U.S. patent application number 12/752349 was filed with the patent office on 2011-10-06 for drill bit jack element with a plurality of inserts.
Invention is credited to Scott Dahlgren, David R. Hall, Jonathan Marshall.
Application Number | 20110240377 12/752349 |
Document ID | / |
Family ID | 44708309 |
Filed Date | 2011-10-06 |
United States Patent
Application |
20110240377 |
Kind Code |
A1 |
Hall; David R. ; et
al. |
October 6, 2011 |
Drill Bit Jack Element with a Plurality of Inserts
Abstract
In one aspect of the present invention, a drill bit has an axis
of rotation and drill bit body intermediate a threaded end and a
working face. The drill bit body houses a jack element protruding
from the drill bit body and the jack element has a plurality of
inserts disposed on the indenting end.
Inventors: |
Hall; David R.; (Provo,
UT) ; Dahlgren; Scott; (Alpine, UT) ;
Marshall; Jonathan; (Provo, UT) |
Family ID: |
44708309 |
Appl. No.: |
12/752349 |
Filed: |
April 1, 2010 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
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12752323 |
Apr 1, 2010 |
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12752349 |
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Current U.S.
Class: |
175/426 |
Current CPC
Class: |
E21B 4/02 20130101; E21B
47/024 20130101; E21B 47/12 20130101; E21B 4/06 20130101; E21B
10/62 20130101 |
Class at
Publication: |
175/426 |
International
Class: |
E21B 10/46 20060101
E21B010/46 |
Claims
1. A drill bit, comprising: an axis of rotation and drill bit body
intermediate a threaded end and a working face; the drill bit body
housing a jack element protruding from the drill bit body; the jack
element comprising a plurality of pointed inserts disposed on an
indenting end; and at least one of the pointed inserts of the
plurality comprises a central axis that is less than 25 degrees
away from parallel with the axis of rotation.
2. The drill bit of claim 1, wherein the plurality of inserts is
disposed primarily on one half of the indenting end.
3. (canceled)
4. The drill bit of claim 1, wherein the plurality of inserts are
attached to the jack element through a braze.
5. The drill bit of claim 1, wherein the plurality of inserts are
attached to the jack element through a press fit.
6. The drill bit of claim 1, wherein the plurality of inserts
comprises a flat ground portion, the flat ground portion disposed
collinearly with an outer circumference of the jack element.
7. The drill bit of claim 1, wherein the jack element is
substantially aligned along the axis of rotation.
8. The drill bit of claim 1, wherein the jack element comprises a
connection with a shaft, the shaft disposed intermediate the
indenting end and a gearbox.
9. The drill bit of claim 8, wherein the gearbox is in mechanical
communication with a generator such that the generator powers the
gearbox.
10. The drill bit of claim 8, wherein the connection is a rotary
spline such that the shaft may oscillate axially within the jack
element.
11. The drill bit of claim 8, wherein the shaft is in mechanical
communication with a piston, the piston circumferentially disposed
around the shaft and slidably connected to the shaft.
12. The drill bit of claim 11, wherein a first piston end and a
second piston end are selectively in fluid communication with a
drilling mud flow such that the piston is actuated axially along
the shaft according to which end of the piston is in fluid
communication with the drilling mud flow.
13. The drill bit of claim 8, wherein as the shaft is rotated, the
jack element may also be rotated to a desired position within the
drill bit through the connection.
14. The drill bit of claim 11, wherein the piston comprises a first
contact surface, the first contact surface comprising a super hard
material.
15. The drill bit of claim 14, wherein the jack element comprises a
second contact surface, the second contact surface comprising a
super hard material.
16. The drill bit of claim 11, wherein the drill bit comprises a
valve which selectively allows a drilling mud flow to contact the
piston.
17. (canceled)
18. (canceled)
19. (canceled)
20. (canceled)
21. The drill bit of claim 1, wherein the working face comprises at
least one face cutter that extends at least as far from the bit
body as the inserts of indenting end of the jack element.
22. The drill bit of claim 1, wherein the plurality of inserts may
include a central insert disposed substantially in the center of
the indenting end and inserts surrounding the central insert.
23. The drill bit of claim 1, wherein the jack element is
configured to move while simultaneously rotating.
24. The drill bit of claim 1, wherein the shaft is configured to
rotate the jack element such that as the tool string component
rotates, the shaft and jack element rotate in an opposite
direction, leaving the jack element stationary in relation to the
formation.
