U.S. patent application number 16/803067 was filed with the patent office on 2020-10-29 for kickover tools and methods of operating the same in hydrocarbon wells.
The applicant listed for this patent is ExxonMobil Upstream Research Company. Invention is credited to Tony W. Hord, Michael C. Romer.
Application Number | 20200340317 16/803067 |
Document ID | / |
Family ID | 1000004685009 |
Filed Date | 2020-10-29 |
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United States Patent
Application |
20200340317 |
Kind Code |
A1 |
Romer; Michael C. ; et
al. |
October 29, 2020 |
Kickover Tools and Methods of Operating the Same in Hydrocarbon
Wells
Abstract
Kickover tools and methods of operating the same. The kickover
tools are configured to engage a downhole component within a
completion structure of a hydrocarbon well. The kickover tools
include a tool body and a kickover arm that extends between a first
arm end and a second arm end. The kickover tools also include an
end effector that is operatively attached to the second arm end and
configured to interface with the downhole component. The kickover
tools further include an actuation mechanism that mechanically
couples the first arm end to the tool body and is configured to
selectively transition the kickover arm between a retracted
configuration and an extended configuration. The kickover tools
also include a data transmission interface and an attachment point.
The kickover tools further include an imaging device configured to
collect an image indicative of an environment proximal the kickover
tool.
Inventors: |
Romer; Michael C.; (The
Woodlands, TX) ; Hord; Tony W.; (Spring, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
ExxonMobil Upstream Research Company |
Spring |
TX |
US |
|
|
Family ID: |
1000004685009 |
Appl. No.: |
16/803067 |
Filed: |
February 27, 2020 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
62839410 |
Apr 26, 2019 |
|
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|
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 47/12 20130101;
E21B 23/03 20130101; E21B 43/123 20130101 |
International
Class: |
E21B 23/03 20060101
E21B023/03; E21B 47/12 20060101 E21B047/12; E21B 43/12 20060101
E21B043/12 |
Claims
1. A kickover tool configured to engage a downhole component within
a completion structure of a hydrocarbon well, the kickover tool
comprising: a tool body; a kickover arm that extends between a
first arm end and a second arm end; an end effector configured to
interface with the downhole component, wherein the end effector is
operatively attached to the second arm end; an actuation mechanism
that mechanically couples the first arm end of the kickover arm to
the tool body and is configured to selectively transition the
kickover arm between a retracted configuration and an extended
configuration; a data transmission interface; an attachment point
configured to operatively interconnect the kickover tool with an
umbilical; and an imaging device configured to collect a collected
image indicative of an environment proximal the kickover tool, to
generate an image signal indicative of the collected image, and to
provide the image signal to the data transmission interface.
2. The kickover tool of claim 1, wherein the image signal includes
information indicative of a spatial relationship between at least
one of: (i) the kickover tool and the completion structure; (ii)
the end effector and the completion structure; and (iii) the end
effector and the downhole component.
3. The kickover tool of claim 1, wherein the image signal includes
information indicative of at least one of: (i) a visual
representation of the kickover tool; (ii) a visual representation
of the tool body; (iii) a visual representation of the kickover
arm; (iv) a visual representation of the completion structure; and
(v) a visual representation of the downhole component.
4. The kickover tool of claim 1, wherein the imaging device
includes at least one of: (i) an optical imaging device configured
to collect visible light; (ii) an electromagnetic imaging device
configured to collect electromagnetic radiation; (iii) an infrared
imaging device configured to collect infrared radiation; and (iv)
an acoustic imaging device configured to detect acoustic
vibrations.
5. The kickover tool of claim 1, wherein the imaging device
includes an active imaging device configured to provide a probe
signal to the environment proximal the kickover tool such that the
probe signal reflects from at least one structure within the
environment proximal to the kickover tool to generate a reflected
signal, wherein the imaging device further is configured to receive
the reflected signal and to generate the image signal based, at
least in part, on the reflected signal.
6. The kickover tool of claim 5, wherein the probe signal includes
at least one of electromagnetic radiation and acoustic
vibration.
7. The kickover tool of claim 1, wherein the imaging device
includes a passive imaging device configured to generate the image
signal responsive to receipt of at least one of: (i) ambient
vibrations within the environment proximal the kickover tool; and
(ii) ambient electromagnetic radiation within the environment
proximal the kickover tool.
8. The kickover tool of claim 1, wherein the kickover tool further
includes a tension sensor configured to generate a tension signal
indicative of a tensile force between the attachment point and the
umbilical and to provide the tension signal to the data
transmission interface.
9. The kickover tool of claim 8, wherein the tension sensor
includes a strain sensor configured to detect mechanical strain
within at least a portion of at least one of the kickover tool, the
attachment point, and the umbilical.
10. The kickover tool of claim 1, wherein the kickover tool further
includes a pressure sensor configured to generate a pressure signal
indicative of a pressure acting upon the pressure sensor and to
provide the pressure signal to the data transmission interface.
11. The kickover tool of claim 1, wherein the kickover tool further
includes a depth sensor configured to generate a depth signal
indicative of a depth of the kickover tool within the hydrocarbon
well and to provide the depth signal to the data transmission
interface.
12. The kickover tool of claim 1, wherein the kickover tool further
includes an orientation-determining structure configured to
generate an orientation signal and to provide the orientation
signal to the data transmission interface, wherein the orientation
signal is indicative of at least one of: (i) a relative orientation
between the tool body and the kickover arm; (ii) a relative
orientation between the end effector and the kickover arm; (iii) a
relative orientation between the end effector and the tool body;
(iv) a relative orientation between the kickover arm and the
downhole component; (v) a relative orientation between the end
effector and the downhole component; (vi) a body-arm angle defined
between a body longitudinal axis of the tool body and an arm
longitudinal axis of the kickover arm; and (vii) an arm-end
effector angle defined between the arm longitudinal axis and an end
effector longitudinal axis of the end effector.
13. The kickover tool of claim 1, wherein the kickover tool further
includes a temperature sensor configured to generate a temperature
signal indicative of a temperature in the environment proximal the
kickover tool and to provide the temperature signal to the data
transmission interface.
14. The kickover tool of claim 1, wherein the kickover tool further
includes an acceleration sensor configured to generate an
acceleration signal indicative of an acceleration of the kickover
tool and to provide the acceleration signal to the data
transmission interface.
