U.S. patent application number 13/357679 was filed with the patent office on 2013-03-28 for module for use with completion equipment.
This patent application is currently assigned to SCHLUMBERGER TECHNOLOGY CORPORATION. The applicant listed for this patent is John Algeroy, Spyro Kotsonis. Invention is credited to John Algeroy, Spyro Kotsonis.
Application Number | 20130075087 13/357679 |
Document ID | / |
Family ID | 47909967 |
Filed Date | 2013-03-28 |
United States Patent
Application |
20130075087 |
Kind Code |
A1 |
Algeroy; John ; et
al. |
March 28, 2013 |
Module For Use With Completion Equipment
Abstract
In general, module is lowered to a position in a well to
communicate with completion equipment in the well for performing a
check of a downhole condition. According to a result of the check,
the module is used to actuate a component of the completion
equipment. In further examples, a string is lowered into the well,
where the string has a first coupler portion and a contraction
joint. The contraction joint is used to align the first coupler
portion on the string with a second coupler portion that is part of
completion equipment in the well.
Inventors: |
Algeroy; John; (Houston,
TX) ; Kotsonis; Spyro; (Missouri City, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Algeroy; John
Kotsonis; Spyro |
Houston
Missouri City |
TX
TX |
US
US |
|
|
Assignee: |
SCHLUMBERGER TECHNOLOGY
CORPORATION
Sugar Land
TX
|
Family ID: |
47909967 |
Appl. No.: |
13/357679 |
Filed: |
January 25, 2012 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
61538471 |
Sep 23, 2011 |
|
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|
Current U.S.
Class: |
166/250.01 ;
166/318; 166/66 |
Current CPC
Class: |
E21B 41/00 20130101;
E21B 47/12 20130101; E21B 23/00 20130101; E21B 47/00 20130101 |
Class at
Publication: |
166/250.01 ;
166/66; 166/318 |
International
Class: |
E21B 47/00 20120101
E21B047/00; E21B 34/00 20060101 E21B034/00; E21B 43/00 20060101
E21B043/00 |
Claims
1. A method comprising: lowering a module to a position in a well
to communicate with completion equipment in the well for performing
a check of a downhole condition; and according to a result of the
check, using the module to actuate a component of the completion
equipment.
2. The method of claim 1, further comprising: establishing
communication between the module and the completion equipment to
perform the check of the downhole condition.
3. The method of claim 2, wherein establishing the communication
comprises establishing the communication using a first coupler
portion that is part of the module and a second coupler portion
that is part of the completion equipment.
4. The method of claim 3, wherein each of the first and second
coupler portions is selected from the group consisting of: an
inductive coupler portion, an electrical wet connect portion, an
optical coupler portion, and a hydraulic coupler portion.
5. The method of claim 3, wherein the module is part of equipment
that further includes a contraction joint, the method further
comprising using the contraction joint to align the first inductive
coupler portion with the second inductive coupler portion.
6. The method of claim 1, wherein performing the check comprises
performing a check of a downhole environmental condition in the
well.
7. The method of claim 1, wherein performing the check comprises
performing a status check of the completion equipment.
8. The method of claim 1, wherein performing the check includes the
module querying a sensor in the completion equipment or the module
querying for a setting of a component of the completion
equipment.
9. The method of claim 1, wherein using the module to actuate the
component comprises using the module to mechanically actuate the
component.
10. The method of claim 1, wherein using the module to actuate the
component comprises using the module to electrically actuate the
component.
11. The method of claim 1, wherein using the module to actuate the
component comprises using the module to hydraulically actuate the
component.
12. A system comprising: a module to be lowered into a well; and a
completion equipment for installation in the well, where the module
is to communicate with the completion equipment in the well for
performing a check of a downhole condition, and where the module is
to, according to a result of the check, actuate a component of the
completion equipment.
13. The system of claim 12, wherein the module includes a first
coupler portion, and the completion equipment includes a second
coupler portion to communicate with the first coupler portion when
the first and second coupler portions are brought into
alignment.
