Member Info for Manwell02

Snaffleman, understand what you’re saying but the royalty deal won’t work like that. There will be a timeline to it and UJO will have to stick to it. They can’t turn around and say “oh please put this deal on hold for a few months so we can raise at a higher price”. EWT & early indications of it will have nothing to do with the raise.

Snaffleman. It looks like it has started going by pictures of the pump on the well.

Why does the UJO placing worry you?

Just had a watch, very good find Heid. Just goes to show that whole industry is interested in this new play and its not just a pipe dream of our JV. Paying for those 3D surveys for phase I & II certainly wont be cheap.

Yeah seen that one before. Was a good flow rate of 3500 and it was only from a formation that was 3.7m thick! They also encountered a high water cut. Still no oil water contact identified at WN which is key.

Heid did you come across what rates Ossian flowed at?

Came across this interview from yesterday.
https://youtu.be/RFzLF8mcGvA

Poiu, as RNS says really. Thou I have read stuff about there being liquids in the borehole (nothing actually official thou) and they wont have been recovered as the pressure in the well isn't suitable enough to bring the liquids to surface on their own, hence they need the use of a pump this time around.

Snaffleman, no it doesn't. They will learn from it and adapt methods on the next drill. This one could also still flow if they manage to achieve a successful remedial job.

SMN, you are correct in what you say but some damage was also caused when drilling. (check UJO RNS - bit more detail) they also state that minimal fluid was lost to the formation in A2 than that of B1z.

If you don't drill a well correctly from the off then it just leads onto problem further down the line.

Uggy, after hearing that it didn't flow I was pretty taken back by it tbh, I was keen to understand why it didn't flow and it was good for the guys to come out and admit that they got it wrong operationally and explain why it didn't flow. For me this is key as its not down to the formation on its own. I'd like to think that they've learnt a lesson in how to drill the formation and hopefully they will look at using a different mud type next time to avoid losses when drilling the reservoir section. It's a new emerging play and they will be learning lessons all the time. Looking forward to hearing what they encounter from A2. My strategy has always been about seeing the results from the B2 horizontal well and then go from there.

Thing is uggy there's always going to be issues in O&G, I see it on a daily occurrence. Things look like they are progressing in the right direction, they are still at site so I take that as a positive. Looks like the pump is back on and testing the upper zone.

Would be nice to see actual confirmation of an oil tanker leaving site with the correct haz plates. Until then I'll take each comment with a pinch of salt.

Also not sure how long the geochemical analysis of the fluids recovered will take. it would be good to know what the API gravity is. gave us the gas and that all looks ok, no flow rates thou but i'm pretty sure the gas is a certain. It'll all be about finding the 'sweet spot' to get optimal flow. Remember this test is still about gathering data for that placement of the horizontal section on the B2 well.

That'll be the waste tanker Rambo. it'll get filled with waste fluids and then once its full a truck will come and latch on and take it away.

So the tank you guys are referring to (if the same one from Adrian's picture) is what they call a pit. The wellbore fluids go into here. If you look at the left end of the pit you will see a blue thing on top which looks like a shaker to me. Below the shaker on the deck is a skip, which will take the solids (if any recovered during clean up phase). Its positioned right next to the rig which is normal.

They will not store crude oil in open top tanks.

Hi Pete, still here, checking in occasionally, just blocking out all the irrelevant noise. Nothing major to add really. Looks like slickline BOPs rigged up on the well. Could possibly be the slugging assembly but hard to tell. 3 guys on site working away. LRP looks like its on the floor next to the two orange barriers in a backwards L shape so likely going to be required again soon or they would have put it away. Possibly the hot oiler on the back of the pick up and trailer in the carpark.

It’s the production tubing racked back in the Derrick in doubles. As they are going to perforate the upper section of the KA they will re-run it again. Racking it back saves time when pulling it if you’re going to re-run it again. They’ll set a plug above the lower zone they’ve already perforated so it’s isolated before moving on to the upper section. Then they’ll run the guns to depth on the bottom of the tubing & start the perforating / EWT for the upper section.

We know the logging truck was on site when they said they was going to carry out the CHLP in April and it was also back on site when they mobilised the rig in late May. At the time I found this rather strange, but could have been a number of reasons for it so wasn't really worth mentioning it, but is now since we are discussing raptor. According to 30th March RNS they said they was going to run the raptor, but from the RNS on 20th April there's no mention of it, only that they got good CBL & VSP data.
Did it not get run in the initial CHLP due to some reason? Therefore was it run on the second visit when the rig was there? going by experience I would go for the latter as I cant think of any reason to mobilise a wireline unit a second time around a month or so later. I thought about them not receiving good data (from the tool rather than what's actually there) but they would have had to run the tool in memory mode and surely they would have sense checked the data before leaving site. however I had a chat with someone about this and for this tool its likely it was run in real time (which means they see the data straight away) for these reasons I don't think it was ever run in the CHLP and was run on the second visit. (tool availability could have also been an issue) truth may never be known and above is only my opinion.

CB it would be good just to have a general discussion with positive & negative points of view without the name calling & constant bickering. Any new investor that pops on the board to get a feel for what it’s like would run a mile after reading the drivel that’s posted on here. It’s clear most have issues with a certain person and that’s fine as it’s up to them, but by constantly engaging & arguing only plays right into his hands.
We all know there’s a 5mil loan available.
We could do with an update on Cali with numbers.
What’s next steps with parta.
Why the cheap deal for C holders.
WN ongoing and flow rates & forward plan crucial to it being a success.
I for one don’t like some of the things the diluting duo have done & I, like everyone else, have the option to sell if we really don’t like it.

Quite possibly. Been a long time since they stopped the test so should know what causes it by now.

Going by the data that I’ve seen to date I’m sitting at a 9 out of 10. Be interesting to see what happens when we go back to A site as we know gas flowed there and fluids did come into the wellbore. If we get OK flow rates from B1z & A2 then the B2 horizontal well will be one to look forward to.

Hi Poiu,

It’s clear to me that they’ve had other operational issues which they haven’t mentioned. Well was perforated 7th June and shouldn’t take that long to clean up. Unfortunately I have more questions than answers. Did they drill the reservoir section correctly, ensuring that no skin damage occurred to the reservoir? Did they encounter any losses to the formation when drilling? Was there losses during the cement job? Was mud & completion fluid weight correct (completion fluid seems not) seems to be too much overbalanced which is why the fluid has gone into the reservoir. Good thing is it is coming back, but they should know how much they lost and how much has been recovered. What down hole pressures are they seeing?

Pics and vids pretty much dried up but it does look like the pump has been on from around 4th July, so tells me they are still recovering clean up fluids. If the recovery stops I’d expect them to perform another slugging run. The recovery of liquids and gas to surface is encouraging but how much has been recovered? The analysis on the fluids will of course be key in determining what we potentially have, would be good to see something in the 35-45 api range so we can actually be told something concrete.

Next month or so going to be crucial, I’d like them to get this first zone to flow before moving to the upper 19 meter section. Everyone just got to be patient and let them get on with it.

https://mobile.twitter.com/leedbartz/status/1415578379693314052/photo/1