U.S. patent application number 13/957925 was filed with the patent office on 2015-02-05 for valve assembly.
This patent application is currently assigned to Schlumberger Technology Corporation. The applicant listed for this patent is Schlumberger Technology Corporation. Invention is credited to William Mark Norrid.
Application Number | 20150034324 13/957925 |
Document ID | / |
Family ID | 52426607 |
Filed Date | 2015-02-05 |
United States Patent
Application |
20150034324 |
Kind Code |
A1 |
Norrid; William Mark |
February 5, 2015 |
VALVE ASSEMBLY
Abstract
A system that is usable with a well includes a string and valve
assemblies that are disposed on the string. The valve assembly
includes at least one control port and at least one radial fluid
communication port. The valve assembly is adapted to serially
receive an untethered object deployed in the string such that
receipt of the object by a valve assembly of the plurality of valve
assemblies creates a fluid obstruction to cause the valve assembly
to expose the at least one control port of the valve assembly;
serially release the untethered object; and jointly respond to
pressurization of the string to open the radial fluid communication
ports.
Inventors: |
Norrid; William Mark;
(Westminster, CO) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Schlumberger Technology Corporation |
Sugar Land |
TX |
US |
|
|
Assignee: |
Schlumberger Technology
Corporation
Sugar Land
TX
|
Family ID: |
52426607 |
Appl. No.: |
13/957925 |
Filed: |
August 2, 2013 |
Current U.S.
Class: |
166/308.1 ;
166/373; 166/72 |
Current CPC
Class: |
E21B 34/103 20130101;
E21B 34/14 20130101; E21B 2200/06 20200501 |
Class at
Publication: |
166/308.1 ;
166/373; 166/72 |
International
Class: |
E21B 34/14 20060101
E21B034/14; E21B 34/16 20060101 E21B034/16; E21B 43/26 20060101
E21B043/26 |
Claims
1. A method usable with a well, comprising: deploying an untethered
object in a string, the string comprising valve assemblies and each
of the valve assemblies comprising at least one control port;
propagating the object through the valve assemblies to cause the
valve assemblies to expose control ports of the valve assemblies;
and pressurizing the string to jointly apply pressure to the
control ports of the valve assemblies to cause the valve assemblies
to open radial fluid communication ports between a passageway of
the string and a region outside of the string.
2. The method of claim 1, wherein propagating the object through
the valve assemblies comprises: landing the object in a first valve
assembly of the plurality of valve assemblies; and using a fluid
obstruction formed from the landed object to shift a sleeve of the
first valve assembly to expose the at least one control port of the
first valve assembly.
3. The method of claim 2, further comprising: releasing the object
in response to shifting of the sleeve; and landing the released
object in a second valve assembly of the plurality of valve
assemblies.
4. The method of claim 1, wherein pressurizing the string comprises
shifting sleeves of the valve assemblies to expose the radial fluid
communication ports.
5. The method of claim 1, further comprising: using the opened
radial fluid communication ports to communicate a fracturing fluid
to a surrounding formation to perform a fracturing operation.
6. The method of claim 1, wherein propagating the object through
the valve assemblies comprises: for at least one of the valve
assemblies, landing the object in the valve assembly, shifting a
sleeve of the valve assembly open, locking the sleeve open and
releasing the object to allow the object to pass through the valve
assembly.
7. The method of claim 1, wherein pressurizing the string
comprises: landing the object in a seat downhole of the valve
assemblies to create a fluid obstruction; using the fluid
obstruction to pressure the string; and shifting sleeves of the
valve assemblies in response to the pressurization of the string to
open the radial fluid communication ports.
8. The method of claim 7, further comprising locking at least one
of the sleeves in a position at which the at least one radial fluid
communication port of the corresponding valve assembly is open.
