U.S. patent application number 14/047984 was filed with the patent office on 2015-04-09 for single size actuator for multiple sliding sleeves.
This patent application is currently assigned to Swellfix BV. The applicant listed for this patent is Swellfix BV. Invention is credited to Christian Atilano, Henry Joe Jordan, Jr., Khai Tran.
Application Number | 20150096767 14/047984 |
Document ID | / |
Family ID | 51688054 |
Filed Date | 2015-04-09 |
United States Patent
Application |
20150096767 |
Kind Code |
A1 |
Atilano; Christian ; et
al. |
April 9, 2015 |
SINGLE SIZE ACTUATOR FOR MULTIPLE SLIDING SLEEVES
Abstract
A multiplier sleeve has a releasable seat coupled to a dog
within the slidable sleeve allows a single sized ball, dart, or
plug to actuate several sliding sleeves. Upon actuation by properly
sized ball the ball, slidable sleeve, seat, and dog move downward
where the dog is no longer supported allowing the seat to move
within the slidable sleeve to a point where the seat is no longer
supported thereby releasing the ball. With the slidable sleeve
moved downward the port or ports in the sliding sleeve is exposed.
A staged port and piston assembly inserted into the ports maintain
pressure within the tubular assembly to allow the ball to move
through and actuate the targeted sliding sleeves.
Inventors: |
Atilano; Christian;
(Houston, TX) ; Jordan, Jr.; Henry Joe; (Willis,
TX) ; Tran; Khai; (Pearland, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Swellfix BV |
Rijswijk ZH |
|
NL |
|
|
Assignee: |
Swellfix BV
Rijswijk ZH
NL
|
Family ID: |
51688054 |
Appl. No.: |
14/047984 |
Filed: |
October 7, 2013 |
Current U.S.
Class: |
166/383 ;
166/317; 166/318; 166/319; 166/386 |
Current CPC
Class: |
E21B 2200/06 20200501;
E21B 34/10 20130101; E21B 34/14 20130101; E21B 43/14 20130101; E21B
34/063 20130101; E21B 43/26 20130101 |
Class at
Publication: |
166/383 ;
166/318; 166/386; 166/319; 166/317 |
International
Class: |
E21B 43/12 20060101
E21B043/12; E21B 43/14 20060101 E21B043/14; E21B 34/06 20060101
E21B034/06 |
Claims
1. A downhole device comprising: a seat in a first position has a
first diameter; a dog coupled to the seat; wherein in a first
position the dog prevents the seat from longitudinal movement
within an inner sleeve; further wherein the dog in a second
position allows the seat to move longitudinally within the inner
sleeve; and the seat in a second position has a second
diameter.
2. The downhole device of claim 1 wherein, the inner sleeve has a
first position within a housing wherein the dog is supported by the
housing in the dog's first position.
3. The downhole device of claim 1 wherein, the inner sleeve has a
second position within a housing wherein the dog is supported by a
relief in the housing in the dog's second position.
4. The downhole device of claim 1 wherein, the seat is coupled to
an anti-reverse tubular, wherein the coupling between the seat and
the anti-reverse tubular is ratcheted.
5. The downhole device of claim 4 wherein, the anti-reverse tubular
has an anti-rotation ring and the inner sleeve has a stop tab.
6. The downhole device of claim 5 wherein, upon rotation the
coupling between the seat and the anti-reverse tubular is
tightened.
7. A method for activating a downhole device comprising: moving a
sleeve from a first position to a second position; disengaging a
dog from a seat within the inner sleeve; moving the seat from a
first position to a second position within the inner sleeve; and
radially expanding the seat from a first diameter to a second
diameter.
8. The method of claim 7 wherein, the inner sleeve has a first
position within a housing wherein the dog is supported by the
housing in the dog's first position.
9. The method of claim 7 wherein, the inner sleeve has a second
position within a housing wherein the dog is supported by a relief
in the housing in the dog's second position.
10. The method of claim 7 further comprising: shearing a lock to
allow the sleeve to move from the first position to the second
position.
