Member Info for Monkey_Junkey

You certainly don’t knock off in the middle of a well test, you run shifts, typically 12 hours.

Equipment and crew is rented by the day to work, not for numb nuts to go the bar and get drunk or take days off.

I guess the interesting thing here to know with Chinook is where in the structures we are with the wellbore. We know the lower zone has 1000 ft. of updip. What is the updip potential of the other two zones?

Was the well path planned for intersecting the highest point of all the structural traps, or was it designed to get a hole through as many structures as possible to see what’s there? I would say the latter. Probably constrained by using old well pad as well since this is a broader structure and we’re not exactly horizontal drilling here.

The legacy oil production at Chinook was probably produced until it started producing water. Where was this well structurally? Which zone was it producing from?

The key to Chinook is where is the oil water contact in the various zones, and what is the volume of the trap above the water. We have hydrocarbons proven, the volume of the traps can be seen from the seismic, so we need to stick a well or two into Chinook at a later date to figure out what things look like.

Don’t write it off as worthless.

In the North Sea 9 of 10 exploration wells or worse are dry or non commercial. It is never a thing that every single well will work out.

So the Drawworks is 1500hp electric drive and the 2 mud pumps are 1600 or 1700 hp each, so “total” 4500 hp. Sounds pretty hefty.

I’ll put my money on a 16,000 foot rig being able to reach 11,500 foot any day of the week.

The website is messed up, but if you dig down in the also messed up cached version you can find this text.

2010

Purchased and upgraded “WSPCL Rig 60”, a 16,000 ft. 1,500 HP electric land based drilling rig, and is awaiting a drilling contract.

These guys buy onshore and offshore drilling rigs at least once a year it looks like a lot of activity both onshore and offshore on the page I looked at.

I seriously doubt they would use a rig that they didn’t think was up to the challenge at Royston. The rig will be certified, Drawworks pull tested, pumps flow tested, diesel and hydraulic motors checked. The rig being older doesn’t necessarily mean it won’t be able to drill as deep. The structure and associated equipment are dimensioned for the depth. Probably been some things replaced and upgraded as well if it is older. Anyways, here’s a video some of you might enjoy. These land rigs are neat how they move around. I’m just used to massive offshore stuff, so these things look like toy.

https://youtu.be/VDy1qUDQA_8

Does it have a top drive installed?

What do you mean “IG is being lifted”?

The transit time from say Houston to Trinidad is 9 days 9 hours at 10 knots.

Why would it take 6 months to get a rig from the US to a Trinidad? The Gulf of Mexico is just a short boat ride from Trinidad, it’s not like the rig is coming from Mars .......

He has also different messages from the equipment owners about when the equipment would be available.

For example a contract might have weekly extensions that have to be declared 5 days in advance (and then this can be done repeatedly), and then at some point move over to daily extensions that have to come with 2 days notice for example. It’s very frustrating to be on the other side of such a deal. It is not uncommon at all to have an extendable period of two months.

Also, the equipment owner might not have informed of pending certification date, but even if had, was probably unaware that some part would fail inspection, and then this had to be manufactured (they don’t sell this stuff at IKEA). This part came from abroad I think. It can also be a customs clearance headache to get things from offshore rigs back on land, although this varies a bit from country to country.

So Paul’s been pulled along with continually expectation that equipment would arrive soon and it dragged out and dragged out. Should have informed market in beginning of March when info from last public communication turned out to be delayed further, but other than that I can guarantee you that this has been quite frustrating for him as well as it has for us. He hasn’t intentionally misled the market with deadlines, he has simply tried to keep up with delays, and not RNS every time he got an updated timeline (which in all honesty could have been too often, or even the supplier which was not very good at communicating the current status of the equipment and managing expectations). Matte even afraid they would try to find a different solution. Happens sometimes that too.

The gas zone at Chinook is not possible to test during the oil EWT. The pump and tubing will be removed, the well packed off (packers can be a permanent set or removable types exist as well, but probably permanent), and then gas zone has to perforated. There will be some circulation of fluids with different densities in the process as well to keep the well under control during these operations. Remember that it also takes time to get the pump installed and everything else to even start the EWT test.

