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Friday, 1 August 2014

Nigeria, U.S. Sign Memorandum of Understanding on Electric Power (July 25, 2014)




July 25, 2014
Ambassador James F. Entwistle and Power Minister Prof Nebo sign MOU on power, July 24.  Photo by Idika Onyukwu
Ambassador James F. Entwistle and Power Minister Prof Nebo sign MOU on power, July 24. Photo by Idika Onyukwu
(L-R), Senior Vice President Peter Nwangwu, and Rod Johnson, President Global Edison sign MOU with and Prof Nebo on power reform. Photo by Idika Onyukwu
(L-R), Senior Vice President Peter Nwangwu, and Rod Johnson, President Global Edison sign MOU with and Prof Nebo on power reform. Photo by Idika Onyukwu
Power Africa, an initiative of President Barack Obama designed to significantly increase the amount of electricity available in sub-Saharan Africa, received a major boost yesterday with the signing of a memorandum of understanding (MOU) between the governments of the United States and Nigeria.  U.S. Ambassador to Nigeria James F. Entwistle and the Minister of Power Professor Chinedu Nebo signed the agreement.
The MOU outlines the parts both the U.S. Government and the Government of Nigeria will play working together to increase access to and availability of electricity in Nigeria. 
Also as part of the agreement, U.S. company, Global Edison, led by its President Rod Johnson and the company’s senior Vice President Peter Nwangwu, signed an MOU with the Minister of power Professor Nebo as part of the Power Africa initiative.  
Earlier in his remarks, Ambassador Entwistle said Nigeria is well-positioned to reap the rewards from the increased focus on the energy sector.  He stated that: “It is our expectation that our joint effort will improve the lives of countless Nigerians and serve as a role model for other African countries whose implementation of energy sector reform is nascent.” 
Power Africa is expected to build on Africa’s enormous power potential, including new discoveries of vast reserves of oil and gas, and the potential to develop clean geothermal, hydro, wind and solar energy. 
Present at the ceremony were the ministry of power’s permanent secretary Ambassador Godknows Ighalli, USAID Mission Director Michael T. Harvey, the managing director/chief executive officer of the Niger Delta Power Holding Company of Nigeria, James Olotu, and other senior government officials.
The Department of State, the U.S. Agency for International Development, the Department of Energy, the Department of the Treasury, the Export-Import Bank, the Overseas Private Investment Corporation, the U.S. African Development Foundation, the Department of Commerce, the Millennium Challenge Corporation, the U.S. Trade and Development Agency, the U.S. Army Corps of Engineers, and the U.S. Department of Agriculture are providing the tools needed to strengthen Africa’s power sector and its economic growth and development. 

