The Immense Scale of Wind Turbine Foundations in Renewable Energy Projects
The Kennedy Energy Park in Hughenden, Far North Queensland, highlights the enormous scale of resources required for wind turbine foundations. For each turbine base, the following materials are necessary:
- Concrete: Over 2,222 tonnes of concrete (approximately 903 cubic meters) are needed. This equates to around 143 concrete agitator truckloads per turbine foundation.
- Reinforcing Steel: Just under 90 tonnes of reinforcing steel bars, commonly known as ‘reo,’ are required to reinforce the concrete.
- Sand: Over 833 tonnes of sand are utilized in the construction of each foundation.
It’s important to note that these figures are per wind turbine base, and the foundations built for other wind projects in Australia can be even larger.
A critical concern is that these massive foundations are apparently not reusable. Considering the relatively short lifespan of wind turbines – some reports now suggest a realistic life expectancy of 15 years, with the most optimistic projections hoping for up to 30 years – serious questions arise about the future. Will these foundations be dug up and recycled at the end of the turbines’ service life?
Reports from both the USA and Australia estimate the cost of decommissioning, removing, and disposing of similar turbines to range between $400,000 and $1,000,000 per turbine. However, the potential costs and feasibility of removing the foundations, roadways, and restoring the landscape to its original state are seldom discussed. Can this even be achieved?
The notion of “clean and green” energy warrants closer scrutiny. Do you agree?
Absolutely!!
You correctly point out the huge expenditure require to build and decommission wind turbines, with decommissioning costing up to one million dollars. The World Nuclear Association provides some very interesting figures on decommissioning nuclear facilities, which I quote in full from their report, which is available in full at
https://world-nuclear.org/information-library/nuclear-fuel-cycle/nuclear-waste/decommissioning-nuclear-facilities
You will note that the cost is given in BILLIONS of dollars and the decommission time is given in DECADES.
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Decommissioning experience
Considerable experience has been gained in decommissioning various types of nuclear facility. About 200 commercial, experimental or prototype power reactors, as well as over 500 research reactors have been retired from operation. About 25 reactors have been fully dismantled.
(Ships and numerous submarines have also been decommissioned but are not included in this paper.)
European reactors
To decommission its retired gas-cooled reactors at the Chinon, Bugey and St Laurent nuclear power stations, EDF chose partial dismantling and postponed final dismantling and demolition for 50 years. As other reactors will continue to operate at those sites, monitoring and surveillance do not add to the cost.
A recycling plant for steel from dismantled nuclear facilities is at Marcoule, in France. This metal will contain some activation products, but it can be recycled for other nuclear plants.
Decommissioning has begun at 33 UK reactors, 26 of them early Magnox types with graphite moderators.* One of the first was Berkeley nuclear power station (2 x 138 MWe), closed for economic reasons in 1989 after 27 years of operation, where defuelling was completed in 1992. The cooling ponds were then drained, cleaned and filled in and the turbine hall was dismantled and demolished. The reactor buildings are in an extended Safstor period. Ultimately they too will be dismantled, leaving the site to be leveled and landscaped. The same pattern is being followed at other UK reactor sites.
* Costs for decommissioning gas-cooled reactors are much higher per unit of capacity than for light water reactors – at least five times for Magnox. This is due to the large volume of material and the need to dispose of a lot of graphite moderator. Decommissioning waste volumes per unit capacity for Magnox are ten times those for Western light water reactors. See also later subsection on Graphite.
Spain’s Vandellos 1, a 480 MWe gas-graphite reactor, was closed down in 1990 after 18 years operation, due to a turbine fire which made the plant uneconomic to repair. In 2003 ENRESA concluded phase 2 of the reactor decommissioning and dismantling project, which allowed much of the site to be released. After 30 years Safstor, when activity levels have diminished by 95%, the remainder of the plant will be removed. The cost of the 63-month project was €93 million.
Eleven of Germany’s 19 shutdown units were subject to immediate dismantling. At Greifswald nuclear power station in the former East Germany, where five reactors had been operating, immediate dismantling was chosen. Similarly, the site of the 100 MWe Niederaichbach nuclear power plant in Bavaria was declared fit for unrestricted agricultural use in mid-1995. The 15 MWe Kahl experimental BWR was shut down in 1985, after 25 years of operation. After decontamination, the plant was completely dismantled and the site was cleared for unrestricted use. The 250 MWe Gundremmingen A unit was Germany’s first commercial nuclear reactor, operating 1966-77. Decommissioning work started in 1983, and moved to the more contaminated parts in 1990, using underwater cutting techniques. This project demonstrated that decommissioning could be undertaken safely and economically without long delays, and recycling most of the metal.
