U.S. patent application number 12/823967 was filed with the patent office on 2010-12-30 for stabilizing downhole tool.
This patent application is currently assigned to PILOT DRILLING CONTROL LIMITED. Invention is credited to Burney J. Latiolais, JR., Thomas G. Roesner, George Swietlik.
Application Number | 20100326731 12/823967 |
Document ID | / |
Family ID | 43379496 |
Filed Date | 2010-12-30 |
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United States Patent
Application |
20100326731 |
Kind Code |
A1 |
Swietlik; George ; et
al. |
December 30, 2010 |
STABILIZING DOWNHOLE TOOL
Abstract
Embodiments disclosed herein relate to a downhole tool and a
method to abate vibration with the downhole tool. The downhole tool
may include a first stabilizing member, a second stabilizing
member, a flexible member, and/or a dampening member, in which the
downhole tool may be disposed downhole within a wellbore. The
flexible member may enable the first stabilizing member and the
second stabilizing member to articulate with respect to an axis of
the downhole tool. The dampening member may enable vibration
received by the downhole tool to be dampened. Further, the first
stabilizing member and the second stabilizing member may be
rotatable with respect to each other about the axis of the downhole
tool.
Inventors: |
Swietlik; George;
(Lowestoft, GB) ; Latiolais, JR.; Burney J.;
(Lafayette, LA) ; Roesner; Thomas G.; (Katy,
TX) |
Correspondence
Address: |
OSHA LIANG LLP - Frank's International
TWO HOUSTON CENTER, 909 FANNIN STREET, SUITE 3500
Houston
TX
77010
US
|
Assignee: |
PILOT DRILLING CONTROL
LIMITED
Lowestoft
GB
|
Family ID: |
43379496 |
Appl. No.: |
12/823967 |
Filed: |
June 25, 2010 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
61220474 |
Jun 25, 2009 |
|
|
|
Current U.S.
Class: |
175/57 ;
175/325.3 |
Current CPC
Class: |
E21B 17/1078 20130101;
E21B 29/00 20130101; E21B 17/1014 20130101; E21B 31/002
20130101 |
Class at
Publication: |
175/57 ;
175/325.3 |
International
Class: |
E21B 7/00 20060101
E21B007/00; E21B 17/10 20060101 E21B017/10 |
Claims
1. A method to abate vibration during drilling within a borehole,
the method comprising: connecting a downhole tool to a string of
tubular members, the string of tubular members having a drill bit
disposed at one end; disposing the downhole tool having an axis
defined therethrough within the borehole, the downhole tool
comprising a first stabilizing member, a second stabilizing member,
and a flexible member; flexing the flexible member such that at
least one of the first stabilizing member and the second
stabilizing member contacts a wall of the borehole; and drilling
into the borehole with the drill bit.
2. The method of claim 1, wherein the drilling into the borehole
comprises at least one of: rotating the string of tubular members
with a drill rig such that the drill bit rotates with respect to
the borehole; and rotating the drill bit with a mud motor such that
the drill bit rotates with respect to the borehole.
3. The method of claim 1, further comprising: rotating the first
stabilizing member and the second stabilizing member with respect
to each other about the axis.
4. The method of claim 1, further comprising: rotating at least one
of the first stabilizing member and the second stabilizing member
with respect to the drill bit such that the at least one of the
first stabilizing member and the second stabilizing member remains
substantially rotationally stationary with respect to the
borehole.
5. The method of claim 1, further comprising: dampening the flexing
of the flexible member.
6. The method of claim 1, further comprising: providing the
downhole tool with a dampening member.
7. The method of claim 6, wherein the dampening member dampens
vibration to a level such that damage is prevented to a sensor
connected to the string of tubular members.
8. The method of claim 1, wherein the string of tubular members
comprises a lower bottom hole assembly and an upper bottom hole
assembly, wherein the downhole tool is connected to the string of
tubular members between the lower bottom hole assembly and the
upper bottom hole assembly.
9. The method of claim 1, wherein at least one of the first
stabilizing member and the second stabilizing member comprises a
dampening member.
10. A method to abate vibration during drilling within a borehole,
the method comprising: connecting a downhole tool to a string of
tubular members, the string of tubular members having a drill bit
disposed at one end; disposing the downhole tool having an axis
defined therethrough within the borehole, the downhole tool
comprising a first stabilizing member and a flexible member;
flexing the flexible member such that the first stabilizing member
contacts a wall of the borehole; and drilling into the borehole
with the drill bit.
11. The method of claim 10, further comprising: rotating the first
stabilizing member with respect to the flexible member.
12. The method of claim 10, further comprising: rotating the first
stabilizing member with respect to the drill bit such that the
first stabilizing member remains substantially rotationally
stationary with respect to the borehole.
13. The method of claim 10, further comprising: dampening the
flexing of the flexible member.
14. The method of claim 10, wherein the downhole tool further
comprises a dampening member.
15. The method of claim 10, wherein the first stabilizing member
comprises a dampening member.
16. The method of claim 10, wherein the drilling into the borehole
with the drill bit comprises milling the borehole with the drill
bit, thereby removing at least a portion of material disposed
within the borehole.
17. The method of claim 10, wherein the drill bit comprises one of
a roller-cone drill bit, a shearing drill bit, a rock bit, a PDC
bit, a reamer, and a milling tool.
18. A method to abate vibration during drilling within a borehole,
the method comprising: connecting a downhole tool to a string of
tubular members, the string of tubular members having a drill bit
disposed at one end; disposing the downhole tool having an axis
defined therethrough within the borehole, the downhole tool
comprising a first stabilizing member and a first dampening member;
providing the downhole tool with a second dampening member; and
drilling into the borehole with the drill bit.
19. The method of claim 18, wherein the downhole tool further
comprises a flexible member.
20. The method of claim 18, wherein the first dampening member is
axially spaced from the second dampening member.
21. A downhole tool to abate vibration during drilling, comprising:
a generally tubular body having an axis defined therethrough; a
first stabilizing member disposed at a first location on the
tubular body; a second stabilizing member disposed at a second
location on the tubular body, wherein the first stabilizing member
and the second stabilizing member are rotatable with respect to
each other about the axis; and a flexible member disposed within
the tubular body such that the first stabilizing member and the
second stabilizing member are configured to articulate with respect
to each other along the axis.
22. The downhole tool of claim 21, further comprising a dampening
member disposed within the tubular body and configured to dampen
vibration received by the downhole tool.
23. The downhole tool of claim 21, wherein the flexible member
comprises a dampening member configured to dampen flexure of the
flexible member.
24. The downhole tool of claim 23, wherein one of the first
stabilizing member and the second stabilizing member comprises the
dampening member.
25. The downhole tool of claim 24, wherein the dampening member
comprises an elastomeric member.
26. The downhole tool of claim 21, wherein one of the first
stabilizing member and the second stabilizing member comprises a
plurality of bladed members.
27. The downhole tool of claim 26, wherein at least one of the
plurality of bladed members comprises an elastomeric material.
28. The downhole tool of claim 21, wherein the generally tubular
body comprises a first body portion and a second body portion,
wherein the first stabilizing member is disposed on the first body
portion and the second stabilizing member is disposed on the second
body portion.
29. The downhole tool of claim 28, wherein at least one component
of the flexible member is disposed within the second body
portion.
30. The downhole tool of claim 28, wherein the second body portion
comprises a first body member and a second body member, wherein the
flexible member is disposed between the first body member and the
second body member.
31. The downhole tool of claim 30, wherein the flexible member
comprises an elastomeric member.
32. The downhole tool of claim 21, wherein a maximum outer diameter
of one of the first stabilizing member and the second stabilizing
member is greater than a maximum outer diameter of the other of the
first stabilizing member and the second stabilizing member.
33. A downhole tool to abate vibration during drilling, the
downhole tool having an axis defined therethrough to be disposed
within a borehole, comprising: a first stabilizing member disposed
at a first location; and a second stabilizing member disposed at a
second location; wherein the first stabilizing member and the
second stabilizing member are rotatable with respect to each other
about the axis, and wherein the first stabilizing member and the
second stabilizing member are each configured to engage a wall of
the borehole.
