U.S. patent application number 13/094927 was filed with the patent office on 2012-11-01 for detecting a reamer position through a magnet field sensor.
Invention is credited to Scott Dahlgren, David R. Hall, Jonathan Marshall.
Application Number | 20120273187 13/094927 |
Document ID | / |
Family ID | 47067006 |
Filed Date | 2012-11-01 |
United States Patent
Application |
20120273187 |
Kind Code |
A1 |
Hall; David R. ; et
al. |
November 1, 2012 |
Detecting a Reamer Position through a Magnet Field Sensor
Abstract
In one aspect of the present invention, a tool string component
comprises at least one end that attaches to an adjacent component
in a through bore. The invention also comprises a laterally
extending member disposed along a length of the tool string
component. A magnetic mechanism is configured to sense an extension
depth of the laterally extending member.
Inventors: |
Hall; David R.; (Provo,
UT) ; Dahlgren; Scott; (Alpine, UT) ;
Marshall; Jonathan; (Provo, UT) |
Family ID: |
47067006 |
Appl. No.: |
13/094927 |
Filed: |
April 27, 2011 |
Current U.S.
Class: |
166/66.5 |
Current CPC
Class: |
E21B 10/322 20130101;
E21B 47/092 20200501 |
Class at
Publication: |
166/66.5 |
International
Class: |
E21B 31/06 20060101
E21B031/06 |
Claims
1. A tool string component, comprising; at least one end comprising
an attachment to an adjacent tool string component and a through
bore; a laterally extending member disposed along a length of the
tool string component; and a magnetic mechanism configured to sense
an extension depth of the laterally extending member.
2. The component of claim 1, wherein the magnetic mechanism
comprises a magnet and at least one sensor.
3. The component of claim 2, wherein the at least one sensor is
configured to be stationary with respect to the magnet.
4. The component of claim 2, wherein the magnet is configured to
move as the laterally extending member changes its depth of
extension.
5. The component of claim 4, wherein the magnet is configured to
move along a length of the component.
6. The component of claim 2, wherein the at least one sensor is
located within the through bore.
7. The component of claim 2, wherein the at least one sensor
comprises a magnetometer.
8. The component of claim 2, wherein the at least one sensor is
communication with processing element that is configured to
transmit data about the movement of the magnet to surface equipment
or downhole tools.
9. The component of claim 8, wherein the processing element is
configured to process the data and send commands based off the data
to adjust a depth of the extendable member.
10. The component of claim 2, wherein the magnet or the at least
one sensor is located in the through bore.
11. The component of claim 10, wherein the magnet or at least one
sensor is isolated from drilling fluid flow in the through
bore.
12. The component of claim 2, wherein a member groove on the
laterally extending member interfaces a sleeve groove on a slidable
sleeve of the component, wherein the magnet is located on the
member and/or sleeve groove.
13. The component of claim 12, wherein at least one sensor is
located in the member and/or sleeve groove.
14. The component of claim 2, wherein the at least one sensor
comprises a plurality of magnetometers distributed within and along
a length of the through bore, the magnet is configured to move in a
direction that follows the distribution of magnetometers as the
laterally extending member moves, and magnetometers are configured
to determine the location of the magnet, which corresponds with the
extension depth of the laterally extending member.
15. The component of claim 2, wherein the magnet is disposed
annularly about a linear distribution of sensors disposed along a
length of the through bore.
16. The component of claim 2, wherein the at least one sensor is
axially fixed within the through bore.
17. The component of claim 2, wherein the laterally extending
member is supported within a slot formed in an outer surface of the
component, the slot comprising a slot wall, and the magnet and/or
senor is disposed proximate a surface of the slot wall.
18. The component of claim 1, wherein the laterally expandable
member is configured to ream a diameter of a well bore.
19. The component of claim 1, wherein the laterally expendable
member is configured to centralize component within a well bore.
