Private Forums
Rig-ready tubulars
13 July 2018
Dear members

At a recent DWOP, we were discussing the benefits of preparing tubulars ("Rig ready") before sending them to the rig.  This was for casing (sizes inclusing 13⅜")
  • Pre-measure
  • Drift
  • Pre-install centralisers (solid and/or spring-bow)
If done properly (QA-QC essential), then there are little downsides to relieving the rig crew of this task (safety, time) and we are aware that a lot of companies are doing this.

If possible, please could you share with us your experience in this regard or, better still, your yard preparation procedures, any additional checks that you make etc.  Also any other considerations/issues with racking offshore.

We are already aware of the need to be careful where centralisers are placed with regards to handling and make-up equipment.

Many thanks

Dave



7 answer(s)
YoussefSallam
Drilling Engineering Manager
BP
Total Posts: 1
Join Date: 07/10/15

Hi Dave,


As you may be aware (from all the DWOPs and CWOPs that you and your company do with us here in Cairo), we run 13⅝” casing string in Nile Delta deepwater fields with centralizers subs and we perform these activities in the base before mobilizing the pipes to the rig.


We measure the pipe, drift it and make up centralizers with full joint, make up float shoe and float collar with full joints, etc.


We assemble or subassembly all small pieces of pipes together before sending them to the rig  (e.g. hanger, float shoe, float collar, centralizers, etc. We send the backup items loose (not made up).


To reduce flat time casing running time we try to remove these activities from the rig and do them in town and or off-line.


I hope that helps


Best wishes

Youssef

JDDrouin
Project Quality
SPREADAssociates
Total Posts: 98
Join Date: 06/05/09
Dave,

This is an old issue, and the better question is why would tubulars (or anything else) be sent to any rig in a non-run ready condition?

Anyway, my two cents worth:  there is NO downside to prepping tubulars into a run-ready configuration prior to shipping.  Some points to consider:

- The drill crew is just exactly that, a drill crew, not a tubular services crew, and they are not trained or competent in evaluating premium connection flaws (if any).  And, without digressing too far, there are few activities drill crews dislike more than cleaning and drifting pipe.  Running it, no problem, prepping it, that's another story ... it's dirty, nasty work they KNOW can be better done elsewhere (and they're right).  And crew morale is critical to any successful drilling program.

- Space / Tools / Environment / Safety / Personnel.  There is no drilling rig, onshore or offshore, that has as much space, or tools, or environmental or safety controls, or personnel available to properly process tubulars into run ready status as a tubular services yard.

-  Handling.  There are no additional handling constraints on run ready tubulars than there are on non-run ready tubulars.  The tubulars are completely ignorant of their run status, and if they're mishandled they'll both experience the same scope and scale of damage.  The key is to ensure they're not mishandled, and that's a matter of planning and compliance.

- Time / Cost / Critical Path / ILT.  Tubular services yards simply do not have a cost as great as any rigs hourly or daily burn rate.  And removing any activity from the critical path and eliminating ILT is or should be one of the highest priorities in any drilling schedule.

Further to all of the above, adopting shipping tubulars in a run ready condition opens the possibility of shipping tubulars in doubles or even triples ... though some deep water vessels simply make singles up offline and rack them back, there's still no reason to NOT ship those tubulars in a run ready condition.

Not too many years ago, I worked on a high-intensity, high cost offshore project where the tubulars and shoe tracks were all prepped to run ready status.  From memory, the only factor we failed to take into consideration was the time span between prepping and running (for nine months of the year, it was either really hot and dry, or really hot and humid, always with a lot of dust in the atmosphere).  We found that six months was the maximum amount of time between prepping and running before the premium connections started experiencing issues during makeup.

On a subjective note, I have found that the service companies which are the 'least enthusiastic' or "most resistant" to shipping run ready tools are the liner hanger suppliers.  In almost every location I've worked in (Macae, Brazil and Malaga, WA being the two execptions), they want to do final assembly on the rig, which requires crane time, deck or drilling crew time, and additional NPT activities slotted into the critical path.  They'll have a host of 'reasons', aka "excuses", why they can't ship run ready, but it's because fully made up L/Hs can be as much as 75ft long (or more), and most don't have baskets for that ... 'We're going to add hours of NPT to your $XXX,000 per day operation because we don't have the approriate basket(s)'.

