Member Info for Manwell02

No squeezing here. Will be a full bore cement job with a 2 plug system.

5 to 7 days lol Will have approx 122 joints to run and should average 10 joints/hours (a slow rate). Plus add couple hours messing about with shoe trac & hanger, the casing run should take roughly 14-16 hrs. Won’t be a big cement job & pumping should only take a few hours & depending on recipe waiting on set time could be anything from 6-12 hours which will be followed by a pressure test. Whilst waiting on cement common practice to lay out previous drilling bha & make up the next one.

Today is day 19 of ops as spudded 4th Oct.

Just seen latest video on twatter and carousel looks empty of drill pipe so could be (& I emphasis could be) at section TD point. Hopefully we will see a trip out of hole followed by a casing run over next few days.

BH that would be the most sensible thing to do. Will get shows on LWD & mud logging which they should announce. Then once drilled that section carry out Wireline logging & coring ops (which they can release individual prelim findings). Providing the data is good all should have positive movement on the SP. Hopefully the duo release 3 RNSs rather than 1.

Can the casing run be seen via footage?

Ugly, everyone has their own opinion of who it is and why they are selling. Details for the SPA with Humber detailed in the RNS below. £1.4 million in the O&G world won’t go far so they will definitely want to be increasing that amount by offloading their allowance.

https://www.lse.co.uk/rns/RBD/acquisition-of-further-16665-in-west-newton-nk46v3zftzoqyuk.html

SP still 25% below last November placing. How many II’s will sell at a loss.....Humber skint & have to sell in an orderly fashion... I know who my money is on doing the selling.

No worries at all Rubey.

The separator & flare will only be used during the well test so we will not see any flare during the drilling phase.

If you google something like drilling mud system you will get to see how it works during the drilling phase.

The drilling mud should be heavy enough to prevent the hydrocarbons returning to surface. Once the well has been drilled the main rig will be demobbed, a smaller workover rig will be used to run a production string plus turn the well over from drilling fluid to completion fluid (this will be a lighter fluid to help the hydrocarbons “come in”) there will also be a run to perforate the casing & formation. This will be the point that we would see the first sign of the flare as they start to clean the well up & produce hydrocarbons.

If the deeper cadeby is successful & depending on the data they will test that first then work their way back up the well to the KA. Once the cadeby has been tested they will isolate that zone by setting & packer.

Hi Rubey, apologies missed your post.

I’ve never encountered anyone flaring off during drilling. Some rigs do have this capability but the amount of hydrocarbons need to be excessive. Normally if a high amount of hydrocarbons are encountered when drilling then the well is shut in and the hydrocarbons circulated out & the mud weight increased. Each situation is different and can be got under control within hours. However I have heard of situations where it’s taken weeks and even resulted in clients suspending the well because it cannot be drilled conventionally. Most of those clients turned to MPD(Managed Pressure Drilling) to drill the well second time round.

Also remember they are rigged up for drilling, therefore the well test equipment won’t be rigged up to connect to the well test flare.

No I don’t, but I don’t claim to know what’s exactly happening in the other industries, that’s the difference.

The photos are good only if you know what you’re looking at. I told one of them yesterday about a sequence of events and how long it would take but they’re into believing what each other says and they make themselves actually believe it. Calling a cement unit a logging truck and guessing what’s happening next. It’s laughable to read. 95% don’t have a clue about the industry they’ve invested in.

But the steps aren’t right Heidi. No mention of installing the wellhead after 13 3/8” then the BOP & pressure test. Then drill out the floats, carry out a FIT prior to drilling ahead. If lee has spoken to someone who knows oil & gas then I would question their knowledge! Couple of days work there at least before drilling starts in the 12 1/4” section. I’ve not seen any evidence of any 13 3/8” casing being picked up yet either, so could just be a trip for the bit or tool failure.

Jeez you would think whoever does share talks post actually had a clue about the oil industry. Casing comes after drilling so they wouldn’t be there now and roughnecks work the drill floor not roustabouts.

Not sure who told you that but it’s less valuable than a good crude between API 40-45. It’s also more expensive to refine as will have other gases to extract.

I just hope it’s not condensate as they mentioned it’s light. Hopefully it’s between API 40-45.

Prove what lies beneath :)

GP even if there is some sort of inclination it will be minor. B2 is the well that’s planned for a big build as it’s horizontal through the KA. You are correct in saying TD could more more than TVD. My +/- covers that as we don’t know exact depths, however I would expect the fm depths to be the same in the short distance from A2.

Last well duration was 26th April to 9th June, just over 6 weeks. If drilling +/- 2100 metres vertically takes 10 weeks I’ll eat my hat. We will at the very least get drilling, logging & core results prior to Xmas.

They need to spud ASAP as 6/8 weeks puts us mid/late November. Doesn’t leave us much time then to rig down & de-mob the rig, then rig up & welltest before Xmas.