34. The downhole tool of claim 33, further comprising: a flexible
member disposed within a tubular member of the downhole tool such
that the first stabilizing member and the second stabilizing member
are configured to articulate with respect to each other along the
axis.
35. The downhole tool of claim 34, wherein the flexible member
comprises an elastomeric member.
36. The downhole tool of claim 33, wherein the flexible member
comprises a dampening member configured to dampen flexure of the
flexible member.
37. The downhole tool of claim 33, further comprising: a dampening
member disposed within a tubular member of the downhole tool such
that the dampening member is configured to dampen vibration
received within the downhole tool.
38. The downhole tool of claim 33, wherein at least one of the
first stabilizing member and the second stabilizing member
comprises a dampening member.
39. A system to abate vibration during drilling, the system having
an axis defined therethrough to be disposed within a borehole, the
system comprising: a downhole tool having a first end and a second
end, comprising: a first stabilizing member having a dampening
member disposed thereon; a second stabilizing member, wherein the
first stabilizing member and the second stabilizing member are
rotatable with respect to each other about the axis; and a flexible
member disposed within the tubular member such that the first
stabilizing member and the second stabilizing member are configured
to articulate with respect to each other along the axis; and an
upper bottom hole assembly having a first end and a second end,
wherein the second end of the upper bottom hole assembly is
connected to the first end of the downhole tool; and a lower bottom
hole assembly having a first end and a second end, wherein the
first end of the lower bottom hole assembly is connected to the
second end of the downhole tool.
40. The system of claim 39, wherein a drill bit is connected to the
second end of the lower bottom hole assembly.
41. The system of claim 39, wherein the upper bottom hole assembly
comprises a sensor.
42. A method to abate vibration during drilling within a borehole,
the method comprising: connecting a downhole tool to a string of
tubular members, the string of tubular members having a drill bit
disposed at one end; disposing the downhole tool having an axis
defined therethrough within the borehole, the downhole tool
comprising a flexible member; drilling into the borehole with the
drill bit; and flexing the flexible member when drilling with the
drill bit.
43. The method of claim 42, wherein the downhole tool further
comprises a first stabilizing member, wherein the flexing the
flexible member comprises flexing the flexible member such that the
first stabilizing member contacts a wall of the borehole.
44. The method of claim 43, further comprising: rotating the first
stabilizing member with respect to the flexible member.
45. The method of claim 43, wherein the downhole tool further
comprises a second stabilizing member.
46. The method of claim 43, further comprising: rotating the first
stabilizing member with respect to the second stabilizing
member.
47. The method of claim 42, further comprising: dampening the
flexing of the flexible member.
48. The method of claim 42, wherein the drill bit comprises a
milling tool, wherein the drilling into the borehole with the drill
bit comprises milling the borehole with the milling tool.
49. The method of claim 42, wherein the drill bit comprises one of
a roller-cone drill bit, a shearing drill bit, a rock bit, a PDC
bit, a reamer, and a milling tool.
50. A downhole tool to abate vibration during drilling, comprising:
a generally tubular body having an axis defined therethrough; a
drill bit connected to the tubular body at an end thereof; and a
flexible member disposed within the tubular body such that the
drill bit is configured to articulate with respect to the axis of
the tubular body.
51. The downhole tool of claim 50, further comprising: a first
stabilizing member disposed at a first location on the tubular
body, wherein the first stabilizing member is configured to
articulate with respect to the axis of the tubular body.
52. The downhole tool of claim 51, further comprising: a second
stabilizing member disposed at a second location on the tubular
body, wherein the first stabilizing member and the second
stabilizing member are rotatable with respect to each other about
the axis.
53. The downhole tool of claim 50, wherein the flexible member
comprises a dampening member configured to dampen flexure of the
flexible member.
54. The downhole tool of claim 50, further comprising: a dampening
member disposed within a tubular member of the downhole tool such
that the dampening member is configured to dampen vibration
received within the downhole tool.
55. The downhole tool of claim 50, wherein the drill bit comprises
one of a roller-cone drill bit, a shearing drill bit, a rock bit, a
PDC bit, a reamer, and a milling tool.
Description
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] This application claims benefit, under 35 U.S.C. .sctn.119,
of U.S. Provisional Application Ser. No. 61/220,474 filed on Jun.
25, 2009 and entitled "Stabilizing Downhole Tool" in the name of
George Swietlik and Burney Latiolais. The disclosure of this U.S.
Provisional Application is incorporated herein by reference in its
entirety.
BACKGROUND OF DISCLOSURE
[0002] 1. Field of the Disclosure
[0003] Embodiments disclosed herein generally relate to methods and
tools to be disposed downhole within a string of tubular members.
More specifically, embodiments disclosed herein relate to a
downhole tool to be connected within a string of tubular members,
in which the downhole tool may be used to assist in stabilizing the
string.
[0004] 2. Background Art
[0005] In oilfield exploration and production operations, various
oilfield tubulars are used to perform important tasks, including,
but not limited to, drilling a borehole (or wellbore) and casing
the drilled borehole. For example, a string of tubular members,
known in the industry as a drill string, may be used to advance
and/or rotate a drill bit at a distal end to create the borehole.
As used herein, the term drill string may be used to describe any
string of tubular members used to rotate and/or advance a drill bit
including, but not limited to, strings of drill pipe, drill
collars, premium threaded connections, casing joints, and coiled
tubing.
[0006] Furthermore, after a borehole has been created, a casing
string may be disposed downhole into the borehole and cemented in
place (or merely cemented in-situ where casing is used as the drill
string) to stabilize, reinforce, or isolate (among other functions)
portions of the borehole. As such, tubular strings may be connected
together, end-to-end by threaded connections, where a female "pin"
member of a first tubular is configured to threadably engage a
corresponding male "box" member of a second tubular. Alternatively,
a tubular string may be made-up of a of male-male ended joints
coupled together by female-female couplers. The process by which
the threaded connections are screwed together is called "making-up"
a threaded joint, and the process by which the connections are
disassembled is referred to as "breaking-out" the threaded joint.
As would be understood by one having ordinary skill, individual
pieces (or "joints") of oilfield tubulars may come in a variety of
materials, weights, diameters, configurations, and lengths.
[0007] As such, in the drilling, completing, or reworking of oil
wells, a variety of downhole tools may be used. FIG. 1 shows one
example of a conventional drilling system 100 for drilling an earth
formation. The drilling system includes a drilling rig 110 that may
lift, lower and/or turn a drilling tool assembly 112 extending
downward into a borehole 114. Drilling tool assembly 112 generally
includes a drill string 116 with a bottom hole assembly 118 having
a drill bit 120 attached to a distal end of drill string 116.
[0008] The drill string 116 may include several joints of drill
pipe 116A connected end-to-end through one or more tool joints
116B. The drill string 116 may be connected such that the drill
pipe 116A is tightened to a certain amount, such as to a specific
torque. The drill string 116 may also be disconnected such that the
drill pipe 116A is threadably taken apart. The drill string 116 may
transmit drilling fluid (such as through a central bore) and/or
rotational torque from the drill rig 110 to the bottom hole
assembly 118. The drill pipe 116A may provide a hydraulic passage
through which drilling fluid (e.g., mud) is pumped. The drilling
fluid typically discharges through selected-size orifices in the
bit (e.g., "jets") for the purposes of cooling the drill bit 120
and lifting rock cuttings out of borehole 114 as it is drilled.
Similarly, rather than using drilling mud, the drill string 116 may
be used to transmit air, such as when air drilling, in which the
air is used to lift rock cuttings out of the borehole 114.
[0009] The bottom hole assembly 118 may include the drill bit 120,
in addition to other components that may be attached between the
drill string 116 and drill bit 120. Examples of additional
downhole, e.g., bottom hole assembly, components may include, but
are not limited to, drill collars, stabilizers, transducers,
measurement-while-drilling tools, logging-while-drilling tools),
downhole motors (e.g., mud motors), or any combination thereof.