25. The drill bit of claim 1, wherein the jack element is
configured to bias the tool string in a desired direction.
Description
CROSS REFERENCE TO RELATED APPLICATIONS
[0001] This application is a continuation of U.S. patent
application Ser. No. 12/752,323, which was filed on Apr. 1, 2010
and is herein incorporated by reference for all that it
contains.
BACKGROUND OF THE INVENTION
[0002] This invention relates to the field of subterranean
drilling. Typically, downhole hammers are used to affect periodic
mechanical impacts upon a drill bit. Through this percussion, the
drill string is able to more effectively apply drilling power to
the formation, thus aiding penetration into the formation.
BRIEF SUMMARY OF THE INVENTION
[0003] In one aspect of the present invention, a drill bit has an
axis of rotation and drill bit body intermediate a threaded end and
a working face. The drill bit body houses a jack element protruding
from the drill bit body and the jack element has a plurality of
inserts disposed on the indenting end.
[0004] The plurality of inserts may be disposed primarily on one
half of the indenting end. The plurality of inserts may be evenly
distributed across the indenting end. The plurality of inserts may
be attached to the jack element through a braze. The plurality of
inserts may be attached to the jack element through a press fit.
The plurality of inserts may comprise a flat ground portion, the
flat ground portion disposed collinearly with an outer
circumference of the jack element.
[0005] The jack element may be substantially aligned along the axis
of rotation. The jack element may comprise a connection with a
shaft disposed intermediate the indenting end and a gearbox. The
gearbox may be in mechanical communication with a generator such
that the generator powers the gearbox. The connection may be a
rotating spline such that the shaft may oscillate axially within
the jack element.
[0006] The shaft may be in mechanical communication with a piston,
the piston circumferentially disposed around the shaft and slidably
connected to the shaft. A first piston end and a second piston end
may be selectively in fluid communication with a drilling mud flow
such that the piston is actuated axially along the shaft according
to which end of the piston is in fluid communication with the
drilling mud flow. As the shaft is rotated, the jack element may
also be rotated to a desired position within the drill bit through
the connection. The piston may comprise a first contact surface,
the first contact surface comprising a super hard material. The
jack element may comprise a second contact surface, the second
contact surface comprising a super hard material.
[0007] The drill bit may comprise a valve which selectively allows
a drilling mud flow to contact the piston. The shaft may be
substantially collinear with the axis of rotation. The plurality of
inserts on the indenting end may be evenly spaced along an insert
cutting profile. The insert cutting profile may comprise a pattern,
the pattern comprising overlapping cutting inserts. The plurality
of inserts may comprise an axis, the axis being at most 25 degrees
away from parallel with the axis of rotation.
[0008] In another aspect of the present invention, a tool string
component has an axis of rotation and a drill bit body intermediate
a threaded end and a working face. The drill bit body houses a jack
element protruding from the working face. A shaft is rotationally
connected and intermediate the jack element and a torque generating
device. A torque generating device is connected to a porting
assembly that causes a piston to move the jack element along a
central axis of the shaft and independently of the drill bit
body.
[0009] The piston may comprise a friction resistant surface
disposed on an inner diameter. The piston may be disposed within a
substantially pressure-sealed cylinder. The pressure-sealed
cylinder may comprise a first and second exhaust port such that a
fluid within the pressure-sealed cylinder may be evacuated. The
pressure-sealed cylinder may comprise a friction resistant surface.
The shaft may comprise a friction resistant surface disposed on at
least a portion of an outer diameter.
[0010] The porting assembly may comprise a first and a second
rotatable disk comprising a plurality of holes which when rotated,
may allow a drilling fluid to pass through the plurality of holes.
The porting assembly may comprise a multi-way valve which regulates
the flow of a drilling fluid. The porting assembly may be in
mechanical communication with the shaft such that the porting
assembly may be rotated by the shaft. The torque generating device
may be a generator. The generator may comprise a signal sent to an
electronic processing device disposed within the component. A
position feedback sensor may be disposed within the component and
in electrical connection with the electronic processing device. The
torque generating device may be a turbine.
[0011] The piston may be disposed circumferentially around the
shaft such that the shaft and piston share a slidable connection.
