Member Info for Monkey_Junkey

https://youtu.be/sP2tUW0HDHA

Thought didn’t cross my mind, but I guess it takes one to know one Buffy. Thanks for input.

I’m constantly working on my tendency to over estimate the intelligence of the general population, and it is constantly being revised downwards at an ever increasing rate, especially the last couple years. There’s not much hope left, and while I used to think I wanted to live forever, I’m starting to wonder if the world is going to turn into a place not worth living in before I die.

Idiocracy is a comedy about dumbing down, that is sadly turning more and more into a documentary about where we are heading.

The really amazing stuff is offshore deepwater, if we had put anywhere near the resources into Space Exploration as we have put into the oil business, people would have been living on Mars a long time ago.

When test 3 comes in good with oil, I can only imagine the banks are going to be fighting with each other to lend money to TXP to get the development drilling running as fast forward as possible. Wouldn’t be surprised if we end up on 3 drill rigs in 2022.

The price of the debt, and the price of the wells here with very simple topside equipment required is ridiculously low, me as MT pointed the opex for higher production figures, are going to be much lower than for legacy production, which means higher net backs. We might be sitting on billions of dollars in netbacks for just this well, and the company is market half a billion, which doesn’t even cover all the other stuff we have found already.

I really don’t understand why the market doesn’t get it.

I really don’t understand why a lot of people are now happy when before Paul’s video, they were unhappy. He just reiterated what was said, and what was said between the lines in the RNS. The RNS is all we needed, and should have rocketed on, but I guess we just wait for the next test results before Christmas before everyone rally can admit to themselves that they “get it”.

Some people don’t get it even if it’s written on their foreheads and they’re looking at a mirror.

The book has tight spreads and is filled by individual orders. My orders or when I buy and sell on the first line of the book, or if I take a big chunk er and chew through the buy or ask side of the book have nothing to do with a market maker, they are orders placed by other investors, and maybe the market makers whose job is to help creat liquidity when there is none.

If I hit the bid or hit the ask, or have more patience and put out an order out of the money fishing, doesn’t really say much to anyone. Maybe I just don’t care to wait, either buying or selling, maybe I have something else to do. Could be any number of things.

Sales of 100.000 shares or more may have some meaning, all these little 10 or 1000 or 5000, don’t mean anything, so stop trying to pretend it’s some way to predict the future, it’s not.

The same with TA in TXP, go jump out the window with that, doesn’t apply to a company like this. You can apply it to large volume large cap where a bunch of other people are also tryin to apply TA. Do the markets move independently according to the rules of TA, or does the rules of TA tend to influence investors into making the market move like the rules of TA? I think you know the answer.

Here is a good video showing some flow testing elopement, and basically what the topside equipment that is required at Royston will look like. It’s not rocket science, it’s not huge and expensive, it’s relatively small, cheap, and simple.

Now let’s bring on the long testing and production, and get the drill but churning out cash. Those hoping for a raise can go jump in a lake, it’s looks like we are sitting in a mighty fine position at the moment.

https://youtu.be/F1IVAu6t05U

There are some very neat ways to deal with water and unwanted gas as well …… check out these videos. The second one is what Petrotal uses.

https://youtu.be/E2g4hxGZP94

https://youtu.be/QJt2fXCcGJw

That was a copy paste to not have to write so much, but the short answer is tubing diameter affects flow.

Also, in the oil test string which will be a smaller diameter, they will likely have more “equipment” on it like inflatable packers and valves, etc, so they can isolate portions of the well perforations and only test that particular interval. It would be like being able to test only the second floor of your house through the windows instead of only having the option to test the first, second, and third floors all together.

So what the RNS is saying is they didn’t have the ability to isolate any part of the perforated section, and therefore produced water from the lowermost perforations. If they were able to pack off the lower section, the results would have been much less water cut than 90%. I don’t know how much less, but now that they know what they are dealing with, and have the fluid at surface to measure resistivity of the water and oil, I imagine the well logs might give them some better understanding or idea where there is more water, and where there is more oil. It would be interesting to see the well logs, but they probably don’t want to show them in public.

A note to those talking about Shell and gas, and now we have oil. From what I recall, Royston has always been termed a “gas effect” by Touchstone, this doesn’t mean it was a gas discovery, it means there is little information from that time, and some gas was indicated. There was solution gas produced with the oil during the Touchstone flow test.

