U.S. patent application number 11/933954 was filed with the patent office on 2009-05-07 for expandable roller reamer.
This patent application is currently assigned to SMITH INTERNATIONAL, INC.. Invention is credited to Tommy Laird, Gail R. Nelson, David William Rodman.
Application Number | 20090114448 11/933954 |
Document ID | / |
Family ID | 40138175 |
Filed Date | 2009-05-07 |
United States Patent
Application |
20090114448 |
Kind Code |
A1 |
Laird; Tommy ; et
al. |
May 7, 2009 |
EXPANDABLE ROLLER REAMER
Abstract
An expandable downhole tool for use in a drilling assembly
positioned within a wellbore includes a tool body having an axial
flowbore extending therethrough and a moveable arm. The moveable
arm includes a roller structure including cutters and rotatably
mounted on the moveable arm. The moveable arm is configured to move
outwardly in response to actuation of the expandable downhole
tool.
Inventors: |
Laird; Tommy; (Cypress,
TX) ; Nelson; Gail R.; (Tomball, TX) ; Rodman;
David William; (Aberdeen, GB) |
Correspondence
Address: |
OSHA, LIANG LLP / SMITH
TWO HOUSTON CENTER, 909 FANNIN STREET, SUITE 3500
HOUSTON
TX
77010
US
|
Assignee: |
SMITH INTERNATIONAL, INC.
Houston
TX
|
Family ID: |
40138175 |
Appl. No.: |
11/933954 |
Filed: |
November 1, 2007 |
Current U.S.
Class: |
175/61 ;
175/265 |
Current CPC
Class: |
E21B 10/34 20130101 |
Class at
Publication: |
175/61 ;
175/265 |
International
Class: |
E21B 7/28 20060101
E21B007/28 |
Claims
1. An expandable downhole tool for use in a drilling assembly
positioned within a wellbore, the expandable downhole tool
comprising: a tool body comprising an axial flowbore extending
therethrough; and a moveable arm comprising a roller structure
comprising cutters and rotatably mounted on the moveable arm,
wherein the moveable arm is configured to move outwardly in
response to actuation of the expandable downhole tool.
2. The expandable downhole tool of claim 1, wherein the tubular
body comprises a plurality of angled channels formed within a
pocket of the tool body and configured to receive corresponding
angled extensions formed on the moveable arm, and wherein the
moveable arm translates along the plurality of angled channels.
3. The expandable downhole tool of claim 1, wherein the moveable
arm comprises a roller pin on which the roller structure is
rotatably fixed.
4. The expandable downhole tool of claim 3, wherein the moveable
arm comprises two roller mounts configured to hold opposing ends of
the roller pin onto the moveable arm.
5. The expandable downhole tool of claim 1, wherein the actuation
of the expandable downhole tool occurs in response to differential
pressure between the axial flowbore and the wellbore.
6. The expandable downhole tool of claim 1, wherein the cutters are
inserts.
7. The expandable downhole tool of claim 1, wherein the expandable
downhole tool is selectively actuatable to allow or prevent a fluid
flowing through the tubular body to translate the at least one
moveable arm between a collapsed position and an expanded
position.
8. The expandable downhole tool of claim 7, further comprising a
selectively actuatable sleeve that prevents or allows a
differential pressure to translate the at least one moveable arm
between a collapsed position and an expanded position.
9. The expandable downhole tool of claim 1, wherein the expandable
downhole tool comprises a plurality of moveable arms.
10. The expandable downhole tool of claim 9, wherein plurality of
moveable arms is spaced circumferentially apart around the tool
body.
11. A moveable arm for an expandable downhole tool, the moveable
arm comprising: a body; a roller structure comprising cutters and
rotatably mounted on the body, wherein the moveable arm is
configured be moveably received into a tool body of the expandable
downhole tool.
12. The moveable arm of claim 11, wherein the body comprises angled
extensions corresponding to angled channels formed in the tool
body.
13. The moveable arm of claim 11, further comprising: a roller pin
on which the roller structure is rotatably fixed.
14. The moveable arm of claim 13, further comprising: two roller
mounts configured to hold opposing ends of the roller pin onto the
body.
15. The moveable arm of claim 11, wherein the cutters are
inserts.
16. A method of underreaming a wellbore to form an enlarged
borehole, comprising: using a drill bit to drill the wellbore;
disposing an expandable underreamer above the drill bit; using the
expandable underreamer to enlarge the borehole; disposing an
expandable roller reamer above the first expandable underreamer,
wherein the expandable roller reamer comprises a moveable arm
comprising a roller structure comprising cutters and rotatably
mounted on the moveable arm; and actuating the expandable roller
reamer such that the cutters disposed on the roller structure
contact the enlarged borehole.
Description
BACKGROUND OF INVENTION
[0001] 1. Field of the Invention
[0002] The present disclosure relates to a roller reamer for
stabilizing a drillstring and reducing torque.
[0003] 2. Description of the Related Art
[0004] In the drilling of oil and gas wells, concentric casing
strings are installed and cemented in the borehole as drilling
progresses to increasing depths. Each new casing string is
supported within the previously installed casing string, thereby
limiting the annular area available for the cementing operation.
Further, as successively smaller diameter casing strings are
suspended, the flow area for the production of oil and gas is
reduced. Therefore, to increase the annular space for the cementing
operation, and to increase the production flow area, it is often
desirable to enlarge the borehole below the terminal end of the
previously cased borehole. By enlarging the borehole, a larger
annular area is provided for subsequently installing and cementing
a larger casing string than would have been possible otherwise.
Accordingly, by enlarging the borehole below the previously cased
borehole, the bottom of the formation can be reached with
comparatively larger diameter casing, thereby providing more flow
area for the production of oil and gas.
[0005] Various methods have been devised for passing a drilling
assembly through an existing cased borehole and enlarging the
borehole below the casing. One such method is the use of an
underreamer, which has basically two operative states--a closed or
collapsed state, where the diameter of the tool is sufficiently
small to allow the tool to pass through the existing cased
borehole, and an open or partly expanded state, where one or more
arms with cutters on the ends thereof extend from the body of the
tool. In this latter position, the underreamer enlarges the
borehole diameter as the tool is rotated and lowered in the
borehole.