Saturday, 14 June 2014

Vanadium: The metal that may soon be powering your neighbourhood



Pile of Vanadium oxide
Hawaii has a problem, one that the whole world is likely to face in the next 10 years. And the solution could be a metal that you've probably never heard of - vanadium.
Hawaii's problem is too much sunshine - or rather, too much solar power feeding into its electricity grid.
Generating electricity in the remote US state has always been painful. With no fossil fuel deposits of its own, it has to get oil and coal shipped half-way across the Pacific.
That makes electricity in Hawaii very, very expensive - more than three times the US average - and it is the reason why 10% and counting of the islands' residents have decided to stick solar panels on their roof.
The problem is that all this new sun-powered electricity is coming at the wrong place and at the wrong time of day.
Hawaii's electricity monopoly, Heco, fears parts of the grid could become dangerously swamped by a glut of mid-day power, and so last year it began refusing to hook up the newly-purchased panels of residents in some areas.
And it isn't just Hawaii.
"California's got a major problem," says Bill Radvak, the Canadian head of American Vanadium, America's only vanadium mining company.
"The amount of solar that's coming on-stream is just truly remarkable, but it all hits the system between noon and 4pm."
That does not marry well with peak demand for electricity, which generally comes in the late afternoon and evening, when everyone travels home, turns on the lights, heating or air conditioning, boils the kettle, bungs dinner in the microwave, and so on.
What the Golden State needs is some way of storing the energy for a few hours every afternoon until it is needed.
And Radvak thinks he holds the solution - an electrochemical solution that exploits the special properties of vanadium.
Vanadium mine, Nevada
Back in 2006, when Radvak's company decided to reopen an old vanadium mine in Nevada, electricity grids were the last thing on their minds.
Back then, vanadium was all about steel. That's because adding in as little as 0.15% vanadium creates an exceptionally strong steel alloy.
"Steel mills love it," says Radvak. "They take a bar of vanadium, throw it in the mix. At the end of the day they can keep the same strength of the metal, but use 30% less."
It also makes steel tools more resilient. If the name vanadium is vaguely familiar to you, it is probably because you have seen it embossed on the side of a spanner.
And because vanadium steel retains its hardness at high temperatures, it is used in drill bits, circular saws, engine turbines and other moving parts that generate a lot of heat.
So steel accounts for perhaps 90% of demand for the metal.
Ford production in the early 1900s
Vanadium's alloying properties have been known about for well over a century. Henry Ford used it in 1908 to make the body of his Model T stronger and lighter.
For the same reasons - and also for its heat resistance - it was used to make portable artillery pieces and body armour in the First World War.
But vanadium's history seemingly goes back even further. Indeed, mankind may have been unwittingly exploiting the metal as far back as the 3rd Century BC.
Knife
That is when "Damascus steel" first began to be manufactured.
Swords made of the steel were said to be so sharp that a hair would split if it were dropped on to the blade.
Damascus steel scimitars were credited with enabling Muslim warriors to fight off the Crusades.
Circa 1250, A crusader and Muslim warrior in hand-to-hand combat.
Samples taken from a handful of antiques were found to contain tiny amounts of impurities, including - crucially - vanadium.
Bizarrely, this two-millennium-old steel-making tradition vanished in the mid-18th Century. The vanadium-rich iron deposits in southern India from which the steel was fashioned must finally have become exhausted, or so the theory goes.
Today, vanadium mainly goes into structural steel, such as in bridges and the "rebar" used to reinforce concrete.
It is a small and sometimes volatile market. Supply is dominated by China, Russia and South Africa, where the metal is extracted mostly as a useful by-product from iron ore slag and other mining processes.
China - which is midway through the longest and biggest construction boom in history - also dominates demand.
A recent decision by Beijing to stop using low-quality steel rebar has bumped up forecast demand for vanadium by 40%.
Yet the biggest source of future demand may have nothing to do with steel at all, and may instead exploit vanadium's unusual electro-chemical nature.
Freyja, Freya or Vanadis - Norse goddess of fertility, love and marriage, beauty and light and peace
"Vanadium was actually discovered twice, and one of the discoverers was the Swedish chemist Nils Sefstrom, who named it after the Norse goddess of beauty, Vanadis," says the Italian chemist, Prof Andrea Sella of University College London.
To explain why, Sella produces a flask of an easily misidentified yellow-coloured liquid.
It is, he says, a solution of "oxidised" vanadium in sulphuric acid - that is, vanadium that has been stripped of all five of its outermost electrons (it inhabits column five of the periodic table).
He then adds a shiny lump of a zinc-mercury amalgam and begins to shake the concoction violently.
Vanadium"The zinc is going to allow us to put electrons back onto the vanadium - the chemical process we call 'reduction'," he explains.
The solution quickly turns green, and then gradually becomes blue. "And if we keep shaking for another few minutes, we will eventually end up with a violet colour."
Each change of colour represents one further electron being passed on to the vanadium.
"The ease with which you can hand electrons to the vanadium and take them away - this is the basis of a very, very stable battery."
Vanadium "redox flow" batteries are indeed stable. They can be discharged and recharged 20,000 times without much loss of performance, and are thought to last decades (they have not been around long enough for this to have been demonstrated in practice).
They can also be enormous, and - in large part thanks to their vanadium content - expensive. The smallest of the "Cellcube" batteries that American Vanadium is producing in partnership with German engineering firm Gildemeister has a footprint the size of a parking bay and costs $100,000.
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How does a Vanadium Redox Flow Battery work?
Vanadium - yellow, blue, green and violet
Consists of two giant tanks of different solutions of vanadium dissolved in sulphuric acid, separated by a membrane