9. A system usable with a well, comprising: a string; and valve
assemblies disposed on the string, each valve assembly comprising
at least one control port and at least one radial fluid
communication port, wherein the valve assemblies are adapted to:
serially receive an untethered object deployed in the string such
that receipt of the object by a valve assembly of the plurality of
valve assemblies creates a fluid obstruction to cause the valve
assembly to expose the at least one control port of the valve
assembly; serially release the untethered object; and jointly
respond to pressurization of the string to open the radial fluid
communication ports.
10. The system of claim 9, wherein a first valve assembly of the
plurality of valve assemblies comprises a sleeve adapted to shift
to expose the at least one control port.
11. The system of claim 10, wherein the first valve assembly
further comprises a seat attached to the sleeve and adapted to
receive the object, and seat is adapted to release the object in
response to the sleeve being shifted.
12. The system of claim 11, wherein the seat is adapted to expand a
cross-sectional size of the seat in response to the sleeve being
shifted.
13. The system of claim 10, further comprising a lock adapted to
lock the sleeve in the shifted position to secure the at least one
control port open.
14. The system of claim 9, further comprising packers disposed on
the string to form an isolated stage of the well containing the
valve assemblies.
15. The system of claim 9, wherein a first valve assembly of the
plurality of valve assemblies comprises a sleeve adapted to shift
to expose the at least one radial fluid communication port.
16. The system of claim 15, further comprising a lock adapted to
lock the sleeve in the shifted position to secure the at least one
radial fluid communication port open.
17. An apparatus usable with a well, comprising: a housing
comprising at least one radial communication port and at least one
control port; a first sleeve slidably attached to the housing to
control fluid communication through the radial communication port
in response to pressure being exerted at least one control port; a
second sleeve slidably attached to the housing and adapted to be
shifted to expose the control port; and a seat attached to the
second sleeve and adapted to receive an untethered object, cause
the second sleeve to shift in response to a fluid obstruction
created by the seat receiving the untethered object, and release
the received object in response to the shifting of the second
sleeve.
18. The apparatus of claim 17, wherein the seat is adapted to
radially expand to release the object.
19. The apparatus of claim 18, further comprising a locking device
adapted to secure the first sleeve in the shifted position.
20. The apparatus of claim 18, further comprising a C-ring or a
collet attached to the seat to configure the seat to radially
expand and contract.
Description
BACKGROUND
[0001] For purposes of preparing a well for the production of oil
or gas, at least one perforating gun may be deployed into the well
via a conveyance mechanism, such as a wireline, a slickline or a
coiled tubing string. The shaped charges of the perforating gun(s)
are fired when the gun(s) are appropriately positioned to perforate
a casing of the well and form perforating tunnels into the
surrounding formation. Additional operations may be performed in
the well to increase the well's permeability, such as well
stimulation operations and operations that involve hydraulic
fracturing. The above-described perforating and stimulation
operations may be performed in multiple stages of the well.
[0002] The above-described operations may be performed by actuating
one or more downhole tools (perforating guns, sleeve valves, and so
forth). A given downhole tool may be actuated using a wide variety
of techniques, such dropping a ball into the well sized for a seat
of the tool; running another tool into the well on a conveyance
mechanism to mechanically shift or inductively communicate with the
tool to be actuated; pressurizing a control line; and so forth.
SUMMARY
[0003] The summary is provided to introduce a selection of concepts
that are further described below in the detailed description. This
summary is not intended to identify key or essential features of
the claimed subject matter, nor is it intended to be used as an aid
in limiting the scope of the claimed subject matter.
[0004] In another example implementation, a system that is usable
with a well includes a string and valve assemblies that are
disposed on the string. The valve assembly includes at least one
control port and at least one radial fluid communication port. The
valve assembly is adapted to serially receive an untethered object
deployed in the string such that receipt of the object by a valve
assembly of the plurality of valve assemblies creates a fluid
obstruction to cause the valve assembly to expose the control
port(s) of the valve assembly; serially release the untethered
object; and jointly respond to pressurization of the string to open
the radial fluid communication port(s).