[0006] A "drilling type" underreamer is typically used in
conjunction with a conventional pilot drill bit positioned below or
downstream of the underreamer. The pilot bit can drill the borehole
at the same time as the underreamer enlarges the borehole formed by
the bit. Underreamers of this type usually have hinged arms with
roller cone cutters attached thereto. Most of the prior art
underreamers utilize swing out cutter arms that are pivoted at an
end opposite the cutting end of the cutting arms, and the cutter
arms are actuated by mechanical or hydraulic forces acting on the
arms to extend or retract them. Typical examples of these types of
underreamers are found in U.S. Pat. Nos. 3,224,507; 3,425,500 and
4,055,226. In some designs, these pivoted arms tend to break during
the drilling operation and must be removed or "fished" out of the
borehole before the drilling operation can continue. The
traditional underreamer tool typically has rotary cutter pocket
recesses formed in the body for storing the retracted arms and
roller cone cutters when the tool is in a closed state. The pocket
recesses form large cavities in the underreamer body, which
requires the removal of the structural metal forming the body,
thereby compromising the strength and the hydraulic capacity of the
underreamer. Accordingly, these prior art underreamers may not be
capable of underreaming harder rock formations, or may have
unacceptably slow rates of penetration, and they are not optimized
for the high fluid flow rates required. The pocket recesses also
tend to fill with debris from the drilling operation, which hinders
collapsing of the arms. If the arms do not fully collapse, the
drill string may easily hang up in the borehole when an attempt is
made to remove the string from the borehole.
[0007] Conventional underreamers have several disadvantages,
including cutting structures that are typically formed of sections
of drill bits rather than being specifically designed for the
underreaming function. Therefore, the cutting structures of most
underreamers do not reliably underream the borehole to the desired
diameter. A further disadvantage is that adjusting the expanded
diameter of a conventional underreamer requires replacement of the
cutting arms with larger or smaller arms, or replacement of other
components of the underreamer tool. It may even be necessary to
replace the underreamer altogether with one that provides a
different expanded diameter. Another disadvantage is that many
underreamers are designed to automatically expand when drilling
fluid is pumped through the drill string, and no indication is
provided at the surface that the underreamer is in the
fully-expanded position. In some applications, it may be desirable
for the operator to control when the underreamer expands.
[0008] Accordingly, it would be advantageous to provide an
underreamer that is stronger than prior art underreamers, with a
hydraulic capacity that is optimized for the high flow rate
drilling environment. It would further be advantageous for such an
underreamer to include several design features, namely cutting
structures designed for the underreaming function, mechanisms for
adjustment of the expanded diameter without requiring component
changes, and the ability to provide indication at the surface when
the underreamer is in the fully-expanded position. Moreover, in the
presence of hydraulic pressure in the drill string, it would be
advantageous to provide an underreamer that is selectively
expandable.
[0009] Another method for enlarging a borehole below a previously
cased borehole section includes using a winged reamer behind a
conventional drill bit. In such an assembly, a conventional pilot
drill bit is disposed at the lowermost end of the drilling assembly
with a winged reamer disposed at some distance behind the drill
bit. The winged reamer generally comprises a tubular body with one
or more longitudinally extending "wings" or blades projecting
radially outwardly from the tubular body. Once the winged reamer
has passed through any cased portions of the wellbore, the pilot
bit rotates about the centerline of the drilling axis to drill a
lower borehole on center in the desired trajectory of the well
path, while the eccentric winged reamer follows the pilot bit and
engages the formation to enlarge the pilot borehole to the desired
diameter.
[0010] Yet another method for enlarging a borehole below a
previously cased borehole section includes using a bi-center bit,
which is a one-piece drilling structure that provides a combination
underreamer and pilot bit. The pilot bit is disposed on the
lowermost end of the drilling assembly, and the eccentric
underreamer bit is disposed slightly above the pilot bit. Once the
bi-center bit has passed through any cased portions of the
wellbore, the pilot bit rotates about the centerline of the
drilling axis and drills a pilot borehole on center in the desired
trajectory of the well path, while the eccentric underreamer bit
follows the pilot bit and engages the formation to enlarge the
pilot borehole to the desired diameter. The diameter of the pilot
bit is made as large as possible for stability while still being
capable of passing through the cased borehole. Examples of
bi-center bits may be found in U.S. Pat. Nos. 6,039,131 and
6,269,893.
[0011] As described above, winged reamers and bi-center bits each
include underreamer portions that are eccentric. A number of
disadvantages are associated with this design. First, before
drilling can continue, cement and float equipment at the bottom of
the lowermost casing string must be drilled out. However, the
pass-through diameter of the drilling assembly at the eccentric
underreamer portion barely fits within the lowermost casing string.
Therefore, off-center drilling is required to drill out the cement
and float equipment to ensure that the eccentric underreamer
portions do not damage the casing. Accordingly, it is desirable to
provide an underreamer that collapses while the drilling assembly
is in the casing and that expands to underream the previously
drilled borehole to the desired diameter below the casing.
[0012] Further, due to directional tendency problems, these
eccentric underreamer portions have difficulty reliably
underreaming the borehole to the desired diameter. With respect to
a bi-center bit, the eccentric underreamer bit tends to cause the
pilot bit to wobble and undesirably deviate off center, thereby
pushing the pilot bit away from the preferred trajectory of
drilling the well path. A similar problem is experienced with
respect to winged reamers, which only underream the borehole to the
desired diameter if the pilot bit remains centralized in the
borehole during drilling. Accordingly, it is desirable to provide
an underreamer that remains concentrically disposed in the borehole
while underreaming the previously drilled borehole to the desired
diameter.