14. The system of claim 13, wherein each of the first and second
coupler portions is selected from the group consisting of: an
inductive coupler portion, an electrical wet connect portion, an
optical coupler portion, and a hydraulic coupler portion.
15. The system of claim 13, wherein the module further includes a
ball-release mechanism to release a ball to actuate the
component.
16. A method comprising: lowering a string into a well, wherein the
string has a first coupler portion and a contraction joint; and
using the contraction joint to align the first coupler portion on
the string with a second coupler portion that is part of completion
equipment in the well.
17. The method of claim 16, wherein the coupler portion is selected
from the group consisting of: an inductive coupler portion, an
electrical wet connect portion, an optical coupler portion, and a
hydraulic coupler portion.
18. The method of claim 16, further comprising setting weight on
the string to shear a shear element of the contraction joint.
19. The method of claim 16, further comprising providing a
mechanism in the contraction joint to actuate the contraction joint
between different stroke positions.
20. A module comprising: a body; an electrical cable connected to
the body to allow for electrical communication; and a ball-release
mechanism having a ball and a release member for releasing the ball
in response to an input stimulus.
Description
CROSS REFERENCE TO RELATED APPLICATIONS
[0001] This application claims the benefit under 35 U.S.C.
.sctn.119(e) of U.S. Provisional Application Ser. No. 61/538,471,
entitled "MODULE FOR USE WITH COMPLETION EQUIPMENT," filed Sep. 23,
2011, which is hereby incorporated by reference.
BACKGROUND
[0002] A well can be drilled into a subterranean structure for the
purpose of recovering fluids from a reservoir in the subterranean
structure. Examples of fluids include hydrocarbons, fresh water, or
other fluids. Alternatively, a well can be used for injecting
fluids into the subterranean structure.
[0003] Once a well is drilled, completion equipment can be
installed in the well. Examples of completion equipment include a
casing or liner to line a wellbore. Also, flow conduits, flow
control devices, and other equipment can also be installed to
perform production or injection operations.
SUMMARY
[0004] In general, according to some implementations, a module is
lowered to a position in a well to communicate with completion
equipment in the well for performing a check of a downhole
condition. According to a result of the check, the module is used
to actuate a component of the completion equipment. In further
implementations, a string is lowered into the well, where the
string has a first coupler portion and a contraction joint. The
contraction joint is used to align the first coupler portion on the
string with a second coupler portion that is part of completion
equipment in the well.
[0005] Other or additional features will become apparent from the
following description, from the drawings, and from the claims.
BRIEF DESCRIPTION OF THE DRAWINGS
[0006] Some embodiments are described with respect to the following
figures:
[0007] FIGS. 1A-1E illustrate example arrangements of equipment
according to some implementations;
[0008] FIG. 2 is a side partial cross-sectional view of a portion
of completion equipment, in accordance with some
implementations;
[0009] FIG. 3 is a schematic diagram of equipment including a
contraction joint according to some implementations; and
[0010] FIG. 4 is a cross-sectional view of completion equipment
according to further implementations.
DETAILED DESCRIPTION
[0011] As used here, the terms "above" and "below"; "up" and
"down"; "upper" and "lower"; "upwardly" and "downwardly"; and other
like terms indicating relative positions above or below a given
point or element are used in this description to more clearly
describe some embodiments. However, when applied to equipment and
methods for use in wells that are deviated or horizontal, such
terms may refer to a left to right, right to left, or diagonal
relationship as appropriate.
[0012] Completion equipment can be installed in a well to allow for
various operations to be performed, including fluid production
and/or injection operations. As examples, the completion equipment
can include a casing or liner, fluid conduits (e.g. tubings, pipes,
etc.), flow control devices, sand control elements, pumps, sealing
elements (e.g. packers), sensors, and so forth.
[0013] The well can be a vertical well, a deviated well, a
horizontal well, or a well that has multiple lateral branches.