11. The method of claim 7 wherein, the seat is coupled to an
anti-reverse tubular, wherein the coupling between the seat and the
anti-reverse tubular is ratcheted.
12. The method of claim 11 wherein, the anti-reverse tubular has an
anti-rotation ring and the inner sleeve has a stop tab.
13. The downhole device of claim 12 further comprising: tightening
the coupling between the seat and the anti-reverse tubular upon
rotation.
14. A port restrictor in a downhole device comprising: a port in a
housing; a disk fixed within the port, wherein the disc has a
nozzle extending through it; and a piston fixed within the port
radially outward from a center of the housing of the disc.
15. The port restrictor of claim 14 wherein, the disc is threaded
to the port.
16. The port restrictor of claim 14 wherein, the disc is pinned to
the port.
17. The port restrictor claim 14 wherein, the piston is threaded to
the port.
18. The port restrictor claim 14 wherein, the piston is pinned to
the disc.
19. The port restrictor of claim 18 wherein, the pins are shear
pins.
20. The port restrictor claim 14 wherein, the piston has a slot
across a surface adjacent to the disc.
21. A method for activating a downhole device comprising: moving an
inner sleeve from a first position to a second position, wherein a
port in a housing is exposed; flowing fluid through a nozzle in a
disc, wherein the disc is fixed in the port; removing a piston
radially outward of the disc; disengaging a dog from a seat within
the inner sleeve; moving the seat from a first position to a second
position within the inner sleeve; and radially expanding the seat
from a first diameter to a second diameter.
22. The method of claim 21 wherein, the inner sleeve has a first
position within a housing wherein the dog is supported by the
housing in the dog's first position.
23. The method of claim 21 wherein, the inner sleeve has a second
position within a housing wherein the dog is supported by a relief
in the housing in the dog's second position.
24. The method of claim 21 further comprising: shearing a lock to
allow the sleeve to move from the first position to the second
position.
25. The method of claim 21 wherein, the seat is coupled to an
anti-reverse tubular, wherein the coupling between the seat and the
anti-reverse tubular is ratcheted.
26. The method of claim 25 wherein, the anti-reverse tubular has an
anti-rotation ring and the inner sleeve has a stop tab.
27. The downhole device of claim 26 further comprising: tightening
the coupling between the seat and the anti-reverse tubular upon
rotation.
Description
BACKGROUND
[0001] In the course of producing oil and gas wells, typically
after the well is drilled, the well may be completed. One way to
complete a well is to divide the well into several zones and then
treat each zone individually.
[0002] One method of individually treating multiple sections in a
well is to assemble a tubular assembly on the surface where the
tubular assembly has a series of spaced apart sliding sleeves.
Sliding sleeves are typically spaced so that at least one sliding
sleeve will be adjacent to each zone. In some instances annular
packers may also be spaced apart along the tubular assembly in
order to divide the wellbore into the desired number of zones. In
other instances when annular packers are not used to divide the
wellbore into the desired number of zones the tubular assembly may
be cemented in place.
[0003] Typically the tubular assembly is run into the wellbore with
the sliding sleeves in the closed position. Once the tubular
assembly is in place and has been cemented in place or the packers
have been actuated the wellbore may be treated.
[0004] One well known wellbore treatment consists of pumping a
viscosified fluid containing a proppant at high pressure down
through the tubular assembly out of a specified sliding sleeve and
into the formation. The high-pressure fluid tends to form cracks
and fissures in the formation allowing the viscosified fluid to
carry the proppant into the cracks and fissures. When the treatment
ends, the proppant remains in the cracks and fissures holding the
cracks and fissures open and allowing wellbore fluid to flow from
the formation zone, through the open sliding sleeve, into the
tubular assembly, and then to the surface.