Of the eight German units shut down in March 2011 for political reasons, most will be dismantled over about 15 years. The four operators had €38 billion set aside for decommissioning and waste disposal.
Japan’s Tokai 1 reactor, a 160 MWe UK Magnox design, is being decommissioned after 32 years service to 1998. After 10 years storage, in Phase 2 (to 2011) the steam generators and turbines were removed, and in Phase 3 (to 2018) the reactor is being dismantled, the buildings demolished and the site left ready for re-use. The total cost will be JPY 93 billion (USD 1.04 billion) – 35 billion for dismantling and 58 billion for waste treatment which will include the graphite moderator (which escalates the cost significantly, see subsection below).
US reactors
Experience in the USA has varied, but about ten power reactors are using the Safstor approach, while about 20 – mostly single-unit plants – are using, or have used, Decon.
Early in 2017 a joint venture, Accelerated Decommissioning Partners, was set up under the leadership of NorthStar Group Services with Orano USA to acquire and decommission shutdown US nuclear reactor facilities and take over their used fuel. Another joint venture in the field is Comprehensive Decommissioning International (CDI), formed in 2018 between SNC-Lavalin and Holtec. Holtec Decommissioning International (HDI) functions as the licensed operator for Holtec-owned nuclear power plants and provides the licensee oversight of CDI. HDI additionally, manages the decommissioning trust fund and other owner interests, such as licensing strategy, insurance, land and government interface. EnergySolutions was already active in this kind of role.
Procedures are set by the Nuclear Regulatory Commission (NRC), and considerable experience has now been gained. A total of 32 power reactors have been closed and decommissioned. NRC requires that the operating licence of a closed reactor be terminated and decommissioning activities be completed within 60 years. Site release often excludes the onsite used fuel storage in an ISFSI (independent spent fuel storage installation), which usually remains, to await the Department of Energy taking away the used fuel (over which it has title) to a national repository sometime in the future.
Rancho Seco (single 913 MWe, PWR) was closed in 1989, and in 1995 NRC approved a Safstor plan for it. However, the utility subsequently decided upon incremental dismantling and this was completed in 2009, leaving about 3 ha still under NRC licence for waste storage. About 32 ha has been released for unrestricted use.
At multi-unit nuclear power stations, the choice has been to place the first closed unit into Safstor until the others end their operating lives, so that all can be decommissioned in sequence. This will optimise the use of staff and the specialised equipment required for cutting and remote operations, and achieve cost benefits.
Thus, after 14 years of comprehensive clean-up activities, including the removal of fuel, debris and water from the 1979 accident, Three Mile Island 2 was placed in post-defuelling monitored storage (Safstor) until unit 1 eventually closed down, so that both units could be dismantled together. EnergySolutions has a contract with FirstEnergy to decommission unit 2. Unit 1 is being placed in Safstor.
San Onofre 1 (436 MWe PWR), which closed in 1992, was put into Safstor until licences for units 2&3 expire in 2022-23. However, after NRC changes, dismantling was brought forward to 1999, so it became an active Decon project which was largely completed in 2008. A small amount of work remains to be completed with eventual dismantling of units 2&3 (each 1070 MWe PWR) on the site, which were shut down in May 2013. In April 2016 the California Public Utilities Commission approved $4.41 billion in decommissioning costs for them, from funds held in trust. Southern California Edison said that funds were then $3.37 billion. Used fuel will be removed from 2024 to an onsite ISFSI, and dismantling the plant is expected to be completed by 2030. SONGS Decommissioning Solutions – a joint venture between Aecom and EnergySolutions – was selected in December 2016 as the general contractor.
A US Decon project was the 60 MWe Shippingport reactor, which operated commercially from 1957 to 1982. It was used to demonstrate the safe and cost-effective dismantling of a commercial scale nuclear power plant and the early release of the site. Defuelling was completed in two years, and five years later the site was released for use without any restrictions. Because of its size, the pressure vessel could be removed and disposed of intact. For larger units, such components have to be cut up.