After completion equipment is installed in a portion of the well,
it may be desirable to actuate at least one component of the
completion equipment. For example, the installed completion
equipment can include a packer that is to be set to provide fluid
isolation for a portion of the well. As another example, the
completion equipment can include a flow control device that is to
be opened or closed to control fluid flow. There can be other
examples of components that can be actuated downhole.
[0014] Prior to actuation of a component (or components) of the
completion equipment, it may be desirable to check a downhole
condition in the well, where the downhole condition can refer to an
environmental condition of a portion of the well or a status of the
completion equipment. As examples, an environmental condition can
include downhole pressure, downhole temperature, fluid content in
the well portion, or other environment condition. Examples of a
status of the completion equipment include positions of components
relative to other components, settings of components (e.g.,
settings of motors, settings of packers, etc.), and so forth. The
check of the downhole condition can be performed to verify that the
downhole condition meets a predefined criterion (or predefined
criteria). For example, the check can confirm that a downhole
pressure does not exceed a particular pressure threshold, or that
the downhole temperature does not exceed a particular temperature
threshold. The check can also confirm that one or more components
(e.g. a motor, a pump, etc.) of the completion equipment is
operating properly or has a proper setting.
[0015] If a component of the completion equipment is actuated
without performing the check to verify that the downhole condition
meets the predefined criterion (or criteria), then a well operator
may have to reverse the actuation when the well operator later
detects that the completion equipment is not function properly or
detects some other fault condition. It may be time-consuming to
reverse the actuation of a component in the completion equipment,
since the well operator may have to run an intervention tool into
the well.
[0016] To perform various downhole operations, communication is
performed between different completion equipment sections. In some
implementations, the communication can include electrical
communication, and an inductive coupler can be used to allow for
communication between the different communication sections. An
inductive coupler can include a first inductive coupler portion on
a first completion equipment section, and a second inductive
coupler portion on a second completion equipment section. When the
first and second inductive coupler portions are brought into
alignment close to each other, then the inductive coupler portions
can communicate using inductive coupling.
[0017] An inductive coupler performs communication using induction.
Induction involves transfer of a time-changing electromagnetic
signal or power that does not rely upon a closed electrical
circuit, but instead performs the transfer wirelessly. For example,
if a time-changing current is passed through a coil, then a
consequence of the time variation is that an electromagnetic field
will be generated in the medium surrounding the coil. If a second
coil is placed into that electromagnetic field, then a voltage will
be generated on that second coil, which is referred to as the
induced voltage. The efficiency of this inductive coupling
generally increases as the coils of the inductive coupler are
placed closer together.
[0018] In other examples, other types of communications can be
performed, including optical communication, hydraulic
communication, and so forth. Optical communication can be
accomplished using an optical fiber (or optical fibers) through
which optical signals can be propagated. Hydraulic communication
can be performed using hydraulic control lines through which
hydraulic pressure can be applied for controlling a component. To
allow for optical communication between separate completion
equipment sections, optical coupler portions can be employed. As
examples, optical coupler portions can include optical lenses and
other optical elements to allow for communication of optical
signals between the optical coupler portions once they are brought
into alignment with respect to each other. If hydraulic
communication is performed, then hydraulic coupler portions can be
provided on the separate completion equipment sections, which can
include hydraulic ports and hydraulic fluid passageways that are
sealingly engaged to each other once the hydraulic coupler portions
on the separate completion equipment sections are brought into
alignment.
[0019] In further examples, coupler portions can include electrical
wet connect portions can take the form of tough logging condition
(TLC) wet connect portions, such as those described in U.S. Ser.
No. 12/897,043, entitled "Active Integrated Completion Installation
System and Method," filed Oct. 4, 2010 (Attorney Docket No.
68.0983); U.S. Pat. No. 4,484,628; U.S. Pat. No. 5,871,052; U.S.
Pat. No. 5,967,816; and U.S. Pat. No. 6,510,899, all the contents
of which are herein incorporated by reference in their entirety.