15. The kickover tool of claim 1, wherein the kickover tool further
includes a velocity sensor configured to generate a velocity signal
indicative of a velocity of the kickover tool and to provide the
velocity signal to the data transmission interface.
16. The kickover tool of claim 1, wherein the kickover tool further
includes a communication structure configured to facilitate
communication with the downhole component when the kickover tool is
proximal the downhole component within the hydrocarbon well.
17. The kickover tool of claim 16, wherein the communication
structure includes an inductive communication structure.
18. The kickover tool of claim 1, wherein the kickover tool further
includes an analysis structure programmed to receive the image
signal from the imaging device, to modify the image signal to
generate a modified image signal, and to provide the modified image
signal to the data transmission interface.
19. A hydrocarbon well, comprising: a wellbore extending between a
surface region and a subsurface region; the kickover tool of claim
1 positioned within the wellbore; the umbilical operatively
attached to the attachment point and extending from the kickover
tool to the surface region; a downhole tubular extending within the
wellbore; the completion structure operatively attached to the
downhole tubular; and the downhole component positioned within the
completion structure.
20. A method of operating a kickover tool, the method comprising:
positioning the kickover tool within a completion structure of a
hydrocarbon well; collecting, with the kickover tool, a collected
image indicative of an environment within the hydrocarbon well and
proximal the kickover tool; displaying, for an operator of the
kickover tool, a displayed image that is based upon the collected
image and is indicative of the environment within the hydrocarbon
well and proximal the kickover tool; and at least one of: (i)
interfacing the kickover tool with a downhole component of the
completion structure while the kickover tool is positioned within
the completion structure, wherein the interfacing is based, at
least in part, on the displaying; and (ii) installing the downhole
component within the completion structure, wherein the installing
is based, at least in part, on the displaying.
21. The method of claim 20, wherein the positioning includes
conveying the kickover tool along a length of a wellbore of the
hydrocarbon well, and further wherein the method further includes
detecting, with the kickover tool and during the conveying, at
least one of: (i) a pressure within the wellbore; (ii) a
temperature within the wellbore; (iii) a velocity of the kickover
tool; (iv) an acceleration of the kickover tool; and (v) a depth of
the kickover tool.
22. The method of claim 20, wherein the method further includes
detecting an orientation of the kickover tool with an
orientation-determining structure of the kickover tool, and further
wherein the interfacing is based, at least in part, on the detected
orientation.
23. The method of claim 20, wherein the method further includes
detecting, with the kickover tool, a tension within a region of the
kickover tool.
24. The method of claim 23, wherein the method further includes
displaying, for the operator of the kickover tool, the tension
within the region of the kickover tool.
Description
CROSS-REFERENCE TO RELATED APPLICATION
[0001] This application claims the benefit of U.S. Provisional
Application 62/839,410 filed Apr. 26, 2019 entitled KICKOVER TOOLS
AND METHODS OF OPERATING THE SAME IN HYDROCARBON WELLS, the
entirety of which is incorporated by reference herein.
FIELD OF THE DISCLOSURE
[0002] The present disclosure relates generally to kickover tools
and to methods of operating kickover tools in hydrocarbon
wells.
BACKGROUND OF THE DISCLOSURE
[0003] Kickover tools may be utilized to engage and/or to interface
with a downhole component within a completion structure of a
hydrocarbon well. As an example, kickover tools may be utilized to
insert and/or to remove a gas lift valve from a side pocket mandrel
of the hydrocarbon well. Gas lift valves may be utilized to provide
artificial (gas) lift to hydrocarbon fluids that may be present
within a subterranean formation. These gas lift valves periodically
may need to be removed, such as to adjust, inspect, or replace the
gas lift valve. Conventional kickover tools utilized for these
purposes are wireline-attached devices that provide an operator
with very little feedback other than the tension on the wireline
that is measured external to the well, such as at a surface region.
As such, gas lift valve removal and/or installation is a highly
specialized process requiring skilled and/or experienced operators,
and problems still occur. These problems, including loss of the
kickover tool within the hydrocarbon well and/or an inability to
insert, or remove, a given gas lift valve from a given side pocket
mandrel may be costly and time-consuming to overcome. Thus, there
exists a need for improved kickover tools and for methods of
operating the improved kickover tools.
SUMMARY OF THE DISCLOSURE
[0004] Kickover tools and methods of operating the same. The
kickover tools are configured to engage a downhole component within
a completion structure of a hydrocarbon well. The kickover tools
include a tool body and a kickover arm that extends between a first
arm end and a second arm end. The kickover tools also include an
end effector that is operatively attached to the second arm end and
configured to interface with the downhole component. The kickover
tools further include an actuation mechanism that mechanically
couples the first arm end to the tool body and is configured to
selectively transition the kickover arm between a retracted
configuration and an extended configuration. The kickover tools
also include a data transmission interface and an attachment point
configured to operatively interconnect the kickover tool with an
umbilical. The kickover tools further include an imaging device
configured to collect a collected image that is indicative of an
environment proximal the kickover tool, to generate an image signal
indicative of the image, and to provide the image signal to the
data transmission interface.
[0005] The methods include positioning the kickover tool within a
completion structure of a hydrocarbon well and collecting, with the
kickover tool, a collected image indicative of an environment
within the hydrocarbon well and proximal the kickover tool. The
methods also include displaying, for an operator of the kickover
tool, a displayed image that is based upon the collected image. The
methods further include interfacing the kickover tool with a
downhole component of the completion structure. The interfacing is
based, at least in part, on the displaying.
BRIEF DESCRIPTION OF THE DRAWINGS
[0006] FIG. 1 is a schematic illustration of examples of a
hydrocarbon well that may include and/or utilize a kickover tool,
according to the present disclosure.
[0007] FIG. 2 is a schematic illustration of examples of a kickover
tool according to the present disclosure.
[0008] FIG. 3 is a flowchart depicting examples of methods of
operating a kickover tool, according to the present disclosure.
[0009] FIG. 4 is a schematic illustration of a portion of the
method of FIG. 3.
[0010] FIG. 5 is a schematic illustration of a portion of the
method of FIG. 3.
[0011] FIG. 6 is a schematic illustration of a portion of the
method of FIG. 3.
