sustainable  electricity and heat for industries from nuclear, across the UK and overseas. We look now towards to how we can support this important project through training and innovation."

The USA is also developing a domestic supply of HALEU. In November last year, Centrus Energy delivered the first HALEU produced at its American Centrifuge Plant in Piketon, Ohio, to the US Department of Energy (DOE). Construction of the 16-centrifuge demonstration cascade plant began in 2019, under contract with the DOE. The delivery by Centrus of more than 20 kilograms of HALEU to the DOE means that phase one of the contract has now been completed and Centrus can move ahead with the second phase: a full year of HALEU production at the 900 kilograms per year plant.

In September, Orano revealed plans to extend enrichment capacity at its Georges Besse II (GB-II) uranium enrichment plant in France, and said it had begun the regulatory process to produce HALEU there.

Urenco is one third owned by the UK government, one third by the Dutch government and one third by two German utilities, E.ON S.E. and RWE AG.

Researched and written by World Nuclear News

KHNP deploys four-legged robot in Kori decommissioning

13 May 2024

Korea Hydro & Nuclear Power's (KHNP) radiation-measuring robot is being used for the first time in the dismantling and decontamination of the 576 MWe pressurised water reactor.

(Image: KHNP)

The four-legged autonomous robot is one of two specialised robots for use in a nuclear power plant environment that KHNP has been developing since 2021: the other one is an indoor autonomous flying robot. The robots are equipped with multiple cameras and radiation sensors, and the ground robot also has temperature and humidity sensors. Together with 3D Lidar technology - a laser-based method of imaging shapes using reflected light - these sensors can be used to "visualise" radiation dose information and monitor dangerous areas to ensure the safety of workers.

(Image: KHNP)

KHNP said it started using "systematic decontamination to dismantle" Kori 1 on 7 May. It plans to use robots to minimise radiation exposure to workers and increase the efficiency of decontamination work.

Kori 1 started commercial operation in 1978 and was permanently shut down in 2017, when it became the first South Korean reactor to enter decommissioning.

Researched and written by World Nuclear News

 

Canadian firms team up for heavy water production

14 May 2024

Canadian Nuclear Laboratories, Atomic Energy of Canada Limited and AtkinsRéalis have signed a memorandum of understanding to explore opportunities to collaborate on the production of heavy water for use in new Candu reactors in Canada.

The Bruce Heavy Water Plant prior to dismantling (Image: Bruce Power)

Heavy water - a form of water in which the normal hydrogen is replaced by a heavier form of hydrogen called deuterium - is used as both the moderator and as the reactor coolant in pressurised heavy water reactors, such as Candus. However, it has not been produced in Canada for more than 25 years.

The MoU brings together AtkinsRéalis' nuclear and industrial capabilities in Canada as the licensee of Candu technology, as well as Atomic Energy of Canada Limited (AECL), owner of Candu intellectual property and other heavy water production technologies, and Canadian Nuclear Laboratories (CNL), a world leader in the industry with extensive experience in heavy water technologies.

The objective of the MoU is to evaluate options and select cost efficient, environmentally responsible, and viable heavy water production technologies, which could include the establishment of industrial scale heavy water production facilities to support the deployment of a new fleet of Candu reactors.

"This collaboration among important stakeholders in the Canadian nuclear sector sets the stage for Canada to lead the global heavy water market, solidifying its role as a key player in the energy transition," said AtkinsRéalis President and CEO Ian Edwards. "With Candu reactors operating across four continents, a global nuclear new build market with expected demand in excess of 1000 new reactors, a strong Candu reactor refurbishment market, and the introduction of the new Candu Monark 1000 MW reactor in addition to the existing Enhanced Candu 6, this memorandum of understanding could not have come at a better time."

AECL President and CEO Fred Dermarkar added: "I am pleased that AECL, CNL and AtkinsRéalis are collaborating and working together to advance heavy water production for Candu reactor technology. Candu technology is uniquely positioned to contribute to important national objectives such as decarbonisation, energy security, economic growth and maintaining Canada's Tier-1 nuclear nation status."

