Jeff Geringer Profile picture
Oct 18 7 tweets 2 min read
Greetings from the NEI International #Uranium Fuel Seminar in sunny Las Vegas. Step into my office.

Day 1 thoughts in no particular order:
A major nuclear utility discussed the impact of the Inflation Reduction Act. New economics might justify unit “uprates,” i.e. increasing the power level of existing reactors.

Bottom line: ~6% generation increase (probably with proportional #uranium demand increase)
There’s enormous promise for small modular reactors (SMRs) - but it’s not clear when these units will actually need uranium (or even when they’ll get built). The DOE seems aware of the challenges and they’re ready to help create a “demand signal.”
Esp. for restart projects, there has been a significant change in lead time for parts. And many of the suppliers from the last cycle aren’t offering the same catalogue of goods. Plus competition with O&G for similar parts and equipment. Experienced operators are dealing with it.
We’re still at the same starting contest/stalemate we’ve been at for a while. US production has some near-term restart capacity but uranium isn’t quite at their target price. Different producers are taking different preparatory steps to be “nearer” to production.
Ammonia, sulphur, and hydrogen peroxide. This is your unholy trinity of mining cost inflation for the near term. I’m tracking these input costs as I evaluate (back of the envelope) where existing/returning projects might end up if they’ve got stale cost estimates.
Anyway - off to more meetings. Be back tomorrow with Day 2 thoughts. Cheers!

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More from @808sandU3O8

Sep 5
It’s a little too early to expect model updates, but the 2023 editions of many #uranium s/d forecasts are going to be messy.

I’m expecting both secondary demand and secondary supply within the enrichment models, and both inventory drawdown and restocking depending on region.
One major thing to sort out will be how uranium inventory is distributed within the utility sector. How convergent are {Russian exposure, uncovered SWU requirements, low inventory levels}? E.g. are the utilities now signing high assay SWU contracts also lighter on U inventory?
So the West will see total uranium requirements go up ~11% if operational enrichment tails assay moves from 0.18% to 0.24%.

But if utilities with less enrichment coverage are also light on inventory - their U needs could increase 26% as their demand is less buffered by inventory
Read 5 tweets
Aug 31
@ChapmanScpa does some good work here with the information that is available to him. And here I am to offer my extra bit of colour. A few of my thoughts below:

#uranium
Firstly - Chapman identified the enrichment level of some inventory (~2%) and that BWRs are wonky. Put another way - if one were to sell material, it’s easier to sell “standard assay” in the 4.X range (esp 4.95%) and harder to sell low assay odd lots.
Secondly - it is my impression that Japanese nuclear fuel accounting uses purchase price rather than mark-to-market accounting. So generally speaking Japanese inventories contracted pre-2011 are probably MORE valuable than market and may look more valuable than they actually are.
Read 11 tweets
Aug 29
This conflates two diff things. Russia is allowed to import ~20% of the EUP used by US reactors, and it possesses 39% of the global nameplate SWU capacity.

B/c of trade barriers, TVEL produces less enriched #uranium per input SWU because much of their capacity is excess.
Europe is, on the whole, slightly more dependent on Russian EUP (and fuel fabrication services) - and Europe's Russian uranium imports policy is a recommendation unlike the US', which is law. In 2020, Russian uranium was roughly 20%, and Russian enrichment was about 26%. ImageImage
In a post-Ukraine War, self-sanctioning world, it seems unlikely that the Russians will be sell any of their currently-unfilled RSA quota, so real imports will likely be less than quota in future years.
Read 5 tweets
Aug 8
So how does a nuclear production tax credit (PTC) increase #uranium requirements? Five key areas:

1.Existing reactors stay on
2.Reactor lifetime extensions
3.Reactor cycle length extensions
4.Reactor power uprates
5.Reduced need for flexible operations
Many US nuclear reactors face periods of negative power prices which are in part driven by existing PTCs for wind & solar. With the certainty of all nuclear generation being worth at least $15/MWh, operators can more easily justify capital expenses to keep existing plants running
Especially as many reactors consider lifetime extension to 80 years – a process which will require significant preparation, upkeep, and maintenance to achieve – the PTC provides more certainty for operators in these investment decisions.
Read 7 tweets
Jul 26
I often hear that #nuclear power and #renewable energy can't work together.

In reality: they can, they do, and they will.

And they must.

Nuclear power is learning new tricks to adapt to electricity grids with high wind/solar fractions. Let's talk about a few:
One of the core features of nuclear power is that a reactor can run at 100% power for 12-24 months without interruption. It's baseload power.

But reactors change power level all the time - for maintenance and when the grid requires it. And the modern grid *will* require it.
The nuclear industry calls it "flexible operations." If power prices are very low a reactor can reduce its power level to minimize grid congestion.

No control room in the world wants to change power if they don't have to, but nuclear (and coal) are learning to be flexible.
Read 7 tweets
Jul 7
Not exactly a revelation, but the #uranium daily prices are often indicative and sometimes move on zero volume. *Literally* zero volume. And this has been true recently for small price movements in both directions.
We want a daily price, but it feels like a “data vs. information” situation. Unlike, say, a front-month oil price which carries location, specification, and timing information, uranium is fuzzy.

Spot is 15 days out? A month? A year? Price is only one datum we need to understand.
100,000 pounds U3O8 (standard volume) is 0.06% of annual requirements.

As a percentage of total volume, that’s like an oil future being 800,000 barrels rather than 1,000.

It’s not worth comparing the spaces too deeply, but a few dozen shares of SPUT is more “future-sized.”
Read 4 tweets

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