[0005] To open a sliding sleeve, an obturator, such as a ball, a
dart, etc., is dropped into the wellbore from the surface and
pumped through the tubular assembly. The obturator is pumped
through the tubular assembly to the sliding sleeve where it lands
on the seat of the sliding sleeve and forms a seal with the seat on
the sliding sleeve to block further fluid flow past the ball and
the seat. As additional fluid is pumped into the well the
differential pressure formed across the seat and ball provides
sufficient force to move the sliding sleeve from its closed
position to its open position. Fluid may then be pumped out of the
tubular assembly and into the formation so that the formation may
be treated.
[0006] In order to selectively open a particular sliding sleeve the
obturator may be sized so that it will pass through multiple
sliding sleeves until finally reaching the sliding sleeve where the
seat size matches the size of the obturator. In practice the
sliding sleeve with the smallest diameter seat is located closest
to the bottom or toe of the well. Each sliding sleeve above the
lowest sliding sleeve has a seat with a diameter that is slightly
larger than the seat below it. By using seats that step up in size
as they get closer to the surface, a small diameter obturator may
be dropped into the tubular assembly and will pass through each of
the larger diameter seats on each sliding sleeve above the lowest
sliding sleeve. The obturator finally reaches the sliding sleeve
with a seat diameter that matches the diameter of the obturator.
The obturator and seat block the fluid flow past the sliding sleeve
actuating the particular sliding sleeve.
[0007] Progressively larger obturators are launched into the
tubular assembly to selectively open each sliding sleeve. Each seat
and obturator must be sized so that the seat provides sufficient
support for the obturator at the anticipated pressure. Due to the
increasing size of the obturators and seats there seems to be an
upper limit on the number of sliding sleeves that may be utilized
in a single well thereby limiting the productivity of the well. An
additional limitation of the current technology is that by
utilizing progressively smaller seats towards the bottom of the
well the productivity of the well is further limited as each seat
chokes fluid flow from the bottom of the well towards the top of
the well. Therefore in practice there is usually the additional
step of drilling out the seats adding further costs to completing
the well.
SUMMARY
[0008] One solution to the problem of the upper limit on the number
of sliding sleeves that may be utilized in a single well is to use
a multiplier sleeve that allows a single obturator to activate
multiple sliding sleeves. In one embodiment an obturator will be
launched into the well. The obturator will land upon the targeted
seat in a particular multiplier sleeve. As pressure builds, the
seat will exert pressure upon a dog that is coupled to both the
seat and to the inner sleeve. At some point a shear pin will shear
allowing the inner sleeve, seat, and dog to move downward towards
the toe of the well. At some point a port in the housing of the
multiplier sleeve will be exposed. However fluid pressure in the
interior of the multiplier sleeve is blocked from passing through
the port by a disc and piston assembly. The disc and piston
maintain fluid pressure within the interior of the multiplier
sleeve. At some preselected pressure level the fluid pressure will
act upon the piston through a nozzle in the disc forcing the piston
out of the port so that fluid may flow through the nozzle and into
the formation. With the port in the housing of the multiplier
sleeve exposed, the dog also reaches a position where a relief has
been cut into the interior wall of the housing to allow the dog to
radially expand outward thereby releasing the seat to move
longitudinally within the inner sleeve. As the fluid pressure
continues to act across the obturator and seat, the seat is forced
downward within the inner sleeve. The seat reaches a position where
a relief has been cut into the interior wall of the inner sleeve to
allow the seat to radially expand outward thereby releasing the
obturator to move through the multiplier sleeve to the next
targeted multiplier sleeve.
[0009] In one embodiment of the multiplier sleeve, the multiplier
sleeve may have a seat in a first position with a first diameter. A
dog may be coupled to the seat. In a first position the dog
prevents the seat from longitudinal movement within an inner sleeve
and in a second position allows the seat to move longitudinally
within the inner sleeve. The seat in a second position has a second
diameter. The inner sleeve has a first position within a housing
wherein the dog is supported by the housing in the dog's first
position. The inner sleeve has a second position within a housing
wherein the dog is supported by a relief in the housing in the
dog's second position. The seat is coupled to an anti-reverse
tubular and the coupling between the seat and the anti-reverse
tubular is ratcheted. The anti-reverse tubular has an anti-rotation
ring and the inner sleeve has a stop tab and upon rotation the
coupling between the seat and the anti-reverse tubular is
tightened.