The shaft may be rotationally connected to the jack element through
a spline connection. The jack element may comprise an angled
portion disposed on an indenting end of the jack element. The shaft
may be substantially collinear with the axis of rotation. The
porting assembly may divert a fluid flow to a first piston end or a
second piston end. The electronic processing device may be in
electrical communication with a direction and inclination tool. The
electronic processing device may be part of a downhole telemetry
network.
BRIEF DESCRIPTION OF THE DRAWINGS
[0012] FIG. 1 is a cross-sectional diagram of an embodiment of a
tool string suspended in a borehole.
[0013] FIG. 2 is a cross-sectional diagram of an embodiment of a
tool string component.
[0014] FIG. 3 is a perspective diagram of an embodiment of a
portion of a tool string component.
[0015] FIG. 4a-b are cross-sectional diagrams of embodiments of a
portion of a tool string component.
[0016] FIG. 5a-b are perspective diagrams of embodiments of a
porting assembly.
[0017] FIG. 6 is a perspective diagram of an embodiment of a spline
connection on a shaft.
[0018] FIG. 7a-c are perspective diagrams of embodiments of an
indenting end of a jack element.
[0019] FIG. 8 is a cross-sectional diagram of an embodiment of a
cutter profile.
[0020] FIG. 9 is a cross-sectional diagram of an embodiment of a
downhole tool string component.
[0021] FIG. 10 is a cross-sectional diagram of an embodiment of a
downhole telemetry network.
[0022] FIG. 11 is a cross-sectional diagram of an embodiment of a
piston in a downhole tool string component.
[0023] FIG. 12 is a cross-sectional diagram of another embodiment
of a downhole tool string component.
DETAILED DESCRIPTION OF THE INVENTION AND THE PREFERRED
EMBODIMENT
[0024] FIG. 1 is a perspective diagram of an embodiment of a
downhole tool string 100 suspended by a derrick 108 in a bore hole
102. A drilling assembly 103 is located at the bottom of the bore
hole 102 and comprises a drill bit 104. As the drill bit 104
rotates downhole the downhole tool string 100 advances farther into
the earth. The downhole tool string 100 may penetrate soft or hard
subterranean formations 105. The drilling assembly 103 and/or
downhole components may comprise data acquisition devices which may
gather data. The data may be sent to the surface via a transmission
system to a data swivel 106. The data swivel 106 may send the data
to the surface equipment. Further, the surface equipment may send
data and/or power to downhole tools, the drill bit 104 and/or the
drilling assembly 103. The downhole tool string 100 may comprise a
downhole tool. The downhole tool may be selected from the group
consisting of drill pipe, drill collars, production pipe, and
reamers. The downhole tool string 100 may be subjected to downhole
drilling stresses as at least a portion of the weight of the drill
string 100 is placed on the drill bit 104. Those drilling stresses
may be compressive stresses, tensile stresses, and/or torque
stresses propagating through portions of the drill string 100.
[0025] FIG. 2 is a cross-sectional diagram of an embodiment of a
tool string component 200. The tool string component 200 may
comprise a drill bit 104 comprising a jack element 202 with an
indenting end 203. The indenting end 203 may comprise a plurality
of inserts 204 disposed in a pattern. The jack element 202 may be
in mechanical communication with a shaft 205. The jack element 202
and shaft 205 may be substantially collinear with an axis of
rotation 206 of the tool string component 200. The shaft 205 may
rotate the jack element 202. The shaft 205 may be disposed
intermediate a gearbox 207 and the jack element 202. The gearbox
207 may be in mechanical communication with a torque generating
device 208. The torque generating device 208 may be an electric
motor or fluid driven turbine. The torque generating device 208 may
rotate the shaft 205. The shaft 205 may be rotated in a clockwise
or counter clockwise direction and at a specific rotational
velocity while the tool string component 200 is rotated in the
opposite direction and the same rotational velocity as the shaft
205. This rotation configuration may leave the shaft 205 and jack
element 202 rotationally stationary with respect to the formation.
In some instances, the shaft 205 and the tool string component 200
may rotate in the same direction. In this case, the shaft 205 and
jack 202 may rotate with respect to the formation. The shaft 205
may also be in mechanical communication with a piston 210, the
piston 210 circumferentially disposed around the shaft 205 and
slidably connected to the shaft 205. The piston 210 may be disposed
intermediate the jack element 202 and the gear box 207.