[0012] FIG. 7 is a schematic illustration of a portion of the
method of FIG. 3.
DETAILED DESCRIPTION AND BEST MODE OF THE DISCLOSURE
[0013] FIGS. 1-7 provide examples of kickover tools 100, of
hydrocarbon wells 30 that include kickover tools 100, and/or of
methods 300, according to the present disclosure. Elements that
serve a similar, or at least substantially similar, purpose are
labeled with like numbers in each of FIGS. 1-7, and these elements
may not be discussed in detail herein with reference to each of
FIGS. 1-7. Similarly, all elements may not be labeled in each of
FIGS. 1-7, but reference numerals associated therewith may be
utilized herein for consistency. Elements, components, and/or
features that are discussed herein with reference to one or more of
FIGS. 1-7 may be included in and/or utilized with any of FIGS. 1-7
without departing from the scope of the present disclosure. In
general, elements that are likely to be included in a particular
embodiment are illustrated in solid lines, while elements that are
optional are illustrated in dashed lines. However, elements that
are shown in solid lines may not be essential and, in some
embodiments, may be omitted without departing from the scope of the
present disclosure.
[0014] FIG. 1 is a schematic illustration of examples of a
hydrocarbon well 30 that may include and/or utilize a kickover tool
100, according to the present disclosure. FIG. 2 is a more
detailed, but still schematic, illustration of examples of kickover
tools 100.
[0015] As illustrated in FIG. 1, hydrocarbon well 30 includes a
wellbore 40 that extends within a subsurface region 20. Wellbore 40
also may be referred to herein as extending between a surface
region 10 and subsurface region 20. Kickover tool 100 is positioned
within wellbore 40, and hydrocarbon well 30 also includes an
umbilical 85 that extends from the kickover tool and/or toward, or
to, surface region 10.
[0016] Hydrocarbon well 30 also include a downhole tubular 50 that
extends within wellbore 40. A completion structure 60 is
operatively attached to and/or forms a portion of the downhole
tubular, and a downhole component 70 is positioned within and/or
operatively attached to the completion structure.
[0017] Kickover tool 100 is configured to engage, or to operatively
engage, with downhole component 70 while the downhole component is
within completion structure 60 of hydrocarbon well 30. With
reference to FIGS. 1-2, kickover tool 100 includes a tool body 110
and a kickover arm 120 that extends between a first arm end 122 and
a second arm end 124.
[0018] Kickover tool 100 also includes an end effector 130. End
effector 130 is operatively attached to second arm end 124 and is
configured to interface, or to selectively interlock, with downhole
component 70, as discussed in more detail herein.
[0019] Kickover tool 100 further includes an actuation mechanism
140. Actuation mechanism 140 operatively and/or mechanically
couples first arm end 122 of kickover arm 120 to tool body 110 and
is configured to selectively transition the kickover arm between a
retracted configuration, as illustrated in dashed lines in FIG. 2,
and an extended configuration, as illustrated in dash-dot lines in
FIG. 2.
[0020] Kickover tool 100 also includes a data transmission
interface 150, an attachment point 160, and a sensor 200, such as
an imaging device 230. Data transmission interface 150 may be
configured to facilitate communication between kickover tool 100
and surface region 10, as discussed in more detail herein.
Attachment point 160 may be configured to operatively interconnect
kickover tool 100 with umbilical 85. Stated another way, umbilical
85 may be operatively attached to the attachment point of the
kickover tool, as illustrated in FIG. 1.
[0021] Imaging device 230 may be configured to collect a collected
image indicative of an environment proximal kickover tool 100.
Imaging device 230 also may be configured to generate an image
signal 232 that is indicative of and/or based upon the collected
image. Imaging device 230 further may be configured to provide the
image and/or the image signal to data transmission interface 150.
During operation of kickover tool 100, a displayed image, which may
be based upon the image signal, may be utilized, such as by an
operator of the kickover tool, to permit and/or facilitate
interfacing between the kickover tool and downhole component 70,
removal of the downhole component from the completion structure
utilizing the kickover tool, and/or installation of the downhole
component within the completion structure utilizing the kickover
tool.
[0022] Completion structure 60 may include any suitable structure
that may be operatively attached to downhole tubular 50, that may
at least partially define downhole tubular 50, that may contain
downhole component 70, and/or that may be operatively attached to
downhole component. Examples of completion structure 60 include a
mandrel or a side pocket mandrel.
[0023] Downhole component 70 may include any suitable structure
that may be positioned within completion structure 60 and/or that
may be operatively attached to the completion structure. Examples
of downhole component 70 include a valve or a gas lift valve.
[0024] As illustrated in dashed lines in FIG. 1, hydrocarbon well
30 may include an electrical cable 80. Electrical cable 80, when
present, may include and/or be a data transmission cable that may
include at least one data electrical conductor configured to convey
image signal 232 between kickover tool 100 and surface region 10.
When hydrocarbon well 30 includes electrical cable 80, the
electrical cable may be in electrical communication with, or may be
electrically connected to, data transmission interface 150.
Additionally or alternatively, data transmission interface 150 may
be configured to provide image signal 232 to the electrical cable.
Additionally or alternatively, electrical cable 80 may include
and/or be a power cable that may include at least one power
electrical conductor configured to provide electrical power to
kickover tool 100, such as from surface region 10.
[0025] It is within the scope of the present disclosure that
umbilical 85 may be defined by, or may be, electrical cable 80.
Additionally or alternatively, it is also within the scope of the
present disclosure that umbilical 85 may be distinct, separate,
and/or spaced-apart from electrical cable 80, as illustrated in
dashed lines in FIG. 1. Other examples of umbilical 85 include a
wireline, slickline, digital slickline that is configured to convey
data, and/or coiled tubing.
[0026] As illustrated in dashed lines in FIG. 1, hydrocarbon well
30 may include a wireless data transmission structure 88. Wireless
data transmission structure 88, when present, may be in wireless
communication with data transmission interface 150, may be
configured to receive image signal 232, in the form of a wireless
image signal 232, from data transmission interface 150, and/or may
be configured to convey the image signal between the kickover tool
and the surface region. Examples of wireless data transmission
structure 88 include a radio frequency wireless data transmission
structure, a wireless data transmission structure configured to
transmit electromagnetic radiation, and/or a wireless data
transmission structure configured to transmit acoustic
vibrations.