[0010] A method of utilizing an embodiment of a multiplier sleeve
has the sleeve moving from a first position to a second position.
The dog is disengaged from a seat within the inner sleeve to allow
the seat to move from a first position to a second position within
the inner sleeve and upon the seat reaching the second position the
seat is radially expanded from a first diameter to a second
diameter. The inner sleeve has a first position within a housing
wherein the dog is supported by the housing in the dog's first
position and the inner sleeve has a second position within a
housing wherein the dog is supported by a relief in the housing in
the dog's second position. A shear pin, screw, C ring, or other
lock is sheared to allow the sleeve to move from the first position
to the second position. The seat is coupled to an anti-reverse
tubular and the coupling between the seat and the anti-reverse
tubular is ratcheted. The anti-reverse tubular has an anti-rotation
ring and the inner sleeve has a stop tab. Upon rotation the
coupling between the seat and the anti-reverse tubular may be
tightened.
[0011] An embodiment of the port restrictor has a port in a
housing. A disc is fixed within the port and has a nozzle extending
through it. A piston may be fixed within the port radially outward
from a center of the housing of the disc. The disc may be threaded
or pinned within the port. The piston may be threaded or pinned to
the port or to the disc by shearable threads or pins. In many
instances the piston may have a slot or slots across the surface of
the piston is adjacent to the disc.
[0012] A method of utilizing an embodiment of a multiplier sleeve
has the sleeve moving from a first position to a second position to
expose a port in the housing. Fluid may then pass through a nozzle
in the disc to act upon the piston radially outward and adjacent to
the disc. The fluid pressure shears the pins or other shareable
device that retain the piston in the port, thereby removing the
piston from the port. The dog is disengaged from a seat within the
inner sleeve to allow the seat to move from a first position to a
second position within the inner sleeve and upon the seat reaching
the second position the seat is radially expanded from a first
diameter to a second diameter. The inner sleeve has a first
position within a housing wherein the dog is supported by the
housing in the dog's first position and the inner sleeve has a
second position within a housing wherein the dog is supported by a
relief in the housing in the dog's second position. A shear pin,
screw, C ring, or other lock is sheared to allow the sleeve to move
from the first position to the second position. The seat is coupled
to an anti-reverse tubular and the coupling between the seat and
the anti-reverse tubular is ratcheted. The anti-reverse tubular has
an anti-rotation ring and the inner sleeve has a stop tab. Upon
rotation the coupling between the seat and the anti-reverse tubular
may be tightened.
BRIEF DESCRIPTION OF THE DRAWINGS
[0013] So that the manner in which the above recited features of
the present invention can be understood in detail, a more
particular description of the invention, briefly summarized above,
may be had by reference to embodiments, some of which are
illustrated in the appended drawings. It is to be noted, however,
that the appended drawings illustrate only typical embodiments of
this invention and are therefore not to be considered limiting of
its scope, for the invention may admit to other equally effective
embodiments.
[0014] FIG. 1 depicts a completion where a wellbore has been
drilled through one or more formation zones and has a tubular
assembly within the wellbore.
[0015] FIG. 2 depicts a multiplier sleeve in its closed
position.
[0016] FIG. 3 depicts the multiplier sleeve just after the
obturator lands on the seat.
[0017] FIG. 4 depicts the multiplier sleeve with the inner sleeve
shifted to its fully open position.
[0018] FIG. 5 depicts the multiplier sleeve as the seat is released
to begin moving downward towards the toe of the wellbore with an
anti-reverse device.
[0019] FIG. 6 depicts the seat and its coupled anti-reverse device
moved to the anti-reverse devices stop position.
[0020] FIG. 7 depicts the first disc and piston inserted in the
port with the inner sleeve fully open.