Shell never got far enough to flow test the well, and thank oil god for that, now the oil is ours instead of being on production for Shell the last 60 years.

artificial lift production period. For a waterflood- ing oil field, after entering the high water cut period of the oil well, the large-size pump with a high pumping rate should often be used in order to ensure stable oil production and rational pro- ducing pressure drawdown. For a different lifting mode, different tubing and production casing sizes should be adopted. The pump diameter should be determined in accordance with the daily fluid production rate during the whole development period of the oil field, and the corresponding tubing and production casing sizes are then selected. In addition, different tubing and production casing sizes are required by stim- ulation and sand control technology. Therefore, the tubing and production casing sizes can only be finally determined after all of the aforemen- tioned factors are taken into consideration.
By comparison with other production modes, under flowing and gas lift production modes, a certain production rate and a certain tubing shoe pressure (flowing bottomhole pressure if the tub- ing shoe is in the middle of the oil reservoir) should be maintained. Under the other produc- tion modes, the flowing bottomhole pressure can be reduced to the full extent if that is allowed by reservoir pressure and casing condition.

Tubing is one of the important component parts in the production system of a flowing well and is the main channel for oil and gas field develop- ment. The pressure drop for fluid lifting from the bottomhole to the surface can be up to 80% of the total pressure drop of the oil and gas well system. Any oil well system has an opti- mum tubing size. Undersized tubing will limit the production rate due to the increased friction resistance caused by excessive flow velocity. Contrarily, oversized tubing may lead to an excessive liquid phase loss due to slippage effect or an excessive downhole liquid loading during lifting. Therefore, sensitivity analysis of tubing size should be carried out using the nodal analy- sis method. On the basis of the sensitivity analy- sis of tubing size, the tubing and production casing sizes required during the flowing period can be determined. However, the production casing size of the well cannot be determined yet. The reason is that the tubing and production casing sizes of the oil and gas well should meet the requirements of the well during the entire pro- duction life, whereas the flowing period of the oil and gas well is limited, and the tubing and pro- duction casing sizes are often on the small side. After the flowing period, the oil and gas well may turn to artificial lift production. The tubing and production casing sizes in the flowing pro- duction period of an oil and gas well cannot meet the requirements of stable production in the

That’s fuc nut that got bleeped

Lol, didn’t see that strong sell. Must have touched the wrong place on the iPad when I was writing.

TXP has been a strong buy from my side since the 0.20 cad days …….

And Sunbed has continued to show that my original post here was spot on the money. What an ABSOLUTE TOOL.

Not that being overly harsh here either, see that others have used the less refined language “over there” as well and told him what a total fu**** he is.

I am absolutely amazed by the absurd amount of really stupid posts today on the various forums.

And on top of that we have a new village idiot named Sunbed, who swooped in to take the crown with flying colors, like he’s wearing a rainbow cape and has super powers of stupidity. Challenging Paul’s background and asking if anyone has Paul’s CV after he flip flopped around like a fish out of water selling and then suddenly buying and then bashing and thrashing around like a child throwing a tantrum puking nonsense. You should be embarrassed of yourself Sunbed, but you’re not smart enough to realize how dumb you look to the rest of us. Please sell all your TXP stock and go away, we had a nice board before you came along. The filter button is tired.

To be honest, it’s not as straight forward as some people think from the well logs. If it was, you wouldn’t see the outcomes we are seeing where the thought is one thing and it turns out to be something different.

After the first well in area, you have more information to further refine your model of what is actually below your feet.

To be honest, the oil business has some of the most advanced technology that exists in the world, and some of the technology that exists is extremely impressive compared to pretty much anything else.

Here is an excellent post from Linz22 in case anyone doesn’t read “over there on that other place”

I was kicking myself first thing this morning upon reading the RNS for not buying the a dip on Friday evening. But the market's misinterpreted the data and I can't believe my luck that the godsend of second opportunities presented itself to top up at 117p, having had t osell out something else at a small loss to do so. Make no mistake, this morning's news is hugely positive. For those who've erred(and sold!), by fretting over the produced water, it's necessary to understand that they're drilling in a complex thrust zone - meaning that area is heavily faulted where broad 'sheets' of strata are pushed by compressional forces to lie over the top of similar strata to which they were originally juxtapoosed, or even lying beneath. Such an conditions typically give rise to severely geological abnormalities, such as unexpected overpressured zones, which can be treacherous to drill through - hence the afforementioned 'heavy mud previously used. And also, as in this case, to misplaced geologic and fluid cycles, with water lying atop of oil. But that phenomenon is only apparent as the water exists at the base of the reservoir strata of the thrusted sheet, underlying the oil in that section, but which in turn now finds itself overlying the oil in the reservoir section of the strata below it and the fault plane. It's not, stricly speaking, even a case of the water being 'perched', or stranded in that position (a phenomenon that's attracted a much maligned discussion over on another, similar, oilie forum) as it's not out of its natural position per se, it's just displaced by faulting to overlie a second oil trap below. The 90% so-called water cut, refenced in today's RNS, is the result of a very simple miscalculation in the placement of peforating, which has accessed the water below the OWC of reservoir section in the upper thrusted sheet. A 'schoolboy error', perhaps? But, at least they now know where that OWC is and, moreover, it's a minor issue that's very easily remedied. It's worth taling stock that this is an investment forum, not some social media page for inane gossip, so everybody's shared purpose for being here should be solely to help each other realise a profit on their investment. The message forwarded by Bernieman is correct and my advice here, then, is to BUY (and if it goes down more, fill your boots). Now I'm only kicking myself for not getting in at 114p -hopefully the bottom.. By the way, I believe Pro's hypothesis to be right, re up dip from Chinook. That would be huger still, and I'm putting my money where my mouth is