[0010] During drilling, axial, lateral, and/or rotational vibration
(e.g., movement, oscillations, etc.) may be imparted to the drill
bit 120 and drill string 116 (including bottom hole assembly 118)
from various downhole (and surface) forces. For example, as the
drill bit 120 compacts and cuts the earth formation, the cutting
forces may impart vibration to the drill bit 120, the bottom hole
assembly 118, and/or the drill string 116. Additionally, the
rotation and/or axial displacement of the drill string 116 may
further impart vibration to the drill string components (116, 118,
and 120) from the forces generated by the rotating drill string 116
contacting the borehole and other downhole components. Furthermore,
if the bottom hole assembly 118 is so equipped, a downhole mud
motor (e.g., progressive cavity positive displacement mud motors or
turbo drills) may impart vibration to the drill bit 120 and drill
string 116 (including other components of bottom hole assembly 118)
from the forces generated by their operation.
[0011] Vibration may cause the drilling apparatus, including drill
string 116, bottom hole assembly 118, and drill bit 120, to bend,
twist, bounce, or otherwise deviate off-course, such as having the
borehole formed larger than desired or having the trajectory of the
borehole formed off-course and generate poor borehole quality.
Thus, vibration may inhibit a more efficient excavation of the
subterranean formation by the drilling rig 100. Further, vibration
may cause damage to one or more of the drill string components
(116, 118, and 120) and any downhole components disposed therein.
For example, a sensor may be included with a bottom hole assembly
118, in which the sensor may be used for measuring and/or sensing
one or more downhole parameters, e.g., drilling parameters.
Vibration received therein may damage a sensor and/or interfere
with the correct operation of the sensor. Vibration may interfere
with the logging, recordation, and/or transmittal of information
(e.g., from a downhole sensor) to and/or from the drilling rig 100,
in addition to interfering with the performance of the bottom hole
assembly 118, and possibly drill string components (116, 118, and
120), altogether. Accordingly, there exists a need to increase the
stability of, as well as reduce downhole vibration imparted to, at
least a portion of drill strings, drill bits, and bottom hole
assemblies.
[0012] Additionally, there also exists a need to more effectively
maintain contact between the cutting surface of a drill bit and an
earth formation during drilling. Drill bit 120 vibration,
particularly during cutting, may damage or prematurely wear drill
bit 120. Furthermore, vibration may cause the drill bit 120, for
example, to lift off of the bottom of the borehole, thereby
reducing the bit's rate of penetration into a formation. As such,
there exists a need to dampen the vibration of a drill string, for
example, a portion of the drill string (including bottom hole
assembly and/or drill bit components) in a drilling system.
SUMMARY OF INVENTION
[0013] In a first aspect, embodiments disclosed herein relate to a
method to abate vibration within a borehole. The method includes
connecting a downhole tool within a string of tubular members, the
string of tubular members having a drill bit disposed at one end,
and disposing the downhole tool having an axis defined therethrough
within the borehole, the downhole tool having a first stabilizing
member, a second stabilizing member, and a flexible member. The
method further includes flexing the flexible member such that one
of the first stabilizing member and the second stabilizing member
contacts a wall of the borehole, and drilling into the borehole
with the drill bit.
[0014] In another aspect, embodiments disclosed herein relate to a
method to abate vibration within a borehole. The method includes
connecting a downhole tool within a string of tubular members, the
string of tubular members having a drill bit disposed at one end,
and disposing the downhole tool having an axis defined therethrough
within the borehole, the downhole tool having a first stabilizing
member located above a flexible member. The method further includes
flexing the flexible member such that one of the first stabilizing
member and the second stabilizing member contacts a wall of the
borehole, and drilling into the borehole with the drill bit.
[0015] In another aspect, embodiments disclosed herein relate to a
method to abate vibration within a borehole. The method includes
connecting a downhole tool within a string of tubular members, the
string of tubular members having a drill bit disposed at one end,
and disposing the downhole tool having an axis defined therethrough
within the borehole, the downhole tool comprising a first
stabilizing member and a dampening member. The method further
includes dampening vibration received within the downhole tool with
the dampening member, and drilling into the borehole with the drill
bit.
[0016] In another aspect, embodiments disclosed herein relate to a
downhole tool to abate vibration. The downhole tool includes a
generally tubular body having an axis defined therethrough, a first
stabilizing member disposed at a first location on the tubular
body, a second stabilizing member disposed at a second location on
the tubular body, in which the first stabilizing member and the
second stabilizing member are rotatable with respect to each other
about the axis, and a flexible member disposed within the tubular
body such that the first stabilizing member and the second
stabilizing member are configured to articulate with respect to
each other along the axis.
[0017] In another aspect, embodiments disclosed herein relate to a
downhole tool having an axis defined therethrough to be disposed
within a borehole. The downhole tool includes a first stabilizing
member disposed at a first location and a second stabilizing member
disposed at a second location. The first stabilizing member and the
second stabilizing member are rotatable with respect to each other
about the axis, and the first stabilizing member and the second
stabilizing member are each configured to engage a wall of the
borehole.
[0018] In another aspect, embodiments disclosed herein relate to a
system having an axis defined therethrough to be disposed within a
borehole. The system includes a downhole tool having a first end
and a second end, the downhole tool including a first stabilizing
member having a dampening member disposed thereon, a second
stabilizing member, wherein the first stabilizing member and the
second stabilizing member are rotatable with respect to each other
about the axis, and a flexible member disposed within the tubular
member such that the first stabilizing member and the second
stabilizing member are configured to articulate with respect to
each other along the axis. The system further includes an upper
bottom hole assembly having a first end and a second end, in which
the second end of the upper bottom hole assembly is connected to
the first end of the downhole tool, and a lower bottom hole
assembly having a first end and a second end, in which the first
end of the lower bottom hole assembly is connected to the second
end of the downhole tool.
[0019] Other aspects and advantages of the invention will be
apparent from the following description and the appended
claims.
BRIEF DESCRIPTION OF DRAWINGS
[0020] FIG. 1 is a schematic view of a drilling rig.
[0021] FIGS. 2A, 2B, and 2C show multiple perspective views of a
downhole tool in accordance with an embodiment of the present
disclosure.
[0022] FIG. 3A shows a cross-sectional view of a downhole tool in
accordance with an embodiment of the present disclosure.
[0023] FIG. 3B shows a detailed perspective view of a flexible
member in accordance with an embodiment of the present
disclosure.
[0024] FIG. 4 shows a perspective view of a downhole tool within a
string of tubular members in accordance with an embodiment of the
present disclosure.
[0025] FIG. 5 shows a cross-sectional view of a downhole tool in
accordance with an embodiment of the present disclosure.
[0026] FIG. 6 shows a cross-sectional view of a downhole tool in
accordance with an embodiment of the present disclosure.
[0027] FIG. 7 shows a cross-sectional view of a downhole tool in
accordance with an embodiment of the present disclosure.
[0028] FIG. 8 shows a cross-sectional view of a downhole tool in
accordance with an embodiment of the present disclosure.
[0029] FIG. 9 shows a cross-sectional view of a downhole tool in
accordance with an embodiment of the present disclosure.
[0030] FIG. 10 shows a cross-sectional view of a downhole tool in
accordance with an embodiment of the present disclosure.
[0031] FIG. 11 shows a cross-sectional view of a downhole tool in
accordance with an embodiment of the present disclosure.
[0032] FIG. 12 shows a cross-sectional view of a downhole tool in
accordance with an embodiment of the present disclosure.
DETAILED DESCRIPTION
[0033] Embodiments of the present disclosure will now be described
in detail with reference to the accompanying Figures. Like elements
in the various figures may be denoted by like reference numerals
for consistency. Further, in the following detailed description of
embodiments of the present disclosure, numerous specific details
are set forth in order to provide a more thorough understanding of
the claimed subject matter. However, it will be apparent to one of
ordinary skill in the art that the embodiments disclosed herein may
be practiced without these specific details. In other instances,
well-known features have not been described in detail to avoid
unnecessarily complicating the description. Additionally, it will
be apparent to one of ordinary skill in the art that the scale of
the elements presented in the accompanying Figures may vary without
departing from the scope of the present disclosure.