[0021] FIG. 8 depicts first disc after sufficient fluid pressure
has been exerted through the hole to release piston.
[0022] FIG. 9 depicts the first disc secured within the port as
fluid flow moves from the interior to the exterior of the
housing.
[0023] FIG. 10 depicts a top view of the first disc with a hole
through the center of first disc but after the piston has been
released.
[0024] FIG. 11 depicts the first disc after fluid has been flowing
from the interior to the exterior of the housing enlarging the hole
over time.
DETAILED DESCRIPTION
[0025] The description that follows includes exemplary apparatus,
methods, techniques, and instruction sequences that embody
techniques of the inventive subject matter.
[0026] FIG. 1 depicts a completion where wellbore 10 has been
drilled through one or more formation zones 22, 24, and 26. A
tubular assembly 12, consisting of casing joints, couplings,
annular packers 32, 34, 36, and 38, multiplier sliding sleeves 42,
44, and 46, that are initially pinned in place in the closed
position by shear pins 62, 64, and 66, and has been run into the
wellbore 10. The well 10, if it is a horizontal or at least a
non-vertical well, may have a heel 30 and at its lower end will
have a toe 40.
[0027] Typically the casing assembly 12 is made up on the surface
20 and is then lowered into the position 10 by the rig 30 until the
desired depth is reached so that multiplier sliding sleeves 42, 44,
and 46 are adjacent formation zones 22, 24, and 26. In many
instances there may be a plurality of sliding sleeves adjacent to
any single formation zone, such as formation zones 22, 24, and 26.
The annular packers are arranged along the tubular assembly so that
annular packer 32 is placed below formation zone 22 and annular
packer 34 is placed above formation zone 22 and both annular
packers 32 and 34 are actuated to isolate formation zone 22 from
all of the zones in the well 10. Annular packer 34 is placed so
that while it is above formation zone 22 is below formation zone 24
and annular packer 36 is placed above formation zone 24 and both
annular packers 34 and 36 are actuated to isolate formation zone 24
from all other zones in the well 10. Annular packer 36 is placed so
that while it is above formation zone 24 is below formation zone 26
and annular packer 38 is placed above formation zone 26 and both
annular packers 36 and 38 are actuated to isolate formation zone 26
from all other zones in the wellbore 10. While the wellbore 10 is
depicted in FIG. 1 as using casing annular packers to isolate the
formation zones in many instances the casing assembly 12 may be
cemented in place to provide zonal isolation.
[0028] In operation an obturator 13 is dropped or inserted into the
fluid flow at the surface. The obturator 13 may be a ball, dart,
plug, or any other device that may be inserted into the fluid flow
to actuate a specific sliding sleeve or group of sliding sleeves
such as the multiplier sleeves. The obturator 13 is sized so that
as the obturator 13 progresses through the casing assembly 12 the
obturator 13 will pass through any sliding sleeves or multiplier
sleeves such as sliding sleeve 46 that may be positioned above the
targeted multiplier sleeves 44 and 42 without actuating the
non-targeted sliding sleeve 46. Upon reaching the first targeted
multiplier sleeve 44 the obturator 13 will land on the seat 70 and
as pressure increases across the seat 70 and obturator 13 shear pin
64 will shear allowing sliding sleeve 44 and seat 70 to move
towards the toe 40 of the wellbore 10 exposing port 72. Initially
port 72 is blocked by a first disc and piston assembly (not shown).
With the port 72 exposed fluid pressure will act upon the first
disc and piston assembly to open a flowpath from the interior of
the casing assembly 12 to the formation zone 24. As the sliding
sleeve 44 and seat 70 and towards the toe 40 the seat 70 will
release the obturator 13 to allow it to continue on to the next
targeted multiplier sleeve 42 were the actuation process is
repeated and eventually the obturator 13 is released to continue on
to the final targeted sliding sleeve 41 where the sliding sleeve 41
is moved towards the toe 40 to expose the port 43 but in this
instance the obturator 13 is not released from the seat 45 so that
targeted formation zones 22, 23, and 24 or portions of formation
zone may be treated.