[0005] In yet another example implementation, an apparatus that is
usable with a well includes a housing, a first sleeve, a second
sleeve and a seat. The housing includes at least one radial
communication port and at least one control port. The apparatus
includes a first sleeve that is slidably attached to the housing to
control fluid communication through the radial communication
port(s) in response to pressure being exerted on the control
port(s) and a second sleeve that is slidably attached to the
housing and adapted to be shifted to expose the control port(s).
The seat is attached to the second sleeve; and the seat is adapted
to receive an untethered object, cause the second sleeve to shift
in response to a fluid obstruction created by the seat receiving
the untethered object, and release the received object in response
to the shifting of the second sleeve.
[0006] Advantages and other features will become apparent from the
following drawing, description and claims.
BRIEF DESCRIPTION OF THE DRAWINGS
[0007] FIG. 1 is a schematic diagram of a well according to an
example implementation.
[0008] FIG. 2 is a schematic cross-sectional view of a valve
assembly of FIG. 1 in a run-in-hole state according to an example
implementation.
[0009] FIG. 3 is a schematic cross-sectional view of the valve
assembly illustrating landing of an actuation ball in the assembly
according to an example implementation.
[0010] FIG. 4 is a schematic cross-sectional view of the valve
assembly in a state in which a bypass sleeve of the assembly has
been shifted to expose pressure control ports for operating a main
sleeve of the assembly according to an example implementation.
[0011] FIG. 5 is a schematic cross-sectional view of the valve
assembly in a state in which the main sliding sleeve valve of the
assembly has been shifted to open radial fluid communication ports
of the assembly according to an example implementation.
[0012] FIG. 6 is a flow diagram depicting a technique to perform a
stimulation operation in a stage of a well according to an example
implementation.
DETAILED DESCRIPTION
[0013] In general, systems and techniques are disclosed herein to
fracture an isolated zone, or stage, of a well using multiple valve
assemblies that are disposed on a tubing string (a production
tubing string or casing string, as examples). The tubing string is
run into the well with the valve assemblies being initially
configured to be in their closed states. In its closed state, the
valve assembly isolates its radial fluid communication ports
(fracture ports, for example) from the central passageway of the
tubing string to prevent fluid communication through these
ports.
[0014] After the tubing string is positioned in the stage and the
valve assemblies are therefore positioned inside the stage, the
valve assemblies are opened in a process that involves deploying a
single untethered object in the tubing string; propagating the
untethered object from one valve assembly to the next to configure
each valve assembly to respond to the string subsequently being
pressurized; and then, pressurizing the string to cause main
sleeves of the valve assemblies to shift to open the radial fluid
communication ports of the assemblies. In this context, an
"untethered object" refers to an object that is communicated
downhole through the passageway of the string along at least part
of its path without the use of a conveyance line (a slickline, a
wireline, a coiled tubing string, and so forth). As examples, the
untethered object may be a ball (or sphere), a dart or a bar.
[0015] More specifically, in accordance with example
implementations that are disclosed herein, the untethered object is
an actuation ball that is deployed into the tubing string from the
Earth surface of the well; and each valve assembly contains a
bypass sleeve and the above-mentioned main sleeve. Similar to the
main sleeve, the bypass sleeve is also "closed" when the valve
assembly is initially run into the well, and in its closed stated,
the bypass sleeve isolates pressure control port(s) of the
assembly, which may be otherwise used to communicate pressurized
fluid to a piston of the assembly to force the main sleeve open. In
this manner, the deployed ball serially propagates through the
valve assemblies for purposes of engaging each assembly one at a
time to open each valve assembly's bypass sleeve. The opened bypass
sleeve exposes the pressure control ports of the valve assembly to
configure the assembly to respond to the subsequent pressurization
of the string.
