U.S. patent number 3,583,480 [Application Number 05/045,038] was granted by the patent office on 1971-06-08 for method of providing a removable packing insert in a subsea stationary blowout preventer apparatus.
This patent grant is currently assigned to Regan Forge and Engineering Company. Invention is credited to John Regan.
United States Patent |
3,583,480 |
Regan |
June 8, 1971 |
METHOD OF PROVIDING A REMOVABLE PACKING INSERT IN A SUBSEA
STATIONARY BLOWOUT PREVENTER APPARATUS
Abstract
A stationary blowout preventer having a balloon-type packing
unit with a central opening therein, a retrievable packing insert
positioned within said opening by the engagement of a lower ring
with the preventer and releaseable secured therein by hydraulically
releasable dogs latchingly engaging a latching notch in an upper
ring, whereby a central rubber portion of the packing insert
sealingly engages the pipe tool therethrough when the packing unit
is pressurized by fluid. The blowout preventer has a fluid
accumulator which absorbs the surge pressure and excess fluid to
maintain a constant pressure on the packing insert as a pipe tool
joint is stripped therethrough to maintain the sealing engagement
between the insert and the pipe.
Inventors: |
Regan; John (Palos Verdes
Penninsula, CA) |
Assignee: |
Regan Forge and Engineering
Company (San Pedro, CA)
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Family
ID: |
21935678 |
Appl.
No.: |
05/045,038 |
Filed: |
June 10, 1970 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
Issue Date |
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868870 |
Oct 23, 1969 |
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Current U.S.
Class: |
166/352; 166/368;
166/359; 166/365; 166/82.1; 166/363 |
Current CPC
Class: |
E21B
33/064 (20130101) |
Current International
Class: |
E21B
33/064 (20060101); E21B 33/03 (20060101); F21b
007/12 (); F21b 033/03 () |
Field of
Search: |
;166/.5,.6,82,83,84,85,86,114 ;251/1 ;277/3,9,34,185 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Leppink; James A.
Parent Case Text
REFERENCE TO RELATED APPLICATION
This application is a division of my copending application Ser. No.
868,870 filed Oct. 23, 1969, entitled "Tool Joint Stripping
Stationary Blowout Preventer With a Retrievable Packing Insert."
Claims
I claim:
1. A method of providing a removable packing insert in a subsea
stationary blowout preventer apparatus having a housing mounted in
a subsea wellhead and connected by a well riser conduit to a remote
vessel floating on the sea above the associated subsea well
comprising the steps of:
providing an annular rubberlike packing insert with an outside
diameter of a size allowing its passage down said riser conduit and
into the bore of an annular radially compressible packing of said
preventer apparatus;
running said insert down said riser conduit from said floating
vessel remote from said wellhead and preventer apparatus packing;
and
compressing said preventer apparatus packing about said insert.
2. The method of providing a removable packing insert of claim 1
with the additional step of:
landing said insert upon a shoulder provided in said blowout
preventer apparatus prior to said step of compressing said
apparatus packing.
3. The method of providing a removable packing insert of claim 1
with the additional step of:
latching said insert in said preventer apparatus prior to said step
of compressing said apparatus packing.
4. The method of providing a removable packing insert of claim 1
with the additional steps of:
running a retrieving tool down said riser conduit and engaging said
insert thereon;
relieving the compression of said apparatus packing about said
packing insert; and
removing said packing insert by said tool to place a substitute
packing insert in said preventer apparatus.
5. The method of providing a removable packing insert of claim 1
wherein said step of compressing said preventer apparatus packing
about said insert includes the substeps of:
applying hydraulic fluid under pressure about said preventer
apparatus packing to compress said packing about said insert;
and
providing a compressible fluid in association with and pressurized
in an accumulator means by said hydraulic fluid to allow said
insert and packing to expand against the compressive pressures of
said hydraulic and associated compressible fluids upon the running
of an enlarged portion of a tool through said insert.
Description
BACKGROUND OF THE INVENTION
This invention relates to stationary blowout preventers and more
particularly to a method of providing a stationary blowout
preventer with a retrievable insert therein and a fluid accumulator
attached thereto which permits the joints of a pipe tool to be
stripped therethrough while a sealing engagement is maintained.