[0013] In drilling operations, it is conventional to employ a tool
known as a "stabilizer." In standard boreholes, traditional
stabilizers are located in the drilling assembly behind the drill
bit for controlling the trajectory of the drill bit as drilling
progresses. Traditional stabilizers control drilling in a desired
direction, whether the direction is along a straight borehole or a
deviated borehole.
[0014] In a conventional rotary drilling assembly, a drill bit may
be mounted onto a lower stabilizer, which is disposed approximately
5 feet above the bit. Typically the lower stabilizer is a fixed
blade stabilizer that includes a plurality of concentric blades
extending radially outwardly and spaced azimuthally around the
circumference of the stabilizer housing. The outer edges of the
blades are adapted to contact the wall of the existing cased
borehole, thereby defining the maximum stabilizer diameter that
will pass through the casing. A plurality of drill collars extends
between the lower stabilizer and other stabilizers in the drilling
assembly. An upper stabilizer is typically positioned in the drill
string approximately 30-60 feet above the lower stabilizer. There
could also be additional stabilizers above the upper stabilizer.
The upper stabilizer may be either a fixed blade stabilizer or,
more recently, an adjustable blade stabilizer that allows the
blades to be collapsed into the housing as the drilling assembly
passes through the casing and then expanded in the borehole below.
One type of adjustable concentric stabilizer is manufactured by
Andergauge U.S.A., Inc., Spring, Tex. and is described in U.S. Pat.
No. 4,848,490. Another type of adjustable concentric stabilizer is
manufactured by Halliburton, Houston, Tex. and is described in U.S.
Pat. Nos. 5,318,137; 5,318,138; and 5,332,048.
[0015] In operation, if only the lower stabilizer was provided, a
"fulcrum" type assembly would be present because the lower
stabilizer acts as a fulcrum or pivot point for the bit. Namely, as
drilling progresses in a deviated borehole, for example, the weight
of the drill collars behind the lower stabilizer forces the
stabilizer to push against the lower side of the borehole, thereby
creating a fulcrum or pivot point for the drill bit. Accordingly,
the drill bit tends to be lifted upwardly at an angle, i.e. build
angle. Therefore, a second stabilizer is provided to offset the
fulcrum effect. Namely, as the drill bit builds angle due to the
fulcrum effect created by the lower stabilizer, the upper
stabilizer engages the lower side of the borehole, thereby causing
the longitudinal axis of the bit to pivot downwardly so as to drop
angle. A radial change of the blades of the upper stabilizer can
control the pivoting of the bit on the lower stabilizer, thereby
providing a two-dimensional, gravity based steerable system to
control the build or drop angle of the drilled borehole as
desired.
[0016] When an underreamer or a winged reamer tool is operating
behind a conventional bit to underream the borehole, that tool
provides the same fulcrum effect to the bit as the lower stabilizer
in a standard borehole. Similarly, when underreaming a borehole
with a bi-center bit, the eccentric underreamer bit provides the
same fulcrum effect as the lower stabilizer in a standard borehole.
Accordingly, in a drilling assembly employing an underreamer,
winged reamer, or a bi-center bit, a lower stabilizer is not
typically provided. However, to offset the fulcrum effect imparted
by to the drill bit, it would be advantageous to provide an upper
stabilizer capable of controlling the inclination of the drilling
assembly in the underreamed section of borehole.
[0017] In particular, it would be advantageous to provide an upper
stabilizer that engages the wall of the underreamed borehole to
keep the centerline of the pilot bit centered within the borehole.
When utilized with an eccentric underreamer that tends to force the
pilot bit off center, the stabilizer blades would preferably engage
the opposite side of the expanded borehole to counter that force
and keep the pilot bit on center.
SUMMARY OF THE INVENTION
[0018] In one aspect, embodiments disclosed herein relate to an
expandable downhole tool for use in a drilling assembly positioned
within a wellbore. The expandable downhole tool includes a tool
body having an axial flowbore extending therethrough and a moveable
arm. The moveable arm includes a roller structure including cutters
and rotatably mounted on the moveable arm. The moveable arm is
configured to move outwardly in response to actuation of the
expandable downhole tool.
[0019] In another aspect, embodiments disclosed herein relate to a
moveable arm for an expandable downhole tool. The moveable arm
includes a body, a roller structure including cutters and rotatably
mounted on the body. The moveable arm is configured be moveably
received into a tool body of the expandable downhole tool.
[0020] In another aspect, embodiments disclosed herein relate to a
method of underreaming a wellbore to form an enlarged borehole. The
method includes using a drill bit to drill the wellbore, disposing
an expandable underreamer above the drill bit, using the expandable
underreamer to enlarge the borehole, and disposing an expandable
roller reamer above the first expandable underreamer, wherein the
expandable roller reamer comprises a moveable arm comprising a
roller structure comprising cutters and rotatably mounted on the
moveable arm. The method further includes actuating the expandable
roller reamer such that the cutters disposed on the roller
structure contact the enlarged borehole.
[0021] Other aspects and advantages of the invention will be
apparent from the following description and the appended
claims.
BRIEF DESCRIPTION OF DRAWINGS
[0022] FIG. 1 is a schematic, cross-sectional view of a drilling
assembly;
[0023] FIG. 2 is a schematic, cross-sectional view of another
drilling assembly;
[0024] FIG. 3 is a schematic, cross-sectional view of another
drilling assembly;
[0025] FIG. 4 is a cross-sectional elevation view of one embodiment
of the expandable tool of the present invention, showing the
moveable arms in the collapsed position;
[0026] FIG. 5 is a cross-sectional elevation view of the expandable
tool of FIG. 4, showing the moveable arms in the expanded
position;
[0027] FIG. 6 is a perspective view of a "blank" arm for the
expandable tool of FIG. 4;
[0028] FIG. 7 is a top view of an exemplary arm for the expandable
tool of FIG. 4 including a wear pad and cutting structures for back
reaming and underreaming;
[0029] FIG. 8 is a side elevation view of the arm of FIG. 7;
[0030] FIG. 9 is a perspective view of the arm of FIG. 7;
[0031] FIG. 10 is a perspective view of the drive ring of the
expandable tool of FIG. 4;
[0032] FIG. 11 is a cross-sectional elevation view of an
alternative embodiment of the expandable tool of the present
invention, showing the moveable arms in the collapsed position;
and
[0033] FIG. 12 is a cross-sectional elevation view of the
alternative embodiment of FIG. 11, showing the moveable arms in the
expanded position.