  • The battery produces an electrical current as the fluids are pumped past electrodes on either side of the battery
  • In one tank, the vanadium releases electrons, turning from yellow to blue
  • In the other tank, the vanadium receives electrons, turning from green to violet
  • The electrons pass around a circuit, generating a current, while at the same time a matching number of protons (hydrogen ions) pass across the membrane between the two solutions
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The BBC's headquarters in London - home to 7,000 employees - would need one the size of two 12-metre trailers, Radvak says, perched up on the roof or perhaps buried underground.
His firm is providing the batteries' key ingredient, the electrolyte (the fluid in the battery).
It is the same chemical solution as in Sella's demonstration, and - conveniently enough - is also the end-product of the standard process of using sulphuric acid to leach the vanadium out of its ore.
Radvak says that among his target customers are large corporate electricity consumers such as the Metropolitan Transport Authority, which runs New York's subway, and with whom his firm has just signed a pilot deal to supply Cellcube batteries.
Modular cellcube
Such companies are facing ever higher charges for the electricity they use during the peak hours of the day, and the Canadian claims they can cut their bills by a quarter if they use a battery to draw down the daytime electricity they need during the night, when it is cheapest.
By flattening out demand between the daily peaks and troughs, the batteries also help out the electricity companies.
One of their biggest expenses is investing in the extra power station capacity that is only ever called upon for a few hours each year when the weather, holidays and the time of day all conspire to produce the biggest peak in electricity demand.
That challenge of balancing electricity supply and demand is set to get a whole lot more difficult as ever more solar and wind energy is added to the grid.
Which brings us back to Hawaii.
Rooftop solar panels don't just produce electricity at the "wrong" time of day, they also produce it at a low voltage, which, according to the German renewable energy entrepreneur Alexander Voigt, means it is effectively trapped at the level of the local community.
"Our traditional electricity grid is built in a way that the energy flows from the high voltage to the low voltage, and not the other way round," he says.
That means the solar energy can only be shared among the few households - typically just a village or a town neighbourhood - that happen to share the same transformer station that plugs them into the high-voltage national grid.
Voigt helped set up the vanadium battery company that was later bought up by Gildemeister. He foresees the batteries being built next to transformers, where they can store up each community's daily solar surplus, before releasing it back again in the evening.
It is a rosy image, but it does prompt two obvious questions.
First, why should vanadium batteries be the technology of choice?
For example, there is a glut of cheap lithium batteries these days, after manufacturers built out their capacity heavily in anticipation of a hybrid and electric cars boom that has yet to arrive.
Lithium batteries can deliver a lot of power very quickly, which is great if you need to balance sudden unexpected fluctuations - as may be caused by passing clouds for solar, or a passing gale for wind.
But a lithium battery cannot be recharged even a tenth as many times as a vanadium battery - it's likely to die after 1,000 or 2,000 recharges.
Nor can lithium batteries scale up to the size needed to store an entire community's energy for several hours. By contrast, vanadium batteries can be made to store more energy simply by adding bigger tanks of electrolyte. They can then release it at a sedate pace, unlike conventional batteries, where greater storage generally means greater power.
At the other end of the scale, there are also plenty of large-scale energy storage systems under development, such as those exploiting liquefied air, and the 1,000-fold shrinkage in the volume of the air when it is cooled to -200C.
But these systems take up a lot of space, Mr Voigt says, and are better suited to the very largest-scale facilities that will be needed to serve for instance a large offshore wind farm plugging into the high-voltage national grid.
The second really big question for vanadium is whether the world contains enough of the stuff.
The immediate challenge is that the birth of the vanadium battery business is coming just as China is ramping up its demand for vanadium steel.
But there is also a longer-term problem - the quantities of vanadium added to steel alloys are so tiny that it is not economic to recover it from the steel at the end of its life. So for the battery market, that vanadium is effectively lost forever.
But Mr Voigt remains optimistic.
"Like with all raw materials, it's always a question of how stable is the need of the market, and how big are the incentives for the industry to set up new mines."
With demand on an upward trend, American Vanadium is not the only one trying to fill the gap. For example, rival battery-maker Imergy has developed a cheap ways of producing vanadium electrolyte from iron ore slag and the fine ash produced by coal-burning.
Over the longer term, demand for vanadium steel could be met by melting down and recasting old vanadium steel rather than making it afresh, so that freshly mined vanadium could be channelled into the energy market instead.
And in the very long run, perhaps we will harvest vanadium from sea squirts - there are plenty of them in the Pacific.
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Sea squirts
Sea squirts
  • Vanadium is an essential micronutrient for animals, but toxic in large dosages
  • Some sea squirts accumulate vanadium in their bodies, turning their blood green, possibly in order to protect them from predators
  • Closely related to vertebrates, in their larval stage sea squirts look like tadpoles and swim around
  • But once they find an appropriate rock to attach to, they metamorphose into something resembling a brightly-coloured vegetable
  • They never leave their spot, and feed by filtering tasty morsels from the sea water they pump through their bodies
  • Having committed themselves to this life of tedium, they also digest their redundant brains
  • Some fungi also accumulate vanadium, including the bright red and white poisonous, hallucinogenic mushroom known as the fly agaric