[0027] As illustrated in dashed lines in FIG. 1, hydrocarbon well
30 may include a power supply structure 90. Power supply structure
90, when present, may be configured to provide electric power to
kickover tool 100, such as via electrical cable 80. Examples of
power supply structure 90 include a battery, an electric generator,
and/or a main power source.
[0028] As also illustrated in dashed lines in FIG. 1, hydrocarbon
well 30 may include a data analysis structure 92. Data analysis
structure 92, when present, may be configured to receive the image
signal from the data transmission interface of the kickover tool.
Data analysis structure 92 additionally or alternatively may be
configured to analyze the image signal and/or to process the image
signal. Examples of data analysis structure 92 include any suitable
computer, personal computer, and/or logic device that may be
programmed to analyze the image signal and/or to process the image
signal.
[0029] As also illustrated in FIG. 1, hydrocarbon well 30 may
include a display 94. Display 94, when present, may be configured
to generate and/or to display a displayed image that is based, at
least in part, on the image signal. This displayed image may be
viewed and/or observed by the operator of kickover tool 100, such
as to permit and/or to facilitate interfacing between the kickover
tool and downhole component 70, removal of the downhole component
from completion structure 60, and/or installation of the downhole
component within the completion structure, as discussed in more
detail herein. Examples of display 94 include a screen, a
television screen, and/or a computer monitor.
[0030] Data transmission interface 150 may include any suitable
structure that may be adapted, configured, designed, and/or
constructed to convey image signal 232 from kickover tool 100
and/or to surface region 10. As an example, data transmission
interface 150 may include a wired data transmission interface
configured to transmit wired image signal 232 from the kickover
tool and/or to the surface region, such as via electrical cable 80
of FIG. 1 and/or the data transmission cable that may be formed
thereby. As another example, data transmission interface 150 may
include a wireless data transmission interface configured to
transmit wireless image signal 232 from the kickover tool and/or to
the surface region, such as via wireless data transmission
structure 88 of FIG. 1.
[0031] Imaging device 230 may include any suitable structure that
may be adapted, configured, designed, and/or constructed to collect
the collected image, to generate image signal 232 based upon the
collected image, and/or to provide the image signal to the data
transmission interface. Examples of imaging device 230 include an
optical imaging device configured to collect visible light, an
electromagnetic imaging device configured to collect
electromagnetic radiation, an infrared imaging device configured to
collect infrared radiation, and/or an acoustic imaging device
configured to detect acoustic vibrations.
[0032] Stated another way, and as examples, imaging device 230 may
be configured to collect and/or to receive electromagnetic
radiation and/or acoustic vibration, such as from the environment
proximal the kickover tool, and to convert this electromagnetic
radiation and/or acoustic vibration to image signal 232. Examples
of such imaging devices 230 include a microphone, a directional
microphone, a solid state acoustic sensor, a camera, a video
camera, and/or a charge coupled device.
[0033] It is within the scope of the present disclosure that
imaging device 230 may include and/or be an active imaging device.
Such an active imaging device may be configured to provide a probe
signal to the environment proximal the kickover tool. The probe
signal may reflect from at least one structure within the
environment proximal the kickover tool to generate a reflected
signal, and the imaging device further may be configured to receive
the reflected signal and to generate the image signal based, at
least in part, on the reflected signal. Examples of the probe
signal include electromagnetic radiation and/or acoustic
vibration.
[0034] Additionally or alternatively, it is also within the scope
of the present disclosure that imaging device 230 may include
and/or be a passive imaging device. Such a passive imaging device
may be configured to generate the image signal responsive to
receipt of and/or based upon ambient vibrations within the
environment proximal the kickover tool and/or ambient
electromagnetic radiation within the environment proximal the
kickover tool.
[0035] The image signal may include any suitable information. As an
example, the image signal may include information indicative of a
spatial relationship between the kickover tool and the completion
structure, between the end effector and the completion structure,
and/or between the end effector and the downhole component. As
another example, the image signal may include information
indicative of a visual representation of the kickover tool, a
visual representation of the tool body, a visual representation of
the kickover arm, a visual representation of the end effector, a
visual representation of the completion structure, and/or a visual
representation of the downhole component.
[0036] Attachment point 160 may include any suitable structure that
may, or that may be utilized to, operatively interconnect, or
attach, kickover tool 100 and umbilical 85. Attachment point 160
also may be referred to herein as an attachment location 160, an
attachment structure 160, a coupling point 160, a coupling
structure 160, and/or a coupling location 160. Examples of
attachment point 160 include any suitable eye, coupler, hook,
clasp, recess configured to receive at least a portion of the
umbilical, and/or projection configured to be received within at
least a portion of the umbilical.
[0037] Turning more specifically to FIG. 2, kickover tools 100,
according to the present disclosure, optionally may include a
variety of additional and/or optional structures. These structures
are illustrated schematically in FIG. 2, and any of the structures
and/or functions of kickover tools 100 illustrated in FIG. 2 and/or
discussed herein with reference thereto may be included in and/or
utilized with kickover tools 100 of FIG. 1 without departing from
the scope of the present disclosure. Similarly, any structure
and/or function of kickover tools 100 that is illustrated in FIG. 1
and/or discussed herein with reference thereto may be included in
and/or utilized with kickover tools 100 of FIG. 2 without departing
from the scope of the present disclosure.
[0038] As illustrated in dashed lines in FIG. 1, kickover tools 100
may include a power supply interface 155. Power supply interface
155, when present, may be configured to provide electric power to
the kickover tool. Kickover tool 100 may be configured to receive
and/or to utilize the electric power. As an example, sensor 200
and/or imaging device 230 thereof may be configured to receive
and/or to utilize the electric power, such as to generate image
signal 232.
[0039] This electric power may be provided to the kickover tool
from power supply structure 90 of FIG. 1 and/or via electrical
cable 80 of FIG. 1. In such a configuration, power supply interface
155 may be configured to electrically interconnect the kickover
tool with the electric cable, which also may be referred to herein
as, may include, and/or may be a power supply cable. Additionally
or alternatively, kickover tool 100 may include a battery 158 that
may be configured to provide the electric power to the power supply
interface.