Electrical wet connect portions establish actual electrical contact
between electrical mating connectors of separate completion
equipment sections. This form of wet connect technology may be used
to allow communication and power to be supplied to completion
equipment, such as by use of a logging cable. Typical tough logging
conditions may be found in wells with high deviation or long
horizontal sections where traditional logging activities with cable
cannot be used.
[0020] A challenge of communicating using coupler portions (e.g.
inductive coupler portions, optical coupler portions, hydraulic
coupler portions, or electrical wet connect portions) on separate
completion equipment sections is that it can be difficult to align
the coupler portions with respect to each other to allow for
corresponding communication (e.g. inductive coupling, optical
coupling, or hydraulic coupling).
[0021] In accordance with some embodiments, as discussed in further
detail below, a contraction joint can be used to perform alignment
of coupler portions.
[0022] In the ensuing discussion, reference is made to inductive
coupler portions. Note, however, that techniques or mechanisms
according to some implementations can also be applied in examples
that employ optical coupler portions, and/or hydraulic coupler
portions, and/or electrical wet connect portions.
[0023] In accordance with some implementations, relatively
convenient techniques or mechanisms are provided to allow for a
check of a downhole condition to be performed prior to actuation of
a component (or components) in completion equipment. In accordance
with some embodiments, as shown in FIG. 1A, a module 110 can be
lowered into a well 104 to communicate with lower completion
equipment 102 installed (possibly in multiple sections) in the well
104. In some implementations, the module 110 can receive data from
downhole sensors, such that the module 110 can be used for
performing a check of a downhole condition. The received sensor
data can be communicated by the module 110 to an uphole location,
such as a controller in earth surface equipment 112. In other
examples, the module 110 can be used to communicate commands sent
by an uphole controller to a downhole electrical component (e.g.
commands to actuate a flow control device, commands to set a
packer, commands to activate a pump, etc.).
[0024] At least a portion of the well 104 can be lined with casing
or liner. Note that although reference is made to checking for a
downhole condition, such reference is intended to also cover
situations where multiple different types of downhole conditions
are checked.
[0025] The module 110 can be lowered on a carrier structure 108,
which can include a cable (e.g. wireline) or other type of carrier
structure (e.g. coiled tubing). The carrier structure 108 includes
a communications medium or communications media (e.g. electrical
conductor(s), fiber optic cable(s), hydraulic control line(s),
etc.) that allows the module 110 to communicate with the surface
equipment 112 located at an earth surface 114 above a subterranean
structure 116 into which the well 104 is formed.
[0026] In some examples, the module 110 is lowered into an inner
bore 118 of a drill pipe 106 (or other workstring) that is used to
deploy at least a section of the lower completion equipment 102. In
the ensuing discussion, although reference is made to the drill
pipe 106, it is noted that the described mechanisms or techniques
can be applied with other types of workstrings. In other examples,
the drill pipe 106 can be omitted. In such other examples, the
module 110 can be lowered into the well 104 through another
conduit, such as a casing, a liner, a tubing, and so forth.
[0027] The module 110 has a communications mechanism for engaging
with a corresponding communications mechanism of a downhole
receiving element 120 (which can be part of the drill pipe 106, or
in a different example, part of the lower completion equipment
102). In some implementations, the communications mechanism of the
module 110 includes an inductive coupler portion for communicating
with a corresponding inductive coupler portion at the downhole
receiving element 120. In other implementations, the communications
mechanism of the module 110 can include an electrical wet connect
portion for electrical connection with a corresponding electrical
wet connect portion at the downhole receiving element 120. In yet
other examples, the communications mechanism of the module 110 can
include an optical coupler portion and/or a hydraulic coupler
portion for optical and/or hydraulic communication with a
corresponding optical coupler portion and/or hydraulic coupler
portion at the downhole receiving element 120.
[0028] In some examples, the drill pipe 106 and/or the lower
completion equipment 102 can be provided with additional coupler
portions to allow for communication between components of the drill
pipe 106 and/or the lower completion equipment 102.