Description
BACKGROUND OF THE INVENTION
[0001] The present invention relates to the fields of oil, gas,
and/or geothermal exploration and more particularly to the fields
of expandable tools for downhole exploration. The prior art
discloses expandable tools that are configured to centralize
downhole tools within the well bore. The prior art also discloses
expandable tools used to enlarge the diameter of a wellbore during
drilling operations. Expandable tools of this type may contain
blades which extend from the sides of a drill string and contact
the bore wall.
[0002] U.S. Pat. No. 7,314,099 to Dewey et al., which is herein
incorporated by reference for all it contains, discloses an
expandable downhole tool comprising a tubular body having an axial
flow bore extending there through, at least one moveable arm, and a
selectively actuatable sleeve that prevents or allows the at least
one moveable arm to translate between a collapsed position and an
expanded position. A method of expanding the downhole tool
comprises disposing the downhole tool within the wellbore, biasing
the at least one moveable arm to a collapsed position corresponding
to an initial diameter of the downhole tool, flowing a fluid
through an axial flow bore extending through the downhole tool
while preventing the fluid from communicating with a different flow
path of the downhole tool, allowing the fluid to communicate with
the different flow path by introducing an actuator into the
wellbore, and causing the at least one moveable arm to translate to
an expanded position corresponding to an expanded diameter of the
downhole tool.
[0003] U.S. Patent App. 2008/0128175 to Radford, et al., which is
herein incorporated by reference for all that it contains,
discloses an expandable reamer apparatus for drilling a
subterranean formation including a tubular body, one or more
blades, each blade positionally coupled to a sloped track of the
tubular body, a push sleeve and a drilling fluid flow path
extending through an inner bore of the tubular body for conducting
fluid there through. Each of the one or more blades includes at
least one cutting element configured to remove material from a
subterranean formation during reaming. The push sleeve is disposed
in the inner bore of the tubular body and coupled to each of the
one or more blades so as to effect axial movement thereof along the
track to an extended position responsive to exposure to a force or
pressure of drilling fluid in the flow path of the inner bore.
BRIEF SUMMARY OF THE INVENTION
[0004] In one aspect of the present invention, a tool string
component comprises at least one end that attaches to an adjacent
component in a through bore. The invention also comprises a
laterally extending member disposed along a length of the tool
string component. A magnetic mechanism is configured to sense an
extension depth of the laterally extending member.
[0005] The magnetic mechanism may comprise a magnet and at least
one sensor. The sensor may be configured to be stationary with
respect to the magnet. The magnet may also be configured to move as
the laterally extending member changes its depth of extension. In
some embodiments, that movement may be along an axis of the
component. Also, in some embodiments, the sensor may be located
near a central axis of the component and within the through
bore.
[0006] The sensor may be communication with processing element that
is configured to transmit data about the movement of the magnet to
surface equipment or downhole tools. The processing element may
process the data and send commands based off the data to adjust a
depth of the extendable member.
[0007] The magnet and/or sensor may be located in the through bore.
In such embodiments, the magnet and/or sensor may be isolated from
drilling fluid flow in the through bore. In other embodiments, the
magnets and sensors may be disposed on or proximate the laterally
extending member. A member groove on the laterally extending member
may interface with a sleeve groove on a slidable sleeve that
supports the laterally extending member. The magnet and senors may
be located on the member and sleeve grooves.
[0008] In some embodiments, the at least one sensor comprises a
plurality of magnetometers linearly distributed within and along a
length of the through bore. The magnet may be configured to move in
a direction that follows the distribution of magnetometers as the
laterally extending member moves. The magnetometers may be
configured to determine the location of the magnet, which
corresponds with the extension depth of the laterally extending
member.
[0009] In other embodiments, the laterally extending member may be
supported within a slot formed in an outer surface of the
component, and the senor may be disposed proximate a surface of the
slot wall.
BRIEF DESCRIPTION OF THE DRAWINGS
[0010] FIG. 1 is a cutaway view of an embodiment of a drilling
operation.
[0011] FIG. 2a is an orthogonal view of an embodiment of a downhole
tool.
[0012] FIG. 2b is an orthogonal view of another embodiment of a
downhole tool.
[0013] FIG. 3a is a cross section of another embodiment of a
downhole tool.