[0034] As used herein, a "drill bit" refers to any tool, mechanism,
device, and/or instrument that may be used to cut, shear, drill,
bore, puncture, penetrate, and/or use any other method known in the
art to remove earth when forming a borehole within a formation. For
example, a drill bit may include one or more of a roller-cone drill
bit, a shearing drill bit, a rock bit, a PDC (polycrystalline
diamond compact) bit, a reamer, a milling tool, and/or any other
device or tool known in the art. A drill bit may further include
one or more of a cutting element, a shearing element, a compression
element, a PCD (polycrystalline diamond) element, and/or any other
element known in the art.
[0035] Furthermore, as used herein, "drilling" may refer to any
procedure and/or method that may be used to remove earth, such as
when forming and/or enlarging a borehole, but may also include
other methods and procedures performed during the course of
drilling, extending, and/or enlarging a borehole, such as when
removing devices and/or components that may be disposed downhole.
For example, "drilling" may include the removal of one or more
packer elements, the removal of one or more tubular members, and/or
the removal of other materials and/or devices disposed within a
formation, such as by milling to remove a packer element disposed
within a formation during a work over of borehole. Accordingly, the
present disclosure contemplates using different structures and
types of drill bits in one or more methods when drilling and
forming a borehole.
[0036] In various aspects disclosed herein, embodiments disclosed
herein generally relate to a downhole tool to be used within a
drill string and to be disposed downhole within a borehole. The
downhole tool may be used to stabilize, or assist in stabilizing,
one or more tubular members when the tubular members are disposed
downhole within a borehole. Particularly, the downhole tool may be
disposed downhole within a borehole, such as having the tool
connected within a string of tubular members disposed downhole, in
which the downhole tool may engage one or more surfaces of the
borehole. Further, the downhole tool may abate vibration (e.g.,
reduce vibration, reduce the transfer of vibration across the tool,
or stop the transfer of vibration across the tool), for example,
vibration received during drilling and/or rotation of a drill
string. As used herein, vibration may refer to any movement, force,
and/or oscillation received by a downhole tool in the axial,
radial, and/or rotational directions. As such, the downhole tool
may prevent damage to the drillstring, bottom hole assembly, or any
other downhole tools disposed within the borehole or attached to a
tubular string.
[0037] Thus, in one aspect, a downhole tool in accordance with one
or more embodiments of the present disclosure may include a
generally tubular body having an axis defined therethrough. A first
stabilizing member may be disposed at one location on the tubular
body, and an optional second stabilizing member may be disposed at
another location on the tubular body. In this arrangement, the
first stabilizing member and the second stabilizing member may be
able to rotate with respect to each other about the axis of the
tubular body. The downhole tool may also include a flexible member
disposed therein, in which the flexible member may enable the first
stabilizing member and the second stabilizing member to be able to
deflect (e.g., flex or articulate) with respect to each other along
their respective axes. As such, the first stabilizing member and/or
the second stabilizing member may be able to engage a wall of a
borehole and provide stabilization to the downhole tool.
[0038] Further, the downhole tool may additionally have a dampening
member. For example, the downhole tool may have a dampening member
included therewith. The dampening member may be used to dampen
vibration in one or more directions, such as dampen vibration in
the axial, radial, and/or rotational direction. As such, when
dampening vibration primarily in the axial direction, the dampening
member may include, for example, a "shock sub" assembly. In such an
embodiment, the shock sub assembly may be disposed within the
downhole tool. Those having ordinary skill in the art, though, will
appreciate that other dampening members may be used to dampen
vibration in one or more directions without departing from the
scope of the present disclosure.
[0039] The downhole tool may include a dampening member disposed
between a first stabilizing member and a second stabilizing member.
Further, the downhole tool may have a dampening member disposed on
or adjacent to the first stabilizing member and/or second
stabilizing member. For example, the dampening member may be
disposed upon an outer surface of a stabilizing member, and/or the
dampening member may be disposed between an outer surface of a
stabilizing member and an inner bore of the downhole tool. The
dampening member may include a dampening material, such as by
having the dampening material disposed between the first
stabilizing member and the second stabilizing member, disposed on a
wellbore contacting surface of the first stabilizing member and/or
the second stabilizing member, and/or disposed within the first
stabilizing member and/or the second stabilizing member. The
dampening member may dampen (e.g., reduce) vibration received by
components of the drill string (including the bottom hole assembly,
e.g., sensors therein, and the drill bit), such as by reducing at
least a portion of the vibration received within the dampening
member, thereby reducing vibration received within the downhole
tool and/or other components of the drill string. In various
embodiments disclosed herein, the dampening member may include an
elastomeric member and/or an elastomeric material. Further, the
downhole tool may be disposed with a bottom hole assembly, for
example, disposed between an upper bottom hole assembly and a lower
bottom hole assembly. In such embodiments, a downhole tool in
accordance with embodiments disclosed herein may dampen vibration
within the bottom hole assembly, for example, between the upper
bottom hole assembly (which may include a downhole component, e.g.,
sensor) and the lower bottom hole assembly.
[0040] Referring now to FIGS. 2A and 2B, multiple perspective views
of a downhole tool 201 in accordance with embodiments disclosed
herein are shown. Particularly, FIG. 2A shows an outlined
perspective view of the downhole tool 201, and FIG. 2B shows a
textured perspective view of the downhole tool 201. The illustrated
downhole tool 201 includes a generally tubular body 203 having an
axis 205 defined therethrough. As such, a bore may be defined
within the body 203 that extends through the body 203 of the
downhole tool 201, such as to induce fluid flow through the
downhole tool 201. Additionally, as shown, the tubular body 203 of
the downhole tool 201 may include one or more body portions. In
this embodiment, the downhole tool 201 includes a first body
portion 207 and a second body portion 209. However, those having
ordinary skill in the art will appreciate that a downhole tool in
accordance with embodiments disclosed herein may include more than
two body portions, as shown, or may include a single body portion
(e.g., with a flexible member).
[0041] Further, the downhole tool 201 may include one or more
stabilizing members disposed thereon and/or attached thereto. As
used herein, the term "stabilizing member" refers to a location
along the outer profile of the drill string (including bottom hole
assembly) having a relatively increased outer profile, e.g., outer
diameter. For example, stabilizers may be constructed as having
multi-blade, longitudinally straight members, as having
multi-blade, radially straight members, or as having single or
multi-bladed spiral (helical) shaped members. As such, the bladed
members may be disposed or constructed on the outer surface of the
stabilizing members, thereby providing a surface for engagement of
the stabilizing members with a wall of a borehole (as discussed
more below). Regardless of particular configuration, stabilizing
members typically function to contact the inner profile of the
borehole wall (or the inner diameter of a cased borehole) such that
adjoining portions of the drill string (or bottom hole assembly)
will not contact the borehole wall. The desire to prevent
components of the drillstring or bottom hole assembly from
contacting the borehole wall may come from a variety or reasons,
including, but not limited to, creating a desired offset from the
borehole for a particular measurement device and protecting an
outer structure the drilling apparatus that might otherwise become
damaged if it were allowed to contact the borehole wall. As
described herein, a stabilizing member may act as a grounding
point(s) in a downhole tool such that the drill string and/or
bottom hole assembly may engage a wall of the borehole to flex
about a single stabilizing member or between two or more
stabilizing members.
[0042] For example, as shown in FIGS. 2A and 2B, the downhole tool
201 includes a first stabilizing member 211 and a second
stabilizing member 213. Specifically, in this embodiment, the first
stabilizing member 211 is disposed on the first body portion 207,
and the second stabilizing member 213 is disposed on the second
body portion 209. As such, the first stabilizing member 211 and the
second stabilizing member 213 may be used to stabilize the downhole
tool 201, such as when disposed downhole and/or attached to a
string of tubular members (discussed more below) by having the
stabilizing members engage the wall of a borehole. Thus, as shown,
the downhole tool 201 may have at least two points-of-contact to
engage the wall of the borehole, in which one point-of-contact by
the first stabilizing member 211 may be axially spaced along the
axis 205 from another point-of-contact by the second stabilizing
member 213. However, those having ordinary skill in the art will
appreciate that a downhole tool in accordance with embodiments
disclosed herein may include more than two stabilizing members
disposed thereon and/or attached thereto. Alternatively, those
having ordinary skill will appreciate that a downhole tool in
accordance with embodiments disclosed herein may include a single
stabilizing member disposed thereupon.