The oil well industry has had a continuing problem, associated with
subsea drilling from a floating platform, of providing a suitable
stationary blowout preventer that could strip tool joints i.e.,
pass the enlarged collars joining two pipe tools together, through
the packing of the blowout preventer while the packing maintained a
sealing engagement around the pipe tools and the tool joint. A
subsea blowout preventer is mounted on the wellhead over the
wellhole at the bottom of the sea and is used to hold the pressure
within the well and to exclude the water therefrom. The stationary
blowout preventer utilizes a radially compressible rubber packing
unit which, in response to hydraulic fluid pressure from the
surface, expands radially inwardly about a well tool inserted
therethrough to sealingly engage the well tool. The well tool so
engaged is commonly made up of a series of lengths of pipe tools
joined together by collars or tool joints which usually have a
larger diameter than the pipe tools themselves. When the subsea
blowout preventer is closed about a drill pipe tool run
therethrough, sooner or later a pipe tool joint must pass through
the blowout preventer.
In the past, a string of stationary blowout preventers have been
provided so that one blowout preventer may be open to admit the
tool joint therethrough while others maintain the seal and so on
until the tool joint is through the blowout preventer string.
However, if the tool joint is in a position close to the blowout
preventer, the vertical motion of the floating platform because of
waves is transferred to the pipe tool and pulls the tool joint back
through the blowout preventer. When this occurs, conventional
blowout preventers are damaged, sometimes to the point of being
inoperative, and must be replaced by dismantling the wellhead on
the bottom of the sea.
Therefore, it is the primary object of this invention to provide a
subsea stationary blowout preventer that will strip tool joints
therethrough when closed.
It is another object of this invention to provide such a blowout
preventer which will maintain a seal around the drill pipe as the
tool joint is being stripped therethrough.
It is yet another object of this invention to provide such a subsea
stationary blowout preventer that will strip a tool joint
therethrough without damage to the preventer to make it
inoperative.
It is a further object of this invention to provide such a subsea
stationary blowout preventer with a retrievable packing insert
which will strip tool joints therethrough.
It is yet a further object of this invention to provide such a
blowout preventer with such a packing insert which is automatically
properly positioned within the blowout preventer as it is lowered
therethrough.
It is yet another object of this invention to provide such a
blowout preventer with such a packing insert which is releasably
latchingly maintained therein after positioning.
It is yet a further object of this invention to provide such a
stationary blowout preventer with such a packing insert having an
accumulator system which absorbs the incompressible fluid
maintaining the packing in sealing engagement with the pipe
therethrough as the tool joint thereof is stripped therethrough and
returns the fluid so absorbed to maintain the pressure and the
sealing engagement between the packing and the pipe tool after the
joint has passed therethrough.
It is yet another object of this invention to provide such a
stationary blowout preventer with such a packing insert which may,
in an emergency, be used as a rotary blowout preventer, with the
wear on the packing seal from the rotating pipe therethrough being
on the retrievable packing insert which is replaceable from the
surface.
SUMMARY OF THE INVENTION
The stationary blowout preventer of this invention has a radially
compressible annular packing mounted therein and a central bore
therethrough for receiving a retrievable packing insert to seal
about a tool run thereto upon radial compression of the annular
packing by hydraulic fluid pressure. The retrievable packing insert
is automatically positioned by the engagement of a landing shoulder
thereof with the bore of the blowout preventer and releaseably
latchingly secured to the blowout preventer by hydraulically
releasable dogs engaging a latching notch in the packing. The
blowout preventer is also provided with an accumulator apparatus
which absorbs the surge pressure and excess hydraulic fluid as a
tool joint passes through the packing insert and the blowout
preventer and returns the fluid afterward to maintain the sealing
engagement therebetween.
These and other objects and advantages of the stationary blowout
preventer of this invention will become apparent from the following
detailed description and drawings in which:
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 is a schematic representation, in elevation, of a floating
vessel positioned above a subsea well having a wellhead with an
improved stationary blowout preventer apparatus according to this
invention;
FIG. 2 is an enlarged cross section elevational view of the
stationary blowout preventer apparatus of FIG. 1 taken along the
plane II-II;
FIG. 3 is a view of a portion of FIG. 2 showing a drill pipe and
collar passing through the stationary blowout preventer apparatus
of FIG. 1; and
FIG. 4 is a view similar to FIG. 3 showing a retrieving tool
removing the packing insert from the stationary blowout preventer
apparatus of FIG. 1.