[0034] FIG. 13 is a perspective view of an embodiment of a moveable
arm having a roller reamer structure.
[0035] FIGS. 14a-c are a perspective view of an embodiment of a
moveable arm having a roller reamer structure.
DETAILED DESCRIPTION
[0036] The present disclosure relates to a roller reamer for
stabilizing a drillstring and reducing torque. The present
invention is susceptible to embodiments of different forms. There
are shown in the drawings, and herein will be described in detail,
specific embodiments of the present invention with the
understanding that the disclosure is to be considered an
exemplification of the principles of the invention, and is not
intended to limit the invention to that illustrated and described
herein.
[0037] In particular, various embodiments of the present invention
provide a number of different constructions and methods of
operation. Each of the various embodiments of the present invention
may be used to enlarge a borehole, or to provide stabilization in a
previously enlarged borehole, or in a borehole that is
simultaneously being enlarged. The embodiments of the expandable
tool of the present invention may be utilized as an underreamer, or
as a stabilizer behind a bi-center bit, or as a stabilizer behind a
winged reamer or underreamer following a conventional bit. The
embodiments of the present invention also provide a plurality of
methods for use in a drilling assembly. It is to be fully
recognized that the different teachings of the embodiments
disclosed herein may be employed separately or in any suitable
combination to produce desired results.
[0038] It should be appreciated that the expandable tool described
with respect to the Figures that follow may be used in many
different drilling assemblies. The following exemplary systems
provide only some of the representative assemblies within which the
present invention may be used, but these should not be considered
the only assemblies. In particular, the embodiments of the
expandable tool of the present invention may be used in any
assembly requiring an expandable underreamer and/or stabilizer for
use in controlling the directional tendencies of a drilling
assembly in an expanded borehole.
[0039] FIGS. 1-3 show various exemplary drilling assemblies within
which embodiments of the present invention may be utilized.
Referring initially to FIG. 1, a section of a drilling assembly
generally designated as 100 is shown drilling into the bottom of a
formation 10 with a conventional drill bit 110 followed by an
underreamer 120. Separated from the underreamer 120 by one or more
drill collars 130 is a stabilizer 150 that controls the directional
tendencies of the drilling assembly 100 in the underreamed borehole
25. This section of the drilling assembly 100 is shown at the
bottom of formation 10 drilling a borehole 20 with the conventional
drill bit 110, while the underreamer cutting arms 125 are
simultaneously opening a larger diameter borehole 25 above. The
drilling assembly 100 is operating below any cased portions of the
well.
[0040] As described previously, the underreamer 120 tends to
provide a fulcrum or pivot effect to the drill bit 110, thereby
requiring a stabilizer 150 to offset this effect. In the drilling
assembly 100, various embodiments of the expandable tool of the
present invention are provided in the positions of both the
underreamer 120 and the stabilizer 150. In one embodiment, the
stabilizer 150 would also include cutting structures to ensure that
the larger borehole 25 is enlarged to the proper diameter. However,
any conventional underreamer may alternatively be utilized with one
embodiment of the present invention provided in the position of
stabilizer 150 in the drilling assembly 100. Further, one
embodiment of the present invention may be utilized in the position
of underreamer 120, and a conventional stabilizer may be utilized
in the position of stabilizer 150.
[0041] Referring now to FIG. 2, where like numerals represent like
components, a drilling assembly 200 is shown disposed within
formation 10, below any cased sections of the well. The drilling
assembly 200 is drilling a borehole 20 utilizing a conventional
drill bit 110 followed by a winged reamer 220. The winged reamer
220 may be separated from the drill bit 110 by one or more drill
collars 130, but preferably the winged reamer 220 is connected
directly above the drill bit 110. Upstream of the winged reamer
220, separated by one or more drill collars 130, is a stabilizer
150 that controls the directional tendencies of the drilling
assembly 200 in the underreamed borehole 25. The drill bit 110 is
shown at the bottom of the formation 10 drilling a borehole 20,
while the wing component 225 of the winged reamer 220 is
simultaneously opening a larger diameter borehole 25 above. In the
assembly 200, one embodiment of the present invention would be
located in the position of stabilizer 150. In one embodiment of
assembly 200, the stabilizer 150 would also include cutting
structures to ensure that the larger borehole 25 is enlarged to the
proper diameter.
[0042] Referring to FIG. 3, where like numerals represent like
components, again a drilling assembly 300 is shown disposed within
formation 10, below any cased sections of the well. The drilling
assembly 300 utilizes a bi-center bit 320 that includes a pilot bit
310 and an eccentric underreamer bit 325. As the pilot bit 310
drills the borehole 20, the eccentric underreamer bit 325 opens a
larger diameter borehole 25 above. The bi-center bit 320 is
separated by one or more drill collars 130 from a stabilizer 150
designed to control the directional tendencies of the bi-center bit
320 in the underreamed borehole 25. Again, the function of the
stabilizer 150 is to offset the fulcrum or pivot effect created by
the eccentric underreamer bit 325 to ensure that the pilot bit 310
stays centered as it drills the borehole 20. In one embodiment of
the drilling assembly 300, one embodiment of the expandable tool of
the present invention would be located in the position of
stabilizer 150. In another embodiment of assembly 300, the
stabilizer 150 would also include cutting structures to ensure that
the larger borehole 25 is enlarged to the proper diameter.
[0043] Referring now to FIGS. 4 and 5, one embodiment of the
expandable tool of the present invention, generally designated as
500, is shown in a collapsed position in FIG. 4 and in an expanded
position in FIG. 5. The expandable tool 500 comprises a generally
cylindrical tool body 510 with a flowbore 508 extending
therethrough. The tool body 510 includes upper 514 and lower 512
connection portions for connecting the tool 500 into a drilling
assembly. In approximately the axial center of the tool body 510,
one or more pocket recesses 516 are formed in the body 510 and
spaced apart azimuthally around the circumference of the body 510.