[0040] It is within the scope of the present disclosure that power
supply interface 155 may be distinct and/or separate from data
transmission interface 150. Additionally or alternatively, it is
also within the scope of the present disclosure that the power
supply interface may be at least partially defined by and/or may
include the data transmission interface.
[0041] As discussed herein, kickover tool 100 includes at least one
sensor 200 in the form of imaging device 230. It is within the
scope of the present disclosure that kickover tool 100 may include
one or more other and/or additional sensors 200, examples of which
are discussed in more detail herein. Sensors 200 also may be
referred to herein as detectors 200 and/or as transducers 200.
[0042] As an example, kickover tool 100 may include a sensor 200 in
the form of a tension sensor 210. Tension sensor 210, when present,
may be configured to generate a tension signal 212. Tension signal
212 may be indicative of a tensile force between attachment point
160 and umbilical 85 (which is illustrated in FIG. 1) and to
provide the tension signal to data transmission interface 150. Data
transmission interface 150 then may convey the tension signal to
the surface region. An example of tension sensor 210 includes a
strain sensor, and tension sensor 210 may be configured to detect
mechanical strain within at least a portion of kickover tool 100,
attachment point 160, and/or umbilical 85.
[0043] Knowledge of the tensile force between attachment point 160
and umbilical 85, such as via tension signal 212, may facilitate
improved operation of kickover tool 100. As an example, with
knowledge of the tensile force, an operator of the kickover tool
may avoid damage to the kickover tool and/or to the umbilical while
the kickover tools is being utilized within the hydrocarbon well.
As a more specific example, the operator of the kickover tool may
utilize tension signal 212 to maintain the tensile force between
attachment point 160 and umbilical 85 below a threshold tensile
force known to provide safe and/or damage-free operation.
[0044] As another example, kickover tool 100 may include a sensor
200 in the form of a pressure sensor 220. Pressure sensor 220, when
present, may be configured to generate a pressure signal 222.
Pressure signal 222 may be indicative of a pressure acting upon the
pressure sensor, such as an ambient pressure within the environment
proximal the kickover tool. Pressure sensor 220 may provide the
pressure signal to data transmission interface 150. Data
transmission interface 150 then may convey the pressure signal to
the surface region.
[0045] Knowledge of the pressure within the environment proximal
the kickover tool may permit an operator of the kickover tool to
equalize pressure across a downhole tubular that contains the
kickover tool prior to insertion and/or removal of the downhole
component utilizing the kickover tool.
[0046] As yet another example, kickover tool 100 may include a
sensor 200 in the form of a depth sensor 240. Depth sensor 240,
when present, may be configured to generate a depth signal 242.
Depth signal 242 may be indicative of a depth of the kickover tool
within the hydrocarbon well. Depth sensor 240 may provide the depth
signal to data transmission interface 150. Data transmission
interface 150 then may convey the depth signal to the surface
region.
[0047] Depth sensor 240 may include and/or be any suitable
structure. Examples of depth sensor 240 include a casing collar
locator and/or a pressure sensor, such as pressure sensor 220.
[0048] As another example, kickover tool 100 may include a sensor
200 in the form of an orientation-determining structure 250.
Orientation-determining structure 250, when present, may be
configured to generate an orientation signal 252.
Orientation-determining structure 250 may provide orientation
signal 252 to data transmission interface 150. Data transmission
interface 150 then may convey the orientation signal to the surface
region.
[0049] Orientation-determining structure 250 may be configured to
determine, and/or orientation signal 252 may be indicative of, any
suitable relative orientation and/or spatial relationship of and/or
between kickover tool 100, completion structure 60, and/or downhole
component 70. As examples, orientation signal 252 may be indicative
of a relative orientation between the tool body and the kickover
arm, a relative orientation between the end effector and the
kickover arm, a relative orientation between the end effector and
the tool body, a relative orientation between the kickover arm and
the downhole component, a relative orientation between the end
effector and the downhole component, a body-arm angle defined
between a body longitudinal axis of the tool body and an arm
longitudinal axis of the kickover arm, and/or an arm-end effector
angle defined between the arm longitudinal axis and an end effector
longitudinal axis of the end effector. Examples of
orientation-determining structure 250 include any suitable
proximity sensor and/or angle-measuring sensor.
[0050] As yet another example, kickover tool 100 may include a
sensor 200 in the form of a temperature sensor 260. Temperature
sensor 260, when present, may be configured to generate a
temperature signal 262. Temperature signal 262 may be indicative of
a temperature in the environment proximal the kickover tool.
Temperature sensor 260 may provide the temperature signal to data
transmission interface 150. Data transmission interface 150 then
may convey the temperature signal to the surface region. Examples
of temperature sensor 260 include any suitable thermocouple,
resistance thermal detector (RTD), and/or infrared sensor.
[0051] Knowledge of the temperature in the environment proximal the
kickover tool may be utilized to detect gas leakage within the
hydrocarbon well. Such gas leakage may produce localized
temperature variation, or cooling, within the hydrocarbon well,
such as may be caused by Joule-Thompson cooling effects.
[0052] As another example, kickover tool 100 may include a sensor
200 in the form of an acceleration sensor 270. Acceleration sensor
270, when present, may be configured to generate an acceleration
signal 272. Acceleration signal 272 may be indicative of
acceleration of the kickover tool within the hydrocarbon well.
Acceleration sensor 270 may provide the acceleration signal to data
transmission interface 150. Data transmission interface 150 then
may convey the acceleration signal to the surface region. Examples
of acceleration sensor 270 include an accelerometer and/or a casing
collar locator.
[0053] As yet another example, kickover tool 100 may include a
sensor 200 in the form of a velocity sensor 280. Velocity sensor
280, when present, may be configured to generate a velocity signal
282. Velocity signal 282 may be indicative of a velocity of the
kickover tool within the hydrocarbon well. Velocity sensor 280 may
provide the velocity signal to data transmission interface 150.
Data transmission interface 150 then may convey the velocity signal
to the surface region. Examples of velocity sensor 280 include a
velocimeter and/or a casing collar locator.
[0054] As illustrated in dashed lines in FIG. 2, kickover tool 100
may include a memory device 185. Memory device 185, when present,
may be configured to store at least one data signal that is
generated by the kickover tool while the kickover tool is utilized
within the hydrocarbon well. Such data signal may be provided to
the memory device by data transmission interface 150. Examples of
the at least one data signal include any data signal that may be
produced and/or generated by sensors 200, such as tension signal
212, pressure signal 222, image signal 232, depth signal 242,
orientation signal 252, temperature signal 262, acceleration signal
272, and/or velocity signal 282. Examples of memory device 185
include a memory chip, a solid state memory chip, a volatile memory
device, and/or a nonvolatile memory device.