[0029] Some example applications are discussed below. In a first
application (Application 1), the drill pipe 106 can be used to
install the lower completion equipment 102 into the well 104. The
lower completion equipment 102 can include inductive coupler
portions that are electrically connected to sensors and other
electrical components (e.g. packers, flow control devices, etc.).
By using the inductive coupler portions of the drill pipe 106 and
the lower completion equipment 102, electrical communication
between the module 110 and the sensors and other electrical
components of the completion equipment 102 is possible.
[0030] In another example application (Application 2), the lower
completion equipment 102 can include a sand control system. In
implementations where the module 110 includes an inductive coupler
portion to allow for communication between the module 110 and the
lower completion equipment 102 (including sensors and other
electrical components), a relatively large inner diameter is
provided through the module 110 to allow for flow of gravel-related
fluids (e.g. gravel slurry, return fluids, etc.) during a gravel
pump operation to pump gravel to the sand control system.
[0031] In a further example application (Application 3), the well
104 can include lateral branches in which respective completion
equipment can be installed. The module 110 can also be used to
establish communication with the completion equipment (which can
include sensors and other electrical components) installed in such
lateral branches.
[0032] Although various example applications are noted above,
techniques or mechanisms according to some implementations can be
used in other applications.
[0033] An example well with lateral branches is shown in FIG. 1B,
which has lateral branches 130 and 132 with respective lateral
completion equipment in the lateral branches 130 and 132. The
module 110 of FIG. 1A (lowered through the drill pipe 106 of FIG.
1B) can also be used to establish communication with the lateral
completion equipment in the lateral branches 130 and 132, and also
to actuate respective components in the lateral branches 130 and
132. A tubing string 140 is coupled to the drill pipe 106. The
tubing 140 is able to establish fluid communication with the
lateral completion equipment in the lateral branches 130 and
132.
[0034] FIG. 1C shows an enlarged view of a portion of the
arrangement depicted in FIG. 1B. FIG. 1C shows communication using
inductive coupler portions between the drill pipe 106 and the
tubing string 140. In the example according to FIG. 1C, the
downhole receiving element 120 shown in FIG. 1A is part of the
drill pipe 106. As noted above, this downhole receiving element 120
has a communications mechanism (e.g. inductive coupler portion 148)
to communicate with an inductive coupler portion of the module 110
that is lowered into the inner bore of the drill pipe 106. In
addition, FIG. 1C further shows that the drill pipe 106 has another
inductive coupler portion 150, which is electrically connected to
the inductive coupler portion 148 in the downhole receiving element
120. The inductive coupler portion 150 on the drill pipe 106 is
arranged to align with a corresponding inductive coupler portion
152 that is mounted to a liner 154 that lines a portion of the well
shown in FIG. 1C. When aligned, the inductive coupler portions 150
and 152 can communicate using inductive coupling.
[0035] The inductive coupler portion 152 is electrically connected
to a cable 156. The cable 156 extends outside of the liner 154
(along an outer wall of the liner 154) to further downhole
locations, as shown in FIG. 1D. In other examples, the cable 156
can be embedded in the wall of the liner 154. In examples where
other types of coupler portions (e.g. optical or hydraulic coupler
portions) are used, then the cable 156 can be replaced with another
type of control line, such as an optical cable or a hydraulic
control line.
[0036] The electrical cable 156 that runs outside the liner 154
extends to a lower inductive coupler portion 158 that is mounted to
the liner 154. The lower liner inductive coupler portion 158 is
located near the junction between the main wellbore and the lateral
branches 130 and 132. As shown in FIG. 1D, the inductive coupler
portion 158 is aligned with an inductive coupler portion 160 that
is part of lateral branch equipment 162 that extends into the
lateral branch 130. In this manner, the inductive coupler portions
158 and 160 can be used to allow for communication between an
uphole location and components (e.g. sensors, flow control devices,
etc.) in the lateral branch equipment 162.