[0029] FIG. 2 depicts a multiplier sleeve such as multiplier sleeve
44 in its closed position. The multiplier sleeve 44 has an outer
housing 80 and an inner sleeve 82. The outer housing 80 has at
least one port 72 through it to allow fluid access from the
interior 84 of the multiplier sleeve 44 to the exterior 86. The
inner sleeve 82 is held in place by shear pins 64 and 65 while
first seal 96 and second seal 98 prevent fluid from flowing around
the inner sleeve 82 to port 72. On the interior surface 81 of the
housing 80 adjacent port 72 a relief 99 may be milled into interior
surface 81 of the housing 80 so that seal 96 may slide across the
port 72 without damage. The relief 99 also tends to reduce friction
between the seal 96 and the housing 80 when the inner sleeve 82 is
shifted. In its run in or closed condition, the port 72 has a first
disc 88 threaded into the port 72.
[0030] While usually the first disc 88 is threaded into port 72 any
means of securing the first disc 88 into the port 72 such as
welding, shear pins, press fitting, or any other means known in the
industry may be used to secure the first disc 88 in the port 72.
Usually the method used to secure the first disc 88 in the port 72
will include a fluid tight seal such as an O-ring or metal to metal
seal. Typically while the first disc 88 has a fluid tight seal
around the exterior the first disc 88 has a hole 92 through the
first disc 88 usually near its center. A piston 90 is secured
adjacent to the first disc 88 in a manner that causes a fluid tight
seal between the first disc 88 and the piston 90. The piston 90 may
be secured adjacent the first disc 88 by shear pins 94, or by any
other means known in the industry, so that when sufficient pressure
is applied through hole 92 in first disc 88 against the bottom of
the piston 90 the shear pins 94 will shear allowing the fluid
pressure to remove the piston 90 from blocking fluid flow through
hole 92. While the piston 90 in shown being positioned in a cutout
in first disc 88 the piston 90 may be secured adjacent first disc
88 by securing the piston 90 directly to the sides of port 72 in
housing 80.
[0031] In the multiplier sleeve's 44 run in condition the dog 102
is supported by the interior surface 81 of the housing 80. In turn
the seat 70 is supported by at least one dog 102. The seat 70 has a
radially exterior profile 104 that operatively matches the radially
interior profile 106 on the dog 102 where the toe end 108 of
profile 106 matches the toe end 112 of the seat 104 and the heel
end 114 of the profile 106 matches the heel end 118 of the seat
104. The angles between the toe end 108 and the toe end 112 as well
as between the heel end 114 and the heel end 118 may be selected to
allow linear downward (towards the toe) motion of the seat 70 to be
transferred to the dog 102 as a radially outward force. The
profiles between the seat 70 and the dog 102 may be angles, curves,
or any other shape that allows a linear downwards force to be
redirected in a radially outwards direction.
[0032] FIG. 3 depicts the multiplier sleeve 44 just after the
obturator 13 lands on seat 70. Fluid pressure from the surface 20
ask across the obturator 13, the seat 70, and a portion of the
inner sleeve 82 to shear the shear pins 64 thereby allowing the
inner sleeve 82 to begin moving towards the toe 40 of the wellbore
10. As depicted in FIG. 3, even though the inner sleeve 82 has
moved some distance towards the toe 40 of the wellbore 10 first
seal 96 and second seal 98 continue to provide a fluid seal between
the interior 84 of the multiplier sleeve 44 and the exterior 86 of
the multiplier sleeve 44. The dog 102 remains supported by the
interior surface 81 of the housing 80 in turn the dog 102 continues
to prevent the seat 70 from moving longitudinally in relation to
the inner sleeve 82. Seat 70 is radially supported by interior
surface 83 of the inner sleeve 82. Additionally, the anti-reverse
ring 134 is also supported by the interior surface 81 of the
housing 80 thereby remaining in a non-actuated configuration.