The one or more recesses 516 accommodate the axial movement of
several components of the tool 500 that move up or down within the
pocket recesses 516, including one or more moveable, non-pivotable
tool arms 520. Each recess 516 stores one moveable arm 520 in the
collapsed position. In one embodiment, the expandable tool includes
three moveable arms 520 disposed within three pocket recesses 516.
In the discussion that follows, the one or more recesses 516 and
the one or more arms 520 may be referred to in the plural form,
i.e. recesses 516 and arms 520. Nevertheless, it should be
appreciated that the scope of the present invention also comprises
one recess 516 and one arm 520.
[0044] The recesses 516 further include angled channels 518 that
provide a drive mechanism for the moveable tool arms 520 to move
axially upwardly and radially outwardly into the expanded position
of FIG. 5. A biasing spring 540 may be included to bias the arms
520 to the collapsed position of FIG. 4. The biasing spring 540 is
disposed within a spring cavity 545 and covered by a spring
retainer 550. Retainer 550 is locked in position by an upper cap
555. A stop ring 544 is provided at the lower end of spring 540 to
keep the spring 540 in position.
[0045] Below the moveable arms 520, a drive ring 570 is provided
that includes one or more nozzles 575. An actuating piston 530 that
forms a piston cavity 535, engages the drive ring 570. A drive ring
block 572 connects the piston 530 to the drive ring 570 via bolt
574. The piston 530 is adapted to move axially in the pocket
recesses 516. A lower cap 580 provides a lower stop for the axial
movement of the piston 530. An inner mandrel 560 is the innermost
component within the tool 500, and it slidingly engages a lower
retainer 590 at 592. The lower retainer 590 includes ports 595 that
allow drilling fluid to flow from the flowbore 508 into the piston
chamber 535 to actuate the piston 530.
[0046] A threaded connection is provided at 556 between the upper
cap 555 and the inner mandrel 560 and at 558 between the upper cap
555 and body 510. The upper cap 555 sealingly engages the body 510
at 505, and sealingly engages the inner mandrel 560 at 562 and 564.
A wrench slot 554 is provided between the upper cap 555 and the
spring retainer 550, which provides room for a wrench to be
inserted to adjust the position of the spring retainer 550 in the
body 510. Spring retainer 550 connects at 551 via threads to the
body 510. Towards the lower end of the spring retainer 550, a bore
552 is provided through which a bar can be placed to prevent
rotation of the spring retainer 550 during assembly. For safety
purposes, a spring cover 542 is bolted at 546 to the stop ring 544.
The spring cover 542 prevents personnel from incurring injury
during assembly and testing of the tool 500.
[0047] The moveable arms 520 include pads 522, 524, and 526 with
structures 700, 800 that engage the borehole when the arms 520 are
expanded outwardly to the expanded position of the tool 500 shown
in FIG. 5. Below the arms 520, the piston 530 sealingly engages the
inner mandrel 560 at 566, and sealingly engages the body 510 at
534. The lower cap 580 is threadingly connected to the body and to
the lower retainer 590 at 582, 584, respectively. A sealing
engagement is also provided at 586 between the lower cap 580 and
the body 510. The lower cap 580 provides a stop for the piston 530
to control the collapsed diameter of the tool 500.
[0048] Several components are provided for assembly rather than for
functional purposes. For example, the drive ring 570 is coupled to
the piston 530, and then the drive ring block 572 is boltingly
connected at 574 to prevent the drive ring 570 and the piston 530
from translating axially relative to one another. The drive ring
block 572, therefore, provides a locking connection between the
drive ring 570 and the piston 530.
[0049] FIG. 5 depicts the tool 500 with the moveable arms 520 in
the maximum expanded position, extending radially outwardly from
the body 510. Once the tool 500 is in the borehole, it is only
expandable to one position. Therefore, the tool 500 has two
operational positions--namely a collapsed position as shown in FIG.
4 or an expanded position as shown in FIG. 5. However, the spring
retainer 550, which is a threaded sleeve, can be adjusted at the
surface to limit the full diameter expansion of arms 520. The
spring retainer 550 compresses the biasing spring 540 when the tool
500 is collapsed, and the position of the spring retainer 550
determines the amount of expansion of the arms 520. The spring
retainer 550 is adjusted by a wrench in the wrench slot 554 that
rotates the spring retainer 550 axially downwardly or upwardly with
respect to the body 510 at threads 551. The upper cap 555 is also a
threaded component that locks the spring retainer 550 once it has
been positioned. Accordingly, one advantage of the present tool is
the ability to adjust at the surface the expanded diameter of the
tool 500. Unlike conventional underreamer tools, this adjustment
can be made without replacing any components of the tool 500.
[0050] In the expanded position shown in FIG. 5, the arms 520 will
either underream the borehole or stabilize the drilling assembly,
depending upon how the pads 522, 524 and 526 are configured. In the
configuration of FIGS. 5, cutting structures 700 on pads 526 would
underream the borehole. Wear buttons 800 on pads 522 and 524 would
provide gauge protection as the underreaming progresses. Hydraulic
force causes the arms 520 to expand outwardly to the position shown
in FIG. 5 due to the differential pressure of the drilling fluid
between the flowbore 508 and the annulus 22.
[0051] The drilling fluid flows along path 605, through ports 595
in the lower retainer 590, along path 610 into the piston chamber
535. The differential pressure between the fluid in the flowbore
508 and the fluid in the borehole annulus 22 surrounding tool 500
causes the piston 530 to move axially upwardly from the position
shown in FIG. 4 to the position shown in FIG. 5. A small amount of
flow can move through the piston chamber 535 and through nozzles
575 to the annulus 22 as the tool 500 starts to expand. As the
piston 530 moves axially upwardly in pocket recesses 516, the
piston 530 engages the drive ring 570, thereby causing the drive
ring 570 to move axially upwardly against the moveable arms 520.
