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Uninterupted 'safe effective efficient' tripping in/out, Some Physical tripping evidence? Please.
03 March 2020
All members.

Can you afford us Physical snippets facts and figures from todays trip sheets or drilling logs for rig types, pipe being tripped and physical mechanical systems being used/applied.

Notably during an uninterrupted tripping sequence in and/or out when no constraints are imposed or presented 
- e.g. generally within the marine riser, and/or in bigger cased holes for onshore and/or offshore MODU wells.

Please also state for dat provided if this is a 
- Land rig. (super single, double, triple stand) Kelly/Top drive
- Fixed installation  (platform, jack up) (double triple, quad) Kelly / Top drive
- Offshore MODU (Semi-drillship), (triples, quads) Conventional, Ram/Hydraulic rig.

Benchmark example that I always measure (loss against) from my work experience in well situations where we had no constraint w.r.t to delivering  safe effective, efficient tripping as follows.
- Offshore platform derrick set - tender barge.
- 3000HP draworks
- Uninterrupted tripping in of 5in pipe, 60stand per hr. (Crew using semi automatic (weight set manual slips) a make up tong/spinning chain. Two crew and a driller.
- Uninterrupted tripping out of 5in pipe, in 40-45stands range per hr (kelly racked back, free spinning blocks, semi-automatic weight set manually slips, break out tong, slight tension held on stand and pipe rotated out with rotary table) Two crew and a driller. 

Maybe we are wrong, but as on bottom drilling has progressed by a factor or 3-5 or more during the last three decades. Tripping and tubular handling has regressed based on physical evidence that exists. Is there evident improvement in 5th 6th and 7th generation, higher tech rigs?    

If not or evidently yes, please afford us your physical tripping evidence.

Area of interest are conventional hoisting system vs hydraulic/ram rigs tripping capabilities etc to conclude where todays drilling time / money is most lost/wasted.

It would be great to share and gather some physical facts and figures from within this SPREAD community to 'SEE' exactly where we are currently at w.r.t tripping pipe in/out of wellbores when no constraints on safety effectiveness and efficient are presented or imposed. 

Further value adding comment on this, i.e. todays pipe handling? All welcomed.

Thanks,  


6 answer(s)
Companyrep
Drilling Specialist/Well Engineer/Training Consultant
Kingdom Drilling
Total Posts: 441
Join Date: 10/01/05
Slender well central North Sea 2007.  Surface hole drilling 

On bottom drilling ROP 670ft/hr for a 3250ft vertical section interval. 

Here More time was EVIDENTLY spent making quick connections VS on bottom drilling  ( ie drill off, stop rotating pick up pipe 20-30ft, drag normal set pipe in slips and make the connection) than was spent on bottom drilling.

Pipe was tripped out on elevators ‘ one of the slickest holes we ever drilled and tripped’ was the supervisors quote! 

This example. How today drilling  loss/waste avoidance can be technically drilled and delivered at all outcomes and benefits desired. 

More of the above ( what we are capable off) vs standard acceptable NPT norm is what is demanded in today’s high tech world with everything at ones fingertips! 
Companyrep
Drilling Specialist/Well Engineer/Training Consultant
Kingdom Drilling
Total Posts: 441
Join Date: 10/01/05
Patrick,

again one tripping problem that today’s management intellects and graduates don’t seem to comprehend. Is float valves. 

In many wells these were never run until MWD arrived. Some operators had a HDIS standing by ( hydril drop in or dart sub) 

With better mud and solids controls that exists, the likeliness of plugging a string while RIH is a risk that can as was done when we never ran floats. Is mitigated by simply watching the trip tank. Where today much more accurate sensors can alarm when pipe is not being filled?

Also convertible floats as used when running casing could be used in conventional wells . 

Tripping times saved is significant. 

Pack off in an annulus with a float is also less than ideal and a key evident issue why pipe gets stuck and severed?  