[0055] As also illustrated in dashed lines in FIG. 2, kickover tool
100 may include a communication structure 190. Communication
structure 190, when present, may be configured to facilitate
communication with the downhole component and/or between the
kickover tool and the downhole component. This communication may be
performed when the kickover tool is proximal the downhole component
and within the hydrocarbon well. An example of communication
structure 190 includes an inductive communication structure, such
as an inductive coupling structure.
[0056] As also illustrated in dashed lines in FIG. 2, kickover tool
100 may include an analysis structure 195. Analysis structure 195,
when present, may be configured to receive one or more data signals
that may be generated by kickover tool 100, to modify the one or
more data signals to generate a modified data signal, and/or to
provide the modified data signal to data transmission interface
150. As an example, analysis structure 195 may receive image signal
232 from imaging device 230, may modify image signal 232 to
generate a modified image signal, and may provide the modified
image signal to the data transmission interface. This modification
may include local and/or downhole analysis, computation,
compression, simplification, encoding, and/or processing of the
data signal.
[0057] Returning more generally to the examples of kickover tools
100 illustrated in FIGS. 1-2, kickover tools may include a variety
of conventional structures. These conventional structures may be
common to conventional kickover tools.
[0058] As an example, and as discussed, kickover tools 100 may
include tool body 110. Tool body 110 may include and/or be an
elongate tool body, such as may extend along a body longitudinal
axis 118 and/or between an uphole body end 112 and a downhole body
end 114.
[0059] In such a configuration, and as illustrated, data
transmission interface 150 and/or attachment point 160 may be
operatively attached to, may be proximal, and/or may at least
partially define uphole body end 112.
[0060] As illustrated in dashed lines in FIGS. 1-2, tool body 110
may include and/or define an arm receptacle 116. Arm receptacle
116, when present, may be sized to receive kickover arm 120 when
the kickover arm is in the retracted configuration, such as is
illustrated in FIG. 1 and in dashed lines in FIG. 2. Arm receptacle
116 also may be sized to end effector 130 when the kickover arm is
in the retracted configuration. Arm receptacle 116 additionally or
alternatively may be sized to receive the downhole component when
the end effector interfaces with the downhole component and the
kickover arm is in the retracted configuration.
[0061] Kickover arm 120 may include and/or be an elongate kickover
arm that extends between first arm end 122 and second arm end 124.
First arm end 122 may be hingedly connected to the tool body, such
as via actuation mechanism 140, such that the kickover arm pivots,
relative to the tool body, about an arm hinge axis 126 upon
transitioning between the retracted configuration and the extended
configuration.
[0062] As discussed, end effector 130 may be configured to
interface with the downhole component. It is within the scope of
the present disclosure that the end effector may interface with the
downhole component in any suitable manner As examples, the end
effector may be configured to selectively interlock with the
downhole component and/or to reliably interlock with the downhole
component.
[0063] End effector 130 may be hingedly connected to second arm end
124 such that the end effector pivots, relative to the kickover
arm, about an end effector hinge axis 136 when the kickover arm
transitions between the retracted configuration and the extended
configuration. End effector hinge axis 136 may be parallel, or at
least substantially parallel, to arm hinge axis 126.
[0064] Actuation mechanism 140 may include any suitable structure
that may be adapted, configured, designed, and/or constructed to
mechanically couple first arm end 122 to tool body 110 and/or to
selectively transition kickover arm 120 between the retracted
configuration and the extended configuration. As an example,
actuation mechanism 140 may include a trigger 142 that may extend
from tool body 110. In such a configuration, actuation mechanism
140 may be configured to selectively transition the kickover arm
from the retracted configuration to the extended configuration
responsive to receipt of at least a threshold trigger force by the
trigger. This trigger force may be applied to the trigger by a side
pocket mandrel and/or by an orienting receptacle 62 of the side
pocket mandrel, as illustrated in FIG. 1.
[0065] Kickover tool 100 further may include a biasing mechanism
175. Biasing mechanism 175, when present, may be configured to bias
the kickover arm toward the extended configuration. As an example,
actuation mechanism 140 may be configured to retain the kickover
arm in the retracted configuration and to selectively permit the
biasing mechanism to transition the kickover arm to the extended
configuration, such as when greater than the threshold trigger
force is applied to trigger 142.
[0066] Kickover tool 100 also may include an orientation structure
170. Orientation structure 170 may extend from tool body 110 and/or
may be configured to selectively interface with orienting
receptacle 62 of the completion structure 60, as illustrated in
FIG. 1. This may orient the kickover arm at a predetermined
orientation relative to the downhole component.
[0067] It is within the scope of the present disclosure that
orientation structure 170 may include and/or may be defined by
trigger 142. Additionally or alternatively, it is also within the
scope of the present disclosure that orientation structure 170 may
be at least partially, or even completely, separate and/or distinct
from trigger 142.
[0068] As illustrated in dashed lines in FIGS. 1-2, kickover tool
100 also may include a jar mechanism 180. Jar mechanism 180, when
present, may be configured to selectively provide a jarring force
to the kickover tool. The jarring force may be oriented and/or
directed to urge the downhole component from a component receptacle
of the completion structure and/or to urge the downhole component
into the component receptacle, such as to facilitate removal of the
downhole component from the completion structure and/or
installation of the downhole component within the completion
structure.
[0069] FIG. 3 is a flowchart depicting examples of methods 300 of
operating a kickover tool, according to the present disclosure.
FIGS. 4-7 are schematic illustrations of kickover tools 100
performing portions of the methods of FIG. 3. Methods 300 may be
performed utilizing kickover tools 100 of FIGS. 1-2, and any of the
structures, functions, and/or features of kickover tools 100
discussed herein with reference to FIGS. 1-2 may be included in
and/or utilized with methods 300 of FIG. 3 and/or kickover tools
100 of FIGS. 4-7 without departing from the scope of the present
disclosure. Similarly, kickover tools 100 of FIGS. 1-2 may include
any of the structures and/or may perform any of the functions
discussed herein with reference to methods 300 of FIG. 3 and/or
kickover tools 100 of FIGS. 4-7.