Immediate Decon also the option chosen for Fort St Vrain, a 330 MWe high temperature gas-cooled reactor which was closed in 1989. This took place on a fixed-price contract for US$ 195 million (hence costing less than 1 cent/kWh despite only a 16-year operating life) and the project proceeded on schedule to clear the site and relinquish its licence early in 1997 – the first US power reactor of this size to achieve this.
Shoreham BWR, on Long Island, generated very little power and never received a full operating licence, so the level of activation products was minimal. It was shut down in 1989 and became a Decon project, completed in 1994. The 59 MWe Pathfinder prototype BWR in South Dakota, shut down in 1967 after a very short life was also a Decon project, completed in 1992.
For Trojan (1180 MWe, PWR) in Oregon the dismantling was undertaken by the utility itself. The plant closed in 1993, steam generators were removed, transported and disposed of at Hanford in 1995, and the reactor vessel (with internals) was removed and transported to Hanford in 1999. Except for the used fuel storage, the site was released for unrestricted use in 2005. The cooling tower was demolished in 2006. This was a relatively low-cost operation – about $300 million.
Another US Decon project was Maine Yankee, a 860 MWe PWR plant which closed down in 1996 after 24 years operation. The containment structure was finally demolished in 2004 and except for 5 ha with the dry store for used fuel, the site was released for unrestricted public use in 2005, on budget (about $500 million) and on schedule.
Haddam Neck/Connecticut Yankee (560 MWe PWR) also shut down in 1996 after 29 years operation. Decommissioning work began in 1998 and demolition was concluded in 2006. The site was released for unrestricted public use in 2007, apart from 2 ha for dry cask used fuel storage. Residual contamination on the land is below the NRC’s limit of 0.25 millisievert per year for maximum radiation dose.
In 2006 the site of 72 MWe Big Rock Point nuclear power plant in Michigan, shut down in 1997 after 35 years operation, was largely returned to greenfield status. In January 2007 most of the land was released for derestricted public use, though 43 hectares still has the dry cask storage facility where used fuel is stored pending transfer to the national repository. The total cost was $836 million.
Vermont Yankee (535 MWe BWR) was shut down in 2014 and is in Safstor and was expected to cost $577 million to decommission over many years. However, Entergy arranged to accelerate the process by transferring the licence and selling the whole site to a consortium of decommissioning companies headed by NorthStar Group Services, which expects to complete the process and sell the cleared site by 2030. Fuel was moved to dry storage in 2017. Areva Nuclear Materials, now Orano USA, is contracted to cut up and remove the reactor vessel and internals.
With Exelon’s Zion 1&2 reactors (2 x 1098 MWe) closed down in 1998 and initially in Safstor, Exelon decided to accelerate the process and contracted a specialist company – EnergySolutions – to dismantle the plant, ship the waste to its disposal site in Utah, and return the site to greenfield status. To achieve this, in 2010 the plant’s licence and decommissioning funds were transferred to EnergySolutions, which became owner and licensee, and the site should be returned to Exelon about 2022. In 12 months to January 2015 EnergySolutions transferred all 2226 used fuel assemblies to 61 Magnastor dry casks onsite – an ISFSI, where it will remain until taken to the future national repository. By September 2021 the site was clean and being vegetated. EnergySolutions had similarly decommissioned LaCrosse, a 50 MWe BWR, Big Rock Point, a 67 MWe BWR, and the small (20 MWt) SEFOR experimental reactor in Arkansas. It is signed up to decommission Three Mile Island 2, San Onofre (see above) and Fort Calhoun.
Exelon’s Oyster Creek (619 MWe BWR) in New Jersey will be dismantled and cleaned up by Comprehensive Decommissioning International (CDI) – the SNC-Lavalin and Holtec JV – starting in 2019 and expected to take less than ten years. The licence was transferred from Exelon in July 2019. CDI will also be the decommissioning general contractor for the Pilgrim BWR shut down in 2019, and for Indian Point 1, 2&3 (1974, 2020, 2021) and Palisades from 2022.
Entergy’s Indian Point plant is expected to cost $2.3 billion to decommission and dismantle over about 12-15 years, by CDI after ownership passed to Holtec in April 2021. Unit 1 of 277 MWe, in Safstor since 1974, would cost $598 million, unit 2 $702 million and unit 3 $1 billion. Decommissioning trust funds for the three reactors amounted to $2.1 billion in 2019 so were expected to cover the work by the time unit 3 shut down in 2021. Only an ISFSI would remain onsite after 2032.