Thursday, 27 March 2014

Nuclear Power in Saudi Arabia



(Updated December 2013)
  • Saudi Arabia plans to construct 16 nuclear power reactors over the next 20 years at a cost of more than $80 billion, with the first reactor on line in 2022.
  • It projects 17 GWe of nuclear capacity by 2032 to provide 15% of the power then, along with over 40 GWe of solar capacity.
In December 2006 the six member states of the Gulf Cooperation Council (GCC) – Kuwait, Saudi Arabia, Bahrain, the United Arab Emirates (UAE), Qatar and Oman – announced that the Council was commissioning a study on the peaceful use of nuclear energy. France agreed to work with them on this, and Iran pledged assistance with nuclear technology.
Together they produce 416 billion kWh per year (2009), all from fossil fuels and with 5-7% annual demand growth. They have total installed capacity of about 90 GWe, with a common grid apart from Saudi Arabia. There is also a large demand for desalination, currently fuelled by oil and gas.
In February 2007 the six states agreed with the IAEA to cooperate on a feasibility study for a regional nuclear power and desalination program. Saudi Arabia was leading the investigation and thought that a program might emerge about 2009.
Saudi Arabia is the main electricity producer and consumer in the Gulf States, with 217 billion kWh production in 2009, 120 billion kWh from oil and 97 from gas. Capacity is over 30 GWe. Demand is growing 8% per year and peak demand is expected to be 70 GWe by 2020 and 120 GWe by 2030. Saudi Arabia is unique in the region in having 60 Hz grid frequency, which severely limits the potential for grid interconnections. Its population is about 26 million.
The Ministry of Water & Electricity (MOWE) is broadly responsible for power and desalination in the country.
It has plans to install 24 GWe of renewable capacity by 2020, and 50 GWe by 2032, and is looking at the prospects of exporting up to 10 GWe of this to Italy or Spain during winter when much generating capacity is under-utilised (cooling accounts for over half the capacity in summer). The 50 GWe in 2032 is to comprise 25 GWe CSP, 16 GWe solar PV, 4 GWe geothermal and waste (together supplying 150-190 TWh, 23-30% of power), complementing 18 GWe nuclear (supplying 131 TWh/yr, 20% of power), and supplemented by 60.5 GWe hydrocarbon capacity which would be little used (c10 GWe) for half the year.
The first of three phases of the King Abdullah Solar water initiative is expected to be operating by the end of 2013. Phase 1 involves construction of two solar plants which will generate 10 MW of power for a 30,000 m³/d reverse-osmosis (RO) desalination plant at Al Khafji, near the Kuwait border. Phase 2 will involve construction of a 300,000 m³/d desalination plant over three years. The third phase aims to implement the solar water initiative throughout Saudi Arabia, with the eventual target of seeing all the country's desalination plants powered by solar energy by 2020.

