U.S. patent application number 16/836496 was filed with the patent office on 2020-12-03 for downhole tool for cementing a borehole.
This patent application is currently assigned to Halliburton Energy Services, Inc.. The applicant listed for this patent is Halliburton Energy Services, Inc.. Invention is credited to Frank Vinicio Acosta, Mayur Narain Ahuja, Kevin Wendell Ardoin, Jinhua Cao, Lonnie Carl Helms, Ishwar Dilip Patil, Tor Sigve Saetre, Steven Daniel Southwell, Brittany Helene Spivey, Saul Emmanuel Vazquez-Niebla.
Application Number | 20200378216 16/836496 |
Document ID | / |
Family ID | 1000004826017 |
Filed Date | 2020-12-03 |
United States Patent
Application |
20200378216 |
Kind Code |
A1 |
Acosta; Frank Vinicio ; et
al. |
December 3, 2020 |
DOWNHOLE TOOL FOR CEMENTING A BOREHOLE
Abstract
A downhole tool. The downhole tool may include a tubular body
and an inner sleeve that is slidable within the tubular body. The
tubular body may include a port that allows fluid flow between a
bore of the downhole tool and an area outside of the tubular body.
The downhole tool may be sequentially positionable in a run-in
position that blocks fluid flow through the port in the tubular
body, then in an open position that allows fluid flow through the
port in the tubular bod, and then in a closed position that blocks
fluid flow through the port in the tubular body.
Inventors: |
Acosta; Frank Vinicio;
(Spring, TX) ; Cao; Jinhua; (Humble, TX) ;
Ahuja; Mayur Narain; (Friendswood, TX) ; Patil;
Ishwar Dilip; (Sping, TX) ; Ardoin; Kevin
Wendell; (Montgomery, TX) ; Helms; Lonnie Carl;
(Humble, TX) ; Vazquez-Niebla; Saul Emmanuel;
(Humble, TX) ; Southwell; Steven Daniel; (Spring,
TX) ; Saetre; Tor Sigve; (Spring, TX) ;
Spivey; Brittany Helene; (Houston, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Halliburton Energy Services, Inc. |
Houston |
TX |
US |
|
|
Assignee: |
Halliburton Energy Services,
Inc.
Houston
TX
|
Family ID: |
1000004826017 |
Appl. No.: |
16/836496 |
Filed: |
March 31, 2020 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
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62855445 |
May 31, 2019 |
|
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|
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 33/14 20130101;
E21B 2200/06 20200501; E21B 34/10 20130101 |
International
Class: |
E21B 34/10 20060101
E21B034/10; E21B 33/14 20060101 E21B033/14 |
Claims
1. A downhole tool comprising: a tubular body comprising a port
that allows fluid flow between a bore of the downhole tool and an
area outside of the tubular body; an inner sleeve slidable within
the tubular body; and wherein the downhole tool is sequentially
positionable in a run-in position that blocks fluid flow through
the port in the tubular body, then in an open position that allows
fluid flow through the port in the tubular bod, and then in a
closed position that blocks fluid flow through the port in the
tubular body.
2. The downhole tool of claim 1, wherein the inner sleeve blocks
fluid flow through the port in the tubular body when in the
downhole tool is in the run-in position.
3. The downhole tool of claim 1, wherein the inner sleeve is
sequentially positionable in a run-in position, then in an open
position, and then in a closed position.
4. The downhole tool of claim 1, further comprising a seat disposed
within the inner sleeve, the seat comprising a shoulder shaped to
receive a plug to shift the inner sleeve to position the downhole
tool in the open position.
5. The downhole tool of claim 1, wherein the inner sleeve and the
tubular body are shaped such that the downhole tool is shiftable
into an open position via an unbalanced force acting on the inner
sleeve, the unbalanced force due to fluid pressure within the
downhole tool.
6. The downhole tool of claim 1, wherein the inner sleeve comprises
a shoulder shaped to receive a plug to shift the inner sleeve to
position the downhole tool in the closed position.
7. The downhole tool of claim 1, wherein the inner sleeve comprises
a profile on an interior surface of the inner sleeve.