[0070] Methods 300 include positioning a kickover tool at 310 and
may include detecting a parameter at 320. Methods 300 also include
collecting a collected image at 330 and displaying the collected
image as a displayed image at 340. Methods 300 further may include
displaying the parameter at 350 and include interfacing the
kickover tool with a downhole component at 360. Methods 300 also
may include separating the downhole component from a completion
structure at 370 and/or installing the downhole component within
the completion structure at 380.
[0071] Positioning the kickover tool at 310 may include positioning
the kickover tool within a completion structure of a hydrocarbon
well. This may include conveying the kickover tool along a length
of the wellbore of the hydrocarbon well, to the completion
structure, and/or into the completion structure.
[0072] An example of the positioning at 310 is illustrated in FIG.
4. As illustrated therein, kickover tool 100 may be positioned
within completion structure 60, which in the example of FIG. 4, is
a side pocket mandrel.
[0073] Detecting the parameter at 320 may include detecting any
suitable parameter with the kickover tool and/or in the hydrocarbon
well. Examples of the parameter include a pressure within the
wellbore, a temperature within the wellbore, a velocity of the
kickover tool, an acceleration of the kickover tool, and/or a depth
of the kickover tool.
[0074] Another example of the parameter includes an orientation of
the kickover tool and/or of at least a portion of the kickover
tool. This orientation may be relative to the downhole component
and may be detected with, via, and/or utilizing an
orientation-determining structure of the kickover tool. When the
detecting at 320 includes detecting the orientation of the kickover
tool, the interfacing at 360 may be performed based, at least in
part, on the detected orientation of the kickover tool. Yet another
example of the parameter includes a tension within a region of the
kickover tool and/or between the kickover tool and an umbilical
that extends between the kickover tool and a surface region.
[0075] The detecting at 320 may be performed with any suitable
timing and/or sequence during methods 300. As examples, the
detecting at 320 may be performed during the positioning at 310,
subsequent to the positioning at 310, during the interfacing at
360, and/or during the separating at 370.
[0076] As illustrated in FIGS. 4-7, kickover tool 100 may include
sensor 200. As discussed in more detail herein, sensor 200 may
include a tension sensor, a pressure sensor, a depth sensor, the
orientation-determining structure, a temperature sensor, an
acceleration sensor, and/or a velocity sensor.
[0077] Collecting the collected image at 330 may include
collecting, with the kickover tool, any suitable collected image
that is indicative of an environment within the hydrocarbon well
and/or proximal the kickover tool. This may include collecting the
collected image with, via, and/or utilizing any suitable sensor
and/or imaging device, examples of which are disclosed herein and
illustrated in FIGS. 4-7 at 200.
[0078] Displaying the displayed image at 340 may include displaying
the displayed image for an operator of the kickover tool. This may
include displaying the displayed image to permit and/or facilitate
the interfacing at 360. Stated another way, the displaying at 340
may permit the operator of the kickover tool to view and/or to
observe at least a region of the kickover tool, at least a region
of the completion structure, and/or at least a region of the
downhole component, such as during the interfacing at 360 and/or
during the installing at 380. This may improve an accuracy of the
interfacing at 360, may decrease a time required to perform the
interfacing at 360, and/or may decrease a potential for error
during the interfacing at 360. The displayed image may be based
upon the image signal and thus at least indirectly based upon
and/or indicative of the collected image.
[0079] Displaying the parameter at 350 may include displaying any
suitable parameter, which was collected during the collecting at
330, for the operator of the kickover tool. As specific examples,
the displaying at 350 may include displaying the pressure within
the wellbore, the temperature within the wellbore, the velocity of
the kickover tool, the acceleration of the kickover tool, the depth
of the kickover tool, the orientation of the kickover tool, and/or
the tension within the region of the kickover tool. The displaying
at 350 may be performed in real-time, such as during the collecting
at 330 and/or concurrently with the collecting at 330. Stated
another way, the displaying at 350 may provide the operator of the
kickover tool with at least substantially real-time, or up-to-date,
information regarding the detected parameter and/or parameters.
[0080] Interfacing the kickover tool with the downhole component at
360 may include interfacing the kickover tool with any suitable
downhole component of the completion structure and may be based, at
least in part, on the displaying. In one example, the interfacing
at 360 may be performed subsequent to the positioning at 310. In
this example, the operator of the kickover tool may view the
displayed image displayed during the displaying at 340 and may
utilize the displayed image to permit, facilitate, and/or perform
the interfacing at 360. Stated another way, the displaying at 340
may permit the operator of the kickover tool to view the kickover
tool and/or the downhole component during the interfacing at 360,
thereby aiding in and/or facilitating the interfacing at 360.
[0081] In this example, the interfacing at 360 may include
transitioning a kickover arm 120 of the kickover tool from a
retracted orientation, as illustrated in FIG. 4, to an extended
orientation, as illustrated in FIG. 5. The interfacing at 360
further may include interfacing an end effector 130 of the kickover
tool with downhole component 70, as illustrated in FIG. 6. The
interfacing with the downhole component may be performed while the
kickover arm is in the extended orientation.
[0082] In another example, the interfacing at 360 may be performed
prior to the positioning at 310, while the kickover tool is
external the wellbore, and/or while the kickover tool is within the
surface region. In this example, the interfacing at 360 may include
gripping the downhole component with the end effector of the
kickover tool, such as to permit and/or to facilitate transfer of
the downhole component within the completion structure during the
positioning at 310.
[0083] When the interfacing at 360 is performed subsequent to the
positioning at 310, methods 300 further may include separating the
downhole component from the completion structure at 370 with the
kickover tool. In this example, the separating at 370 may be
performed subsequent to the interfacing at 360 and may include
applying a tensile force to the downhole component, with the
kickover tool, to separate the downhole component from the
completion structure. The detecting at 320 may be performed during
the separating at 370. As an example, the detecting at 320 may be
utilized to detect the tension within the region of the kickover
tool during the separating at 370, such as to determine whether the
tension within the region of the kickover tool is below a safe, a
predetermined, and/or an acceptable tension threshold.
[0084] An example of the separating at 370 is illustrated in FIG.