Saudi Nuclear power plans

In August 2009 the Saudi government announced that it was considering a nuclear power program on its own, and in April 2010 a royal decree said: "The development of atomic energy is essential to meet the Kingdom's growing requirements for energy to generate electricity, produce desalinated water and reduce reliance on depleting hydrocarbon resources." The King Abdullah City for Nuclear and Renewable Energy (KA-CARE) was set up in Riyadh to advance this agenda as an alternative to oil and to be the competent agency for treaties on nuclear energy signed by the kingdom. It is also responsible for supervising works related to nuclear energy and radioactive waste projects.
In June 2010 it appointed the Finland- and Swiss-based Poyry consultancy firm to help define "high-level strategy in the area of nuclear and renewable energy applications" with desalination. In November 2011 it appointed WorleyParsons to conduct site surveys and regional analysis to identify potential sites, to select candidate sites then compare and rank them, and to develop technical specifications for a planned tender for the next stage of the Saudi nuclear power project. Three sites were short-listed as of September 2013: Jubail on the Gulf; and Tabuk and Jizan on the Red Sea. The Nuclear Holding Company was being set up in 2013.
In June 2011 the coordinator of scientific collaboration at KA-CARE said that it plans to construct 16 nuclear power reactors over the next 20 years at a cost of more than 300 billion riyals ($80 billion). These would generate about 20% of Saudi Arabia's electricity. Smaller reactors such as Argentina’s CAREM are envisaged for desalination. An April 2013 timeline showed nuclear construction starting in 2016.
In May 2012 KA-CARE projected 18 GWe of nuclear capacity by 2032 of total 123 GWe, with 16 GWe solar PV, 25 GWe solar CSP (to provide for heat storage), and 4 GWe from geothermal, wind and waste. About half the capacity in 2032 would still be hydrocarbon, with one-third solar following investment in that of some $108 billion. In addition 9 GWe of wind capacity would be used for desalination.
In September 2013 both GE Hitachi Nuclear Energy and Toshiba/ Westinghouse signed contracts with Exelon Nuclear Partners (ENP), a division of Exelon Generation, to pursue reactor construction deals with KA-CARE. GEH is proposing its ABWR and ESBWR, while Toshiba/ Westinghouse is proposing the AP1000 and its ABWR version. Areva is also interested in supplying its technology.
A national Saudi Arabian Atomic Regulatory Authority (SAARA) has been set up and will commence activities early in 2014.

International agreements

A nuclear cooperation agreement with France in early 2011 is likely to energetically advance French interests in the country’s plans. A mid-2011 nuclear cooperation agreement with Argentina is evidently related to smaller plants for desalination. A November 2011 agreement with South Korea calls for cooperation in nuclear R&D, including building nuclear power plants and research reactors, as well as training, safety and waste management. In June 2013 Kepco offered support for the localization of nuclear technology, along with joint research and development of nuclear technologies if Saudi Arabia purchases South Korean reactors. A January 2012 agreement with China relates to nuclear plant development and maintenance, research reactors, and the provision of fabricated nuclear fuel. KA-CARE said it was negotiating with Russia, Czech Republic, UK and the USA regarding "further cooperation".
Saudi Arabia has had a safeguards agreement in force with the IAEA since 2009, but no Additional Protocol.

Sources

Muhammad Garwan, K.A.CARE, Nov 2013, Sustainable Energy Mix for Saudi Arabia.