Referring now to the aforedescribed FIGS. and especially to FIG. 1,
a floating vessel or barge 10 is positioned by suitable anchor
means (not shown) in a body of water or sea 11 over a well hole 12
in the sea bottom 13 and having mounted thereover a subsea wellhead
14. A conventional drilling rig 15 is provided on the barge or
vessel 10 for running a conduit riser 16 from the barge 10 to the
wellhead 14 to guide individual lengths of drill pipe tools 17
connected together by collars 18 into the wellhead 14. The conduit
riser 16 also contains hydraulic pressure lines 19 and return lines
20 therein for connection to the subsea wellhead 14.
The subsea wellhead 14 includes an improved stationary blowout
preventer apparatus with a stationary blowout preventer 25, a
removable or retrievable packing insert 45, means positioning the
insert 50, and latching means for releasably latching the insert 55
therein. The blowout preventer 25 also has connected thereto a
fluid accumulator means 75 for absorbing the surge pressure caused
by a pipe collar passing through the packing insert 45 of the
blowout preventer 25 and then restoring the pressure to the blowout
preventer 25 and the packing insert 45.
As best illustrated in FIG. 2, the stationary blowout preventer
apparatus 25 includes a preventer body or housing 26 having a lower
central bore 27 meeting a horizontal annular surface 28 at a
chamfered landing shoulder 29, and an upper cylindrical internal
surface 30 extending upwardly from the annular surface 28 to the
open top of the preventer body 26.
An annular packing unit indicated generally at 31 is inserted into
the open top of the preventer body 26. The packing unit is of the
pure bag or balloon type and an outer annular or tubular element 32
having a central rubber portion 33 mounted between upper and lower
reinforcing rings 34 and 35. An inner annular or tubular element 36
is positioned within the outer tubular element 32 and also contains
a central rubber portion 37 with a radially inwardly opening
V-notch 38, and upper and lower reinforcing rings 39 and 40.
A preventer cap 41 is conventionally mounted by bolts to the
preventer body 26 to close the open upper end thereof. The
preventer cap 41 has an upper central bore 42 axially aligned with
the center bore 27 of the preventer body 26 but of a slightly
larger diameter and a flat annular surface 43 which is parallel to
the horizontal annular surface 28 of the preventer body 26 but
spaced a distance therefrom to form a housing chamber. The two
horizontal annular surfaces 28 and 43 engage the upper and lower,
inner and outer rings 39 and 34 and 35 and 40, respectively, to
locate and maintain the packing unit 31 in a housing chamber within
the blowout preventer 25. A suitable number of seals 44 are
provided to seal the cap 41, the rings 28, 34, 39 and 43 and the
body 26.
The removable or retrievable packing insert 45 is annular or
tubular in shape and includes a central rubber portion 46, mounted
between a rigid upper ring 47 and a rigid lower ring 48. The insert
45 has an external diameter slightly less than the internal
diameter of the upper central bore 42 but slightly greater than the
internal diameter at the lower central bore 27, and an internal
diameter greater than both the external diameter of the drill pipe
tools 17 and the collars or tool joints 18.
The packing insert 45 is for insertion into the stationary blowout
preventer 25 and includes means, indicated generally at 50, for
properly positioning the insert within the stationary blowout
preventer 25. In the preferred embodiment, the means for
positioning the packing insert 50 includes a chamfered landing
shoulder 51 on the lower metal ring 48 and the chamfered landing
shoulder 29 of the preventer body 26 which engage, because the
lower ring 48 has a greater diameter than the lower central bore
27, as the retrievable packing insert 45 is slid into the blowout
preventer 25. This engagement halts downward movement of the
packing insert 45 at the proper position within the blowout
preventer 25.
The blowout preventer 25 and the packing insert 45 have latching
means, indicated generally at 55, associated therewith for
releasably latching the packing insert 45 to the stationary blowout
preventer 25. In the preferred embodiment, the latching means 55
includes a circumferentially outwardly opening latching notch or
groove 56 on the upper ring 47, and radial openings 57 through the
preventer cap 41 containing movable dog means 58 for releasable
engagement with the latching notch or groove 56.