8. The downhole tool of claim 1, further comprising a seat slidable
within the inner sleeve, wherein: the inner sleeve further
comprises a port that, when the downhole tool is positioned in the
run-in position, is aligned with the port in the tubular body; and
the seat is positionable in a run-in position that blocks fluid
flow through the port in the inner sleeve and an open position that
allows fluid flow through the port in the inner sleeve.
9. A cementing system for a borehole, the cementing system
comprising: a casing string positionable within the borehole, the
casing string comprising a downhole tool comprising: a tubular body
comprising a port that allows fluid flow between a bore of the
downhole tool and an area radially outside of the tubular body; and
an inner sleeve slidable within the tubular body; and wherein the
downhole tool is sequentially positionable in a run-in position
that blocks fluid flow through the port in the tubular body, then
in an open position that allows fluid flow through the port in the
tubular bod, and then in a closed position that blocks fluid flow
through the port in the tubular body.
10. The cementing system of claim 9, wherein the inner sleeve
blocks fluid flow through the port in the tubular body when in the
downhole tool is in the run- in position.
11. The cementing system of claim 9, wherein the inner sleeve is
sequentially positionable in a run-in position, then in an open
position, and then in a closed position.
12. The cementing system of claim 10, wherein the downhole tool
further comprises a seat disposed within the inner sleeve, the seat
comprising a shoulder shaped to receive a plug to shift the inner
sleeve to position the downhole tool in the open position.
13. The cementing system of claim 9, wherein the inner sleeve and
the tubular body are shaped such that the inner sleeve is shiftable
into an open position via an unbalanced force acting on the inner
sleeve, the unbalanced force due to fluid pressure within the
downhole tool.
14. The cementing system of claim 9, wherein the inner sleeve
comprises a shoulder shaped to receive a plug to shift the inner
sleeve to position the downhole tool in the closed position.
15. The cementing system of claim 9, wherein the inner sleeve
comprises a profile on an interior surface of the inner sleeve.
16. The cementing system of claim 9, wherein: the inner sleeve
further comprises a port that, when the downhole tool is positioned
in the run-in position, is aligned with the port in the tubular
body; and the downhole tool further comprises a seat slidable
within the inner sleeve, the seat positionable in a run-in position
that blocks fluid flow through the port in the inner sleeve and an
open position that allows fluid flow through the port in the inner
sleeve.
17. A method for cementing a casing string in a borehole, the
method comprising: positioning a casing string comprising a
downhole tool within a borehole, wherein the downhole tool is
positioned in a run-in position that blocks fluid flow between a
bore of the downhole tool and an annulus formed between the casing
string and a wall of the borehole; then shifting the downhole tool
to an open position to allow fluid flow between the bore of the
downhole tool and the annulus; and then shifting the downhole tool
to a closed position to block fluid flow between the bore of the
downhole tool and the annulus.
18. The method of claim 17, wherein shifting the downhole tool to
the open position comprises shifting an inner sleeve of the
downhole tool via an unbalanced force acting on the inner sleeve to
shift the downhole tool to the open position, the unbalanced force
due to fluid pressure within the downhole tool.
19. The method of claim 17, wherein shifting the downhole tool to
the open position comprises pumping a plug downhole to engage with
a shoulder of a seat of the downhole tool to shift the downhole
tool to the open position.
20. The method of claim 17, wherein shifting the downhole tool to
the closed position comprises pumping a plug downhole to engage
with a shoulder of an inner sleeve of the downhole tool to shift
the downhole tool to the closed position.
Description
BACKGROUND
[0001] This section is intended to provide relevant background
information to facilitate a better understanding of the various
aspects of the described embodiments. Accordingly, these statements
are to be read in this light and not as admissions of prior
art.
[0002] Hydraulic cement compositions are commonly utilized in
subterranean operations, particularly subterranean well completion
and remedial operations. For example, hydraulic cement compositions
are used in primary cementing operations where pipe strings, such
as casings and liners, are cemented in well bores.