[0037] Although not shown in FIG. 1D, the electrical cable 156 can
further extend to another inductive portion mounted to the liner
154, for positioning adjacent lateral branch equipment 164 in the
lateral branch 132. This allows for communication between an uphole
location and components of the lateral branch equipment 164.
[0038] FIG. 1E illustrates a different example arrangement for use
in a multilateral well. The completion equipment provided in the
multilateral well of FIG. 1E includes upper completion equipment
170, lateral completion equipment 172 provided in a lateral branch
173, and lateral completion equipment 174 provided in lateral
branch 175.
[0039] A lower portion of the upper completion equipment 170 has an
inductive coupler portion 176, which is aligned with an inductive
coupler portion 177 mounted to liner 178. As shown in FIG. 1E, an
electrical cable 179 is connected to the inductive coupler portion
176 mounted to the upper completion equipment 170. The electrical
cable 179 extends to an uphole location, such as to earth surface
equipment.
[0040] The inductive coupler portion 177 mounted to the liner 178
is connected to an electrical cable 181, which runs outside the
liner 178 for connection with inductive coupler portions 180 and
182 that are positioned adjacent junctions to lateral branches 173
and 175, respectively. The liner inductive coupler portions 180 and
182 are mounted to the liner 178. The liner inductive coupler
portion 180 is positioned adjacent inductive coupler portion 183
that is part of the lateral branch equipment 172 that extends into
the lateral branch 173. As shown in FIG. 1E, an electrical cable
184 connects the inductive coupler portion 173 to electrical
components 185 in the lateral branch equipment 172.
[0041] The liner inductive coupler portion 182 is aligned with an
inductive coupler portion 186 that is part of the lateral branch
equipment 174 that extends into the lateral branch 175. The
inductive coupler portion 186 is connected to an electrical cable
187 that is connected to various electrical components 188 arranged
along the length of the lateral branch equipment 174.
[0042] FIG. 2 shows details of a portion of completion equipment
according to further examples. In FIG. 2, an isolation packer 202
can be arranged on the drill pipe 106. The isolation packer 202 can
be set in the wellbore to provide hydraulic isolation in between
portions above and below the packer 202. In the example arrangement
of FIG. 2A, the packer 202 when set can engage casing 204 that
lines the well. The drill pipe 106 has an inductive coupler portion
206 mounted to the drill pipe 106. The drill pipe 106 has an inner
conduit 208 through which a tool (such as a tool including the
module 110 of FIG. 1A) can be provided. This module 110 can be
positioned adjacent the inductive coupler portion 206 to allow for
inductive coupling between an inductive coupler portion that is
part of the module 110 and the inductive coupler portion 206 on the
drill pipe 106.
[0043] The drill pipe 106 further has another inductive coupler
portion 210 below the inductive coupler portion 206. The inductive
coupler portions 206 and 210 on the drill pipe 106 can be
interconnected by a cable 207. The lower inductive coupler portion
210 is positioned adjacent an inductive coupler portion 212 that is
part of a lower completion equipment 213 that extends into a lower
wellbore portion 214, which in some examples is an unlined (open)
lower well portion. The inductive coupler portion 212 is connected
to a cable 215, which extends to various points (having sensors or
other electrical components, for example) along the lower
completion equipment 213.
[0044] As depicted in FIG. 2, the lower completion equipment 213
has various isolation packers 216 that can be set to define
respective isolated zones in the lower well portion 214. The
isolation packers 216 are arranged on a tubing 218 defining an
inner conduit through which fluid flow can occur (injection fluid
flow or production fluid flow).
[0045] To perform electrical communication from an uphole location
(such as the earth surface equipment 112 depicted in FIG. 1A), the
module 110 is lowered into the drill pipe 106 for communicative
engagement with the inductive coupler portion 206. In this way,
communication can occur between the uphole component and a
component (or components) in the lower completion equipment 102,
through the inductive coupler portions of the module 110 and the
inductive coupler portions 206, 210, and 212, as well as
interconnecting cables 207 and 215.