The arms 520 will move axially upwardly in pocket recesses 516 and
also radially outwardly as the arms 520 travel in channels 518
disposed in the body 510. In the expanded position, the flow
continues along paths 605, 610 and out into the annulus 22 Through
nozzles 575. Because the nozzles 575 are part of the drive ring
570, they move axially with the arms 520. Accordingly, these
nozzles 575 are optimally positioned to continuously provide
cleaning and cooling to the cutting structures 700 disposed on
surface 526 as fluid exits to the annulus 22 along flow path
620.
[0052] The underreamer tool 500 of the one embodiment of the
present invention solves the problems experienced with bi-center
bits and winged reamers because it is designed to remain
concentrically disposed within the borehole. In particular, the
tool 500 of the present invention preferably includes three
extendable arms 520 spaced apart circumferentially at the same
axial location on the tool 510. In one embodiment, the
circumferential spacing would be 120.degree. apart. This three arm
design provides a full gauge underreaming tool 500 that remains
centralized in the borehole at all times.
[0053] Embodiments of the present invention may provide hydraulic
indication at the surface, thereby informing the operator whether
the tool is in the contracted position shown in FIG. 4, or the
expanded position shown in FIG. 5. Namely, in the contracted
position, the flow area within piston chamber 535 is smaller than
the flow area within piston chamber 535 when the tool 500 is in the
expanded position shown in FIG. 5. Therefore, in the expanded
position, the flow area in chamber 535 is larger, providing a
greater flow area between the flowbore 508 and the wellbore annulus
22. In response, pressure at the surface will decrease as compared
to the pressure at the surface when the tool 500 is contracted.
This decrease in pressure indicates that the tool 500 is
expanded.
[0054] FIGS. 6-10 provide more detail regarding the moveable arms
520 and drive ring 570 of FIGS. 4 and 5. FIG. 6 shows a "blank" arm
520 with no cutting structures or stabilizing structures attached
to pads 522, 524, 526. The arm 520 is shown in isometric view to
depict a top surface 521, a bottom surface 527, a front surface
665, a back surface 660, and a side surface 528. The top surface
521 and the bottom surface 527 are preferably angled, as described
in more detail below. The arm 520 preferably includes two upper
pads 522, one middle pad 524, and two lower pads 526 disposed on
the front surface 665 of the arm 520. The arm 520 also includes
extensions 650 disposed along each side 528 of arm 520. The
extensions 650 preferably extend upwardly at an angle from the
bottom 527 of the arm 520 towards pads 522, 524 and 526. The
extensions 650 protrude outwardly from the arm 520 to fit within
corresponding channels 518 in the pocket recess 516 of the tool
body 510, as shown in FIGS. 4 and 5. The interconnection between
the arm extensions 650 and the body channels 518 increases the
surface area of contact between the moveable arms 520 and the tool
body 510, thereby providing a more robust expandable tool 500 as
compared to prior art tools. The arm 520 depicted in FIG. 6 is a
blank version of either an underreamer cutting arm or a stabilizer
arm. By changing the structures disposed on pads 522, 524 and 526,
the tool 500 is converted from an underreamer to a stabilizer or
vice versa, or to a combination underreamer/stabilizer.
[0055] Referring now to FIGS. 7, 8 and 9, an exemplary arm 520 is
shown that includes two sets of cutting structures 700, 710. FIG. 7
depicts the arm 520 from a top perspective, FIG. 8 provides an
elevational side view, and FIG. 9 shows an isometric perspective.
The top surface 521 and the bottom surface 527 of the arm 520 are
preferably angled in the same direction as best shown in FIG. 7.
These surfaces 521, 527 are designed to prevent the arm 520 from
vibrating when pads 522, 524 and 526 engage the borehole. Namely,
when pads 522, 524 and 526 engage the borehole, the arms 520 are
held in compression by the piston 530. The angled top surface 521
and the angled bottom surface 527 bias the arms 520 to the trailing
side of the pocket recesses 516 to minimize vibration.
[0056] In the top view of FIG. 7, pads 522 comprise cutting
structures 710 such that the arm 520 provides back reaming
capabilities. Back reaming is pulling the tool 500 upwardly in the
borehole while underreaming. Pad 524 is preferably covered with
wear buttons 800 that provide a stabilizing and gauge protection
function. Pads 526 comprise cutting structures 700 for
underreaming. In the side view of FIG. 8, the extensions 650 that
fit within channels 518 of the body 510 are shown extending
upwardly at an angle along the side 528 from the back surface 660
of the arm 520 towards pads 522, 524 and 526. FIG. 9 shows the same
arm 520 in isometric view.
[0057] To change the arm 520 shown in FIGS. 7, 8, and 9 from a back
reaming and underreaming arm to simply an underreaming arm, the
back reaming cutting structures 710 would be replaced with wear
buttons, such as buttons 800. This configuration would result in
the underreaming arm 520 shown in FIGS. 4 and 5. Modifying the tool
500 from an underreamer to a stabilizer simply requires providing
stabilizing structures on all of the pads 522, 524 and 526. As a
stabilizer, surfaces 522, 524, and 526 would be covered with a
dense plurality of wear buttons 800 without any cutting structures.
The material for the wear buttons 800 may be, for example, a
tungsten carbide or diamond material, which provides good wear
capabilities. In an alternative embodiment, the pads 522, 524, and
526 may be coated with a hardened material called TCI 300H
hardfacing.
[0058] Accordingly, the pads 522, 524, 526 could comprise a variety
of structures and configurations utilizing a variety of different
materials. When the tool is used in an underreaming function, a
variety of different cutting structures 700 could be provided on
surfaces 526, depending upon the formation characteristics.
Preferably, the cutting structures 700, 710 for underreaming and
back reaming, respectively, are specially designed for the
particular cutting function. More preferably, the cutting
structures 700, 710 comprise the cutting structures disclosed and
claimed in co-pending U.S. patent application Ser. No. 09/924,961,
filed Aug. 8, 2001, entitled "Advanced Expandable Reaming Tool,"
assigned to Smith International, Inc., which is hereby incorporated
herein by reference.