[0003] In typical primary cementing operations, hydraulic cement
compositions are pumped into the annulus between the wall of a
borehole and the exterior surface of the pipe string disposed
within the borehole. The cement composition is permitted to set in
the annulus, forming an annular sheath of hardened, substantially
impermeable cement that supports and positions the pipe string in
the borehole and bonds the exterior surface of the pipe string to
the wall of the borehole. The cement composition may be pumped down
the inner diameter of the pipe string, out through a casing shoe
and/or circulation valve at the bottom of the pipe string and up
through the annulus to its desired location.
[0004] In some scenarios, the conventional cementing operations may
be performed in two or more stages, where casing is placed within a
borehole and a portion of the casing is cemented. Thereafter, one
or more cementing operations are performed to cement the remaining
portion(s) of the casing into place.
BRIEF DESCRIPTION OF THE DRAWINGS
[0005] Embodiments of the downhole tool for cementing a borehole
are described with reference to the following figures. The same
numbers are used throughout the figures to reference like features
and components. The features depicted in the figures are not
necessarily shown to scale. Certain features of the embodiments may
be shown exaggerated in scale or in somewhat schematic form, and
some details of elements may not be shown in the interest of
clarity and conciseness.
[0006] FIG. 1 is a drilling system, according to one or more
embodiments;
[0007] FIG. 2 is a cementing system for performing a multi-stage
cementing operation, according to one or more embodiments;
[0008] FIG. 3 is a cross-sectional view of a downhole tool in a
run-in position, according to one or more embodiments;
[0009] FIG. 4 is a cross-sectional view of the downhole tool of
FIG. 3 in an open position;
[0010] FIG. 5 is a cross-sectional view of the downhole tool of
FIG. 3 in a closed position;
[0011] FIG. 6 is a cross-sectional view of a downhole tool in a
run-in position, according to one or more embodiments;
[0012] FIG. 7 is a cross-sectional view of the downhole tool of
FIG. 6 in an open position;
[0013] FIG. 8 is a cross-sectional view of the downhole tool of
FIG. 6 in a closed position;
[0014] FIG. 9 is a cross-sectional view of a downhole tool in a
run-in position, according to one or more embodiments;
[0015] FIG. 10 is a cross-sectional view of the downhole tool of
FIG. 9 in an open position; and
[0016] FIG. 11 is a cross-sectional view of the downhole tool of
FIG. 9 in a closed position.
DETAILED DESCRIPTION
[0017] The present disclosure describes a downhole tool for
cementing a borehole. The downhole tool is used in a multi-stage
cementing operation to be conducted within the borehole.
[0018] A main borehole may in some instances be formed in a
substantially vertical orientation relative to a surface of the
well, and a lateral borehole may in some instances be formed in a
substantially horizontal orientation relative to the surface of the
well. However, reference herein to either the main borehole or the
lateral borehole is not meant to imply any particular orientation,
and the orientation of each of these boreholes may include portions
that are vertical, non-vertical, horizontal or non-horizontal.
Further, the term "uphole" refers a direction that is towards the
surface of the well, while the term "downhole" refers a direction
that is away from the surface of the well.
[0019] FIG. 1 is a drilling system 100, according to one or more
embodiments. The well site 102 includes include a drilling rig 104
that has various characteristics and features associated with a
"land drilling rig." Various types of drilling equipment such as a
rotary table, drilling fluid pumps, and drilling fluid tanks (not
shown) may also be located at a well site 102. However, downhole
drilling tools incorporating teachings of the present disclosure
may be satisfactorily used with drilling equipment located on
offshore platforms, drill ships, semi-submersibles and drilling
barges (not shown).
[0020] The drilling system 100 includes a drill string 106
associated with a drill bit 108 that is used to form a borehole
110. Specifically, FIG. 1 depicts a rotary steerable system (RSS)
112 that may be used to perform directional drilling The term
"directional drilling" may be used to describe drilling a wellbore
or portions of a wellbore that extend at a desired angle or angles
relative to vertical. The desired angles may be greater than normal
variations associated with vertical wellbores. Directional drilling
may be used to access multiple target reservoirs within a single
borehole or reach a reservoir that may be inaccessible via a
vertical wellbore. The RSS 112 may use a point-the-bit method to
cause the direction of the drill bit 108 to vary relative to the
housing of the rotary steerable drilling system 112 by bending a
shaft running through the rotary steerable drilling system 112.