Duke’s Crystal River 3 (860 MWe) was expected to cost $1.18 billion (2013 dollars) to decommission via Safstor over 60 years, during which time the funds reserved for the purpose would accrue interest, thereby fully covering the cost, despite the fact that is was closed after only 35 years of operation. Immediate decommissioning (Decon) was then expected to cost $994 million, but the decommissioning fund would have had less time to grow sufficiently to cover it, and a $195 million impact on Florida ratepayers would have resulted.
Construction of an onsite dry cask storage facility commenced in 2016, and fuel transfer started in summer 2017 and completed in January 2018. The spent fuel is planned to remain at the onsite storage facility until 2036, when it would be moved to a federal facility. Safstor was expected to end with removal of the unit’s remaining components about 2070 and site restoration in 2074. In August 2020 the Florida Public Service commission approved Accelerated Decommissioning Partners completing demolition by 2027 and managing the ISFSI to 2038 for a fixed price of $540 million, fully covered by the existing trust funds of over $700 million (with balance plus any money recovered from suing the DOE returned to ratepayers). Duke will remain the owner to 2038, but Accelerated Decommissioning Partners became the licensed operator of the plant and ISFSI in October 2020.
However, in May 2019 Duke announced that it had contracted with Accelerated Decommissioning Partners (NorthStar and Orano joint venture) for decommissioning Crystal River by 2027, and that this would be covered by the decommissioning fund, which was worth $717 million in the first quarter of 2019. The contract structure transfers the risk of potential cost overruns and latent liabilities to the joint venture. Duke would remain the NRC-licensed owner of the plant, as well as the owner of the land and the trust fund. However, Accelerated Decommissioning Partners would become the plant operator and would take ownership of the associated dry cask storage facility as well as spent nuclear fuel onsite.
Omaha Public Power District’s Fort Calhoun plant (482 MWe) closed in 2016 after 43 years operation, since 2012 by Exelon. It is being decommissioned by EnergySolutions from 2019. Safstor was originally intended at a cost of $1.3 billion, but following an OPPD board decision in October 2018 and a contract with EnergySolutions it will now be cleaned up by mid-2020s with an expected saving of $200 million.
In summary, US plants with Decon completed are: Big Rock Point, Elk River, Fort St Vrain, Haddam Neck/Connecticut Yankee, La Crosse, Maine Yankee, Pathfinder, Rancho Seco, San Onofre 1, Saxton, Shippingport, Shoreham, Trojan, Zion 1&2 and Yankee Rowe. (Also Santa Susana Field Laboratory’s Sodium Reactor Experiment, which is not included in power reactor tables.) Decon is in progress at Humboldt Bay 3, and will now be adopted at Fort Calhoun and Indian Point.
Yankee-Rowe-after-decommissioning-_12_12_2006_2_lg-(Yankee-Rowe).jpg
Yankee Rowe after decommissioning (Yankee Rowe)
US plants in Safstor, either in part or in full, include Crystal River 3, Dresden 1, Fermi 1, Indian Point 1, Kewaunee, Millstone 1, and Peach Bottom 1, as well as NS Savannah. Three Mile Island 2 is in post-defuelling monitored storage. San Onofre 2&3 will also enter Safstor when defuelled.
The only US plants subject to the Entomb option are small experimental ones: Bonus BWR in Puerto Rico, Piqua organic-moderated reactor in Ohio, Hallam graphite-moderated sodium-cooled reactor in Nebraska, and in 2015, EBR-II. No NRC-licensed plant has used this option.
In addition to the above is the first floating nuclear power plant, installed in a former liberty ship, and utilised at Panama 1967-76. The Sturgis had a 45 MWt/10 MWe (net) PWR which provided power to the Canal Zone. After it was defuelled in 1977, some 89 m3 of solid radioactive waste and 363 m3 of liquid waste was removed and the vessel placed in safstor at Fort Belvoir, Virginia. In 2014 CB&I was awarded a contract from the US Army to decommission and dismantle the MH-1A PWR. In 2015 the vessel was towed to Texas for dismantling, which was completed in 2019. About 700 tonnes of radioactive waste was removed and 270 tonnes of lead was recycled.