"The deployment of large-scale nuclear power in Canada is an enormous undertaking, and will require extensive alignment and coordination between organisations, industries, public officials and regulators from across the country," said CNL President and CEO Jack Craig. "Heavy water is one key piece of the larger puzzle, and CNL is working hard to play a leadership role in this process, ensuring that the broader industry is working towards a shared vision, and that the necessary inventory and production capabilities are in place to supply these reactors."

The Bruce Heavy Water Plant, which operated from 1973 until 1998, was built by AECL and located within the boundaries of the Bruce nuclear power plant, but was owned and operated by Ontario Power Generation. The plant was built to supply the heavy water needed for Canada's nuclear power programme. Candus are very efficient in their use of heavy water, which is recycled, meaning that the Bruce Heavy Water Plant's output was no longer needed after sufficient stockpiles were produced. Decommissioning of the plant began in 2004, with demolition work completed in 2006.

Researched and written by World Nuclear News

What Tesla’s Charging U-Turn Means for U.S. EV Adoption

By Felicity Bradstock - May 12, 2024

Tesla's reversal on EV charging expansion in the US, coupled with layoffs in the charging infrastructure team, has raised questions about the pace of EV uptake and charging infrastructure development.

Despite Tesla's setback, other automakers and private investors are expected to step in to fill the gap, spurred on by President Biden's pro-renewable energy policies and growing interest in the EV sector.

The shift in plans by Tesla may lead to greater competition in the charging space, with companies like EVgo eyeing opportunities to expand their charging infrastructure and expertise.


After high expectations for U.S. electric vehicle (EV) charging infrastructure, following big promises from market leader Tesla, plans have come crashing down as Musk scraps the company’s expansion scheme. Tesla announced this month that it would not be going ahead with plans for a major EV charging expansion programme. This followed hundreds of layoffs in April, which led many to question Tesla’s plans for sustained growth in the U.S. and global markets. The question now is whether other automakers will step in to roll out their own charging infrastructure across the country and whether this will lead the EV expansion to be severely delayed.

This month, Tesla’s CEO Elon Musk reversed the company’s plans to massively expand EV charging infrastructure in the U.S. This followed the lay-off of 500 employees in a team that was developing plans for U.S. charging infrastructure. The announcement has thrown the EV industry into turmoil and automakers question whether the U.S. charging infrastructure will expand at the pace needed to match rising EV uptake. It is uncertain whether other companies can step in to develop the charging capacity needed to ensure EV uptake continues to increase in the U.S. market.

Tesla continues to own the biggest charging network in the country, with 25,500 out of 42,000 fast chargers in the U.S. The company began developing its Supercharger stations as early as 2012, providing Model S owners with a place to charge their vehicles on the road. This has made the company experts in developing charging stations, which encouraged many investors to fund Tesla-led infrastructure projects across the U.S. The shift in direction has shocked many in the industry, particularly potential investors in the company’s EV charging scheme.

Despite fears of what this could mean for U.S. charging infrastructure, some experts believe that Tesla will not be missed. President Biden’s pro-renewable energy policies, such as the Inflation Reduction Act (IRA), have fuelled interest in the EV sector and encouraged private investors to fund the development of EV charging stations. The number of public fast chargers across the country has risen by almost 11,000, around 36 percent, from April 2023 to April 2024. Peter Slowik, an auto expert at the International Council on Clean Transportation, explained, “The public charging experience is going to get easier… I don’t think the charging market and the electric vehicle market is slowing down because of Tesla.”

The rapid development of a fast-charging network in the U.S. is seen as key to encouraging drivers to shift away from internal combustion engine (ICE) vehicles to electric battery alternatives, supporting the national green transition. At the beginning of 2024, Biden announced the ambitious goal of installing half a million EV charging stations across the country by 2030, investing $623 million in the sector. Tesla was once the market leader for fast chargers in the U.S., but in recent years fast charging equipment has become more standardised. Most automakers in North America recently agreed to use the charging plug developed by Tesla commencing in 2025 to make charging more straightforward for EV owners.

The National Electric Vehicle Infrastructure (NEVI) Programme said 10 states have chosen Tesla as the charging station developer, and it is now uncertain whether the company will fulfil its contracts with these states. However, a spokesperson for the NEVI stated, “Because NEVI provides grants to states, which run competitive procurements to select vendors, we don’t expect individual business decisions to impact EV charging projects funded by the Bipartisan Infrastructure Law… We are focused on delivering a positive charging experience for every driver and an even playing field for American companies.”