[0021] The drilling system 100 also includes a bottom hole assembly
(BHA) 114. The BHA 114 may include a wide variety of components,
such as components 116 and 118, configured to form the borehole
110. Such components may include, but are not limited to, drill
bits (e.g., the drill bit 108), coring bits, drill collars, rotary
steering tools (e.g., the RSS 112) or other directional drilling
tools, downhole drilling motors, reamers, hole enlargers or
stabilizers. The number and types of components included in the BHA
114 may depend on anticipated downhole drilling conditions and the
type of wellbore that is to be formed. The BHA 114 may also include
various types of well logging tools and other downhole tools
associated with directional drilling of a wellbore such as
so-called measurement- while-drilling (MWD) or
logging-while-drilling (LWD) tools. Examples of logging tools
and/or directional drilling tools may include, but are not limited
to, acoustic, neutron, gamma ray, density, photoelectric, nuclear
magnetic resonance, rotary steering tools and/or any other
available well tool. Further, the BHA 114 may also include a rotary
drive (not expressly shown) that rotates at least part of the drill
string 106 together with components 116 and/or 118.
[0022] The drill bit 108 includes one or more blades 120 disposed
outwardly from exterior portions of a rotary bit body 122. The
drill bit 108 rotates with respect to a bit rotational axis 124 in
a direction defined by directional arrow 126. The blades 120
include one or more cutting elements 128 disposed outwardly from
exterior portions of each blade 120. The blades 120 may also
include one or more depth of cut controllers (not shown) configured
to control the depth of cut of the cutting elements 128. The blades
120 may further include one or more gage pads (not expressly shown)
disposed on blades 120.
[0023] Various types of drilling fluid may be pumped from the
surface of the well site 102 downhole through the drill string 106
to the attached drill bit 108. The drilling fluids may be directed
to flow from the drill string 106 to respective nozzles passing
through the drill bit 108. The drilling fluid may be circulated
uphole to the well surface through an annulus 130 surrounding the
drill string 106.
[0024] The borehole 110 is defined in part by a casing string 132
extending from the surface of the well site 102 to a selected
downhole location. Portions of the borehole 110 that do not include
the casing string 132 may be described as "open hole," while
portions of the borehole 110 that include the casing string 132 may
be referred to as a "cased hole." In open hole sections, the
annulus 130 is be defined in part by an outside diameter 134 of the
drill string 106 and an inside diameter 136 of the borehole 110. In
cased hole sections, the annulus 130 is defined in part by an
outside diameter 134 of the drill string 106 and an inside diameter
138 of the casing string 132.
[0025] To case the borehole 110, casing string 132 is run into the
borehole 110 (e.g., using a running tool) and hung on a casing
hanger (not shown). Cement is pumped through the casing string 132
and into the annulus 130 between the casing string 132 and the
borehole wall 118 (or a previously run casing string) in order to
cement the casing string 132 into place. In one or more
embodiments, the cementing process may be done in stages in which
multiple sections of cement are pumped behind the same casing
string. For example, when a casing string 132 is too long to cement
by only pumping cement into the annulus from a distal end of the
casing string 132, a multi-stage cementing operation may be
performed. To avoid drilling through the casing string 132 and
cement at that location, a first stage of a multi-stage cementing
operation may be performed to cement the portion of the casing
string 132 below the predetermined location and a second stage of a
multi-stage cementing operation may be performed to cement the
casing string 132 above the predetermined location.
[0026] FIG. 2 depicts a cementing system for performing a
multi-stage cementing operation in accordance with one or more
embodiments. The system 200 includes a downhole tool 202
interconnected in a casing string 204 having an upper casing
portion 206 and a lower casing portion 208, the upper casing
portion 206 being located above the downhole tool 202 and the lower
casing portion 208 being located below the downhole tool 202. The
downhole tool 202 is interconnected in the casing string 204 at a
location determined based on the operation, borehole conditions,
operating equipment, and/or predetermined well plans, among other
factors, and is used to perform a multi-stage cementing operation
in which a first stage of cementing is performed followed by one or
more additional stages of cementing.