As stated before MWD we often did not run floats and monitored the well on the trip tank and in my experience never plugged a string, and getting unstuck in pack off situations was easier, and we never had major secondary control issue due to all best practices primary control in place.  
Companyrep
Drilling Specialist/Well Engineer/Training Consultant
Kingdom Drilling
Total Posts: 441
Join Date: 10/01/05
Thanks Colin 

I have a 2016 drilling report from All wells drilled offshore Canada.

again total Drilling days data presents little bottom line EVIDENT improvement on wells overall despite a dramatic reduction in bit trips and on bottom drilling time.  

Wells are typically revolving not evolving unlike other industries EVIDENCE! 
PatrickLemmers
Technical Mgr - Drilling Tools
Franks International
Total Posts: 6
Join Date: 10/11/16

Hi Peter,

Reading this inquiry from you, I thought to let you know that Frank's International has a device that is called the Versaflo. This is actually a combination tool, as it contains a Casing Module and a Drillpipe Module. It is mainly the Drillpipe module that is of interest for this topic. The tool avoids having to screw in the topdrive when experiencing backflow (eg. on a landing string when running tight tolerance casing strings), or when having to circulate/lubricate during tripping out of hole (eg HPHT wells). The tool contains a hydraulic activated piston the stabs into the drilpipe and seals off up to some 4500PSI so it can catch backflow or can be used for circulating. It is Wifi operated and the piston is extended or retracted by a push on a button. It saves quite a lot of time wrt spinning in or out the drillpipe, torquing it up and untorquing. Average gain would be some 5-6 mins per stand, which adds up, mainly for deep water application. Rig-up time is about 10-15 mins, same for laying down the tool.

Hope this is a kind of optimization you would be looking for.

Kind regards,

Patrick

cmcandrew
SPREAD Associates
Total Posts: 37
Join Date: 16/08/10
Benchmark or target ?  Similarly , never seen a good rhythm trip outside USA: outside= futile to improve or not "appreciated" ! - but can see improvement on charts if you are on floor !
Just quick look through files, but attached is something to look at from 2003 La after new casing, RR. guess you need charts though for breakdown. You might also be interested in below, pasted below is from a 2014 McKinsey report-hard to see a reason for improvement since- technology, eh ?.
On CAPEX, the time taken to drill a typical well on the UKCS has increased by 17 days over the past 5 years11. On the NCS, crews drill 17 metres per day less on average today than five years ago. One operator told us that their drilling speed has dropped from 175 metres per day in 2004 to less than 100 metres per day in 2013–14. While the operator acknowledges that water and well depths have affected drilling efficiency, they believe that less experienced drilling crews and the scarcity of appropriate drilling facilities and other specialised inputs have greatly exacerbated the problem. Other analyses, comparing the time taken to drill almost identical wells on the same facilities, but a decade apart, confirm this point by highlighting a doubling on average of the time taken to carry out a broad sample of standard procedures.
Documents uploaded by user:
DR la.docx
hank
fishing tool hand / consultant / advisor / coordinator / tech. rep.
SPREAD Associates
Total Posts: 40
Join Date: 13/03/12
Peter,

 45 - 60 stds a hour?....I have not seen anything close to that for years,I worked land rigs for 20 years and now have been running fishing tools international for 20 +..... 
  It would be 30 or 40 years ago since I tripped or saw tripping that fast...on the prairies …. RIH open ended DP to run cement plugs in open hole to about 4000 ft in a hour.... brakes smoking... ….and in the foot hills, RIH on a big old Loffland rig......freefall 2 singles then all on the Elmago and brakes....
  Any more from what I see every day on land and offshore in the ME, 3 or 4 floor hands...12 to 30 stds a hour is realistic...…… in the prairies some rigs can near drill at that rate.....lol

Posted by

Peter Aird

Drilling Specialist/Well Engineer/Training Consultant

Kingdom Drilling

Total Posts: 441
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