The shift in plans by Tesla has led many in the industry to believe that it could spur greater competition in the U.S. Badar Khan, the CEO of EVgo – an EV charging network developer, said that Tesla’s shift in plan is “a very significant change in competitive dynamics in the charging space.” Khan said that EVgo is in discussions with Tesla’s EV charging site hosts and may also be open to hiring ex-employees from the Tesla Supercharger team. This could provide EVgo with the potential to develop charging infrastructure on sites that have already acquired permits, as well as to expand its knowledge and expertise in fast EV-charging technology.

Tesla’s change of plan is expected to slow down the development of the U.S. EV charging network in the short term, as other companies compete to fill the gap. This could have a knock-on effect on EV adoption over the next few years. However, it could also leave room for more market competition, knocking Tesla off the top spot. Further, greater standardisation over the last few years will reduce potential complications around different, competing charging infrastructure, assuring consumers that they will be able to charge their EVs countrywide.

By Felicity Bradstock for Oilprice.com

 

Australia to Invest $15 Billion in Clean Energy Over the Next Decade

By Tsvetana Paraskova - May 14, 2024

Australia plans to invest as much as US$15 billion (AUS$22.7 billion) over the next decade to become a renewable energy superpower and boost its domestic critical minerals economy, the country’s Labor Government said on Tuesday.

The cabinet unveiled today a Future Made in Australia plan to bring new jobs and opportunities and “help Australia succeed and remain an indispensable part of the global economy as the world undergoes the biggest transformation since the industrial revolution.”

The 2024-25 Budget will invest the equivalent of US$15 billion over a decade to boost clean power generation and facilitate private sector investment in low-carbon energy solutions.

Australia will allocate funding to support innovative technologies, including green metals, batteries, and low-carbon liquid fuels. The new plan also introduces a Hydrogen Production Tax Incentive and a Critical Minerals Production Tax Incentive.

The government has also earmarked funding for a national hydrogen strategy to make Australia a global hydrogen leader by 2030.

Last year, Australia allocated $1.32 billion (AUS$2 billion) in the 2023-24 budget to accelerate large-scale renewable hydrogen projects, aiming to become a world leader in green hydrogen production. 

The country is also a major producer of lithium, the key mineral in the current leading global battery technology, and of nickel, which is also crucial for battery manufacturing. 

While allocating billions of dollars to low-carbon energy, Australia is recognizing that natural gas will play a key role in the energy transition.

The government said in its Future Gas Strategy last week that Australia would continue to back exploration and increased production of natural gas as the fuel will play a key role in the country’s transition to a net-zero economy by 2050 and help provide a reliable source of energy to Australia’s allies.  

“The Strategy makes it clear that gas will remain an important source of energy through to 2050 and beyond, and its uses will change as we improve industrial energy efficiency, firm renewables, and reduce emissions,” said Madeleine King, Australia’s Minister for Resources and Northern Australia.

Russia Discovers Massive Oil and Gas Reserves in British Antarctic Territory

  City A.M - May 13, 2024

• 
  
• Russia's Rosgeo uncovered oil and gas reserves in British Antarctic territory, estimated at around 511 billion barrels.
• 
  
• The discovery poses environmental risks and challenges the 1959 Antarctic Treaty, which prohibits oil developments in the region.
• 
  
• Geopolitical tensions rise as Russia's activities in Antarctica are viewed as a move towards resource extraction rather than scientific research, sparking concerns among international observers.

Russia has found huge oil and gas reserves in British Antarctic territory, potentially leading to drilling in the protected region.

The reserves uncovered contain around 511bn barrels worth of oil, equating to around 10 times the North Sea’s output over the last 50 years.

The discovery, per Russian research ships, was revealed in evidence submitted to the Commons Environment Audit Committee last week. The committee was assessing questions regarding oil and gas research on ships owned by the Kremlin’s Rosgeo, the largest geological exploration company in Russia.

Antarctica is currently protected by the 1959 Antarctic Treaty, which prohibits all oil developments in the area.

It was set up to ensure the region was used “exclusively for peaceful purposes” and would “not become the scene or object of international discord.”