[0027] As shown, the casing string 204 is run into a borehole 210
that includes a previously run casing string 212 which was cemented
into place using cement 214. The casing string 204 may be run into
the borehole 210 using a running tool (not shown) connected to a
rig, such as drilling rig 104 in FIG. 1, and/or other operating
equipment known in the art.
[0028] Once the casing string 204 is run into the borehole 210, a
first stage of a multi-stage cementing process may be performed.
Cement is pumped along a flow path through a bore 216 inside of the
casing string 204 and the downhole tool 202 as indicated by arrows
218 and out a distal end 220 of the casing string 204. Cement may
then flow into an annulus 222 between the casing string 204 and a
borehole wall 224 and uphole along a length of the casing string
204. Pumping may be stopped when the cement slurry reaches a
predetermined depth 226 along the length of the casing string 204.
Once the cement slurry has set, the downhole tool 202 is opened and
additional cement slurry is pumped downhole and enters the annulus
222 through the downhole tool. Once the cement slurry pumped
through the downhole tool 202 is set, the process can be repeated
with additional downhole tools 202 as necessary until the
multi-stage cementing process is completed.
[0029] In one or more embodiments, the predetermined depth 226 may
be determined based on the total length of the casing string 204,
borehole conditions, operating equipment, and/or predetermined well
plans, among other factors. It should be understood that the
predetermined depth 226 may be at any location along the length of
the casing string 204 and may extend into the annulus 222 between
the casing string 204 and the previously run casing string 212. In
addition, although not shown, it should be understood that other
equipment such as guide shoes, float collars, flapper valves, stage
plugs, and the like, may be included and used in the multi-stage
cementing process without departing from the scope of the present
disclosure.
[0030] In another embodiment, a packer (not shown), such as, but
not limited to, an inflatable packer or a swellable packer, may be
set or a fluid barrier of fluid denser than the cement slurry may
be created downhole the downhole tool 202. A packer may be used to
isolate the formation downhole of the downhole tool 202 prior to
pumping cement slurry into the annulus. A packer or fluid barrier
may be used when the formation downhole of the downhole tool 202 is
weak and will not allow the cementing operation to be
completed.
[0031] Turning now to FIGS. 3-5, FIGS. 3-5 illustrate a downhole
tool 300 that may be used in place of downhole tool 202 when
performing a multi-stage cementing process. The downhole tool 300
is sequentially positionable between a run-in position, an open
position, and a closed position, as described in more detail below.
The downhole tool 300 includes a tubular body 302 that includes one
or more ports 304 and an inner sleeve 306. The inner sleeve 306 is
initially held in the run-in position that blocks the port 304, as
shown in FIG. 3, via one or more shear pins 308. The inner sleeve
and/or tubular body 302 also include multiple seals 310 to prevent
fluid from flowing out from the bore 312 of the downhole tool 300
to an area radially outside of the downhole tool 300 when the inner
sleeve 306 is in the run-in position.
[0032] When it is desired to open the downhole tool 300, a
pressurized fluid is flowed through the bore 312 of the downhole
tool 300 in the indicated direction 314. The geometry of the sleeve
and positions of the seals 310 is such that the pressure applies an
unbalanced force on the inner sleeve 306. The unbalanced force on
the inner sleeve 306 causes the inner sleeve 306 to shift into an
open position, as shown in FIG. 4. The open position exposes the
ports 304 and allows fluid to pass from the bore 312 of the
downhole tool, through the ports 304, and into an annulus
surrounding the downhole tool 300. In at least one embodiment, the
inner sleeve 306 is retained in the open position via a locking
mechanism (not shown) such as, but not limited to a ratcheting
mechanism, a lock ring, or a collet.
[0033] Once the cementing operation has been completed, a plug 500
is pumped downhole and engages with a shoulder 502 coupled to or
formed in an uphole end portion 504 of the inner sleeve 306. The
pressure applied to the plug 500 is great enough that the locking
mechanism holding the inner sleeve 306 in the open position is
overcome and the inner sleeve 306 shifts into a closed position, as
shown in FIG. 5. The movement to the closed position blocks the
ports 304 in the tubular body 302 and prevents fluid from flowing
out from the bore 312 of the downhole tool 300. In at least one
embodiment, the inner sleeve 306 is retained in the closed position
via a second locking mechanism such as, but not limited to a
ratcheting mechanism, a lock ring, or a collet.