The US Army’s SM-1A reactor at Fort Greely in Alaska was shut down in 1972 after ten years’ operation. Most of the radioactive waste was then removed and primary components were sealed inside the containment with concrete to Safstor status. Further work is planned to 2022. It operated at 1.8 MWe and 10 MW thermal. The Army’s SM-1 at Fort Belvoir, Virginia, was similar and shut down in 1973. It is in Safstor and further work is planned from 2020.
Further information on decommissioning in USA is available from the Nuclear Energy Institute, and from the NRC.
Russian reactors
Rostechnadzor oversees a major program of decommissioning old fuel cycle facilities, financed under the Federal target program on Nuclear and Radiation Safety. Six civil reactors are being decommissioned: three early LWGRs, the Melekess VK-50 prototype BWR, and two larger prototype VVER-440 units at Novovoronezh. Most were shut down 1981-90, the fuel removed, and they now await dismantling, which is staring to progress at Novovronezh.
Russia’s Rosenergoatom has concluded that moving from the ‘deferred’ to ‘immediate’ dismantling approach to its nuclear reactors being decommissioned would bring a 20% cost saving. Immediate dismantling enables the maximum use of the residual life of the equipment and structures of the shutdown units, reduces maintenance costs, makes use of existing radioactive waste management facilities, and employs the skills of personnel.
Graphite
A number of first-generation reactors had graphite blocks as moderator. This is high-quality reactor-grade material produced at about 3000°C which accumulates some radionuclide contamination while in service, particularly carbon-14 at levels which often means that it must be classified as intermediate-level waste. While it oxidizes slightly under neutron bombardment and also at high temperatures (to CO), it does not burn, but sublimes at 3652°C. There is no risk of oxidation under Safstor conditions.
A 2006 report commissioned by EPRI states: “The graphite moderators of retired gas-cooled nuclear reactors present a difficult challenge during demolition activities. As a result, utilities have not dismantled any moderators of CO2 cooled power reactors to date.” However, it concludes that adequate information exists to enable the safe dismantling and processing of graphite moderators, and that the three main options for disposal of this graphite are oxidation to the gas phase and release as carbon dioxide (difficult), direct burial, or recycling into new products for the nuclear industry. In each case, opportunities exist for pre-processing to concentrate or remove radionuclides to enhance the safety of the chosen option. The radionuclide inventory of irradiated graphite is unusual in comparison with other nuclear wastes. Cobalt-60 and tritium are the principal isotopes of short-term importance, carbon-14 and chlorine-36 are dominant in the longer term.
Fast neutron reactors
Several sodium-cooled fast reactors have been decommissioned, but only a few have been dismantled. Germany’s KNK-2 at Karlsruhe was shut down in 1991 after 14 years’ operation, with fuel removal and initial dismantling in 1993. High levels of activation products meant that much work was remote, and residual sodium meant that some cutting was done in a nitrogen atmosphere. Total cost is estimated as €364 million, with completion expected in 2020.
Other facilities
The French Atomic Energy Commission is decommissioning the UP1 reprocessing plant at Marcoule. This plant started up in 1958 and treated 18,600 tonnes of metal fuels from gas-cooled reactors (both defence and civil) to 1997. Progressive decontamination and dismantling of the plant and waste treatment will span 40 years and cost some EUR 5.6 billion, nearly half of this for treatment of the wastes stored on the site.
Areva is decommissioning the Eurodif enrichment plant at Marcoule since 2012. This involved over 2012-15 the decontamination with ClF3 gas to remove the residual uranium left inside, and extract it as UF6, then recovery of all produced chloride and fluoride gas before the opening of equipments and circuits. Then over 2016-25 the plant is being dismantled.
Areva completed the dismantling and clean-up of the MOX fuel fabrication plant and plutonium technology workshops (ATPu) at CEA’s Cadarache site in 2017. The small fuel fabrication plant had produced fuel for French fast reactors and was closed down in 2003; the ATPu was closed in 2008. Areva described the project as “one of the largest dismantling projects in the world.”
The US Department of Energy in August 2010 awarded a $2.1 billion contract to a joint venture between Fluor Corp and Babcock and Wilcox (B&W, now BWXT) for decontamination and decommissioning of the huge (1500 ha) Portsmouth Gaseous Diffusion Plant (GDP) uranium enrichment site in Ohio, from March 2011. In March 2016 the contract was extended by 30 months.