The movable dog means 58 includes a dog 59 slidably inserted in
each radial opening 57. The dog 59 has a downwardly sloping
radially inwardly extending nose 60 for mating insertion into the
latching notch 56. The dog 59 is connected to a piston rod 61
extending radially outwardly therefrom and through an opening 62 in
a hollow cylinder 63 secured to the preventer cap 41 in each
opening 57. The outward end of the piston rod 61 is conventionally
attached to a piston 64 movably positioned with the cylinder
63.
The cylinder 63 has its outward end closed by a cylinder cap 65
having a spring 66 extending radially inward from the end thereof
and engaging the radially outward end of the piston 64 to bias the
piston 64 radially inwardly and thereby bias the dog 59 also
radially inwardly. The cylinder 63 has a pair of openings 67 and 68
adjacent either end of the cylinder, operably connected to
surface-controlled fluid supply lines (not shown) part of the
pressure lines 19. The cylinder piston assembly is provided with a
suitable number of seals 69 to prevent the escape of fluid or
pressure therein.
The dog 59 is moved from the latching position shown in FIGS. 2 and
3, radially outwardly to the open position shown in FIG. 4 against
the biasing action of the spring 5 by a differential fluid pressure
via the openings 67 and 68, and upon release of the differential
fluid pressure is returned to the latching position of FIGS. 2 and
3 by the biasing of spring 65.
The stationary blowout preventer 25 also has means indicated
generally at 70 associated therewith for selectively applying
hydraulic fluid pressure thereto. In the preferred embodiment, the
means 70 includes a pressure line 71, one of the pressure lines 19,
is attached to the preventer body 26 and supplies fluid under
pressure through inlet opening 72 in the preventer body 26 to the
space between outward surface of the rubber portion 33 of the outer
element 32, and the upper cylindrical internal surface 30 of the
preventer body 26, as is best seen in FIG. 1.
The fluid accumulator means 75 includes an outlet opening 76
through the preventer body 26. A line 77 from the opening 76
conducts the fluid into an opening 78 in the upper end of an
accumulator cylinder 79. The accumulator cylinder 79 has a
vertically slidable piston 80 therein suitably sealed by seals 81
to maintain the fluid in the cylinder 79 on the top thereof. A
spring 82 is mounted within the cylinder 79 between the bottom of
the piston 80 and the bottom of the cylinder 79 to bias the piston
80 upwardly. The cylinder 79 also has a lower opening 83 to line 84
containing pressurized gas which acts as a balance between the
spring 82 and the fluid above the piston 80.
As the pressure on the fluid in the blowout preventer 25 increases,
it drives the piston 80 lower against the biasing of the spring 82
and the pressurized gas to permit more of the fluid to escape out
of the blowout preventer 25. Conversely, when the pressure on the
fluid in the blowout preventer drops, the biasing of spring 82 and
the pressurized gas raises the piston 80 to drive the fluid
thereabove back into the blowout preventer.
The packing insert 45 is slid in the stationary blowout preventer
25 from the vessel 10 by sliding a drill pipe tool 17 therethrough
and then mounting a pin sub (not shown) below the packing insert 45
and above the bit (not shown). The drill pipe tool 17 with the
packing insert 45 is lowered down the conduit riser 16. As the
lower ring 48 of the packing insert 45 reaches the blowout
preventer 25, the landing shoulder 51 engages the sloping nose 60
of the dog 59 and slides it radially outwardly against the biasing
of the spring 66 in the open position permitting the packing unit
45 to pass thereby.
As best seen in FIG. 4, the packing insert 45 slides through the
upper central bore 42, and through the blowout preventer 25 until
landing shoulder 51 engages the chamfered landing shoulder to halt
the downward movement of and position the packing insert 45
properly in the blowout preventer 25.
When the packing insert 45 is being positioned within the
stationary blowout preventer 25, the slope nose 60 of the dog 59 is
slid radially inwardly by the spring 66 into latching notch 56
which is simultaneously aligned therewith. The nose 60 of the dog
59 engages the latching notch 56 on the upper ring 47 to hold the
insert 45 within the blowout preventer 25.
