Member Info for Adon30

https://newsday.co.tt/2023/01/23/young-tt-making-strides-with-hydrogen/

“ He said works on the carbon capture sequestration and utilisation (CCSU) process are not moving as quickly as he’d hope, but it is happening. CCSU is a process in which carbon dioxide emissions from coal-driven power plants are either reused or stored, so that emissions do not enter the atmosphere.”

As well as the freezing conditions there is a blanket of snow across Utah. Visible on satellite for the paradox. Will expect that to have slowed things substantially.
For them to cope with the 36-2 drill and those conditions while operating safely is testament to the crews working.

Cloud, temperature and Moisture can all have a big effect on those images. They are good for confirmation of something being there or not.
There may be less reflections as there’s more metal pipe in the ground rather than laid out on the pad….

Theirs is no flare or fire. Easy to tell as I’ve mentioned.
Looks like the passing clouds cooled things considerably and possibly some rain.

If a flare suddenly appeared it could be for safety reasons. ZPHR had an almighty kick while drilling an oil reservoir and are now flaring over pressured gas via the rig to stabilise the situation.
Not expecting this with PRD but be open to all possibilities.

Would expect flaring during flow testing a few weeks after drilling complete.

Even at school gas was lighter than liquids…..

The flare is like a pressure relief valve.
I used the bottle of coke analogy several times. If you open the lid a tiny bit you can release the gas without loosing the liquid. Open it quickly and everything can come whooshing out until pressure is equalised.

Another thought. They said that they had a ‘kick’. They would have known that they were close to the reservoir by the vertical depth (vertical in this instance doesn’t mean they went straight down, you can go at an angle and still get to the same depth. Just takes longer!). I would have assumed at this point that they would have increased the mud weight. So if they still had a ‘kick’ it must have been a lot more than they were expecting. And more than the state 16-2. The analysis and results are going to be interesting.

I posted a section of that earlier as well blissful. You do wonder whether people read things…

It was supposed to be a 10,000ft lateral as well so we may have seen something like X ft was completed if so. Seems like a straight hit as they entered. These wells do seem fairly high pressured. Almost like a coke bottle that’s been shaken and ready to go.
The TP note said 3-4 weeks to evaluate so won’t be long before they have more details.
As you say McDoog there’s no point guessing as there’s several things that they could do.

I'd have thought that they would have started 'turning the corner' when they hit it. But no horizontal. And they did get to the full vertical depth (cane creek reservoir)

Zephyr’s Board has not yet formally decided on the Well’s next stages of development. These are expected to be considered over the next three or four weeks, whereupon the detail will be provided to shareholders. While potential volumes remain unknown, a ‘significant kick’ was witnessed upon reaching the Cane Creek reservoir. Subsequent ‘wet’ flaring indicates a range in the expected hydrocarbon mix (gas/oil/condensate).
The Board’s most likely choice is expected to be to complete a standard natural fracture well, while still retaining the option to return to its originally proposed hydraulically stimulated lateral at a later stage depending on the underlying rate of decline. The alternative could be to keep with existing planning while seeking to manage pressure blowouts as they occur. Based on the more likely choice, the Well could be on schedule for a production test during Q1 2023.

They have poked into a Gas and condensate pocket by the sounds of things

That is definitely the $64,000 question.
At present the well is not completed with production casing. So if they went that route they would still need to complete that first and then 2-3 weeks for flow tests and results. If this is going to be as prolific as they say I can see them needing a lot of liquids storage.
Last time for the state 16-2 lateral they tip toed into the stimulation. Testing bits and needing fracking fluids and sands. These are (possibly) not going to be needed here. That will also reduce the OPEX on this well.
They know a lot more than me about these wells so I trust them to make the decision that is best.

As I've mentioned previously. I am not sure now if they will progress with the 36-3 at this location into the C9 overlying layer. Again depends on their plans which will hopefully be released in the coming weeks.

I don’t think it will be BP. Very unlikely that they would be interested, although stranger things have happened.
It’d more likely be someone like Whiting or Dominion. Or similar…

Encountering natural facture networks has historically been the key to delivering major wells in the basin. For instance, the Cane Creek 12-1 well drilled in 2012 recovered 1 mmbbl and flowed at IP rate >1.4 mbbl/d with no decline over the first few months

It doesn't look like a lot of gas. Just using it to stop pressure build up in the system. A bit like opening the lid on a coke bottle slightly to stop it exploding when you open it.

Ezhik. A bit of a double edged sword. I think more positives than negatives. They have found good hydrocarbons so not a duster which proves the acreage that they have. Previous completion blueprint is out the window as you say. But others across the Cane Creek have hit natural fractures and produced from it very well. So they have previous completion methods available to them. Just a matter of time now to stabilise and keep things safe.

What do they say...
The most testing times are the most rewarding

I think it would have been quite scary stuff when they hit it. Working in freezing conditions with snow and rain can drain a crew. But as they say they had planned for the eventuality and have got it under control.
Now the evaluation begins to get producing hydrocarbons.
I wonder if the university will be involved.

WOW. That is amazing.
They have encountered no end of problems with getting this drilled and then they hit something that is going to be 'prolific' and produce without a lateral or fracking.
Sounds like they have it under control now. Shame the weather couldn't have been nicer to them as that has hampered them all the way.
I think they may have to forget about targeting the C9 layer from this well but the Upside from the other part is tremendous.

I did think that their 30 day timescale was quite ambitious.
State 16 took 27 days to drill the vertical and then 27 days again for a 4000ft lateral. This is a 10,000ft lateral.
They also had a few weeks of issues at the beginning of the drill with commissioning and as pointed out need to complete a data collect during the drill again which will add more time. I would still be leaning more towards an 8 week drill than a 4 week one.

Yep, weather in Utah is not great working conditions for drilling or oilfield work this time of year. Currently between -5 and 5 degrees C with snow and rain showers.
Yes you can drill in the cold. The artic rigs (mainly) drill when it is super cold but they are designed for the conditions. They even have internal pipe storage so that ice and snow doesn't build up on them and affect the steel. Even then conditions can be dangerous.
The original State 16 vertical was drilled in cold conditions and credit to the crews for completing it.
I wouldn't be surprised if the pace has slowed due to the conditions and for safety reasons across all current operations