The US Department of Energy in May 2017 awarded a $1.5 billion contract to Four Rivers Nuclear Partnership LLC for the continued deactivation and remediation (D&R) of facilities at the Paducah gaseous diffusion uranium enrichment plant in Kentucky and clean-up of the 1400 ha site. Four Rivers is a CH2M-led company with partners Fluor and BWX Technologies. The Paducah plant was commissioned in 1952 for defence purposes and was leased to USEC from 1993 to 2013. The D&R contract is valued at $750 million for five years, followed by three-year and two-year option periods together worth about $750 million. Fluor had a three-year $420 million DOE contract to clean up the Paducah site from 2014-17.
The US Department of Energy contractors in 2016 finished demolishing the Oak Ridge diffusion enrichment plant in Tennessee, which operated from the early 1940s to 1985, making 120 ha available for other uses.
Many nuclear submarines have been decommissioned over the last decade. In USA, after defuelling, the reactor compartments are cut out of the vessels and are transported inland to Hanford, where they are buried as low-level waste. Russia has decommissioned three nuclear powered icebreakers: Lenin, Sibir and Arktika.
Cost and finance
In most countries the operator or owner is responsible for the decommissioning costs.
The total cost of decommissioning is dependent on the sequence and timing of the various stages of the program. Deferment of a stage tends to reduce its cost, due to decreasing radioactivity, but this may be offset by increased storage and surveillance costs.
Even allowing for uncertainties in cost estimates and applicable discount rates, decommissioning contributes a small fraction of total electricity generation costs. In USA many utilities have revised their cost projections downwards in the light of experience.
Financing methods vary from country to country. Among the most common are:
Prepayment, where money is deposited in a separate account to cover decommissioning costs even before the plant begins operation. This may be done in a number of ways but the funds cannot be withdrawn other than for decommissioning purposes.
External sinking fund (Nuclear Power Levy): This is built up over the years from a percentage of the electricity rates charged to consumers. Proceeds are placed in a trust fund outside the utility’s control. This is the main US system, where sufficient funds are set aside during the reactor’s operatinig lifetime to cover the cost of decommissioning.
Surety fund, letter of credit, or insurance purchased by the utility to guarantee that decommissioning costs will be covered even if the utility defaults.
In the USA, utilities are collecting 0.1 to 0.2 cents/kWh to fund decommissioning. They must then report regularly to the NRC on the status of their decommissioning funds. About two-thirds of the total estimated cost of decommissioning all US nuclear power reactors has already been collected, leaving a liability of about $9 billion to be covered over the remaining operating lives of about 100 reactors (on the basis of an average of $320 million per unit). NRC data for the end of 2018 indicated that there was a combined total of $64.7 billion held in the decommissioning trust funds covering the 119 operational and retired US nuclear power reactors.
An OECD Nuclear Energy Agency survey published in 2016 reported US dollar (2013) costs in response to a wide survey. For US reactors the expected total decommissioning costs range from $544 to $821 million; for units over 1100 MWe the costs ranged from $0.46 to $0.73 million per MWe, for units half that size, costs ranged from $1.07 to $1.22 million per MWe. For Finland’s Loviisa (2 x 502 MWe) the estimate was €326 million. For a Swiss 1000 MWe PWR the detailed estimate amounts to CHF 663 million (€617 million). In Slovakia, a detailed case study showed a total cost of €1.14 billion to decommission Bohunice V1 (2 x 440 MWe) and dismantle it by 2025.
Recycling and reuse of materials from decommissioning
Significant volumes of concrete and steel arise from demolishing decommissioned nuclear facilities. Much of this can be recycled or reused in some way where allowed by national regulation, and unlike ‘wastes’, transferred to other countries. Clearance levels differ internationally, leaving scope for greater harmonisation, and some levels are unjustifiably conservative, e.g. 100 Bq/kg applying for many radionuclides. Public acceptance of recycling and reuse is often low.
There are several options for recycle and reuse:
Material which is essentially uncontaminated and unconditionally released.
Material that can be melted in a regulated environment followed by metal recycle for consumer products (conditional clearance).
Material with short half-life products that is melted and fabricated in a regulated environment and released for specific industrial applications (e.g. steel bridge).