[0014] FIG. 3b is a cross section of another embodiment of a
downhole tool.
[0015] FIG. 4 is a cross section of another embodiment of a
downhole tool.
[0016] FIG. 5a is an orthogonal view of an embodiment of an
expandable member.
[0017] FIG. 5b is an orthogonal view of an embodiment of an
expandable member.
[0018] FIG. 6a is a cross section of another embodiment of an
expandable member.
[0019] FIG. 6b is a cross section of another embodiment of an
expandable member.
DETAILED DESCRIPTION OF THE INVENTION AND THE PREFERRED
EMBODIMENT
[0020] FIG. 1 discloses an embodiment of a drilling operation
comprising a drilling derrick 101 supporting a tool string 100
inside a borehole 102. The drill string 100 may comprise a bottom
hole assembly 103 that includes electronic equipment and an
expandable tool 107. Rotating the drill string 100 may also rotate
a drill bit 103 and cause the drill bit 103 to degrade the bottom
104 of the borehole 102. The expandable tool may ream a larger
diameter in the borehole than formed by the drill bit. In other
embodiments, the expandable tool may primarily centralize the tool
string within the bore hole. In some embodiments, the expandable
tool 107 may limit drilling vibrations by stabilizing the drill
string 100. The tool string may incorporate a telemetry system for
bi-directional communication between surface equipment 106 and
downhole tools. For example, operators may input commands at the
surface to control the extension depth of a laterally extending
member. Also, downhole sensors may send data to the surface that
indicates the current extension depth of the laterally extending
members.
[0021] FIG. 2a discloses an embodiment of the expandable tool 107.
A proximal end 200 of the expandable tool 107 may connect to other
downhole tool string components at tool joints. A distal end 201 of
the tool may connect directly the bottom hole assembly, drill bit
104, or other drill string components. In this embodiment, the
expandable tool 107 may comprise a mandrel with a tubular body and
an outer surface, a plurality of laterally extending members 202
disposed around the mandrel's outer surface, and a slidable sleeve
203.
[0022] The slidable sleeve 203 comprises the plurality of blades
202 disposed in slots formed in the thickness of the sleeve. A
plurality of axial segments may form the slidable sleeve 203. The
laterally extending members 202 may comprise a plurality of cutting
elements 204 and may be configured to ream the borehole wall 102.
The laterally extending members 202 are depicted in the embodiment
of FIG. 2a in a retracted position.
[0023] FIG. 2b discloses the slidable sleeve 203 configured to
slide along a length of an outer diameter of the expandable tool
107. The slidable sleeve 203 and the laterally extending members
202 may be connected such that as the slidable sleeve 203 slides
along the expandable tool 107 in the direction of arrow 205, the
members 202 shift laterally out of the slot. Sliding the sleeve 203
in the reverse direction may retract the laterally extending
members.
[0024] FIG. 3a discloses the laterally extending members 202 in a
retracted position. The expandable tool 107 may comprise an
actuating assembly 300 that controls the extension depth of the
laterally extending members and a magnetic mechanism 302 that
records the member's extension depth. The actuating assembly may
depend on a dynamic force from the drilling fluid to extend the
members. By opening valves located in the through bore, the
actuating assembly may divert drilling fluid to engage the
laterally extending members and push them out. A spring 303 may be
disposed within the expandable tool and along the length of the
tubular member. The spring may be configured to retract the
laterally extending member 202 in the absence of the dynamic fluid
force. However, in other embodiments, other electrical and/or
mechanical assemblies may be used to control the extension depth of
the members.
[0025] In the embodiment of FIG. 3a, the actuating assembly 300
comprises a central cylindrical structure 301 located within the
through bore 306 and in mechanical communication with the spring.
The central cylindrical structure is configured to translate along
a length of the through bore as the spring moves. The central
cylindrical structure may support magnets 310 that move with the
central cylindrical structure, but with respect to sensors 311 that
are axially fixed within the through bore. The combination of at
least one of the sensors and the magnets may form the magnetic
mechanism 302.
