I was involved in the development of the floatation collar when it
was first used by Hamiliton Brothers Liverpool Bay, BP Wytch Farm,
Esso and Woodside in Australia back in the 90's.
There were several issues with these early jobs and subsequent ones,
and probably still are.
There are many things to consider when floating casing in : the
inability to circulate, well control, potential premature shear out
of the device with mud above it, leaving trapped air inside and
circulating it out, the device not travelling to the end of the pipe
once sheared, how to get the air out at surface with the cement head
and manifold, extra block weight sometimes required, holding the
casing down etc.
Whilst the technique has obviously been successful I believe there
is a much simplier solution to getting casing down in ERD wells or
long horizontal section where floatation might be considered.
Maintaining the ability to circulate, wash down and possibly ream
could be beneficial to ensure you reach planned TD. We have acquired
a product that is run on the casing string made of a ultra low
friction engineered polymer material that dramatically reduces drag
and torque in these complex wells and is being used extensively by
most of the majors. This means you could possibbly run the casing
conventionally. We would need to do some modelling to check. We are
seeing open hole friction factors below .10 routinely.
Alternatively you could consider running the casing as a liner, and
tie-back, and there is some other new swivel technology we
developed for ERD wells being used widely for this purpose.
However, the former would be a better solution in my opinion, but
both techniques offer benefits over floatation. Would be happy to
share some hard data from field experience with you if you are
interested, and offer to do some complimentary modelling for you
wells if you would like.
Contact me on [email protected]
if you want.
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