[0033] FIG. 4 depicts the multiplier sleeve 44 with the inner
sleeve 82 shifted to its fully open position so that the
anti-rotation tab 120 on the inner sleeve 82 is in position so that
in the event that the inner sleeve 82 rotates within the housing 80
the anti-rotation tab 120 on the inner sleeve 82 will contact the
stop tab 122 on the second housing 130. As depicted the second
housing 130 is threaded into housing 80 with seals 124 and 126 to
prevent fluid pathways between the interior 84 of the multiplier
sleeve 44 and the exterior 86 of the multiplier sleeve 44. While
second housing 130 is depicted as being threaded into the housing
80 the second housing 130 and the housing 80 could be welded
together, they could be machined as a single unit, the housing 80
could be threaded into the second housing 130, they could be pinned
together, or they could be attached by any means known in the
industry. With the inner sleeve 82 shifted to its fully open
position both the anti-reverse ring 134 and the dog 102 are moved
to a second relief 132 are formed in the housing 80 and are no
longer supported in their initial positions by the interior surface
81 of the housing 80. Once the anti-reverse ring 134 moves into the
second relief 132 anti-reverse ring 134 may expand radially outward
into the second relief 132. The anti-reverse ring 134 is sized such
that after the anti-reverse ring 134 expands radially outward into
the second relief 132 at least a portion of the anti-reverse ring
134 will remain within slot 140 and the inner sleeve 82 so that in
the event that inner sleeve 82 begins to move towards the heel 30
of wellbore 10, the anti-reverse ring 134 engages first shoulder
144 on the housing 80 and second shoulder 146 on the inner sleeve
82 preventing further movement by the inner sleeve 82 towards the
heel 30 of the wellbore 10.
[0034] With the inner sleeve 82 shifted to its fully open position
seal 96 is moved from its position above port 72 to below port 72
thereby exposing the first disc 88 disposed in port 72 to the fluid
in the interior 84 of the multiplier sleeve 44. The fluid through
hole 92 may exert pressure against the piston 90. When sufficient
pressure is present shear pins 94 will release the piston 90 to
allow fluid to flow through the whole 92 to the exterior 86.
[0035] FIG. 5 depicts the multiplier sleeve 44 with the
anti-reverse ring 134 expanded radially outward into the second
relief 132 and with dog 102 also expanded radially outward into the
second relief 132. With the dog 102 expanded radially outward the
seat 70 is released to begin moving downward towards the toe 40 of
the wellbore 10. As the seat 70 moves downward the seat carries
with it an anti-reverse device 150. The seat 70 and the
anti-reverse device 150 are coupled together at interface 152 by
ratcheting rings or threads that may or may not be ratcheted.
Anti-reverse device 150 includes an anti-rotation tab 154.
[0036] FIG. 6 depicts the multiplier sleeve 44 with the seat 70 and
its coupled anti-reverse device 150 moved to its stop position
against insert 160. Insert 160 serves to halt the longitudinal
movement of the anti-reverse device 150 and the seat 70 towards the
toe 40 of the wellbore 10. In addition insert 160 has a stop tab
162. In the event that the seat 70 and the anti-reverse device 150
begin to rotate anti-rotation tab 154 will engage against the stop
tab 162 to prevent the anti-reverse device 150 from rotating.
Preferably the seat 70 and the anti-reverse device 150 are coupled
together at interface 152 by ratcheting left-hand threads. During
mill out with right-hand rotation the left-hand threads at
interface 152 causes the seat 72 threaded onto the anti-reverse
device 150 becoming tighter or more difficult to turn as right-hand
rotation continues, eventually the seat 70 can no longer be tight
on to anti-reverse device 150 and may be milled out. Insert 160 may
be threaded or otherwise coupled to inner sleeve 82.