[0016] In accordance with example implementations, the valve
assembly, in its run-in-hole state, has a seat that is constructed
to receive the actuation ball to form a corresponding fluid
barrier, or obstruction, in the central passageway of the tubing
string. Because of this fluid obstruction, the central passageway
of the string above the obstruction may be pressurized to shift the
bypass sleeve of the valve assembly to expose the pressure control
ports of the assembly and simultaneously cause the seat to release
the ball, thereby allowing the ball to descend further into the
well to land in the seat of the next valve assembly. Thus, the
above-described process may be repeated from one valve assembly to
the next (i.e., from the valve assembly at the uphole end of the
stage to the bottom valve assembly at the downhole end of the
stage), until the ball reaches a final seat where the ball forms a
corresponding final, or end, fluid obstruction in the string at the
downhole end of the stage. Using this end fluid obstruction, the
central passageway of the tubing string may then be pressurized to
exert sufficient pressure on the pressure control ports of all of
the valve assemblies of the stage to simultaneously or near
simultaneously shift the main sleeves of the valve assemblies open
to expose the assemblies' fracturing ports. Thus, more fluid may be
pumped into the string to communicate fracturing fluid into the
surrounding formation for purposes of performing a stimulation
operation (a fracturing operation, for example) in the stage.
[0017] Referring to FIG. 1, as a more specific example, well 10, in
accordance with example implementations, includes a wellbore 15
that traverses one or more hydrocarbon-bearing formations. As an
example, a tubing string 26 (a coiled tubing string or a jointed
tubing string, as examples) extends downhole inside the wellbore 15
and is secured to the surrounding formation(s) by packers, such as
example upper 60 and lower 64 packers. For the example of FIG. 1,
the tubing string 26 is deployed in an open hole wellbore, which is
uncased. In further example implementations, the tubing string 26
may be deployed inside another string (a "casing") that lines, or
supports, the wellbore 15 and which may be cemented to the wellbore
15 (such wellbores are typically referred to as "cased hole"
wellbores). Thus, many variations are contemplated, which are
within the scope of the appended claims.
[0018] In general, the wellbore 15 may extend through multiple
stages. For the specific example segment of the well 10 that is
depicted in FIG. 1, the wellbore 15 extends through an example
stage 50. In this manner, the tubing string 26 extends into the
stage 50, and the upper 60 and lower 64 packers of the tubing
string 26 form corresponding uphole and downhole boundaries for the
isolated stage 50. In this regard, each packer 60, 64 forms an
annular barrier between the outer surface of the tubing string 26
and the wellbore wall. As examples, the packer 60, 64 may be a
mechanically-set packer, a weight-set packer, a hydraulically-set
packer, an inflatable bladder-type packer, a swellable packer, and
so forth, depending upon the particular implementation.
[0019] Although FIG. 1 depicts the isolated stage 50 as being
disposed in a lateral wellbore, the techniques and systems that are
disclosed herein may likewise be applied to vertical wellbores.
Moreover, in accordance with some implementations, the well may
contain multiple wellbores, which contain tubing strings that are
similar to the illustrated tubing string 26 of FIG. 1. The well 10
may be a subsea well or may be a terrestrial well, depending on the
particular implementation. Additionally, the well 10 may be an
injection well or may be a production well. Thus, many
implementations are contemplated, which are within the scope of the
intended claims.
[0020] The tubing string 26 contains valve assemblies that, when
open, are used to communicate fluid from the central passageway of
the string 26 into the surrounding formation(s) of the stage 50. In
accordance with example implementations, these valve assemblies may
include, in general, two types of valve assemblies: valve
assemblies 70 that share a common design and are irregularly or
regularly distributed along the stage 50 (depending on the
particular implementation); and a terminating valve assembly 80
that is located downhole of the valve assemblies 70 and at or near
the downhole end of the stage 50.
[0021] In general, each valve assembly 70 has a central passageway
that forms part of the central passageway of the tubing string 26
and contains radial fluid communication ports 72 (or "fracture
ports" for some applications), which are openings in the wall of
the tubing string 26 and when permitted by an open state of the
valve assembly 70, may be used to communicate fluid between the
central passageway of the tubing string 26 and the region outside
of the tubing string 26 (the region extending into the surrounding
formation(s), for example).