[0043] A stabilizing member may be rotationally fixed or rotatable
relative to the body portion it is connected to, e.g., be
rotationally stationary relative to a borehole. In accordance with
embodiments disclosed herein, dual stabilizing members and may be
rotatable with respect to each other about the axis of the downhole
tool. For example, as shown in FIGS. 2A and 2B, the first
stabilizing member 211 may be able to rotate, e.g., about the axis
205, with respect to the second stabilizing member 213. More
particularly, the body 203 of the downhole tool 201 may be able to
rotate between the first body section 207 and the second body
section 209, thereby enabling rotation between the first
stabilizing member 211 and the second stabilizing member 213. In
this embodiment, the first body section 207 and the second body
section 209 may be able to rotate with respect to each other
through the use of, for example, a bearing being disposed
therebetween. However, those having ordinary skill in the art will
appreciate that other mechanisms may be used to enable rotation
between the body sections and/or the stabilizing members in
accordance with embodiments disclosed herein.
[0044] Additionally, an outer diameter of one or more of the
stabilizing members may be larger than an outer diameter of the
remainder of the tubular body of the downhole tool. For example, as
shown in FIGS. 2A and 2B, the outer diameter of the first
stabilizing member 211 and the second stabilizing member 213 is
larger than the outer diameter of the remainder of the tubular body
203. Further, an outer diameter of one of the stabilizing members
may be larger than an outer diameter of the other stabilizing
members. For example, with reference to FIGS. 2A and 2B, the outer
diameter of the first stabilizing member 211 may be larger than the
outer diameter of the second stabilizing member 213. In such an
embodiment, the first stabilizing member 211 may engage and contact
a wall of a borehole before the second stabilizing member 213
engages and contact the wall of the borehole. As such, in an
embodiment in which a borehole has a diameter of at least about
8.75 inches (22.2 cm), the second stabilizing member 213 may have
an outer diameter of about 8.5 inches (21.6 cm), and the first
stabilizing member 211 may have an outer diameter of about 8.625
inches (21.9 cm). Further, in another embodiment, the outer
diameter of the second stabilizing member 213 may be larger than
the outer diameter of the first stabilizing member 211.
[0045] One or more of the stabilizing members of a downhole tool in
accordance with embodiments disclosed herein may include one or
more bladed members disposed thereon and/or attached thereto. As
shown, the first stabilizing member 211 includes a plurality of
bladed members 215 formed thereon and disposed radially thereabout,
and the second stabilizing member 213 includes a plurality of
bladed members 217 formed thereon and disposed radially thereabout.
In such an embodiment, the bladed members 215 and 217 may be used
to engage and contact a wall of a borehole, thereby providing
stabilization to the downhole tool 201.
[0046] Further, the downhole tool 201 may include one or more
dampening members, e.g., disposed thereon and/or attached thereto.
More specifically, one or more of the stabilizing members 211 and
213 of the downhole tool 201 may include one or more dampening
members, e.g., disposed thereon and/or attached thereto. For
example, as shown in FIGS. 2A and 2B, the plurality of bladed
members 215 of the first stabilizing member 211 each includes a
dampening member 219 formed thereon. As used herein, a dampening
member refers to a member that may be configured to dampen
vibration (e.g., reduce vibration, movement, and/or energy), such
as by having the dampening member stabilize the downhole tool
against a borehole wall for dampening. As shown, though only the
first stabilizing member 211 includes a dampening member 219 in
FIGS. 2A and 2B, those having ordinary skill in the art will
appreciate that the second stabilizing member 213 may additionally
or alternatively include a dampening member in accordance with
embodiments disclosed herein.
[0047] The dampening member may be formed from any dampening
material and/or mechanism known in the art. For example, in FIGS.
2A and 2B, the bladed members 215 of the first stabilizing member
211 may include a dampening material, such as an elastomeric
material, in which the dampening material of the bladed members 215
may engage a borehole wall to provide stabilization to the downhole
tool 201, e.g., a dampening material on the outer surface of the
bladed members 215.
[0048] Further, in another embodiment, a stabilizing member of a
downhole tool in accordance with embodiments disclosed herein may
include a dampening member disposed within a stabilizing member.
For example, with reference to FIG. 2C, a detailed cross-sectional
view of a stabilizing member 211 in accordance with embodiments
disclosed herein is shown. In this embodiment, rather than having a
dampening member 219 formed upon the stabilizing member 211, the
dampening member 219 is disposed within the stabilizing member 211.
The dampening member 219 may still dampen vibration, such as dampen
vibration within the stabilizing member 211 when engaging a wall of
a borehole. Additionally, when disposing a dampening member upon
the downhole tool and within the stabilizing member, the dampening
member 219 may be fixed to the body section of the downhole tool,
or alternatively, the dampening member may be rotatable about the
body section of the downhole tool.
[0049] Furthermore, in accordance with one or more embodiments
disclosed herein, the downhole tool may additionally, or
alternatively, have a dampening member disposed within the body of
the downhole tool. More particularly, the downhole tool may have a
dampening member disposed within the downhole tool between the
first stabilizing member and the second stabilizing member. For
example, in one embodiment, the first stabilizing member may be
able to move along and/or about the axis of the tool with respect
to the second stabilizing member. As such, a dampening member may
be disposed between the first stabilizing member and the second
stabilizing member to dampen vibration therebetween. The dampening
member may include an elastomeric material, as described above, a
biasing mechanism (e.g., a spring), and/or any other dampening
material and/or mechanism known in the art. For example, the
dampening member may include a cavity, such as a fluid cavity, in
which the cavity may be used to dampen vibration received therein.
Those having ordinary skill in the art will also appreciate that a
dampening member may be disposed in other locations of a downhole
tool in accordance with embodiments disclosed herein with departing
from the scope of the present disclosure. For example, a downhole
tool having only one stabilizing member, rather than two
stabilizing members as shown in FIGS. 2A and 2B, may include a
dampening member disposed within the body of the downhole tool,
such as at the location or adjacent to the stabilizing member,
without departing from the scope of the present disclosure.
[0050] Furthermore still, one or more bladed members may include
one or more pads disposed thereon and/or attached thereto, thereby
providing protection for the stabilizing members. For example, in
FIGS. 2A and 2B, the bladed members 217 of the second stabilizing
member 213 may include a protection member, e.g., one or more pads
221 (a plurality of pads 221 as shown in this embodiment) disposed
thereon, e.g., in which the pads 221 may be used to engage the
borehole wall. In this embodiment, the pads 221 may provide
protection to the second stabilizing member 213, such as by
preventing, or assist in preventing, wear to the second stabilizing
member 213 when engaging a borehole wall. Those having ordinary
skill in the art will also appreciate that other protection members
may be added to one or more of the stabilizing members of a
downhole tool in accordance with embodiments disclosed herein
without departing from the present disclosure.
[0051] Referring now to FIG. 3A, a cross-sectional view of a
downhole tool 301 in accordance with embodiments disclosed herein
is shown. Similar to above, the downhole tool 301 includes a
tubular body 303 having a first body portion 307 and a second body
portion 309 with a first stabilizing member 311 and a second
stabilizing member 313 disposed thereon, respectively. The first
stabilizing member 311 may rotate with respect to the second
stabilizing member 313 about an axis 305 of the downhole tool
301.
[0052] Further, a downhole tool in accordance with embodiments
disclosed herein may have a flexible member, such as by having a
flexible member disposed therein. With reference to FIG. 3A, the
downhole tool 301 includes a flexible member 331, in which the
flexible member 331 may be disposed within the tubular body 303.
For example, as shown, the flexible member 331 may be disposed
particularly within the second body portion 309 of the downhole
tool 301. FIG. 3B provides a detailed perspective view of the
flexible member 331 shown in FIG. 3A. The flexible member 331 may
enable the first stabilizing member 311 to flex (e.g., bend) along
the axis 305 of the downhole tool 301 with respect to the second
stabilizing member 313.