[0034] In at least one embodiment, the interior surface 316 of the
inner sleeve 306 includes a profile 318 as shown in FIGS. 3-5
shaped to receive a setting tool (not shown). The setting tool
engages with the profile to shift the inner sleeve 306 to the open
and closed positions. In other embodiments, the profile may be
omitted.
[0035] Referring now to FIGS. 6-8, FIGS. 6-8 illustrate a downhole
tool 600 that may be used in place of downhole tool 202 when
performing a multi-stage cementing process. FIGS. 6-8 include many
features that are similar to the features described above with
reference to FIGS. 3-5. Accordingly, such features will not be
described again in detail, except as necessary for the
understanding of the downhole tool 600 shown in FIGS. 6-8.
[0036] Similar to the downhole tool 300 described above, downhole
tool 600 includes a tubular body 302 having one or more ports 304
and an inner sleeve 602 that is slidable within the tubular body
302 to control flow from the bore 312 of the downhole tool 600
through the ports 304 in the tubular body 302. As shown in FIG. 6,
the inner sleeve 602 includes one or more ports 604 that are
aligned with the ports in the tubular body 302 when the inner
sleeve is positioned in the run-in position. The downhole tool 600
also includes a seat 606 positioned within the inner sleeve 602.
When positioned in the run-in position, shown in FIG. 6, the seat
606 and associated seals 608 block the flow of fluid from the bore
312 through the ports 304, 604 in the tubular body 302 and the
inner sleeve 602. Similar to the inner sleeve, the seat is retained
in the run-in position via one or more shear pins 610.
[0037] When it is desired to open the downhole tool 600, an opening
plug 700 is pumped downhole and engages with a shoulder 702 coupled
to or formed in the seat 606, as shown in FIG. 7. The opening plug
700 shifts the seat 606 as shown, allowing fluid to flow from the
bore 312 of the downhole tool, through the ports 304, 604 in the
tubular body 302 and the inner sleeve 602, and into an annulus
surrounding the downhole tool 600. In at least one embodiment, the
seat 606 is retained in the open position via a locking mechanism
such as, but not limited to a ratcheting mechanism, a lock ring, or
a collet.
[0038] Once the cementing operation has been completed, a plug 500
is pumped downhole and engages with a shoulder 502 coupled to for
formed in an uphole end portion 504 of the inner sleeve 602. The
pressure applied to the plug 500 is great enough that the shear
pins 308 holding the inner sleeve 306 in the open position are
sheared and the inner sleeve 602 shifts into a closed position, as
shown in FIG. 8. The movement to the closed position blocks the
ports 304 in the tubular body 302 and prevents fluid from flowing
out from the bore 312 of the downhole tool 300. In at least one
embodiment, the inner sleeve 602 is retained in the closed position
via a second locking mechanism such as, but not limited to a
ratcheting mechanism, a lock ring, or a collet.
[0039] Turning now to FIGS. 9-11, FIGS. 9-11 illustrate a downhole
tool 900 that may be used in place of downhole tool 202 when
performing a multi-stage cementing process. FIGS. 9-11 include many
features that are similar to the features described above with
reference to FIGS. 3-8. Accordingly, such features will not be
described again in detail, except as necessary for the
understanding of the downhole tool 900 shown in FIGS. 9-11.
[0040] Similar to the downhole tools 300, 600 described above,
downhole tool 900 includes a tubular body 302 having one or more
ports 304 and an inner sleeve 902 that is slidable within the
tubular body 302 to control flow from the bore 312 of the downhole
tool 900 through the ports 304 in the tubular body 302. As shown in
FIG. 6, the inner sleeve 902 includes one or more ports 904 that
are offset from ports in the tubular body 302 when the inner sleeve
is positioned in the run-in position. The downhole tool 900 also
includes a seat 606 positioned within the inner sleeve 902. When
positioned in the run-in position, shown in FIG. 9, the inner
sleeve 902 blocks the flow of fluid from the bore 312 through the
ports 304 in the tubular body 302.