[0026] FIG. 3b discloses the laterally extending member 202
extended, which compresses the spring 303 and shifts the central
cylindrical structure with the associated magnets along the length
of the expandable tool. A ramp 309 formed in the tool body 107 may
cause the extending member 202 to extend radially as an axial force
from the fluid is applied. One of the laterally extending members
is removed for illustrative purposes to show the ramp 309.
[0027] The valves may be controlled by downhole tools and/or
surface equipments. Preferably, commands over a telemetry system to
open the valve fully or partially. A telemetry system that may be
compatible with the present invention is disclosed by U.S. Pat. No.
6,670,880, which is herein incorporated by reference for all that
it contains. The execution of the commands sent to the valves may
be confirmed through the recordings of the magnetic mechanism.
[0028] FIG. 4 discloses a detailed view of an embodiment of the
magnetic mechanism 302. In this embodiment, the magnetic mechanism
302 comprises a plurality of sensors 311 and a magnet 310. The
magnet 310, annularly disposed about the sensors 305, radiates a
magnetic field 400 that is detected by the plurality of sensors
311. The sensors 311 are rigidly attached to a rod 312 that is
axially fixed to the through bore. The magnets, however, move with
respect to the sensors as the laterally expendable members retract
and expand.
[0029] The sensors 311 may include a plurality of magnetometers
311. The plurality of magnetometers 311 may sense the strength of
the magnetic field 400 when in the field's vicinity. In some
embodiments, the magnetic field 400 is focused, by a magnetic
shield, toward the axis 305.
[0030] The sensors 311 may be distributed along a length of the rod
312. As the cylindrical structure and magnets 310 moves along the
length of the through bore, the magnetic field 400 moves
accordingly, and the location of the magnetic field correlates with
the extension depth of the members. The sensors 311 may be in
communication with a processing element that can transmit the data
to downhole tools or to surface equipment. In some embodiments, the
processing element may comprise enough intelligence to send
commands directly to the valves to adjust a depth of the laterally
extending member.
[0031] The magnets may be housed in a sealed compartment to protect
the magnets from the abrasive forces of the drilling fluid. Also,
the rod may be sealed to protect the sensors from the harsh
downhole environment.
[0032] The sensors 311 may gauge extension depth by the strength of
the magnetic field 400 on each magnetometer. Each magnetometer of
the sensors 311 may detect an increasing magnetic field 400 as the
magnet 310 approaches. For example, when the magnetometers on a
first end 401 sense the magnetic field, the expandable tool 107 may
be in a retracted position; and when the magnetometers on a distal
end 402 detect the magnetic field 400, the expandable tool 107 may
be in an extended position. As the magnetic field 400 approaches
the distal end 402 of the sensors 311, the expandable tool 107 may
approach maximum expansion.
[0033] In some embodiments, a single magnetic field detector may
sense the position of the magnet. For example, the magnetic field
sensor and associated instrumentation may be configured to detect
the strength of the magnetic field. Thus, a weak magnetic field may
indicate that the magnet is far from the magnetic field sensor,
while a strong detected field may indicate that the magnet is
closer. The instrumentation may be configured to determine the
relative location based off of a continuum of field strengths.
[0034] FIGS. 5a and 5b discloses a magnet/magnetic source 310
located on a member groove 501 formed in the expandable member 107.
Corresponding sleeve grooves 500 located in the slot formed in the
sleeve that supports the members may comprise the sensors 311.
Thus, the relative position of the magnets and magnetometers may be
used to determine the position of the laterally extending members.
In some embodiments, the magnets may be positioned in the sleeve,
and the sensors may be disposed within the sleeve.
[0035] FIG. 6 discloses an expandable tool 107 that translates
laterally as indicated by arrow 604. The magnet 310 may be disposed
within any surface 602 that comes into contact or near contact with
the member, and the magnetometers may be disposed within an
adjacent surface 603 of the blade or vice versa.
[0036] Whereas the present invention has been described in
particular relation to the drawings attached hereto, it should be
understood that other and further modifications apart from those
shown or suggested herein, may be made within the scope and spirit
of the present invention.
* * * * *