Hope that helps,

Hope all that helps,
hossybhoy
Technical Sales Specialist, Cementing Products & Liner Systems
Weatherford
Total Posts: 7
Join Date: 07/08/12

Dave, I've been involved in pre rig prep of tubulars on many occasions and each one can have challenges.

When running non weld style hinged centralisers it is best to install these offshore, preferably while the pipe is being run as they are relatively easy to fit, but we would regularly fit the stop collars on the beach as they are the time consuming part of the operation, especially ones with grub screws securing them to the casing. It's very important that these are fitted correctly to prevent slippage on the pipe.

With solid body slip on centralisers you can certainly have these fitted onshore but care must be taken when slinging the pipe into bundles as this can damage the centralisers, especially composite material ones. Steel bodied centralisers are less susceptible to damage when doing this.

If you are running centralizer subs then you have little option but to buck these onto the casing joints onshore as doing this on the rig would be extremely time consuming and probably be seen as unsafe. When we do these we always have wooden batons that sit slightly proud of the centralizer bows between each bow and these are held in place by plastic banding straps and can be removed just prior to make up on the rig floor.

stevedev
Drilling Consultant
SPREADAssociates
Total Posts: 38
Join Date: 11/02/09

We found that some centralisers slipped down the pipe when picked up off the v door as stop collars had not been correctly installed.  Installing centralisers in town can be worthwhile but there should be an awareness on the rig of incorrect installation.

If a centraliser drops down the pipe when it's picked up, there is a danger of injury or damage.

Augusto
Consultant [retired Shell staff]
SPREADAssociates
Total Posts: 244
Join Date: 02/09/05
Transit damage my major worry; drift, float equipment and thread protectors, mainly.

Float equiment in general is cement-filled very fragile.

Thread protectors must be prequalified for the thread and task ahead.
Sacha
Senior Drilling Engineer
Drilling Consultant
Total Posts: 3
Join Date: 03/12/17
Dave,

I used rig prep casing for deepwater projects. Main reason was deck space. Not enough time to prep the casing on the rig between two casing strings. And also as you mentioned, to make the drill crew job more safe and save time.
Rig prep was done by casing inspection company in the yard. Depending on the objective, not full prep needs to be done onshore.
- Main objectives was to clean, inspect and dope the threads onshore, which takes a long time offshore.
- Casing was strapped, length painted in big on the joints (no joint number, as done on the rig)
- Drifted.
- Float equipment M/U with centralizer installed.

Depending on casing size (special drift), drift was done again offshore, as transport could damage a joint.
Length of joints was also double checked offshore, but on a couple of joints only.

Joints with centralizers placed separately on deck. Only slip on centralizer pre installed. Hinged centralizer are easy enough to install on the catwalk before picking up joint.

I hope it helps.
PaulHowlett
CEO
Sudelac
Total Posts: 90
Join Date: 10/04/08
Dave, I am sure there are various levels of sophistication in the process of drifting, measuring and the installation of accessories in the preparation of casing to be loaded out to the rig site and run. I would measure the lengths with a laser measurement tool. I would add measuring the ID accurately to the list of to-do's in the process to help with accurate volume and displacement calculations to ensure plug bump. I would add QAQC on the float equipment up to and including pressure testing it pre-use pre-load out. I would select my centralisers and placement with pre-use preparation in mind, some will be better for pre-installation and shipping than others but still suitable for the running and cementing in the well. I would investigate pre-doping the connections and ensuring the thread protectors are suitable for running the casing with easy removal I would also investigate or create an intelligent electronic tally so that all the information relating to a joint number is held electronically this in turn may lead to bar coding labels on the joints and electronic readers to be able to access the data and create the permanent as run well records.It would be good to hear from others what they already do and what time/cost saving is realised.
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