[0022] Similar to the valve assembly 70, the valve assembly 80 also
has a central passageway that forms part of the central passageway
of the tubing string 26 and contains radial fluid communication
ports 82 (or "fracture ports " for some applications), which, when
permitted by an open state of the valve assembly 80, may be used to
communicate fluid between the central passageway of the tubing
string 26 and the region outside of the tubing string 26 (the
region extending into the surrounding formation(s), for example).
In accordance with some implementations, the valve assembly 80 is
constructed to catch an untethered object (such as an actuation
ball) and unlike the valve assembly 70 (as described herein) retain
the object as fluid pressure in the central passageway of the
tubing string 26 is increased.
[0023] Initially, when the valve assemblies 70 are run downhole on
the tubing string 26, main sleeves of the assemblies 70 are in
positions to close off fluid communication through the fluid
communication ports 72 (i.e., the valve assemblies 70 are closed).
As disclosed herein, an untethered object, such as an actuation
ball, may be deployed from the Earth surface through the central
passageway of the tubing string 26 for purposes of serially
propagating through the valve assemblies 70 to configure the
assemblies 70, one at a time, to be subsequently responsive to the
pressurization of the string 26 for purposes of translating, or
shifting, the main sleeves of the assemblies 70. In this manner, as
disclosed herein, after this configuration by the actuation ball,
the tubing string 26 may be pressurized for purposes of causing all
of the valve assemblies 70 to shift their main sleeves open so that
a stimulation operation (a fracturing operation, for example) may
be performed in the stage 50 using the now opened fluid
communication ports 72.
[0024] The serial propagation of the actuation ball through the
valve assemblies 70 occurs from a heel end of the wellbore to the
toe end of the wellbore (i.e., from left to right in FIG. 1), in
accordance with an example implementation. In further
implementations, however, propagation may be performed in a reverse
direction, from the toe end to the heel end of the wellbore 15.
Thus, may variations are contemplated, which are within the scope
of the intended claims.
[0025] FIG. 2 depicts a schematic cross-sectional view of the valve
assembly 70 in accordance with an example implementation. In
general, the valve assembly 70 contains a tubular housing 200 that
is concentric with a longitudinal axis 290 and is generally coaxial
with the tubing string 26. The tubular housing 200 has concentric
upper tubular 200A, intermediate 200B and lower 200C sections, in
accordance with example implementations; and the tubular housing
200 has an uphole end 280 and a downhole end 282. The valve
assembly 70 further includes tubular main 220 and bypass 219
sleeves, which are concentric with the longitudinal axis 290,
contained within the housing 200, and are slidably mounted to the
housing 200. The main sleeve 220 controls fluid communication
through the radial fluid communication ports 72, which radially
extend through the housing 200B and are isolated by the main sleeve
220 in the state of the assembly 70 shown in FIG. 2. The bypass
sleeve 219 controls fluid communication with pressure control ports
217, which are formed in the upper tubular housing section 200A and
may be used to shift the main sleeve 220 to open fluid
communication through the fluid communication ports 72, as further
described herein.
[0026] The valve assembly 70, as depicted in FIG. 2, is in its
run-in-hole state. In this state, the main sleeve 220 of the valve
assembly 70 covers, or isolates, the fluid communication ports 72.
In this manner, seals (o-rings, for example) are disposed between
the outer surface of the main sleeve 220 and the inner surface of
the surrounding housing section 200B for purposes of forming a
fluid seal to prevent fluid communication between the interior of
the valve assembly 70 and the valve assembly's exterior. The main
sleeve 220 may be initially secured in place to the housing 200 in
the assembly's run-in-hole state by one or more shear devices 221
(shear screws or pins, as examples).
[0027] For the initial run-in-hole state of the valve assembly 70,
the bypass sleeve 219 circumscribes an inner sleeve 204, which
contains a seat 206 at an upper end of the sleeve 204. The inner
sleeve 204 is initially secured to the bypass sleeve 219 via one or
more shear devices 223 (shear screws, or pins, for as examples) and
is used to operate the sleeve 219 via the use of a deployed
untethered object, as further described herein.