[0037] As seat 70 moves downward, the seat 70 moves to relief 170
that is formed on an interior surface of inner sleeve 82. Once the
seat 70 moves to relief 170 the seat 70 is no longer radially
supported by interior surface 83 and may move radially outward to
release obturator 13. The seat 70 may be formed from a single piece
of material where the single piece of material may be slotted, may
be frangible, or may be made from multiple pieces of material that
are retained by spring an elastomer or the interior surface of the
inner sleeve 82 as long as the circumferential expansion of the
sleeve 70 caused by the sleeve moving radially outward is provided
for so that obturator 13 may be released. Typically as the
obturator 13 radially expands the seat 70 the seat 70 will be
forced downward in outward over anti-reverse device 150. The
ratcheting threads at interface 152 prevent the seat 70 from
returning to its initial diameter thereby allowing the obturator 13
to flowing out of the wellbore 10 as the formations 22, 24, and 26
are produced.
[0038] FIGS. 7, 8, and 9 are close-ups of the port 72. FIG. 7
depicts a first disc 88 and piston 90 inserted in the port 72 with
inner sleeve 82 fully open. As depicted in FIG. 7 first disc 88 has
threads 200 that engage with the port side walls 202 that fix the
first disc 88 in place within the port 72. The first disc 88 is
threaded into the port 72 so that seal 204 is captured between
shoulder 206 and first disc 88 to form a fluid seal between the
shoulder 206 and the first disc 88 thereby limiting fluid flow from
the interior 84 of the multiplier sleeve 44 to the hole 92. Further
fluid flow through the first disc 88 is then blocked by piston 90.
As depicted piston 90 is inserted into a recess 208 formed in first
disc 88. Piston 90 is inserted into recess 208 so that seal 212 is
captured between first disc 88 and piston 90 to block fluid flow
through hole 92. Piston 90 may have slots formed in his radially
inward surface 220 so that fluid flowing through hole 92 made be
distributed across the radially inward surface 220 of the piston
90. Piston 90 may be fixed to first disc 88 by shear pins such as
shear pins 214. In practice the first disc 88 and piston 92
assembly may be assembled prior to being inserted into port 72. In
certain instances the first disc 88 may be pressed into port 72 or
may be machined into the housing 80 as part of port 72. The piston
may then be threaded, pressed, or otherwise fixed in place adjacent
to first disc 88 without necessarily being inserted into a recess
such as recess 208 in the first disc 88.
[0039] As depicted in FIG. 8 sufficient fluid pressure has been
exerted through hole 92 in first disc 88 and across the radially
inward surface 220 to shear the shear pins 214 thereby releasing
the piston 90 from recess 208 in first disc 88. FIG. 9 depicts
first disc 88 secured within port 72 as fluid flow, depicted by
arrows 222, is allowed to move from the interior 84 to the exterior
86 of the housing 80.
[0040] FIG. 10 depicts a top view of first disc 88 having hole 92
through the center of first disc 88 but after piston 90 has been
released. FIG. 11 depicts first disc 88 having an enlarged hole 92.
In many instances depending upon the material used to construct
first disc 92 as the fluid flows from the interior 84 to the
exterior 86 of the housing 80 through hole 92 the material will be
worn away enlarging hole 92 over time.
[0041] Bottom, lower, or downward denotes the end of the well or
device away from the surface, including movement away from the
surface. Top, upwards, raised, or higher denotes the end of the
well or the device towards the surface, including movement towards
the surface. While the embodiments are described with reference to
various implementations and exploitations, it will be understood
that these embodiments are illustrative and that the scope of the
inventive subject matter is not limited to them. Many variations,
modifications, additions and improvements are possible.
[0042] Plural instances may be provided for components, operations
or structures described herein as a single instance. In general,
structures and functionality presented as separate components in
the exemplary configurations may be implemented as a combined
structure or component. Similarly, structures and functionality
presented as a single component may be implemented as separate
components. These and other variations, modifications, additions,
and improvements may fall within the scope of the inventive subject
matter.
[0043] While the foregoing is directed to embodiments of the
present invention, other and further embodiments of the invention
may be devised without departing from the basic scope thereof, and
the scope thereof is determined by the claims that follow.
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