I don’t think they were done with oil EWT test yet during the presentation. I think 2 tests Paul is referring to are the two short interval flow tests that showed oil and water at the bottom and oil further up (notice lack of water). I haven’t heard the presentation yet, but this is a logical explanation which fits with what people have written.

We all agree it could have been communicated better, and Paul has acknowledged that. Let’s give him a chance to communicate and if this time it’s not proper ever single one of us should bombard him with e-mails to show we are not happy with the way things have been communicated. Give him a chance first after acknowledging the mistake last time.

David Black - stop ranting about the delays. There is one kit on the island for the gas test. It was in use longer than anticipated by another client, then had to get repaired and recertified. I have taken huge pieces of offshore equipment on contract extensions many times and even for weeks and weeks. It’s how the business works, you have weather delays, project delays for whatever reason, sometimes you are in line, every single contract I have ever been involved in has extension agreements.

Oil companies will rent harder to find drilling equipment, have it on land or on the rig, JUST IN CASE they might need to use it during a period. This means other can’t use it, but it makes financial sense for them to do this to avoid extremely costly delays on offshore rigs.

This is the biggest test rig in Trinidad. There is only ONE of them. There is also a finite number of people that are qualified to run this testing equipment as well, so just stop it with the ranting, it’s getting quite boring.

The test equipment is the same as was used on Casc and Coho. It’s not bigger, better, or anything, it’s the same. It’s the largest on the island, I asked Paul directly in a webinar about using larger equipment and he said no they wouldn’t, it’s not necessary. In all the comments from Paul there has never been anything to indicate a different set of equipment, so I don’t understand why people keep saying this. It’s the biggest one, it’s the only one, and that’s why when others using or being certified and repaired, it was not available and caused the delays we have. Really really simple people.

Flow testing Casc Deep could have been done if the equipment did arrive as indicated. Paul did not say whether he would release after flow, or after both flow and pressure buildup were completed which takes more time. I think they should have done it after flow, cause anyone watching would have seen the flare, but he might think after having the complete test of the zone. Seems like Paul doesn’t like to RNS very much for some reason.

The extended oil test - stop being so bothered about it. It’s called extended for a reason, but who cares, these oil sheets we’re not even an original target, and are likely not drilled anywhere near the optimal placement for an oil well. The lower zone has 1000 ft. of vertical from where it was penetrated. These two zones may mirror their shape a bit, we don’t have any info let, but the positive is we found oil and there are better places to produce it.

On the idea about comments that testing is already completed on 2 zones. It was, Paul talked about this before. 41 API and 35 API ......... so how in the world do they have two different oil weights? I’ll tell you, they tested the lower, got 41 oil and water, they plugged if off and then test the upper oil zone and got 35 oil. So, now they have completed two oil flow tests. AFTER completing two flow test for oil, then decided to put the upper oil zone on an extended well test and were going to install a pump. So this is the 3rd oil test. We have the results from the first 2 tests, we are waiting for results on 3rd oil test which is EWT.

It makes sense to move over to Chinook gas zone while Casc Deep is on pressure buildup because this takes some time to perform.

Seems like some people are trying to create confusion about testing and decamp a bit, or they are just not paying attention to the details.

Can’t watch the presentation, downloaded or viewed by too many people. Can someone post it again?

Disgusting really, I’m down to selling bodily fluids to top up because I have no more cash!

Oil is moved in trucks all over the world. This ESG nonsense is not going to stop them from moving oil in Trucks in Trinidad, like they already do 365 days a year by the way.

The extended flow rates also give you an idea about permeability which is useful for field development.

Flowing longer also cleans up all the drilling fluid crap the volume around where you are producing gets loaded with, so gives a better fluid sample.

You plan where to put further wells mostly on structural data from seismic and well logs showing OWC.

I think they will produce gas from this well if the gas test is good. The oil section will be plugged and abandoned after this extended test. Although I would love to see an extended extended extended oil test to truck to cash in bank while we are waiting for the pipelines to built and connected.

Oil will be produced from other wells.

The extended oil test is to monitor flow rates over longer period of time so you don’t make decisions on a very short flush flow rate. It’s a good thing to do, but it doesn’t mean this zone will be commercial in this particular location, only the test will determine that. Remember also that this well was probably not optimally positioned for the lower zones, but the upper zone which is yet to be tested.