The committee heard from minister David Rutley, who assured MPs Russia was conducting scientific research in the region. “Russia has recently reaffirmed its commitment to the key elements of the treaty,” he said.

But Klaus Dodds, a professor of geopolitics at Royal Holloway University, argued the Antarctic policy environment was “arguably at its most challenging since the late 1980s and early 1990s.”

Russia’s invasion of Ukraine has created “widespread concern that a worsening relationship with the country will spark strategic competition and make it even more explicit in Antarctica.”

He believes Russian activity in the region equated to hunting for oil and gas as opposed to scientific research.

“Russia’s activities need to be understood as a decision to undermine the norms associated with seismic survey research, and ultimately a precursor for forthcoming resource extraction,” Dodds said in comments reported by the Telegraph.

The Antarctic Treaty is the largest of Britain’s 14 overseas territories but it has faced competition claims from Argentina and Chile in the past.

The Foreign, Commonwealth and Development Office said: “Russia has repeatedly assured the Antarctic Treaty Consultative Meeting that these activities are for scientific purposes.”

Construction Industry Braces for Impact as Copper Prices Rise

WATCH FOR INCREASING JOB SITE  THEFT

By Metal Miner - May 14, 2024, 

Rising copper prices could increase building costs and result in budget overruns or project delays.

The construction sector faces uncertainty due to fluctuating copper prices, making it difficult to predict costs and plan projects accurately.

Construction companies need to employ sophisticated risk management strategies to mitigate the impact of copper price volatility, such as hedging against price fluctuations and exploring alternative materials.

The Construction MMI (Monthly Metals Index) remained firmly in a sideways trend, only budging upward by 1.28%. The rising price of iron ore PB fines in China had the heaviest impact on the index, holding it more up than down. After that, the next biggest factor was European commercial 1050 aluminum sheets. Meanwhile, all other components of the index’s metal prices trended sideways or down. Despite this, the recent ban on Russian aluminum and copper could impact aluminum and copper prices and snowball into the U.S. construction industry.

How Rising Copper Prices Impact the U.S. Construction Industry

Recent increases copper prices could pose a significant challenge for the U.S. construction industry and the copper market. The primary drivers behind the escalating prices is projected supply-demand imbalances and the recent LME and CME ban on Russian copper. With copper being a crucial material used in various construction applications, including electrical wiring, plumbing, and roofing, recent price increases could have ramification for construction projects all across the nation.

There are several ways that increasing copper prices could impact the construction sector. First of all, copper-based products could become expensive, forcing building costs to increase depending on how much copper is needed. This could result in budget overruns, project delays or even project termination. Furthermore, contractors and developers often find it difficult to precisely predict costs when significant fluctuations happen with copper prices. This adds a degree of uncertainty to bidding and planning procedures.

Furthermore, the consequences of the current copper price forecast go beyond the immediate expenses associated with the commodity. For instance, the economic burden on building projects may increase if manufacturers of copper-containing HVAC systems, electrical equipment and other items feel compelled to boost their pricing.

Mitigating Challenges in Copper Price Volatility

Some industry participants continue to look at other materials to lessen the impact of increased copper prices. For example, HVAC manufacturers continue to produce more air conditioners and heat exchangers out of aluminum since it is currently a more affordable option. Nonetheless, wholesalers and contractors may need to work together to persuade homeowners and contractors to choose these options.

Although the construction sector typically withstands changes in commodity prices, the recent spike in copper prices still poses a threat. Sophisticated risk management techniques, such as protecting against price fluctuations and investigating substitute materials, will be essential for construction companies to maneuver through these challenges.

Other U.S. Construction Market Trends: April and May 2024

The government’s increased funding for infrastructure development projects had a notable influence on the construction industry over the past couple of months. The government’s emphasis on enhancing the nation’s infrastructure resulted in a rise in building activity in a number of industries. Not only did this investment promote economic growth, it produced a wide range of job possibilities.

But despite this rise, the U.S. construction sector continues to face a skilled labor shortage. In fact, the need for trained labor grew right along with the demand for construction projects. Still, the lack of personnel with the necessary experience made it difficult for construction businesses to obtain professional labor.

By Jennifer Kary