[0026] FIG. 3 is a perspective diagram of an embodiment of a drill
bit 104. The jack element 202 can be seen in substantially the
center of the drill bit 104 and comprising a plurality of inserts
204. The jack element 202 may comprise an angled portion adapted to
bias the tool string 100 in a desired direction.
[0027] FIG. 4a-b are cross-sectional diagrams of embodiments of a
portion of a downhole tool string component 200. The piston 210 can
be seen proximate the jack element 202. The piston 210 may comprise
a first piston end 400 and a second piston end 401. The piston 210
may be disposed within a pressure-sealed cylinder 300. The
pressure-sealed cylinder 300 may comprise at least one exhaust port
301 such that drilling fluid entering the pressure-sealed cylinder
300 may be exhausted into a borehole when needed. The
pressure-sealed cylinder 300 may comprise a drilling mud under
pressure such that as the drilling mud contacts the first or second
end of the piston 400/401, the piston 210 may be biased. As the
piston 210 is biased, the piston 210 may contact the jack element
202. The jack element 202 may then contact a formation. The
drilling fluid may then be rerouted to the opposite end of the
piston 202 so as to bias the piston 202 in the opposite direction.
As the jack element 202 contacts the formation and retracts back
into the drill bit 104, the formation may be impacted. FIG. 4a
shows the piston 210 in an extended position while FIG. 4b shows
the piston 210 in a retracted position.
[0028] The shaft 205 within the tool component 200 may be in
mechanical communication with the jack element 202 through a
connection. The connection may be a rotary spline. The jack element
202 may slide axially along the shaft 205. The shaft 205 may rotate
the jack element 202 such that as the tool string component 200
rotates, the shaft 205 and jack element 202 rotate in an opposite
direction, leaving the jack element 202 stationary in relation to
the formation. An angled portion of the jack element 202 may guide
the drill bit 104 along a direction within the formation.
[0029] FIG. 5a-b are perspective diagrams of embodiments of a
porting assembly 550. The porting assembly 550 may comprise a first
and a second disc 298/299. During operation, the first disc and the
second disc 298/299 may be placed one on top of the other and
adapted to rotate. The first and second disc 298/299 may also
comprise a plurality of holes 292 such that as the porting assembly
550 is rotated, the plurality of holes 292 align and misalign. The
porting assembly may be in fluid communication with a fluid flow
within the tool string 100. As the plurality of holes align and
misalign, the fluid flow may be diverted to one or another channel
leading to an end of the piston chamber. As the flow reaches an end
of the chamber, the piston may be forced to move.
[0030] FIG. 6 is a perspective diagram of an embodiment of a rotary
spline connection 422 on a shaft 205. The rotary spline 422 may be
adapted to mechanically connect with a jack 202. As the jack 202 is
forced towards the formation by the piston 210 (shown in FIG. 4a)
the jack 202 may move along the rotary spline 422 while continuing
to rotate from the force of the shaft 205 on the rotary spline 422.
In this way, the jack 202 may move axially to impact the formation
while simultaneously rotating axially.
[0031] FIG. 7a-c are perspective diagrams of embodiments of an
indenting end of a jack element 202 that disclose possible cutter
insert arrangements. Generally, the cutter inserts may be brazed or
press-fit into the indenting end of the jack element 202. The
degrading end may comprise an angled portion adapted to bias the
jack element 202 in a specific direction. In the case of FIG. 7a,
the cutting inserts are disposed primarily on one side of the
indenting end whereas in FIG. 7c, the cutting inserts are disposed
substantially evenly on the indenting end. The plurality of inserts
may include a central insert disposed substantially in the center
of the indenting end and inserts surrounding the central insert.
FIG. 7c shows a plurality of inserts on an indenting end. In this
embodiment, as least one of the circumferentially spaced inserts
comprises a portion 625 ground with a radius that may substantially
match a radius of the jack element 202 and be disposed collinearly
with an outer circumference of the jack element 202. The central
axis of the circumferentially spaced inserts may be non-collinear
with the central axis of the jack element 202. Tilting the central
axis of the inserts may expand a cutting diameter determined by the
distance from the center of the jack element to the point of a
cutting insert. As the cutting insert is tilted, the distance
between the center of the jack element and the point of the cutting
insert may increase. FIG. 7b shows a plurality of cutting inserts
disposed on the outer circumference of the indenting end of the
jack element. One of the plurality of cutting inserts may be
disposed on an angled surface of the jack element. As the jack
element 202 is forced into the formation, the angle on the jack
element 202 may bias the direction of travel of the jack element
202 within the formation. Mounting an insert on the angled portion
of the jack element 202 may increase the life of the indenting end
and aid in the degradation of the formation.