[0053] In the embodiment shown in FIGS. 3A and 3B, the second body
portion 309 may include a first body member 323 and a second body
member 325, in which the flexible member 331 may be disposed within
the second body portion 309 between the first body member 323 and
the second body member 325. As such, the flexible member 331 may
enable the first body member 323 and the second body member 325 to
flex (e.g., bend) with respect to each other along the axis 305,
thereby enabling the first stabilizing member 311 and the second
stabilizing member 313 to rotate with respect to each other along
the axis 305. Particularly, in one or more embodiments, the
flexible member 331 may enable the first body member 323 and the
second body member 325 to flex across substantially 360 degrees
about the axis 305 with respect to each other. For example, the
first body member 323 may flex in substantially every direction
about the axis 305 with respect to the second body member 325.
However, those having ordinary skill in the art will appreciate
that the embodiments disclosed herein are not so limited, in which
other flexible members may be used with departing from the scope of
the present disclosure.
[0054] A flexible member in accordance with embodiments disclosed
herein may include and/or be formed from a flexible material. For
example, in FIGS. 3A and 3B, the flexible member 331 may include an
elastomeric material 337, in which the elastomeric material may
allow the downhole tool 301 to flex along the axis 305. The
elastomeric material 337 may be disposed in one or more locations
within the flexible member 331. For example, as shown in FIG. 3B,
the elastomeric material 337 may be disposed adjacent to the first
body member 323 and the second stabilizing member 313, in which the
second stabilizing member 313 is attached to the second body member
325. Further, elastomeric material 340 may also be disposed
adjacent to teeth 339 of the flexible member 331. As such, the
elastomeric material 337 may allow the flexible member 331, and,
thus, the downhole tool 301, to flex along the axis 305 thereof.
Additionally, the elastomeric material 337 may be used to provide
support (e.g., to dampen) in the axial and/or radial direction of
the flexible member 331 with respect to the axis 305 of the
downhole tool 301. Those having ordinary skill in the art, however,
will appreciate that other flexible materials and/or locations of
the flexible materials may be used within the flexible member in
FIGS. 3A and 3B without departing from the scope of the present
disclosure. For example, as shown in FIG. 3B, the flexible member
331 may include elastomeric material 338 disposed at the lower end
of the flexible member with departing from the scope of the present
disclosure.
[0055] The dampening of flexure, e.g., dampening of the flexure in
flexible member 331 by elastomeric material 337, 338, and/or 340,
e.g., the elastomeric material 337 radially disposed about axis 305
of the downhole tool 301, as depicted, may abate vibration, e.g.,
abate vibration transmitted across the flexible member 331. As
discussed above, elastomeric material may also be utilized to
dampen axial movement, e.g., an axial dampening member. For
example, elastomeric material may be disposed between axially
spaced components to dampen axial vibration.
[0056] The teeth 339 of the flexible member 331 may be used to
translate torque from the first body member 323 to the second body
member 325, such as by having the teeth 339 engage recesses formed
within an inner surface of the second stabilizing member 313, or
vice versa. Teeth 339 may have an arcuate and/or rounded surface
formed thereon, as shown in FIG. 3B, in which the teeth 339 may
enable the flexing within the flexible member 331 between the first
body member 323 and the second body member 325.
[0057] Further, the flexible member within the downhole tool of the
present disclosure may include a straightening member disposed
therein, in which the straightening member may be used to provide
rigidity (e.g., restoring force) within the flexible member. For
example, as shown in FIGS. 3A and 3B, the flexible member 331 may
include a straightening member 335 disposed within the downhole
tool 401. In this embodiment, the straightening member 335 is a
spring beam formed as a tubular member, in which the straightening
member 335 extends from the first body member 323 to the second
body member 325 of the second body portion 309 and enables fluid
flow therebetween. However, those having ordinary skill in the art
will appreciate that another straightening member may used within
the downhole tool to provide rigidity to the flexible member of the
downhole tool without departing from the scope of the present
disclosure.
[0058] Furthermore, those having ordinary skill in the art will
appreciate that other flexible members may used within the downhole
tool to enable a rotation of the stabilizing members with respect
to each other along the axis of the downhole tool without departing
from the scope of the present disclosure. For example, in another
embodiment, one or more swivels, joints, intersections for flexure
and/or other flexible members may be included within a downhole
tool in accordance with embodiments disclosed herein to provide
flexing of the tubular body along the axis of the downhole. For
example, downhole tools having a flexible member and/or a flexible
joint may include those described in U.S. Pat. Nos. 6,945,338 and
7,216,726, which are each incorporated herein by reference in their
entirety.
[0059] The flexible member within the downhole tool of the present
disclosure may provide a point of flexure, in which the point of
flexure provides articulation along the axis of the downhole tool.
As such, in one or more embodiments, the point of flexure for the
flexing member is disposed between or at the location of the
stabilizing members of the downhole tool. For example, as shown in
FIG. 3A, the point of flexure 333 of the flexible member 331 is
disposed at about the location of the second stabilizing member
313. However, those having ordinary skill in the art will
appreciate that the point of flexure may also be disposed at about
the location of the first stabilizing member 311, or a location
between the first stabilizing member 311 and the second stabilizing
member 313, without departing from the scope of the present
disclosure. Additionally, while the term "point of flexure" may be
understood to mean a single location along the axis of the downhole
tool, it should be understood that the flexure of flexible member
331 may occur over a region. For example, flexible member 331 may
be characterized as having a point of flexure that is distributed
along a selected axial length of the downhole tool rather than a
single "point" location.
[0060] Referring now to FIG. 4, a perspective view of a downhole
tool 401 disposed within a string of tubular members 441 in
accordance with embodiments disclosed herein is shown. In this
embodiment, the downhole tool 401, having a first stabilizing
member 411 and a second stabilizing member 413 with a flexible
member 431 disposed therein, is attached to and connected within
the string of tubular members 441. As shown, the string of tubular
members 441 may include a lower bottom hole assembly 443 and an
upper bottom hole assembly 445. As such, the string 441 may be used
as a drill string, e.g., in which the lower bottom hole assembly
443 includes a drill bit 447 disposed at an end thereof. It should
be understood that the use of terms "upper" and "lower" is
arbitrary in referring to components of the drill string (and
bottom hole assembly). However, by convention, "upper" typically
refers to a location placed farther away from the drill bit than a
"lower" location.
[0061] While it should be understood that any variety of drill
collars, stabilizers, transducers, measurement-while-drilling
tools, logging-while-drilling tools, downhole motors (e.g., mud
motors), or any combination thereof may be located within either
the upper 445 or lower 443 bottom hole assemblies, typically, a
lower bottom hole assembly 443 includes drilling components (e.g.,
mud motors, air drilling hammers, etc.) that may be used to
facilitate drilling and the upper bottom hole assembly 445 includes
ancillary components (e.g., transducers, measurement-while-drilling
tools, logging-while drilling tools, etc).
[0062] As discussed above, a downhole tool in accordance with
embodiments disclosed herein may be disposed downhole within a
borehole, in which the downhole tool may be used to stabilize, or
assist in stabilizing, one or more tubular members and/or other
downhole tools disposed within the borehole. For example, with
reference to FIG. 4, the downhole tool 401 and the string of
tubular members 441 may be disposed downhole to drill within and/or
form a borehole within a formation. The string of tubular members
441 may be disposed downhole, in which the drill bit 447 may
rotated with respect to the borehole to drill at the bottom of the
borehole. Drill bit 447 may be rotated by the rig (e.g., top drive
or rotary table) and/or downhole motor. During drilling, the first
stabilizing member 411 and second stabilizing member 413 may be
used to stabilize the downhole tool 401 and the string 441, such as
by engaging a wall of the borehole. Particularly, in this
embodiment shown, the downhole tool 401 may have at least two
points-of-contact to engage the wall of the borehole, in which one
point-of-contact 451 may be established by the first stabilizing
member 411 engaging the wall of the borehole, and another axially
spaced point-of-contact 453 may be established by the second
stabilizing member 413 engaging the wall of the borehole. The
points-of-contact with the wall of the borehole may be used to
stabilize, or assist in stabilizing, the string of tubular members
441 and drill bit 447. Additionally, while the term
"point-of-contact" may be understood to mean a single location
along the surface of a stabilizing member of the downhole tool that
engages the wall of the borehole, it should be understood that the
contact of a stabilizing member may occur over a region. For
example, the first stabilizing member 411 and/or the second
stabilizing member 413 may be characterized as having a
point-of-contact with the wall of the borehole that is distributed
along a selected radial section of the downhole tool, rather than a
single location with the first stabilizing member 411 and/or the
second stabilizing member 413.