7. As illustrated therein, kickover tool 100 has moved downhole
component 70 vertically upward and is in the process of separating
downhole component 70 from completion structure 60.
[0085] When the interfacing at 360 is performed prior to the
positioning at 310, methods 300 further may include installing the
downhole component within the completion structure at 380. In this
example, the collecting at 330, the displaying at 340, and/or the
displaying at 350 may be utilized, by the operator of the kickover
tool, to permit and/or facilitate efficient and/or effective
installation of the downhole component within the completion
structure. As an example, the displaying at 340 may permit the
operator of the kickover tool to view the kickover tool, the
completion structure, and/or the downhole component during the
installing at 380, such as to facilitate alignment of the downhole
component with a downhole component receptacle of the completion
structure.
[0086] In the present disclosure, several of the illustrative,
non-exclusive examples have been discussed and/or presented in the
context of flow diagrams, or flow charts, in which the methods are
shown and described as a series of blocks, or steps. Unless
specifically set forth in the accompanying description, it is
within the scope of the present disclosure that the order of the
blocks may vary from the illustrated order in the flow diagram,
including with two or more of the blocks (or steps) occurring in a
different order and/or concurrently.
[0087] As used herein, the term "and/or" placed between a first
entity and a second entity means one of (1) the first entity, (2)
the second entity, and (3) the first entity and the second entity.
Multiple entities listed with "and/or" should be construed in the
same manner, i.e., "one or more" of the entities so conjoined.
Other entities may optionally be present other than the entities
specifically identified by the "and/or" clause, whether related or
unrelated to those entities specifically identified. Thus, as a
non-limiting example, a reference to "A and/or B," when used in
conjunction with open-ended language such as "comprising" may
refer, in one embodiment, to A only (optionally including entities
other than B); in another embodiment, to B only (optionally
including entities other than A); in yet another embodiment, to
both A and B (optionally including other entities). These entities
may refer to elements, actions, structures, steps, operations,
values, and the like.
[0088] As used herein, the phrase "at least one," in reference to a
list of one or more entities should be understood to mean at least
one entity selected from any one or more of the entities in the
list of entities, but not necessarily including at least one of
each and every entity specifically listed within the list of
entities and not excluding any combinations of entities in the list
of entities. This definition also allows that entities may
optionally be present other than the entities specifically
identified within the list of entities to which the phrase "at
least one" refers, whether related or unrelated to those entities
specifically identified. Thus, as a non-limiting example, "at least
one of A and B" (or, equivalently, "at least one of A or B," or,
equivalently "at least one of A and/or B") may refer, in one
embodiment, to at least one, optionally including more than one, A,
with no B present (and optionally including entities other than B);
in another embodiment, to at least one, optionally including more
than one, B, with no A present (and optionally including entities
other than A); in yet another embodiment, to at least one,
optionally including more than one, A, and at least one, optionally
including more than one, B (and optionally including other
entities). In other words, the phrases "at least one," "one or
more," and "and/or" are open-ended expressions that are both
conjunctive and disjunctive in operation. For example, each of the
expressions "at least one of A, B, and C," "at least one of A, B,
or C," "one or more of A, B, and C," "one or more of A, B, or C,"
and "A, B, and/or C" may mean A alone, B alone, C alone, A and B
together, A and C together, B and C together, A, B, and C together,
and optionally any of the above in combination with at least one
other entity.
[0089] In the event that any patents, patent applications, or other
references are incorporated by reference herein and (1) define a
term in a manner that is inconsistent with and/or (2) are otherwise
inconsistent with, either the non-incorporated portion of the
present disclosure or any of the other incorporated references, the
non-incorporated portion of the present disclosure shall control,
and the term or incorporated disclosure therein shall only control
with respect to the reference in which the term is defined and/or
the incorporated disclosure was present originally.
[0090] As used herein the terms "adapted" and "configured" mean
that the element, component, or other subject matter is designed
and/or intended to perform a given function. Thus, the use of the
terms "adapted" and "configured" should not be construed to mean
that a given element, component, or other subject matter is simply
"capable of" performing a given function but that the element,
component, and/or other subject matter is specifically selected,
created, implemented, utilized, programmed, and/or designed for the
purpose of performing the function. It is also within the scope of
the present disclosure that elements, components, and/or other
recited subject matter that is recited as being adapted to perform
a particular function may additionally or alternatively be
described as being configured to perform that function, and vice
versa.
[0091] As used herein, the phrase, "for example," the phrase, "as
an example," and/or simply the term "example," when used with
reference to one or more components, features, details, structures,
embodiments, and/or methods according to the present disclosure,
are intended to convey that the described component, feature,
detail, structure, embodiment, and/or method is an illustrative,
non-exclusive example of components, features, details, structures,
embodiments, and/or methods according to the present disclosure.
Thus, the described component, feature, detail, structure,
embodiment, and/or method is not intended to be limiting, required,
or exclusive/exhaustive; and other components, features, details,
structures, embodiments, and/or methods, including structurally
and/or functionally similar and/or equivalent components, features,
details, structures, embodiments, and/or methods, are also within
the scope of the present disclosure.
INDUSTRIAL APPLICABILITY
[0092] The systems and methods disclosed herein are applicable to
the oil and gas industries.
[0093] It is believed that the disclosure set forth above
encompasses multiple distinct inventions with independent utility.
While each of these inventions has been disclosed in its preferred
form, the specific embodiments thereof as disclosed and illustrated
herein are not to be considered in a limiting sense as numerous
variations are possible. The subject matter of the inventions
includes all novel and non-obvious combinations and subcombinations
of the various elements, features, functions, and/or properties
disclosed herein. Similarly, where the claims recite "a" or "a
first" element or the equivalent thereof, such claims should be
understood to include incorporation of one or more such elements,
neither requiring nor excluding two or more such elements.
[0094] It is believed that the following claims particularly point
out certain combinations and subcombinations that are directed to
one of the disclosed inventions and are novel and non-obvious.
Inventions embodied in other combinations and subcombinations of
features, functions, elements and/or properties may be claimed
through amendment of the present claims or presentation of new
claims in this or a related application. Such amended or new
claims, whether they are directed to a different invention or
directed to the same invention, whether different, broader,
narrower, or equal in scope to the original claims, are also
regarded as included within the subject matter of the inventions of
the present disclosure.
* * * * *