[0041] When it is desired to open the downhole tool 900, an opening
plug 700 is pumped downhole and engages with a shoulder 702 coupled
to or formed in the seat 606, as shown in FIG. 10. The opening plug
700 shifts the seat 606 as shown, allowing fluid to flow from the
bore 312 of the downhole tool, through the ports 304, 904 in the
tubular body 302 and the inner sleeve 902, and into an annulus
surrounding the downhole tool 900. In at least one embodiment, the
inner sleeve 902 is retained in the open position via a locking
mechanism such as, but not limited to a ratcheting mechanism, a
lock ring, or a collet.
[0042] Once the cementing operation has been completed, a plug 500
is pumped downhole and engages with a shoulder 502 coupled to for
formed in an uphole end portion 504 of the inner sleeve 902. The
pressure applied to the plug 500 is great enough that the locking
mechanism holding the inner sleeve 902 in the open position is
overcome and the inner sleeve 902 shifts into a closed position, as
shown in FIG. 11. The movement to the closed position blocks the
ports 304 in the tubular body 302 and prevents fluid from flowing
out from the bore 312 of the downhole tool 900. In at least one
embodiment, the inner sleeve 902 is retained in the closed position
via a second locking mechanism such as, but not limited to a
ratcheting mechanism, a lock ring, or a collet.
[0043] Further examples include:
[0044] Example 1 is a downhole tool. The downhole tool includes a
tubular body and an inner sleeve that is slidable within the
tubular body. The tubular body includes a port that allows fluid
flow between a bore of the downhole tool and an area outside of the
tubular body. The downhole tool is sequentially positionable in a
run-in position that blocks fluid flow through the port in the
tubular body, then in an open position that allows fluid flow
through the port in the tubular bod, and then in a closed position
that blocks fluid flow through the port in the tubular body.
[0045] In Example 2, the embodiments of any preceding paragraph or
combination thereof further include wherein the inner sleeve blocks
fluid flow through the port in the tubular body when in the
downhole tool is in the run-in position.
[0046] In Example 3, the embodiments of any preceding paragraph or
combination thereof further include wherein the inner sleeve is
sequentially positionable in a run-in position, then in an open
position, and then in a closed position.
[0047] In Example 4, the embodiments of any preceding paragraph or
combination thereof further include a seat disposed within the
inner sleeve. The seat includes a shoulder shaped to receive a plug
to shift the inner sleeve to position the downhole tool in the open
position.
[0048] In Example 5, the embodiments of any preceding paragraph or
combination thereof further include wherein the inner sleeve and
the tubular body are shaped such that the downhole tool is
shiftable into an open position via an unbalanced force acting on
the inner sleeve, the unbalanced force due to fluid pressure within
the downhole tool.
[0049] In Example 6, the embodiments of any preceding paragraph or
combination thereof further include wherein the inner sleeve
includes a shoulder shaped to receive a plug to shift the inner
sleeve to position the downhole tool in the closed position.
[0050] In Example 7, the embodiments of any preceding paragraph or
combination thereof further include wherein the inner sleeve
comprises a profile on an interior surface of the inner sleeve.
[0051] In Example 8, the embodiments of any preceding paragraph or
combination thereof further include a seat slidable within the
inner sleeve. Additionally, the inner sleeve further includes a
port that, when the downhole tool is positioned in the run-in
position, is aligned with the port in the tubular body. Further,
the seat is positionable in a run-in position that blocks fluid
flow through the port in the inner sleeve and an open position that
allows fluid flow through the port in the inner sleeve.
[0052] Example 9 is a cementing system for a borehole. The
cementing system includes a casing string positionable within the
borehole and including a downhole tool. The downhole tool includes
a tubular body and an inner sleeve that is slidable within the
tubular body. The tubular body includes a port that allows fluid
flow between a bore of the downhole tool and an area radially
outside of the tubular body. The downhole tool is sequentially
positionable in a run-in position that blocks fluid flow through
the port in the tubular body, then in an open position that allows
fluid flow through the port in the tubular bod, and then in a
closed position that blocks fluid flow through the port in the
tubular body.