The blowout preventer 25 is actuated from the surface vessel 10 by
hydraulic fluid under pressure supplied through pressure line 71,
through inlet opening 72 into the stationary blowout preventer 25
space between the upper cylindrical internal surface 30 and the
outward surface of the central rubber portion 33 of the outer
tubular element 32 to expand the outward surface of the rubber
portion 33 in the outer tubular element 32 bulging the center
thereof radially inwardly to bulge the rubber portion 37 of the
inner tubular element 36 radially inwardly to press the central
rubber portion 46 to the packing insert 45 radially inwardly until
the inner surface thereof sealingly engages the drill pipe 17 run
therethrough. The pressure on the exterior surface of the rubber 33
of the outer element 32 is also exerted on the piston 80 of the
fluid accumulator 75 but is balanced by the spring 82 and the gas
pressure from the well.
If, for some reason, such as the vessel 10 bobbing up and down on
the surface of the sea 11, a collar or tool joint 18 is forced
through the blowout preventer 25, as is shown in FIG. 3, the
passage of the collar 18 locally expands the center rubber portion
46 of the retrievable packing insert 45 with the balance of the
center rubber portion 46 surrounding the pipe 17 to sealingly
engage the pipe tool 17 and the collar 18 as the collar 18 passes
therethrough. The bulging of the rubber 46 in turn presses against
the rubber portion 37 of the inner tubular element 36 to press
against the rubber portion 33 of the outer tubular element 32 to
raise the hydraulic pressure between the outward surface of the
rubber portion 33 and the internal surface 30 of the preventer body
26. Because the fluid is essentially incompressible in order for
any expansion of the rubber portions 46, 37 and 33 to occur, the
surge pressure applied to the fluid must exhaust some of the fluid
therein. The fluid should not be forced up the pressure line 71,
and so it exhausts into the fluid accumulator 75 through the
opening 76 and the line 77 and opening 78 into the cylinder 79 on
the upper side of the piston as is shown in FIG. 3. The piston 80
is driven downwardly thereby against the biasing of spring 82 in
the pressure of the wellhead 14 as has been previously
explained.
Once the collar 18 is through the blowout preventer 25, the
additional pressure is released and the biasing of the spring 82
and the gas pressure in the wellhead 14, acting against the bottom
side of the piston 80, returns the fluid above the piston 80 via
opening 78, line 77 opening line 76 to the space between the rubber
portion 33 of the outer element 32 and the upper cylindrical
internal surface 30 of the preventer body 26 to maintain the
central rubber portion 46 of the packing unit 45 in sealing
engagement with the pipe 17. This action occurs as many times as
the collar 18 on the drill pipe 17 is forced through the blowout
preventer 25.
If after repeated use, the rubber portion 46 of the packing insert
45 is thought to be worn, the packing insert 45 may be removed from
the blowout preventer 25 for inspection at the surface. To remove
the packing insert 45, the pressure in the pressure lines 19 is
released, permitting the central rubber 46, the rubber 37, and the
rubber 33 to return to the open position shown in FIG. 4.
A retrieving tool 85 is attached to the drill pipe 17. The
retrieving tool 85, as shown in FIG. 4, includes radially movable
flanges 86 extending through openings 87 in the retrieving tool 85.
The flanges 86 are biased by spring 88 radially inwardly. The
retrieving tool 85 also contains a wedge 89 which drives the
flanges 86 radially outwardly against the spring biasing.
The retrieving tool 85 is lowered through the packing insert 45
with the flanges 86 retracted, and the wedge 89 is driven
downwardly spreading the flanges 86 radially outwardly until they
will engage the lower metal ring 48 of the packing insert 45. With
the flanges 86 of the retrieving tool 85 extended radially
outwardly, the tool 85 is raised until the flanges 86 thereof
engage the lower metal ring 48.
The latching means 55 is then released by supplying fluid under
pressure through opening 68 to the radially inward end of the
piston 64 moving the piston 64, the piston rod 61 and the dog 59
radially outwardly against the biasing of spring 65, to move the
sloped nose 60 out of the latching notch 56 in the upper metal ring
47. As seen in FIG. 4, this releases the packing insert 45, so that
the retrieving tool 85 and the packing insert 45 can be raised by
raising drill pipe 17 using derrick 15 to the barge or vessel 10
where the insert 45 can be inspected and replaced if need be by
repeating the insertion operation.
Thus the improved stationary blowout preventer according to this
invention adds a retrievable packing insert within the blowout
preventer and latching means securing the packing insert within the
blowout preventer, and adds a fluid accumulator to facilitate the
action of the packing insert in allowing the collar of a drill pipe
to pass therethrough without breaking the sealing engagement
between the rubber of the packing insert and the drill pipe.
* * * * *