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Stuck Casing on Floater
08 October 2011
With casing stuck off bottom and left protruding above the rotary table, what to do?
Using a false rotary table, heave will be a concern.
Ballasting rig, using a cutting torch, deballast rig. Heave will still be a concern. Main risk is potential collision between casing stump and diverter housing or rigfloor substructure which could bend the casing stump. Same applies to blind backoffs if the joint below the rotary releases.
Best option seems to be sourcing a wireline deployed and electrically or chemically activated severing tool. Schlumberger contacted and searching for a tool for 10" casing.
What is your contingency plan? What is the industry contingency plan in general?

regards from sunny Stavanger,
Ivan Sogard
Maersk Oil
12 answer(s)
markknorz
Senior Drilling Engineer
SPREADAssociates
Total Posts: 19
Join Date: 04/05/06
Ivan
Depends on which string is stuck- recently we were in a similar situation with 13 3/8" casing differentiallystuck 200m off bottom. We used a split shot from Spex to split the casing coupling 200m below the 20 inch shoe.
Alternatively you can trim the rig down, cut the pipe and then get in with a rotating spear to cut below the wellhead to clear the casing from the stack. Then for intermediate string a HP casing patch could be used (not recommended for production casing if the well is to be kept). Whats important in these situations is to identify the risk first and then have the contingency equipment at the rig site (casing cutter, spear, split shots, casing patch, whipstock etc).
ivansogard
Senior Drilling Engineer
Maersk Oil
Total Posts: 2
Join Date: 08/04/11
Many thanks for taking the time to comment. I would like to share what we have found so far.

We have been chasing suitable wireline deployed tools for our 13-3/8" (72 ppf) and 10" (68.8 ppf) casings for a while. We have been offered split-open shots and radial cutting torches but so far we have not been presented with any convincing track records for application from floaters.

Our contingency plan will most likely be to have a spear-motor-cutter assembly made up and racked, ready to go. Then a cut can be made in safe distance from the rig substructure and slip joint just in order to re-gain access to the RT.

Once again, thanks for all the input and good suggestions.
Ivan
admin
Managing Director (rp-squared.com)
Relentless Pursuit Of Perfection Ltd.
Total Posts: 377
Join Date: 10/01/05
Hi folks,

It's good to see the healthy responses on this thread.

I can't help thinking in this situation that having float equipment on the end that has been tested would be a comfort, especially in deeper sections with hydrocarbon-bearing intervals... and imagine that every risk assessment on running casing on a floater should consider this event and what to do.

The guys at Sudelac have previously mentioned this on our site, as a service they can offer. We test drill-string floats onshore, so we should think about testing casing floats the same.

With kind regards

Dave
e_normington
Drilling Supervisor
SPREADAssociates
Total Posts: 1
Join Date: 22/09/08
Once got round a similar situation with an explosive cutter on 13.3/8" if that helps. think it was Halliburton's.
ps- Dave Junior - have you been bunking off school? Spelling needs considerable attention...
andypettitt
director
SPEX Services Ltd
Total Posts: 1
Join Date: 11/10/11
Ivan
Could you perhaps contact me we might have solution but would need to discuss with you

We have guys offshore for Maersk in Denmark already who could help

number is +44 77 11 217742

Regards

Andy

_________
Note from moderator : It would be good if either this respondent or Ivan could provide more details of this potential solution - for the benefit of the members
________
By the way .. the response from "Dave Junior" was a spoof that I wrote just to add a bit of humour from time to time.
____
Kind regards
Dave Taylor
Westdrie
Deepwater Drilling Advisor
Hess Corporation
Total Posts: 6
Join Date: 20/06/10
You have a couple of options:
- For riserless sections, you can add a 60" chop saw as part of the ROV toolbox. Oceaneering make one. Spec sheet attached.
Once you are risered up you can look at running an EBO sub (Emergrency Back Off) from Dril-Quip. Used to run them on TLPs in case we got the spaceout wrong. Put it in the string prior to the casing shoe going out into openhole, that way you know you can always back out if you do plant the string.