[0059] Referring now to FIG. 10, additional advantages of one or
more embodiments of the present invention are provided by the one
or more nozzles 575 disposed in the drive ring 570. The
underreamer/stabilizer preferably includes three moveable arms 520
spaced apart circumferentially at the same axial location along the
tool body 510. In one embodiment, the three moveable arms 520 are
spaced 120.degree. circumferentially. This arrangement of the arms
520 is preferred to centralize the tool 500 in the borehole. The
drive ring 570 is moveable with the arms 520 and preferably
includes three extended portions 576 spaced 120.degree.
circumferentially with angled nozzles 575 therethrough that are
designed to direct drilling fluid to the cutting structures 700 of
the underreamer at surfaces 526. The boreholes 578 in the extended
portions 576 adjacent nozzles 575 accept bolts 574 to connect the
drive ring 570 to the drive ring block 572 and piston 530. An
aperture 571 is disposed through the center of the drive ring 570
to enable a connection to the piston 530. Because the drive ring
570 is connected to the piston 530, it moves with the piston 530 to
push the moveable arms 520 axially upwardly and outwardly along the
channels 518 to the expanded position. Accordingly, because drive
ring 570 moves with the arms 520, the nozzles 575 continuously
provide drilling fluid to the cutting structures 700 on the
underreamer surfaces 526. The nozzles 575 are optimally placed to
move with and follow the cutting structures 700 and thereby assure
that the cutters 700 are properly cleaned and cooled at all
times.
[0060] FIGS. 11 and 12 depict a second embodiment of the present
invention, generally designated as 900, in the collapsed and
expanded positions, respectively. Many components of tool 900 are
the same as the components of embodiment 500, and those components
maintain the same reference numerals. There are, however, several
differences. The inner mandrel 560 of the first embodiment tool 500
is replaced by a stinger assembly 910, preferably comprising an
upper inner mandrel 912, a middle inner mandrel 914, and a lower
inner mandrel 916. The lower inner mandrel 916 includes ports 920
that must align with ports 595 in the lower retainer 590 before
fluid can enter piston chamber 535 to actuate the piston 530. As
shown in FIG. 11, fluid flows through the flowbore 508 of tool 900,
along pathway 605 depicted by the arrows. Because the ports 920 of
the lower inner mandrel 916 do not align with the ports 595 of the
lower retainer 590, the fluid continues flowing along path 605,
past ports 595, down through the tool 900.
[0061] The tool 900 is selectively actuated utilizing an actuator
(not shown), which aligns the ports 920 with the ports 595 to
enable the expandable tool to move from the contracted position
shown in FIG. 11 to the expanded position shown in FIG. 12. Below
lower inner mandrel 916, a bottom spring 930 is disposed within a
bottom spring chamber 935 and held within the body 510 by a bottom
spring retainer 950. Bottom spring retainer 950 threadingly
connects at 952 to the lower retainer 590. The spring 930 biases
the stinger assembly 910 upwardly such that stinger 910 must be
forced downwardly by an actuator to overcome the force of bottom
spring 930. By moving the stinger 910 downwardly, the ports 920
disposed circumferentially around the bottom of lower inner mandrel
916 align with the ports 595 of lower retainer 590 that lead into
piston chamber 535.
[0062] FIG. 12 shows the tool 900 in an expanded position. In this
position, drilling fluid flows through the flowbore 508, along
pathway 605. However, because stinger 910 has been actuated
downwardly against the force of bottom spring 930 by an actuator,
the ports 920 in lower inner mandrel 916 now align with ports 595
in the lower retainer 590. Therefore, when the drilling fluid
proceeds downwardly along flow path 605 through the flowbore 508 to
reach ports 920, it will flow through ports 920, 595 and into the
piston chamber 535 as depicted by flow arrows 610.
[0063] Due to the differential pressure between the flowbore 508
and the wellbore annulus 22 surrounding tool 900, the fluid flowing
along pathway 610 will actuate the piston 530 upwardly against the
force of spring 540. The piston 530 will push the drive ring 570,
which will push the arms 520 axially upwardly and outwardly as the
extensions 650 on the arms 520 move along channels 518 in the body
510. Once the fluid flows through the nozzles 575 in the drive ring
570, it exits at an angle along pathway 620 to cool and clean the
cutting structures 700 disposed on surfaces 526 that underream the
borehole. Accordingly, the second embodiment 900 of FIGS. 11 and 12
is capable of being selectively actuated. Namely, by engaging the
upper surface 975 of stinger 910 with an actuator, the tool 900 can
be selectively actuated at the election of the operator to align
the ports 920 and 595. A suitable actuator is the flow switch
described and claimed in U.S. Pat. No. 6,289,999 entitled "Fluid
Flow Control Devices and Methods for Selective Actuation of Valves
and Hydraulic Drilling Tools," hereby incorporated herein by
reference.
[0064] Referring again to FIGS. 11 and 12, typically a gap is
provided between the upper end 975 of the stinger 910 and the
actuator when the tool is in the collapsed position. That gap
length must be maintained to ensure that actuation occurs only when
it is meant to occur. Accordingly, upper inner mandrel 912 may
include an adjustment ring portion 918, which is just a spacer ring
that makes up any discrepancies in the area between the upper inner
mandrel 912 and the middle inner mandrel 914 such that the
appropriate gap dimension can be maintained.
[0065] As one of ordinary skill in the art will readily appreciate,
any actuating mechanism can be utilized to selectively actuate the
tool 900 of FIGS. 11 and 12. However, the flow switch provides the
advantage of additional hydraulic indications to the surface, in
addition to the pressure indications provided by the increased flow
area in the piston chamber 535 when the tool 900 is in the expanded
position of FIG. 12. Namely, the flow switch includes an uplink
pulser capable of providing position and status information to the
surface via mud pulse telemetry. Accordingly, one embodiment
comprises the tool 900 of FIGS. 11 and 12, and more preferably
comprises the tool 900 in combination with the referenced flow
switch.