Are Spawny and Sunbed one in the same muppet?

I wish they would ride off into the sunset together on a horse named Buffy.

Posting thoughts with no grounding what so ever in technical facts or theories doesn’t exactly increase the value of the board, and on the contrary serves to decrease the value by confusing others with misinformation.

NGMS27 has some different ideas on horizontals and compartmentalized water, or no water at all, communication and aquifers thrown in to make it all more interesting.

I’m not a reservoir engineer with a specialization in fluid dynamics, and don’t pretend to be one. For simplicity, I tend to think of the discoveries as conventional, with gas on oil on water. It’s not impossible to have extremely complex geology like NGMS27 is describing, but at the very least I would have to say that we haven’t seen anything even close to the amount of information we would need to see to be able to ascertain that this is the case with Royston. The team working with Royston will have all of this information, and so for us, it is better to go from the guidance from the management which is a summary of all of this information we don’t have access to.

Maybe instead of Paul giving a presentation on proactive tonight, he should send Xavier instead with a technical presentation.

Maybe NGMS27 has seen more information than we have, maybe he is just taking the most extreme possibility that could exist and throwing it out there?

Still, at the end of the day, it’s an oil discovery, it’s fairly light, and the areal extent is huge, so we all won the lottery (again) even though the payout isn’t coming today.

I’m very interested in the high mud weight needed to kill the first test from crap rock, and the possibilities for multizone long term production testing. How long can we possibly be on “long term testing”. Pro mentioned 12 months ……. That would be fantastic if it were true, we can test the next zone and then immediately bang out cash while all the paperwork is being completed for permanent production, and smoothly transition the paperwork while never ceasing real production.

Those that don’t understand the technical aspects of the RNS will freak out about water cut, not understanding that this can be isolated and largely reduced in the lower perforated intervals. They have perforated this long section with spaces between the guns, so if there is an oil water contact, this can be blocked off in the well.

Also, water is not a show stopper in any way shape or form. Might I refer to PTAL where they have up to 95% water cut and reinject the water. PTAL are also drilling horizontal wells, all from the same pad, and having production of several thousand bopd from their horizontal wells. They drill long horizontals, and use these really cool inlet valves on the production tubing that limits water production passively through physics.

So, TXP is going to have good possibilities to isolate the water, so this is not an issue. They can drill horizontal wells from the same pad for oil production which can be immediately monetized, and will require no pipelines to start, but an oil pipeline eventually will be more efficient. Oil is worth more than gas.

THEY HAD TO USE HEAVYWEIGHT MUD TO CONTROL THE OIL FROM THE FIRST TEST !!! Because it kept wanting to flow from the “crappy” rock under high pressure.

This RNS is fantastic, but you have to have a much higher level of understanding than what is average in here and on the other forum. Spangle, myself, and a couple others are the ones you should be listening to if you don’t have the knowledge to understand what is being said here. Pro nailed it with oil.

We need to find out where the owc is at Chinook.

It’s going to very interesting to look deeper under Royston, this charged oil discovery didn’t come out of thin air.

DON’T FREAK OUT ABOUT THE WATER CUT, IT’S NOT A HUGE PROBLEM. They designed the completion to give them options in case there was an oil water contact. Water will flow into the well easier than oil, so the water in the lowermost interval is the predominate flow over the entire interval, this will be drastically reduced or eliminated when the water perforations are isolated.

Gambflin - I accept payments in both dollars and pounds.

I’m currency non binary, they both work for me.

In the old days, before people felt the need to make up a bunch of new words, I would have just said that I go both ways, play for both teams, or take anything I can get.

I’m just gonna throw 3 billion out there as a reference point, which would mean my part is like ……….. oh god, I jizzed in my pants!