Myles
Documents uploaded by user:
60 chopsaw spec.pdf
cnduncan
Drilling Consultant
SPREADAssociates
Total Posts: 25
Join Date: 10/04/11
I do like Ron's advice above as it can be implimented quickly however the point of backoff is quite a concern.
One possible option would be to run a timmons backoff tool on pipe to back off at a safe depth relative to the rig floor and other infrastructure. Run this on two sets of elevators. Recover that section and then with the rotary table safely available, go in and get some more. Once below the BOP you have more options.

Regards

Craig Duncan
Note from admin
Dear member, Thank-you for submitting your response. However, we have with-held posting it to the site for the following reason... What's a Timmons Back off Tool .. I had a look on Google and nothing came up. So, it's a fantastic response, that would be made perfect if you could add a little info about it (or a link to a site etc.,). With very kind regards Dave Taylor
Sloving
Vice President
Thru Tubing Solutions
Total Posts: 1
Join Date: 08/10/11
We have an Abrasive Cutting System that is ran on coiled tubing. Used successfully in deep water applications for Woodside Australia as well as land locations around the world.

Mobile number 405-641-2068 (USA)
admin
Managing Director (rp-squared.com)
Relentless Pursuit Of Perfection Ltd.
Total Posts: 377
Join Date: 10/01/05
Ivan

When we had the same (with 20"; open water), we cut a window in the casing and ran a back-off tool down inside the casing and backed off.

We had little scope, because it was far N Sea and the weather was brewing up.

Our biggest concern was backing off just below the pontoons and puncturing them. Fortunately we backed off close to the seabed.

In your case, Ron's suggestion makes sense.

Good luck .. and please let us know how you get on.

Dave
MD - Relentless Pursuit of Perfection Ltd
Titiloyefemi
Drilling Fluids Engineer
Pishon BEFY Nig Ltd
Total Posts: 2
Join Date: 06/10/11
This Question to you:
Can you guys circulate? If yes, try & establish circulation, step on these;
  • Apply maximum flow rate as much as you can.
  • Slack off weight of it to maximum sit down weight.
  • Jar down with maximum trip load. Torque may be applied with jarring down with caution. The chance of freeing by jarring down is more than jarring up. Please be patient when a hydraulic jar trips because it may take around 8 minutes each circle.
    The Next/secondary action; you may try
  • Reduce hydrostatic pressure by pumping low weight mud/pill. You must ensure that overall hydrostatic pressure is still able to control reservoir fluid to accidentally come into the wellbore.
  • Continue jarring down with maximum trip load and apply torque into it.
  • It may take long time to free the pipe therefore patient requires.
Regards,
Titiloyefemi
HBCurlett
Consultant
SPREADAssociates
Total Posts: 2
Join Date: 19/05/11
Ivan... I would suggest that a coil tubing deployed abrasive jet cut off system would be your best/surest chance at successfully cutting the casing the first time (which is always the least expensive)... There are transportable offshore coil tubing unit available and Schlumberger, Halliburton and Weatherford each have thier own version of an abrasive casing cut-off tool...
Alternatley, there is a unique fishing service available that uses a surface oscillator that can be hung from the travelling equipment that may be able to free your stuck casing... Please refer to http://www.vibrationtechnology.com/index.html... This system can be run on an offshore drilling operation... Regards - Hal...
Ron.Mackay
DTL Offshore Coach
Relentless Pursuit Of Perfection Ltd.
Total Posts: 7
Join Date: 06/01/07
Ivan,
In the late 1980's I was caught out as a Driller in similar curcumstances running 13 3/8" csg but the weather was picking up in the next day or so and requiring us to have to un-latch the LMRP.
What we did next was as an "emergency measure". We checked out our space out to where our csg connection were in relation to the BOP. Shears Rams in particular.
The Annular was closed and the casing connections above it over torqued against the closed Annular.
Once the Annular was opened we backed out and fortunately the connection below the Shear Rams backed out so we could close the Shears and continue preparing too and eventually having to un-latch the LMRP.
This is perhaps not the type of thing you want to do but if there is a chance the weather is going to force your hand then you may have to consider doing this??
Best of luck and I hope you get some feedback from the rest of the forum with other less high risk solutions.

Regards,
Ron Mackay
Relentless Pursuit of Perfection
Drilling Performance Eng.
North Sea
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