[0053] In Example 10, the embodiments of any preceding paragraph or
combination thereof further include wherein the inner sleeve blocks
fluid flow through the port in the tubular body when in the
downhole tool is in the run-in position.
[0054] In Example 11, the embodiments of any preceding paragraph or
combination thereof further include wherein the inner sleeve is
sequentially positionable in a run-in position, then in an open
position, and then in a closed position.
[0055] In Example 12, the embodiments of any preceding paragraph or
combination thereof further include wherein the downhole tool
further includes a seat disposed within the inner sleeve. The seat
includes a shoulder shaped to receive a plug to shift the inner
sleeve to position the downhole tool in the open position.
[0056] In Example 13, the embodiments of any preceding paragraph or
combination thereof further include wherein the inner sleeve and
the tubular body are shaped such that the inner sleeve is shiftable
into an open position via an unbalanced force acting on the inner
sleeve, the unbalanced force due to fluid pressure within the
downhole tool.
[0057] In Example 14, the embodiments of any preceding paragraph or
combination thereof further include wherein the inner sleeve
includes a shoulder shaped to receive a plug to shift the inner
sleeve to position the downhole tool in the closed position.
[0058] In Example 15, the embodiments of any preceding paragraph or
combination thereof further include wherein the inner sleeve
comprises a profile on an interior surface of the inner sleeve.
[0059] In Example 16, the embodiments of any preceding paragraph or
combination thereof further include wherein the inner sleeve
further comprises a port that, when the downhole tool is positioned
in the run-in position, is aligned with the port in the tubular
body. Additionally, the downhole tool further includes a seat
slidable within the inner sleeve, the seat positionable in a run-in
position that blocks fluid flow through the port in the inner
sleeve and an open position that allows fluid flow through the port
in the inner sleeve.
[0060] Example 17 is a method for cementing a casing string in a
borehole. The method includes positioning a casing string
comprising a downhole tool within a borehole, wherein the downhole
tool is positioned in a run-in position that blocks fluid flow
between a bore of the downhole tool and an annulus formed between
the casing string and a wall of the borehole. The method also
includes shifting the downhole tool to an open position to allow
fluid flow between the bore of the downhole tool and the annulus.
The method further includes shifting the downhole tool to a closed
position to block fluid flow between the bore of the downhole tool
and the annulus.
[0061] In Example 18, the embodiments of any preceding paragraph or
combination thereof further include wherein shifting the downhole
tool to the open position includes shifting an inner sleeve of the
downhole tool via an unbalanced force acting on the inner sleeve to
shift the downhole tool to the open position, the unbalanced force
due to fluid pressure within the downhole tool.
[0062] In Example 19, the embodiments of any preceding paragraph or
combination thereof further include wherein shifting the downhole
tool to the open position includes pumping a plug downhole to
engage with a shoulder of a seat of the downhole tool to shift the
downhole tool to the open position.
[0063] In Example 20, the embodiments of any preceding paragraph or
combination thereof further include wherein shifting the downhole
tool to the closed position includes pumping a plug downhole to
engage with a shoulder of an inner sleeve of the downhole tool to
shift the downhole tool to the closed position.
[0064] Certain terms are used throughout the description and claims
to refer to particular features or components. As one skilled in
the art will appreciate, different persons may refer to the same
feature or component by different names. This document does not
intend to distinguish between components or features that differ in
name but not function.
[0065] Reference throughout this specification to "one embodiment,"
"an embodiment," "an embodiment," "embodiments," "some
embodiments," "certain embodiments," or similar language means that
a particular feature, structure, or characteristic described in
connection with the embodiment may be included in at least one
embodiment of the present disclosure. Thus, these phrases or
similar language throughout this specification may, but do not
necessarily, all refer to the same embodiment.
[0066] The embodiments disclosed should not be interpreted, or
otherwise used, as limiting the scope of the disclosure, including
the claims. It is to be fully recognized that the different
teachings of the embodiments discussed may be employed separately
or in any suitable combination to produce desired results. In
addition, one skilled in the art will understand that the
description has broad application, and the discussion of any
embodiment is meant only to be exemplary of that embodiment, and
not intended to suggest that the scope of the disclosure, including
the claims, is limited to that embodiment.
* * * * *