[0063] Flexible member 431 may be used to provide flexure (e.g.,
bending) along an axis of the downhole tool 401, thereby enabling
the first stabilizing member 411 and the second stabilizing member
413 to also flex along the axis. As such, depending on the
direction and/or force used by the drill bit 447 to drill, one or
both of the first stabilizing member 411 and the second stabilizing
member 413 may engage the borehole wall. The first stabilizing
member 411 and the second stabilizing member 413 may also provide
additional control for the string 441, such as by dampening
vibration and/or flexure within the string 441. For example, the
flexible member 431 may have a dampening member disposed therein,
in which the flexible member 431 may be used to dampen vibration.
As such, the flexible member 431 may be used to dampen vibration
between the first stabilizing member 411 and the second stabilizing
member 413 within the downhole tool 401 and other portions of the
string 441, in addition to providing flexure between the first
stabilizing member 411 and the second stabilizing member 413 within
the downhole tool 401 and other portions of the string 441.
[0064] For example, during use of the string 441 downhole, the
drill bit 447 may be used to form and/or extend a borehole
downhole. During this use of the string 441, the drill bit 447 may
generate vibration from the drilling within the earth formation. As
such, the vibration generated by the drill bit 447 may propagate
along the string 441, such as through the lower bottom hole
assembly 443, and into the downhole tool 401. To stabilize the
string 441, one or both of the stabilizing members 411 and 413 may
be used to engage the wall of the borehole, in which vibration
received by the stabilizing members 411 and 413 may be dampened
against the wall of the borehole. The vibration that has propagated
into and through the lower bottom hole assembly 443 may be dampened
using the downhole tool 401, thereby reducing and/or insulating
altogether the vibration the upper bottom hole assembly 445 may
receive. As such, the downhole tool 401 may dampen the vibration
received by the upper bottom hole assembly 445. Further, to
additionally dampen vibration, the downhole tool 401 may include a
dampening member (as discussed above). During use of the string
441, the dampening member may additionally dampen vibration within
the downhole tool 401 to reduce and/or insulate altogether the
vibration the upper bottom hole assembly 445 may receive.
[0065] Furthermore, as mentioned above, at least one or both of the
first stabilizing member 411 and the second stabilizing member 413
may be able to rotate about the axis of the downhole tool 401 with
respect to the tool mandrel (e.g., be rotationally geostationary
relative to the borehole). The first stabilizing member 411 may be
rotatable with respect to the second stabilizing member 413, and
vice-versa, or, in an embodiment having only one of the stabilizing
members (e.g., 411 and 413), the body 403 of tool 401. A motor may
be disposed within the string 441, such as within the lower bottom
hole assembly 443. A motor may rotate the drill bit 447 and may
also rotate the remainder of the lower bottom hole assembly (e.g.,
if a motor is disposed within the lower bottom hole assembly 443)
and/or the second stabilizing member 413, e.g., if a stabilizing
member is rotationally fixed to the tool 401. However, because of
the enabled rotation about the axis of the downhole tool 401
between the first stabilizing member 411 and the second stabilizing
member 413, the first stabilizing member 411 may rotate at a slower
rate with respect to the second stabilizing member 413, or the
first stabilizing member 411 may remain substantially rotationally
stationary with respect to the borehole while the second
stabilizing member 413 is rotating with the lower bottom hole
assembly 413. As such, the first stabilizing member 411 may remain
rotationally stationary during engagement and stabilization with
the wall of the borehole, while the second stabilizing member 413
rotates during engagement and stabilization with the wall of the
borehole. Additionally, in an embodiment in which both the first
stabilizing member 411 and the second stabilizing member 413 may be
able to rotate about the axis of the downhole tool 401, the first
stabilizing member 411 and the second stabilizing member 413 may
remain substantially rotationally stationary with respect to the
borehole while the lower bottom hole assembly 443 is rotating. In
such an embodiment, both the first stabilizing member 411 and the
second stabilizing member 413 may remain rotationally stationary
during engagement and stabilizing with the wall of the
borehole.
[0066] Referring now to FIG. 5, a cross-sectional view of a
downhole tool 501 in accordance with embodiments disclosed herein
is shown. Similar to above, the downhole tool 501 includes a
tubular body 503 having a first body portion 507 and a second body
portion 509 with a first stabilizing member 511 and a second
stabilizing member 513 disposed thereon, respectively. The first
stabilizing member 511 may rotate with respect to the second
stabilizing member 513 about an axis 505 of the downhole tool
501.
[0067] Further, as shown and similar to the embodiments above, the
downhole tool 501 includes a flexible member 531. However, in this
embodiment, rather than having the flexible member 531 disposed at
about the location of the second stabilizing member 513, the
flexible member 531 is disposed between the first stabilizing
member 511 and the second stabilizing member 513. Particularly, the
depicted flexible member 531 is disposed substantially the same
distance from the first stabilizing member 511 and the second
stabilizing member 513. As mentioned above, though, those having
ordinary skill in the art will appreciate that the location of the
flexible member within the downhole tool is not so limited, as the
flexible member may be disposed at any of the multiple locations
within the downhole tool (e.g., at any location between the first
and second stabilizing members, at the location of the first
stabilizing member, or at a location outside of the section between
the first and second stabilizing members) without departing from
the scope of the present disclosure.
[0068] Additionally, as shown, the flexible member 531 may have an
outer diameter substantially the same as an outer diameter of the
remainder of the tubular body of the downhole tool, as depicted,
excluding the diameter of the stabilizing members. As such, the
flexible member 531 may have an outer diameter that is smaller than
an outer diameter of the first stabilizing member 511 and/or the
second stabilizing member 513. However, those having ordinary skill
in that art will appreciate that the diameter of the flexible
member may be selected from any of the multiple diameters available
within a downhole tool without departing from the scope of the
present disclosure.
[0069] Referring now to FIG. 6, a cross-sectional view of a
downhole tool 601 in accordance with embodiments disclosed herein
is shown. Similar to the above embodiments, the downhole tool 601
includes a tubular body 603. Further, the downhole tool 601
includes a drill bit 661 disposed at an end thereof, in which the
drill bit 661 may be used to drill to form, enlarge, and/or remove
earth and/or other material within a borehole. As such, in this
embodiment, the downhole tool 601 may include a flexible member
631, in which the flexible member 631 may have substantially the
same outer diameter as the tubular body 603. Furthermore, the
downhole tool 601 may include another drill bit 663, in which the
drill bit 663 may be included and/or attached to the downhole tool
601 adjacent to the flexible member 631.
[0070] In the embodiment shown in FIG. 6, and as discussed above,
the drill bit 661 may be a milling tool, in which the drill bit 661
may be used to mill within a borehole when drilling. Further, the
drill bit 663 may be a milling tool and/or a reamer, in which the
drill bit 663 may be used to also mill within the borehole when
drilling. Accordingly, a downhole tool in accordance with
embodiments disclosed herein may include one or more drill bits
and/or drilling tools, in which the drill bits and/or drilling
tools may be one of a number of different tools, devices, and/or
components, as discussed above.
[0071] In FIG. 6, a deflector 671 is shown disposed within the
borehole. The deflector 671, which may also be a diverter, a
whipstock, and/or may include a concave surface for receiving the
downhole tool 601, may be used to deflect the downhole tool 601
when contacting the deflector 671. The angle of deflection may
vary, but the deflector 671 may be used to deflect the drill bit
661 of the downhole tool 601 when in contact, and thereby deflect
the trajectory of the downhole tool 601 such that the downhole tool
601 may be used to drill through casing 691 within the borehole and
drill within the formation. As such, the flexible member 631 may be
used to provide flexure and/or dampen vibration when using the
downhole tool 601, particularly when drilling through the casing
691 and into the formation.