[0046] The arrangement of FIG. 2 can be used to perform
Applications 1 and 2 noted above. For Application 3, a similar type
of connectivity from the earth surface can be accomplished by using
the module 110. However, for Application 3, the inductive coupler
on a lower completion string connects to a corresponding inductive
coupler portion in a casing or liner.
[0047] FIG. 3 is a schematic diagram of completion equipment
according to further implementations. In FIG. 3, the drill pipe 106
is provided in casing 300. The module 110 is lowered into the inner
bore of the drill pipe 106 on the carrier structure 108. In FIG. 3,
the module 110 includes an inductive coupler portion 302 to
communicate with a corresponding inductive coupler portion 304 on
the drill pipe 106. The inductive coupler portion 304 is
electrically connected by an electrical cable 303 to another
inductive coupler portion 306 on the drill pipe 106. The other
inductive coupler portion 306 is aligned with an upper inductive
coupler portion 308 of the casing 300. The upper casing inductive
coupler portion 308 is electrically connected over an electrical
cable 314 to a lower inductive coupler portion 310 mounted to the
casing 300. The lower casing inductive coupler portion 310
communicates with an inductive coupler portion 312 of a lower
completion equipment 316. The inductive coupler portion 312 is
connected to sensors and/or other electrical components of the
lower completion equipment 316.
[0048] In accordance with some embodiments, a shearable contraction
joint 320 is provided to allow proper alignment of the drill pipe
inductive coupler portion 306 and the upper liner inductive coupler
portion 308. In some examples, the contraction joint 320 can
include concentrically arranged tubular members that are
longitudinally movable with respect to each other to provide an
expanded state and contracted state of the contraction joint
320.
[0049] The contraction joint 320 of FIG. 3 allows for space-out
when landing in the lower completion equipment 316. The upper
portion of the contraction joint 320 is sealably engaged to the
drill pipe 106 (using a stroke lock mechanism 326 that has a
sealing element). The lower portion of the contraction joint 320 is
connected to a packer 322 that can be set to isolate the well
region below the packer 322.
[0050] The contraction joint 320 allows for the drill pipe 106 to
continue downward movement until the drill pipe inductive coupler
portion 306 is aligned with the upper casing inductive coupler
portion 308. This downward movement is provided by setting down
weight on the drill pipe 106 to cause a shear mechanism (e.g. shear
pin) in the contraction joint 320 to shear. Shearing of the shear
mechanism allows the tubular members of the contraction joint 320
to move relative to one another. The contraction joint 320 has
seals to ensure pressure integrity when setting a packer 322 in the
lower completion equipment 316.
[0051] During installation, the lower inductive coupler portions
310 and 312 are aligned using a selective landing nipple or other
alignment profile (not shown) in the casing 300. By continuing to
set down weight on the drill pipe 106, the shearing mechanism in
the sealed contraction joint 320 shears. The downward movement of
the drill pipe 106 continues until an alignment profile 324 of the
drill pipe 106 lands in a corresponding profile 325 (e.g. nipple
profile) in the casing 300, such that the inductive coupler
portions 306 and 308 are aligned. Once landed, the module 110 can
be lowered into the drill pipe 106, and the module 110 can land
inside a corresponding profile of the drill pipe 106, to be aligned
with the upper drill pipe inductive coupler portion 304.
[0052] The contraction joint 320 in some implementations can have
the following additional features. In the event that the lower
inductive coupler (310, 312) has not fully engaged, pulling up on
the drill pipe 106 will stroke open the contraction joint 320 to
its expanded state. In some examples, a J-slot mechanism (part of
the stroke lock mechanism 326 in FIG. 3) included in the
contraction joint 320 will shift, hence maintaining the contraction
joint in the open position (expanded state) when setting down
weight. This will allow for additional downward force to be applied
to fully engage with the lower inductive coupler.
[0053] Upward pulling will stroke the J-slot again, and this time
allow the contraction joint to close (contracted state). Downward
movement of the drill pipe 106 will move the inductive coupler
portion 306 down until engaged in the corresponding casing
inductive coupler portion 308, due to engagement of the engagement
profiles 324 and 325.