[0032] FIG. 8 is a cross-sectional diagram of an embodiment of a
cutter profile 444 on a jack 202. The jack 202 may comprise a
plurality of inserts 204. The inserts 204 may be attached to the
jack 202 through a braze. The inserts 204 may also be attached to
the jack 202 through a press fit. The inserts 204 may be
substantially evenly spaced such that as the jack 204 contacts the
formation, the formation may evenly be degraded and/or an equal
portion of the formation may be contacted. As can be seen, the
cutter profile 444 may include inserts 204 which overlap. Thus, the
space between inserts 204 may vary leading to more closely spaced
or more distantly spaced inserts 204. The inserts 204 may be placed
on the jack 202 such that their central axis 488 is as much as 25
degrees away from vertical with reference to the axis of rotation
206 of the jack 202.
[0033] FIG. 9 is a cross-sectional diagram on an embodiment of a
portion of a downhole tool string 100. The downhole tool string 100
may comprise a Direction and Inclination package which will be
herein referred to as D & I. The D & I may be in electrical
communication with an electronic processing device 330 disposed on
the tool string 100. The D & I may evaluate the orientation of
the tool string 100 in relation to the Earth or other standard. The
electronic processing device 330 may also be in electrical
communication with a position sensor 331 disposed on or adjacent to
the shaft 205. The position sensor 331 may send the electronic
processing device 330 signals relating to the position of the shaft
205, and thus, the position of the jack 202. Electrical line 384
displays a connection between the position sensor 331 and
electronic processing device 330. Also, a generator 385 may be
electrically connected to the electronic processing device 331 such
that all incoming signals may be processed for use by a drilling
operator or for other purposes.
[0034] FIG. 10 discloses a downhole network 717 that may be used to
transmit information along a tool string 100. The network 717 may
include multiple nodes 718a-e spaced up and down a tool string 100.
The nodes 718a-e may be intelligent computing devices 718a-e, or
may be less intelligent connection devices, such as hubs or
switches located along the length of the network 717. Each of the
nodes 718 may or may not be addressed on the network 717. A node
718e may be located to interface with a bottom hole assembly 103
located at the end of the tool string 100. A bottom hole assembly
103 may include a drill bit, drill collar, and other downhole tools
and sensors designed to gather data and perform various tasks.
[0035] As signals from downhole tools are obtained, they may be
transmitted uphole or downhole using the downhole network 717. This
may assist downhole tools in communicating with each other. The
downhole network 717 may be in electrical communication with an
uphole computing device 728. The electronic processing device 331
and D&I may be in electrical communication with the downhole
network 717.
[0036] Transmitting the jack element's orientation signal to the
surface may allow drillers to make real time decisions and correct
drill string trajectories that are off of the desired path before
trajectory correction. In some embodiments, the signal may be
transmitted wirelessly to off site locations once the signal is at
the surface. Such an embodiment would allow drilling experts to
position themselves in a central location and monitor multiple
wells at once.
[0037] FIG. 11 displays a cross-sectional diagram of an embodiment
of a portion of a tool string component 100. The shaft 205 within
the tool string component 100 may comprise a super hard material
230 disposed on an outer diameter of the shaft 205 may provide an
increase in wear resistance. The piston 210 may also comprise a
super hard material 239. Additionally, the piston 210 may comprise
a super hard material 800 disposed on a contact end of the piston
210 adjacent to the jack 202 and the jack 202 may comprise a super
hard material 801 adjacent the piston 210 such that as the piston
210 contacts the jack 202, the super hard material from the piston
210 contacts the super hard material from the jack 202 contact each
other.
[0038] FIG. 12 discloses a cross-sectional diagram of another
embodiment of a portion of a tool string 100. The tool string 100
may comprise a shaft 205 comprising tabs 269. As the shaft 205
rotates, the tabs 269 rotate as well, contacting a multi-way valve
293. The first time the multi-way valve 293 is contacted, it may be
actuated to allow a fluid flow into a channel leading to a first
piston end 400. As the multi-way valve is actuated again, it may
allow the fluid flow into a different channel leading to the second
piston end 401.
[0039] 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.
* * * * *