[0028] More specifically, the seat 206 of the inner sleeve 204 is
configured to receive an untethered object, such as an actuation
ball. In this manner, in accordance with example implementations,
the seat 206 has an inner diameter that is appropriately sized to
catch an actuation ball having a given minimum outer diameter, in
accordance with example implementations.
[0029] In general, the bypass sleeve 219, in the run-in-hole state
of the valve assembly 70, isolates the pressure control ports 217
of the valve assembly 70 from fluid inside the tubing string's
central passageway. In this manner, the outer surface of the bypass
sleeve 219, in conjunction with fluid seals (o-rings, for example)
between the sleeve 219 and an inner surface of the upper tubular
housing section 200A, isolate the pressure control ports 217 from
the central passageway of the tubing string 26. The pressure
control ports 217, in turn, are in fluid communication with a
piston surface of the main sleeve 220. Therefore, with the bypass
sleeve 219 in the position that is depicted in FIG. 2, the pressure
control ports 217 are covered, or isolated, so that fluid
pressurization of the tubing string's central passageway does not
exert a shifting force on the piston of the main sleeve 220.
[0030] FIG. 3 depicts the landing of an actuation ball 300 in the
seat 206 of the valve assembly 70. In this manner, in accordance
with example implementations, the actuation ball 300 may be
deployed from the Earth surface of the well 10 (see FIG. 1) into
the central passageway of the tubing string 26 and travel through
the central passageway until the ball 300 lands in the seat 206.
The landing of the actuation ball 300 in the seat 206 creates a
fluid barrier, or obstruction, in the tubing string 26 uphole of
the ball 300. Pressurization of the string 26 above the ball 300
may be subsequently used to shift the bypass sleeve 219 to expose
the pressure control ports 217 so that the pressure control ports
217 may be subsequently used to respond to pressure to shift the
main sleeve 220.
[0031] Due to the initial connection of inner sleeve 204
(containing the seat 206) to the bypass sleeve 219, the
pressurization of the tubing string 26 uphole of the actuation ball
300 shears the shear device(s) 207 that secure the sleeve 219 in
place and shifts the sleeve 219 downwardly to the open position
(i.e., a position in which the ports 410 of the sleeve 219 align
with the pressure control ports 217 and thus, expose the ports 217
to fluid pressure inside the tubing string 26). In accordance with
example implementations, the shifted bypass sleeve 219 is secured
in the open position due to a split ring 211 on the sleeve 219
engaging an interior annular groove 213 in the upper housing
section 200A. Forces resulting from the pressurization of the
tubing string 26 may also be used to, after the bypass sleeve 219
is locked into its open position, exert a downward shifting force
on the inner sleeve 204 to shear the shear device(s) 223 that
initially secure the sleeve 204 to the sleeve 219, thereby allowing
the sleeve 204 to be shifted, or translated, in a downhole
direction to a lower position that is depicted in FIG. 4.
[0032] Referring to FIG. 4 in conjunction with FIG. 3, the inner
sleeve 204 is radially expandable and contractable and is held in a
radially contracted state when the sleeve 204 is in inside the
bypass sleeve 219 (see FIG. 3). In this radially contracted state,
the sleeve 204 has a tendency, or bias, to radially expand. As an
example, in accordance with some implementations, the sleeve 204
may be a C-ring or a collet.
[0033] More specifically, in its initial position that is depicted
in FIG. 3, the inner sleeve 204 is in a radially restricted region
202 of the valve assembly 70. In the restricted region 202, the
relatively reduced inner diameter of the bypass sleeve 219 radially
constricts the inner sleeve 204 so that the seat 206 of the sleeve
204 has a sufficiently small inner diameter to "catch," or land,
the actuation ball 300. However, when the inner sleeve 204 and
attached seat 206 shift downwardly to the position that is depicted
in FIG. 4, the inner sleeve 204 enters a radially expanded section
203 of the valve assembly 70, which allows the seat 206 to radially
expand. Due to the radial expansion of the seat 206, the inner
diameter of the seat 206 is no longer sufficiently small enough to
retain the actuation ball 300. As a result, the seat 206 releases
the actuation ball 300, thereby allowing the ball 300 to travel to
the next valve assembly 70 downhole of the valve assembly 70 from
which the ball 300 was released (i.e., the ball 300 is not shown in
FIG. 4, as the ball 300 has been released from the valve assembly
70).
