U.S. patent number 3,638,721 [Application Number 04/883,727] was granted by the patent office on 1972-02-01 for flexible connection for rotating blowout preventer.
This patent grant is currently assigned to Esso Production Research Company. Invention is credited to Otto R. Harrison.
United States Patent |
3,638,721 |
Harrison |
February 1, 1972 |
FLEXIBLE CONNECTION FOR ROTATING BLOWOUT PREVENTER
Abstract
A rotating blowout preventer or wellhead mounted on and above
but not rigidly attached to a blowout preventer stack. The
attachment between the blowout preventer and the blowout preventer
stack is flexible but pressuretight. The attachment allows lateral
movement of the blowout preventer or rotating head and the drill
string or kelly so that stresses resulting from a crooked or
nonaligned kelly or eccentric location of a drill string are not
created in the rotating blowout preventer or head while stationary
or while rotating.
Inventors: |
Harrison; Otto R. (New Orleans,
LA) |
Assignee: |
Esso Production Research
Company (N/A)
|
Family
ID: |
25383205 |
Appl.
No.: |
04/883,727 |
Filed: |
December 10, 1969 |
Current U.S.
Class: |
166/351;
175/7 |
Current CPC
Class: |
E21B
33/085 (20130101); E21B 33/064 (20130101) |
Current International
Class: |
E21B
33/08 (20060101); E21B 33/02 (20060101); E21B
33/03 (20060101); E21B 33/064 (20060101); E21b
033/035 () |
Field of
Search: |
;166/.5,.6 ;175/7 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Champion; Marvin A.
Assistant Examiner: Favreau; Richard E.
Claims
Having fully described the apparatus, operation, objects and
advantages of our invention, we claim:
1. Apparatus for use in conducting drilling operations comprising a
rigid blowout preventer stack;
a rotating laterally movable blowout preventer arranged above said
blowout preventer stack;
a flexible joint arranged between said blowout preventer stack and
said rotating blowout preventer to permit lateral movement of said
rotating blowout preventer relative to said rigid blowout preventer
stack; and
drill pipe extending through said rotating blowout preventer, said
flexible joint and said blowout preventer stack, said rotating
blowout preventer preventing flow of fluid through the space
surrounding said drill pipe.
2. Apparatus as recited in claim 1 in which said rotating blowout
preventer, flexible joint and blowout preventer stack are located
subsea.
3. Apparatus as recited in claim 1 in which said flexible joint
permits about 5.degree. lateral movement of said rotating head in
any lateral direction.
4. Apparatus as recited in claim 3, in which said flexible joint
comprises a sleeve member.
5. Apparatus as recited in claim 4 in which said blowout preventer
stack is connected to a subsea wellhead.
6. Apparatus as recited in claim 5, in which said sleeve member
comprises rubber.
7. Apparatus for use in conducting drilling operations
comprising:
a rigid blowout preventer stack;
a rotating head arranged above said blowout preventer stack;
a rubber sleeve member arranged between said blowout preventer
stack and said rotating head permitting lateral movement of about
5.degree. of said rotating head in any lateral direction relative
to said rigid blowout preventer stack; and
a subsea wellhead, said blowout preventer stack being connected to
said subsea wellhead.
Description
BACKGROUND OF THE INVENTION
When drilling oil and/or gas wells on shore the kelly may be at
times crooked or nonaligned or the position of the drill string may
be eccentric and when drilling such wells offshore from a floating
vessel the drill string must be permitted lateral movement to
accommodate lateral movement of the floating vessel caused by wave
and wind action. The present invention meets the requirements of a
nonrigid, connected, pressure tight, rotating blowout preventer.
The blowout preventer is installed on top of the rigid blowout
preventer stack and has the capacity for lateral movement to
compensate for any noncentered position of the drill string (or
kelly) or lateral movement of the drill string in offshore
operations. Vertical movement of the drill string in offshore
operations may be accommodated for in conventional ways.
SUMMARY OF THE INVENTION
In accordance with the teachings of the invention, the apparatus
for use in conducting drilling operations comprises a rigid blowout
preventer stack and a laterally movable rotating blowout preventer
and a flexible joint arranged between said blowout preventer stack
and said rotating blowout preventer to permit lateral movement of
said rotating blowout preventer with respect to said rigid blowout
preventer stack. In offshore operations the laterally movable
rotating blowout preventer permits lateral movement of the drill
string and on land operations such lateral movement compensates for
a crooked or nonaligned kelly or an eccentrically located drill
string.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 is an elevational view illustrating the features of the
invention;
FIG. 2 is an elevational view showing the apparatus of the
invention positioned subsea for offshore operations; and
FIG. 3 illustrates a rotating head for use in subsea
operations.
DESCRIPTION OF THE PREFERRED EMBODIMENTS
There is shown in FIG. 1 a rigid ram-type blowout preventer stack
10 mounted on a wellhead 11. A flexible connector 12 forms a
pressuretight connection between blowout preventer stack 10 and a
rotating blowout preventer 13.