Material that cannot be released from regulatory control but which may be recycled in the nuclear industry.
Recycling materials from decommissioned nuclear facilities is constrained by the level of radioactivity in them. This is also true for materials from elsewhere, such as gas plants, but the levels specified can be very different. For example, scrap steel from gas plants may be recycled if it has less than 500,000 Bq/kg (0.5 MBq/kg) radioactivity (the exemption level). This level however is one thousand times higher than the clearance level for recycled material (both steel and concrete) from the nuclear industry, where generally anything above 500 Bq/kg may not be cleared from regulatory control for recycling.*
* EC proposed clearance levels for specific nuclides in 1996 were 10 MBq/kg for Fe-55 and Ni-63. Those for the IAEA were 0.3 and 3 MBq/kg respectively. For mixtures of artificial radionuclides, the weighted sum of the nuclide specific activities or concentrations in the same matrix divided by the corresponding release limit must be applied.
There is increasing concern about double standards developing in Europe which allow 30 times the dose rate from non-nuclear recycled materials than from those out of the nuclear industry. Norway and Holland are the only countries with consistent standards. Elsewhere, 0.3 to 1.0 mSv/yr individual dose constraint is applied to oil and gas recyclables, and 0.01 mSv/yr for release of materials with the same kind of radiation from the nuclear industry. The double standard means that the same radionuclide, at the same concentration, can either be sent to deep disposal or released for use in building materials, depending on where it comes from. The 0.3 mSv/yr dose limit is still only one-tenth of most natural background levels, and two orders of magnitude lower than those experienced naturally by many people, who suffer no apparent ill effects.
The main radionuclide in scrap from the oil and gas industry is radium-226, with a half-life of 1600 years as it decays to radon. Those in nuclear industry scrap are cobalt-60 and caesium-137, with much shorter half-lives. Application of a 0.3 mSv/yr dose limit results in a clearance level for Ra-226 of 500 Bq/kg, compared with 10 Bq/kg for nuclear material.
In 2011, 16 decommissioned steam generators from Bruce Power in Canada were to be shipped to Sweden for recycling. Although the Canadian Nuclear Safety Commission (CNSC) approved Bruce Power’s plans in 2011 and confirmed steam generator processing is an excellent example of responsible and safe nuclear waste management practices, this caused public controversy at the time, and following the Fukushima nuclear accident plans for this shipment were shelved. These steam generators were each 12m long and 2.5m diameter, with mass 100 t, and contained some 4g of radionuclides with about 340 GBq of activity. Exposure was 0.08 mSv/hr at one metre. They were classified as low-level waste (LLW). Studsvik in Sweden would recycle much of the metal and return about 10% of the overall volume as LLW for disposal in Ontario. The balance would be under 100 Bq/kg, which appeared to be the clearance level.
In 2012 five steam generators from UK plants were shipped to Studsvik in Sweden for recycling. Studsvik has also set up a plant in the UK, at Lillyhall in Cumbria, to recycle materials from nuclear facilities, and this became fully operational in 2013 after processing 2000 t of metal from numerous sites and recycling 96% of it. The balance went to a LLW repository.
To 2015, Studsvik had processed by melting 32,000 tonnes of carbon steel, 5200 t stainless steel, 2033 t aluminium, 1153 t lead, and 3896 t copper cables. All this could be released. EnergySolutions in the USA has recycled over 62,000 tonnes of metal, mostly ferrous.
Under the NEA CPD program (see below) a 2017 report on Recycling and Reuse of Materials Arising from the Decommissioning of Nuclear Facilities has been published.
International cooperation
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If these things lasted 20 years they would have to be replaced 4 times over the life of a nuclear plant, so would the solar panels. Cheap? NO. Reliable? Occasionally.
Here is a question to put to this brain-dead Bowen; With all this renewable crap when the life span is only 15 years, we the taxpayers should be able to take his long service and pension for life of this clown to clean up this mess
These wind turbines are the Greatest Waist of Money that any Government could have come up with. No wonder our Power Bills are going through the roof. It is past time that Australia has a Government for the People instead of pandering to these idiots from overseas. Why the hell are we paying the Chinese to load our country up with all the garbage they will not use? And still, our Looney Left Pollies carry on about how great they are. I don’t know if they mean the wind turbines or themselves, they are about as useless as each other.