[0054] The J-slot mechanism allows for continued operation until
full engagement of the inductive couplers are achieved. In other
implementations, other mechanisms for actuating or stroking the
contraction joint between the expanded state (or expanded stroke
position) and the contracted state (or contracted stroke position)
can be used. For example, an electrically-controlled,
pressure-actuated, hydraulic-actuated, or other type mechanism can
be used for actuating or stroking the contraction joint between its
different states.
[0055] After the lower completion is landed, but prior to setting
the packer 322, the operation includes a check of the state of the
equipment in the lower completion before setting the packer 322,
using the module 110 and inductive couplers as discussed above.
[0056] FIG. 4 shows the module 110 according to further examples.
The module 110 has a body 402 (having an outer housing) that
defines an inner chamber 404. As discussed above, the module 110
has the inductive coupler portion 302, which is arranged to align
with the inductive coupler portion 304 on the drill pipe 106.
[0057] The module 110 further includes a ball release mechanism
406, which has a ball 408 positioned in a receptacle 408 of a
release member 410 in the ball release mechanism 406. The release
member 410 is arranged to open in response to applied pressure
against the ball 408. In other examples, the release member 410 is
arranged to open in response to another input stimulus. The release
member 410 is pivotably connected to the body 402 of the module 110
by a hinge mechanism 412, in some examples. The ball 408 is held
against the receptacle 408 by a protruding portion 414 inside the
module 110. In other examples, other types of ball release
mechanisms can be employed.
[0058] The module 110 has inlet ports 416 to allow for fluid
pressure to be applied from outside the module 110 to the inner
chamber 404 of the module 110.
[0059] In operation, the module 110 is lowered through the drill
pipe 106 on the carrier structure 108. Once the module 110 is
positioned in place, such that the inductive coupler portions 302
and 304 are aligned, communication can be established using the
module 110 to allow for a status check to be performed, as
discussed above. For example, measurement data from a sensor can be
communicated through the various inductive couplers discussed
herein, and communicated through the module 110 over the carrier
structure 108 to an uphole location.
[0060] Once the well operator determines that the well can be
operated, pressure can be applied inside the drill pipe 106 to
cause fluid pressure to be created inside the inner chamber 404 of
the module 110. If sufficient pressure is applied, the differential
pressure across the ball 408 will cause a shear mechanism 418 that
attaches the release member 410 to the housing 402 to shear, which
allows the release member 410 to pivot open to allow the ball 408
to drop.
[0061] Dropping the ball 408 can be used to set the packer 302,
once the ball 408 reaches a setting mechanism of the packer 302. In
some examples, when the ball 408 is set against the packer 302,
applied pressure against the ball 408 in the setting mechanism of
the packer 302 will cause increased pressure against the packer 302
such that packer setting can be achieved.
[0062] In other examples, instead of using the ball release
mechanism 406 in the module 110, a separate ball can be dropped
into the drill pipe 106 after the module 110 is retrieved, where
this ball can be engaged in the setting mechanism of the packer 302
to set the packer.
[0063] As yet other examples, instead of using a ball setting
mechanism, the packer 302 can be set using other techniques, such
as in response to a signal (electrical signal, optical signal,
hydraulic pressure, etc.) from the earth surface.
[0064] In other examples, the module 110 can be used in other
applications, such as during gravel packing operation. In such
other examples, the module 110 has an inner conduit that allows
gravel slurry to be flowed through the inner conduit of the module
110. The module 110 can be used to monitor the efficiency of the
gravel packing using sensors placed in a sand control system that
is part of the completion equipment.
[0065] In the foregoing description, numerous details are set forth
to provide an understanding of the subject disclosed herein.
However, implementations may be practiced without some or all of
these details. Other implementations may include modifications and
variations from the details discussed above. It is intended that
the appended claims cover such modifications and variations.
* * * * *