[0072] Referring now to FIG. 7, a cross-sectional view of a
downhole tool 701 in accordance with embodiments disclosed herein
is shown. The downhole tool 701 may include a drill bit 761
disposed at an end thereof, in which the drill bit 761 may be used
to drill to form, enlarge, and/or remove earth and/or other
material within a borehole. Further, the downhole tool 701 may
include a flexible member 731, in which the flexible member 731 may
be used to provide flexure and/or dampen vibration when using the
downhole tool 701.
[0073] Further, as shown in FIG. 7, equipment 773 may be disposed
downhole within the borehole. The equipment 773, which may include
a packer, a bridge plug, a wellbore flow control device, a wellbore
isolation device, a tubular member, and/or any other type of
equipment that may be disposed downhole within a borehole, may be
impeding the performance of the well including the borehole. As
such, the downhole tool 701 may be used to drill through the
equipment 773, such as mill through the equipment 773, thereby
removing the equipment 773 from the borehole. Accordingly, a
downhole tool in accordance with one or more embodiments disclosed
herein may be used to mill to remove equipment from a borehole, in
which the flexible member of the tool may be used to provide
flexure and/or dampen vibration when using the downhole tool,
particularly when drilling through the equipment disposed
downhole.
[0074] Referring now to FIG. 8, a cross-sectional view of a
downhole tool 801 in accordance with embodiments disclosed herein
is shown. The downhole tool 801 may include a drill bit 861
disposed at an end thereof. Further, the downhole tool 801 may
include a stabilizing member 811 and/or a flexible member 831. The
stabilizing member 811 may be used to provide stability when using
the downhole tool 801, and the flexible member 831 may be used to
provide flexure and/or dampen vibration when using the downhole
tool 801.
[0075] As such, in this embodiment, the downhole tool 801 may be
used to drill through the equipment 873, such as mill through the
equipment 873, to remove the equipment 873 from the borehole.
Accordingly, a downhole tool in accordance with one or more
embodiments disclosed herein may be used to mill to remove
equipment from a borehole, in which the stability member and the
flexible member of the tool may be used to provide stability,
flexure and/or dampen vibration when using the downhole tool,
particularly when drilling through the equipment disposed
downhole.
[0076] Referring now to FIG. 9, a cross-sectional view of a
downhole tool 901 in accordance with embodiments disclosed herein
is shown. The downhole tool 901 may include a drill bit 961
disposed at an end thereof, and may further include a flexible
member 931. Equipment 973 may also be disposed downhole within the
borehole. The equipment 973, in this embodiment, may include a
tubular member disposed downhole within the borehole. As such, the
downhole tool 901 may be used to drill through the equipment 973,
such as mill through the equipment 973, thereby removing the
equipment 973 from the borehole. Accordingly, a downhole tool in
accordance with one or more embodiments disclosed herein may be
used to mill to remove equipment from a borehole, in which the
flexible member of the tool may be used to provide flexure and/or
dampen vibration when using the downhole tool, particularly when
drilling through the equipment disposed downhole.
[0077] Referring now to FIG. 10, a cross-sectional view of a
downhole tool 1001 in accordance with embodiments disclosed herein
is shown. The downhole tool 1001 may include a drill bit 1061
disposed at an end thereof, and may further include a stabilizing
member 1011 and/or a flexible member 1031. The stabilizing member
1011 may be used to provide stability when using the downhole tool
1001, and the flexible member 1031 may be used to provide flexure
and/or dampen vibration when using the downhole tool 1001. As
discussed above, the downhole tool 1001 may be used to drill
through the equipment 1073 to remove the equipment 1073 from the
borehole. Accordingly, a downhole tool in accordance with one or
more embodiments disclosed herein may be used to mill to remove
equipment from a borehole, in which the stability member and the
flexible member of the tool may be used to provide stability,
flexure and/or dampen vibration when using the downhole tool,
particularly when drilling through the equipment disposed
downhole.
[0078] Referring now to FIG. 11, a cross-sectional view of a
downhole tool 1101 in accordance with embodiments disclosed herein
is shown. The downhole tool 1101 includes a tubular body 1103 with
a drill bit 1161 disposed at an end thereof. The downhole tool 1101
may further include a first stabilizing member 1111, a second
stabilizing member 1113, and/or a flexible member 1131. The
stabilizing members 1111 and 1113 may be used to provide stability
when using the downhole tool 1101, such as when drilling with the
downhole tool 1101. Further, the flexible member 1131 may be used
to provide flexure and/or dampen vibration when using the downhole
tool 1101. As such, the downhole tool 1101 may be used to drill
through the equipment 1173 to remove the equipment 1173 from the
borehole.
[0079] As shown in FIG. 11, the first stabilizing member 1111 may
be able to rotate, such as about an axis of the downhole tool 1101,
with respect to the second stabilizing member 1113. For example,
the second stabilizing member 1113 may be able to rotate with
respect to the tubular body 1103 of the downhole tool 1101.
Accordingly, when drilling with the downhole tool 1101, the second
stabilizing member 1113 may remain rotationally stationary and/or
rotate independently of the first stabilizing member 1113 if the
first stabilizing member 1111 rotates during the drilling with the
downhole tool 1101. Accordingly, a downhole tool in accordance with
one or more embodiments disclosed herein may include one or more
stabilizing members, one or more flexible members, and/or one or
more drill bits included therewith.
[0080] Similar to FIG. 11, FIG. 12 shows a cross-sectional view of
a downhole tool 1201 in accordance with embodiments disclosed
herein. As with the above embodiments, the downhole tool 1201
includes a drill bit 1261 disposed at an end thereof and further
includes a first stabilizing member 1211, a second stabilizing
member 1213, and/or a flexible member 1231. The stabilizing members
1211 and 1213 may be used to provide stability when using the
downhole tool 1201, and the flexible member 1231 may be used to
provide flexure and/or dampen vibration. As such, the downhole tool
1201 may be used to drill through the equipment 1273 to remove the
equipment 1273 from the borehole. Further, the first stabilizing
member 1211 may be able to rotate, such as about an axis of the
downhole tool 1201, with respect to the second stabilizing member
1213. Accordingly, a downhole tool in accordance with one or more
embodiments disclosed herein may be used to mill to remove
equipment from a borehole, in which the stability member and the
flexible member of the tool may be used to provide stability,
flexure and/or dampen vibration when using the downhole tool,
particularly when drilling through the equipment disposed
downhole.
[0081] It should also be understood that the present disclosure
contemplates having other structures and/or arrangements for a
downhole tool to stabilize a string of tubular members within a
borehole. As shown in the above embodiments, the downhole tool
includes two stabilizing members. However, in another embodiment,
more than two stabilizing members may be used within the downhole
tool. Further, the downhole tool may include more than one flexible
member, or the flexible member may be disposed at different
locations and/or have different arrangements than as shown and
discussed above. It should also be understood that the present
disclosure contemplates a method to dampen a downhole assembly
while drilling (including reaming, etc.). In particular, a downhole
tool may be disposed in a borehole and may include a first
stabilizing member, a second stabilizing member, and a flexible
member. The method may include flexing the flexible member such
that the first or the second (if present) stabilizing member
contacts the wall of the bore hole and dampens remaining components
of the drill string, bottom hole assembly, or drill bit.
[0082] Embodiments disclosed herein may provide for one or more of
the following advantages. First, embodiments disclosed herein may
provide for a downhole tool that may be connected within a string
of tubular members disposed downhole, in which the downhole tool
may engage one or more surfaces of the borehole. When engaging the
surfaces of the borehole, the downhole tool may dampen vibration
(e.g., reduce vibration) received by the downhole tool. As such,
the downhole tool may prevent damage to the tubular members and/or
other downhole tools disposed downhole within a borehole and/or
attached to a tubular string. Further, embodiments disclosed herein
provide for a downhole tool that may include at least two
stabilizing members. In such embodiments, each of the stabilizing
members may provide a point-of-contact with a borehole wall,
thereby providing additional control and direction to a string of
tubular members, such as during drilling.
[0083] While the present disclosure has been described with respect
to a limited number of embodiments, those skilled in the art,
having benefit of this disclosure, will appreciate that other
embodiments may be devised which do not depart from the scope of
the disclosure as described herein. Accordingly, the scope of the
invention should be limited only by the attached claims.
* * * * *