Monday, 24 March 2014

A plan to turn Japan’s nuclear past into its future with molten salt reactors



March 22nd, 2013
Posted by Mark Halper
Motoyasu Kinoshita NRKno
Moto-yasu Kinoshita speaking in Norway in 2011. Kinoshita hopes to run molten salt fuel tests at Norway’s Halden reactor.
Japan’s fleet of conventional nuclear reactors remains mostly shut following the Fukushima meltdowns two years ago but a significant aspect of it lives on – its high level nuclear waste.
One company has a plan that would use that waste for fuel in an altogether different type of reactor and thus turn Japan’s troubled nuclear past into a revived future.
Tokyo-based Thorium Tech Solution (TTS) wants to combine the reactors’ waste – their spent fuel full of actinides like plutonium – with thorium, the element that many people believe makes a superior alternative nuclear fuel to today’s uranium.
And rather than use the fuel in conventional solid rod form, TTS would put it into a liquid, molten salt form. TTS’ molten salt reactor (MSR) would thus deliver the classic advantages of an MSR, while also helping Japan deal with its nuclear waste. Compared to conventional solid fuel uranium reactors MSRs are safer, cannot melt down, generate less long-lived dangerous and weapons-prone waste, and are more efficient. All the better if they use thorium instead uranium, many believe.
TTS, founded by the late Dr. Kazuo Furukawa, bases its designs on the work of Dr. Alvin Weinberg, who built a thorium MSR in the 1960s at Oak Ridge National Laboratory in Tennessee.
Furukawa started TTS in 2011, soon before his death in December of that year at the age of 84. TTS picked right up where his previous company, ITheMS (International Thorium Energy & Molten Salt Technology Inc.) left off. It aims to build a 160–megawatt electric MSR called a FUJI, and a smaller 7-megawatt model called a miniFUJI (in this case, the word “fuji” implies “the only one” – as in the only solution for a carbon free energy future).
ITheMS, which was run by Japanese politician Keishiro Fukushima with Furukawa as its chief scientist, closed in 2011 after it was unable to secure $300 million it had sought.
MOLTEN IN THE BLOOD
Furukawa, who devoted much of his career to molten salt nuclear research (in the early1980s he worked on an accelerator-drive molten salt system before shifting to the Oak Ridge design), was steeled on making TTS the success that ITheMS was not.
His successors at TTS are working hard to realize that. In a stroke of abject determination, his younger brother Masaaki Furukawa, who is the company’s president, has declared that TTS will build a working prototype by 2018 – not one near the scale of even a miniFUJI, but a tiny primitive version that will produce electricity and prove the concept.
Masaaki Furukawa’s fellow shareholders at TTS include Kazuo Furukawa’s son Kazuro, who is a professor at the Koh Energy Kasokuki higher energy accelerator research group; and chief engineer Moto-yasu Kinoshita.
Kinoshita is also a vice president of the International Thorium Molten Salt Forum and a researcher at the University of Tokyo. We featured him on the Weinberg blog last November from Shanghai, where he was proudly displaying a Chinese language version of Alvin Weinberg’s autobiography, The First Nuclear Era – The Life and Times of a Technological Fixer.
Motoyasu Kinoshita Weinberg Book Halper
The source. Kinoshita displays a Chinese language version of Alvin Weinberg’s autobiography at the       Thorium Energy Conference in Shanghai last November. Weinberg’s MSR design has inspired TTS and other new MSR companies.
I spoke with him  at length this week via Skype, when Kinoshita told me that TTS could begin building commercial FUJIs and miniFUJIs by around 2025.
Obviously, a lot has to happen between now and then, not the least of which will be that TTS has to secure funding.
The company is taking things in stages.
The focus at the moment will require that TTS raise a mere $300,000 – pocket change in the world of nuclear development – to soon test different molten salts. TTS wants to establish which it will use, as it tries to develop a fluid that will not corrode common nickel alloys such as hastelloy and inconel that would form the plumbing in an MSR.