Flexible connector 12 may be a thick sleeve of high-strength
rubber, reinforced if necessary. The sleeve is bonded to flanges on
the BOP stack 10 and rotating blowout preventer 13. The size of the
sleeve depends on the working pressure required and the type rubber
used. Preferably, the flexibility of the sleeve allows about
5.degree. lateral movement of the rotating blowout preventer 13 in
any lateral direction without reducing the strength of the sleeve
below the working pressure required. No torque is applied to the
sleeve. Alternatively, the flexible connector may be a knuckle
joint or ball and socket joint. Such type connector permits limited
deviation from a centerline axis of the blowout preventer stack and
does not expose any of the flexible joint to wear nor does it
restrict the size opening over that maintained with no
deviation.
The kelly or drill string indicated at 14 may be crooked or
nonaligned or eccentric as it extends through rotating blowout
preventer 13, flexible connector 12, BOP stack 10 and wellhead 11.
No stresses caused by such nonalignment or eccentricity position
are created or transmitted to the rigid blowout preventer.
A subsea arrangement of a rotating head, flexible joint and BOP
stack combination is illustrated in FIG. 2. In that figure, a drill
pipe 20 is shown suspended from a floating drilling barge 21 and
extending to and through subsea well apparatus which includes a
rotating head 22, a flexible joint or connection 23, a subsea
connector 24, a BOP stack 25, another subsea connector 26 and a
wellhead 27. The subsea well apparatus is lowered into position on
guidelines 30 (other known guide means could be used instead) which
connect wellhead 27 to drilling barge 21. The subsea apparatus is
provided with guide arms 31, connected to guide sleeves 32 through
which the guidelines extend. A flexible mud return line 35 connects
into the subsea apparatus below rotating head 22 and above flexible
joint 23 and extends to drilling barge 21. Rotating head 22 is
provided with hydraulic control lines 36 and 37 and a lubrication
line 38, all of which extend to drilling barge 21. Additional
control lines, not shown, may be provided to control operation of
the blowout preventers in the BOP stack 25 and in the subsea
connectors 24 and 26.
For a more detailed description, of rotating head 22, reference is
made to FIG. 3. As shown in that figure, a sealing element 40,
formed of resilient materials similar to that used in bag-type
blowout preventers, fits inside of and is retained in and rotates
with a bearing element 41 to which it is attached. Bearing element
41 is contained within a housing 42 and is covered by an upper
retainer plate 43. A number of roller (and/or thrust) bearings 44
are arranged between the interior walls of housing 42 and bearing
element 41 and retainer plate 43 is in contact with bearing element
41 by way of roller bearings 44a. A number of seals 45 are also
arranged between the inner walls of housing 42 and retainer plate
43 and the outer walls of bearing element 41. A conduit 50 formed
in bearing element 41 fluidly communicates the interior of scaling
element 40 and a passageway 51 formed in the walled housing 42,
which in turn connects to hydraulic control line 36. Another
conduit or passageway 52 is formed in bearing element 41 and
fluidly communicates the lower end of bearing element 41 exposed to
well pressures and the interior of sealing element 40. Another
passageway 53 formed in the wall of housing 42 connects to
lubrication line 38 at one end and the space between the inner wall
of housing 42 and the outer wall of bearing element 41. A
hydraulically operated latch member 55 includes a hydraulically
driven lug member 56 which is movable into and out of a recess 57
formed in retainer plate 43 and is supplied with hydraulic fluid
through hydraulic line 37. A flange (or hub or other type
connection) 60 formed in the lower end of housing 42 connects to
mud return line 35.
In operation, wellhead 27 is lowered through the water from
drilling barge 21 on guidelines 30 and secured to the land
underlying the water, in accordance with conventional practice.
Then BOP stack 25, together with subsea connector 26, subsea
connector 24, flexible joint 23 and rotating head 22, including
housing 42, sealing element 40, bearing element 41, and retainer
plate 43 may be lowered on drill pipe 20 and guidelines 30 with the
mud return line 35 connected to the subsea apparatus. Sealing of
sealing element 40 against drill pipe 20 or other tool is achieved
by applying fluid pressure through hydraulic line 36 and
passageways 51 and 50 or alternatively pressure from the well bore
acting on sealing element 40 through passageway 52 may be used.
Rotation of drill pipe 20 rotates sealing element 40 and bearing
element 41 against which sealing element 40 is sealed. Bearing
surfaces between bearing element 41 and housing 42 are lubricated
by a liquid similar to water-soluble oil which is supplied from
drilling barge 21 through lubricating line 38 and passageway 53.
The retainer plate or cap 43 may be released by withdrawing lug 56
from recess 57 by hydraulic operation of the latch 55 through
hydraulic lines 37 to permit replacing sealing element 40. Sealing
element 40, bearing element 41 and retaining plate 43 are run and
retrieved on drill pipe 20. When in subsea position, sealing
element 40 permits passage of tool joints. Drill collars on drill
pipe 20 raise sealing element 40 and bearing element 41 out of
housing 42 when coming out of the hole with drill pipe 20.
The rotating element may have grooves which spiral along its outer
surface to carry away solids or other foreign material.
* * * * *