[0066] In operation, an expandable tool 500 or 900 is lowered
through casing in the collapsed position shown in FIGS. 4 and 11,
respectively. The first embodiment of the tool 500 would then be
expanded automatically when drilling fluid flows through flowbore
508, and the second embodiment of the tool 900 would be expanded
only after selectively actuating the tool 900. Whether the
selective actuation feature is present or not, the tools 500, 900
expand due to differential pressure between the flow bore 508 and
the wellbore annulus 22 acting on the piston 530. That differential
pressure may be in the range of 800 to 1,500 psi. Therefore,
differential pressure working across the piston 530 will cause the
one or more arms 520 of the tool to move from a collapsed to an
expanded position against the force of the biasing spring 540.
[0067] Before the drilling assembly is lowered into the borehole,
the function of the present invention as either an underreamer or
as a stabilizer would be determined. Referring again to FIG. 1, one
example would be to use either embodiment of the tool 500, 900 in
the position of underreamer 120, and preferably to use the second
embodiment of the tool 900 in the position of stabilizer 150. As
another example, referring to FIGS. 2 and 3, if a winged reamer 220
or a bi-center bit 320 is used instead of an underreamer 120, the
second embodiment of the tool 900 would preferably be used in the
position of stabilizer 150. As an underreamer, one or more
embodiments of the present invention are capable of underreaming a
borehole to a desired diameter. As a stabilizer, one or more
embodiments of the present invention provide directional control
for the assembly 100, 200, 300 within the underreamed borehole
25.
[0068] Turning to FIG. 13, a moveable arm 820 with a roller
structure 162 in accordance with another embodiment is shown. The
moveable arm 820 shown in FIG. 13 is similar in structure to the
blank arm shown in FIG. 6. A body 830 includes extensions 650
formed on the sides and configured to fit within corresponding
channels of the tool body, such as the embodiment shown in FIGS. 4
and 5. The body 830 is further configured to accommodate the roller
structure 162 rotatably attached thereto. The shape of the roller
structure 162 may be, for example, cylindrical or frusto-conical.
Cutting structures 163 are distributed azimuthally about the roller
structure 162. The cutting structures 163 may be integrally formed
with the roller structure 162 or provided as inserts in
corresponding pockets formed in the roller structure 162. If
provided as inserts, any suitably hard material may be used, such
as, for example, tungsten carbide or diamond material. The cutting
structures 163 may be, for example, bullet-shaped. Those having
ordinary skill in the art will appreciate that the shape of the
cutting structures 163 may vary without departing from the scope of
the present disclosure.
[0069] The expandable roller reamer may include a plurality of
moveable arms azimuthally spaced around the tool body. To balance
the forces on the expandable roller reamer and better stabilize the
drillstring, the plurality of moveable arms may be
circumferentially spaced apart around the tool body. For example,
in one embodiment, the expandable roller reamer may include three
moveable arms with roller structures spaced 120.degree. apart.
[0070] In the embodiment shown in FIG. 13, the roller structure 162
is formed as a sleeve disposed on a roller pin 161. A set screw 165
fixes the roller structure 162 relative to the roller pin 161. To
attach the roller pin 161 to the moveable arm 820, roller mounts
171 are provided at opposing ends of the roller pin 161 and
disposed in corresponding pockets formed in the moveable arm 820.
The roller mounts 171 may be attached to the moveable arm 820
using, for example, bolts 172. Bearing assemblies (not shown) may
be provided within the roller mounts 171.
[0071] The structure of the moveable arm 820 of FIG. 13 may provide
several advantages. The moveable arm 820 may be configured to be
interchangeable with other moveable arms disclosed herein in order
for the same tool body to be useable for different applications by
changing out the moveable arms, which can be performed at a
drilling site with readily available tools. Interchangeability of
moveable arms also reduces manufacturing costs by increasing
quantities of the tool body. Further, the various types of moveable
arms may be manufactured with the common dimensions (e.g.
extensions 650) before being finished with specialized features,
such as pockets to accommodate the roller pin.
[0072] FIGS. 14a-c, show another embodiment of a roller structure
in accordance with disclosed features. In FIG. 14b, blades 921, may
form the cutting structure, as opposed to inserts, or other cutting
elements. The blades may be formed from a super hard material, such
as tungsten carbide, or may be formed from a matrix material, and
be impregnated with another material, such as diamond. Thus, in one
embodiment, the blades 921 are diamond impregnated matrix blades.
Those having ordinary skill in the art will appreciate that a
number of other materials may be used as the cutting structure in
this fashion. In addition, a combination of inserts, shown at 922,
and blades may be used together to form a cutting structure. As
with FIG. 13, the structure may be bolted on, or otherwise
attached. In addition, wear features 923 may be added to contact
the hole wall for stabilization purposes. These wear features 923
may comprise a super hard material, such as tungsten carbide. FIGS.
14a and 14c show other views of the embodiment.
[0073] Although interchangeability is a potential advantage, those
having ordinary skill in the art will appreciate that an expandable
roller reamer may provide other advantages associated with
stabilizing the drillstring. For example, the expandable roller
reamer may be deployed above another expandable reamer on the
drillstring. The outer diameter of the expandable roller reamer can
be configured to substantially match or slightly exceed the outer
diameter of the expandable reamer. By so doing, the expandable
roller reamer is able to smooth the wellbore and provide active
stabilization of the drillstring during drilling operations. While
contacting the wall of the wellbore, the roller structures freely
roll rather than drag, thereby reducing torque on the drillstring.
Further, the diameter of the expandable roller reamer may be
reduced to later pull the drillstring from the wellbore, thereby
reducing the risk of the drillstring being stuck in the
wellbore.
[0074] While the invention 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
can be devised which do not depart from the scope of the invention
as disclosed herein. Accordingly, the scope of the invention should
be limited only by the attached claims.
* * * * *