While some competing MSR researchers want to substitute and develop exotic metal replacements, Kinoshita says that TTS is determined to stick with existing materials, an approach he calls “practical and cheaper.”
SEARCHING FOR CHEMISTRY
Instead of material moves, Kinoshita says TTS will apply “chemistry control” to come up with the right recipe of molten salt ingredients that would avoid corroding common alloys.
A typical fluid in MSR designs is a compound known as FLiBe, which is a mixture of lithium fluoride and beryllium fluoride. Kinoshita notes that it is the fluid that Oak Ridge National Laboratory used in the MSR it built in the 1960s under the direction of Weinberg (from whom the Weinberg Foundation, publisher of this blog, takes its name; “FLiBe” is also the namesake of Huntsville, Ala.-based MSR company Flibe Energy, another Oak Ridge inspired group).
In fact, Oak Ridge included beryllium to help avoid corrosion.
But Kinoshita notes that beryllium has its own problems.
“It is not easy to use beryllium – it’s a controlled material because of its toxicity,” he says.
And perhaps more to the point in TTS’ plans – beryllium does not get along well with plutonium, which is one of the “waste” elements that would help form TTS’ mixed thorium fuel.
So TTS is investigating other solutions, such as adding sodium to FLiBe. It is also considering another molten salt called FLiNaK, which is a combination of sodium, potassium and lithium.
Kinoshita is confident that TTS will be able to raise the $300,000, which he thinks could come from anti-nuclear weapon groups who would back the idea of destroying weapons-linked nuclear waste.
THE NEXT TEST
TTS could wrap up its molten salt tests by “this year or next,” Kinoshita says.
It could then focus on a bigger project, would require about $5 million: Testing the behaviour of nuclear waste’s transuranic elements like neptunium, plutonium, americium and curium.
For that, TTS plans to burn simulated-fuel versions of molten salts in a test reactor. It hopes to use the Halden reactor in Norway – the same place where Norway’s Thor Energy will soon begin irradiating a thorium-plutonium mix, with backing from Westinghouse and others.
Other possible test sites would be the Nuclear Research Institute in the Czech Republic, and Japan’s currently halted Japan Materials Testing Reactor.
Kinoshita envisions about five years of the transuranic tests. Then begins the heavy lifting of building the MSR and overcoming technical challenges that all MSR developers face.
FREEZING HOT
Among the hurdles: molten salts in MSRs tend to solidify when temperature drop to around 460 degrees C.  Molten salt reactors are meant to operate at somewhere between 700 degrees C and 900 degrees C. That’s much higher than conventional reactors, and is a reason why MSRs can make more efficient use of fuel (higher temperatures burn more fuel). One of the great attributes of molten salts is that they don’t boil easily – thus they can flow as they need to in an MSR system at high temperatures.
But if things cool too much, they solidify, and pipes can burst. So-called “freezing accidents” would not pose meltdown type threats associated with extreme accidents in conventional reactors, but they would destroy the reactor.
Another challenge: TTS will have to develop chemistry to separate waste from fuel within its reactor. TTS is using a single fluid approach, unlike the dual fluid approach under development at other MSR projects. In a dual fluid MSR, one fluid produces fissile uranium 233 fuel from fertile thorium, and feeds that into a second fluid where reactions take place. TTS’ single fluid technology will have to apply a still unproven technique for separating the fissile uranium 233 from the fertile thorium and from wastes.
On the other hand, companies developing the two fluid approach will have to overcome materials challenges – in a typical MSR design, the silicon carbide that separates the two molten salt fluids can fail (which is why Furukawa decided on the single fluid approach in the first place).
All told, Kinoshita thinks TTS can start building commercial miniFUJIs and FUJIs by around 2025.
As for the 2018 proof of concept model? That will be tough, but not impossible. Scientific geniuses are welcomed to apply at TTS.
Photos: Kinoshita in Norway, Aksel Kroglund Persson/NRK. Kinoshita with Weinberg book, Mark Halper