[0034] Referring to FIG. 1, after exiting the lowermost valve
assembly 70 of the stage 50, the actuation ball 300 lands in a seat
of the valve assembly 80, where, in accordance with example
implementations, the ball 300 remains to form a fluid obstruction
at the bottom end of the stage 50 for purposes of allowing the
string's central passageway uphole of the valve assembly 80 to be
adequately pressurized for the subsequent shifting open all of the
main sleeves 220 to open the fluid communication ports 72 of all of
the valve assemblies 70 of the stage 50. A subsequent stimulation
operation (a fracturing operation, for example) that relies on the
open valve assemblies 70 may then be performed.
[0035] As depicted in FIG. 4, when the bypass sleeve 219 shifts
downwardly, the radial ports 410 of the bypass sleeve 219 align
with the radial pressure control ports 217, thereby allow the
communication of tubing fluid pressure to the piston surface of the
main sleeve 220.
[0036] More specifically, referring to FIG. 5, after the bypass
sleeve 219 has been shifted (and all of the other bypass sleeves
219 of the other valve assemblies 70 have been shifted), the
central passageway of the tubing string 26 may be pressurized using
the fluid obstruction that is created by the ball 300 landing in
the valve 80 (located at the bottom of the stage 50, as depicted in
FIG. 1). The resulting fluid pressure concurrently exerts downward
forces on the pistons of the main sleeves 220 to shear the shear
device(s) constraining the sleeves 220 and cause the sleeves 220 to
translate downwardly, to expose the radial fluid communication
ports 72. Thus, the main sleeves 220 of the stage 50 are
concurrently, are jointly, opened, in accordance with example
implementations.
[0037] In accordance with example implementations, the main sleeve
220 is secured in its open position due to a split ring 209 on a
downhole end of the sleeve 220 engaging an interior annular groove
227 that is formed in the intermediate housing section 200B.
Therefore, when the valve assembly 70 is in the state that is
depicted in FIG. 5, fluid communication is allowed through the
fluid communication ports 72 so that for a string containing
multiple valve assemblies 70 that extend in a given stage 50 of a
well, a simulation fluid may be communicated through the ports 72
of the valve assemblies 70 (a fracturing fluid may be communicated
into the stage 50 to perform a fracturing operation, for
example).
[0038] After the stimulation operation in the stage 50 is complete,
the ball 300 may be removed from the valve assembly 80 (see FIG. 1)
to allow work below the valve assembly 80. Depending on the
particular implementation, the ball 300 may be milled out, forced
through an expandable seat of the valve assembly 80 by increasing
pressure, dissolved, and so forth, as can be appreciated by the
skilled artisan.
[0039] Stimulation operations may be performed in one or more
stages through which the tubing string 26 extends using additional
valve assemblies 70 and 80 of the string 26, as can be appreciated
by the skilled artisan.
[0040] Thus, referring to FIG. 6, in accordance with example
implementations, a technique 600 includes deploying an untethered
object in a string that contains valve assemblies, pursuant to
block 602 and serially propagating (block 604) the object through
valve assemblies to shift bypass sleeves of the assemblies to
expose pressure control ports of the assemblies. Pursuant to the
technique 600, the string is pressurized (block 606) to shift main
sleeves of the assemblies open to expose radial fluid ports of the
assemblies. The technique 600 includes using the opened valve
assemblies to perform simulation operation, pursuant to block 608.
For example, the string may be further pressurized to perform a
fracturing operation.
[0041] While a limited number of examples have been disclosed
herein, those skilled in the art, having the benefit of this
disclosure, will appreciate numerous modifications and variations
therefrom. It is intended that the appended claims cover all such
modifications and variations.
* * * * *