U.S. patent application number 14/546224 was filed with the patent office on 2015-05-21 for retrieval tool and methods of use.
The applicant listed for this patent is SMITH INTERNATIONAL, INC.. Invention is credited to Thomas J. Armstrong, John E. Campbell, Shantanu N. Swadi.
Application Number | 20150136398 14/546224 |
Document ID | / |
Family ID | 53172117 |
Filed Date | 2015-05-21 |
United States Patent
Application |
20150136398 |
Kind Code |
A1 |
Armstrong; Thomas J. ; et
al. |
May 21, 2015 |
RETRIEVAL TOOL AND METHODS OF USE
Abstract
A retrieval tool may include a body having a first end portion
and a second end portion. A protrusion may extend laterally from
the body proximate the second end portion of the body. The
protrusion may have an engaging surface, two opposing side
surfaces, and an outer surface. A path of fluid communication may
extend from the first end portion of the body, through the body and
the protrusion, to an engaging surface of the protrusion. A method
for moving a downhole tool in a wellbore may include running a
retrieval tool into a wellbore and pumping fluid to the retrieval
tool. The retrieval tool may be engaged with the downhole tool,
which may cause a path of fluid communication to experience a
change in fluid pressure.
Inventors: |
Armstrong; Thomas J.;
(Perth, AU) ; Campbell; John E.; (Houston, TX)
; Swadi; Shantanu N.; (Cypress, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
SMITH INTERNATIONAL, INC. |
Houston |
TX |
US |
|
|
Family ID: |
53172117 |
Appl. No.: |
14/546224 |
Filed: |
November 18, 2014 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
61906280 |
Nov 19, 2013 |
|
|
|
Current U.S.
Class: |
166/301 ;
166/98 |
Current CPC
Class: |
E21B 23/00 20130101;
E21B 31/18 20130101; E21B 7/061 20130101 |
Class at
Publication: |
166/301 ;
166/98 |
International
Class: |
E21B 31/18 20060101
E21B031/18; E21B 23/00 20060101 E21B023/00 |
Claims
1. A retrieval tool, comprising: a body having a first end portion
and a second end portion; a protrusion extending laterally from the
body, the protrusion including an engaging surface; and at least
one bore defining a path of fluid communication extending from the
first end portion of the body to the engaging surface of the
protrusion.
2. The retrieval tool of claim 1, the protrusion further including
two opposing side surfaces and an outer surface, a distance between
the two opposing side surfaces being greater proximate the outer
surface than proximate the body.
3. The retrieval tool of claim 1, the protrusion extending
laterally from the second end portion of the body.
4. The retrieval tool of claim 1, the at least one bore including
an axial bore extending at least partially through the body from
the first end portion toward the second end portion.
5. The retrieval tool of claim 1, further comprising: a seal
configured to obstruct flow out of the at least one bore.
6. The retrieval tool of claim 1, the at least bore including at
least one lateral bore extending from the path of fluid
communication to an outer surface of the body.
7. The retrieval tool of claim 1, the at least one bore including a
radial bore extending at least partially into the protrusion.
8. The retrieval tool of claim 7, the at least one bore including
an axial bore in the protrusion and extending at least partially
from the radial bore to the engaging surface of the protrusion.
9. The retrieval tool of claim 1, the path of fluid communication
being configured to be at least partially obstructed when the
protrusion engages a corresponding slot in a downhole tool.
10. A retrieval tool, comprising: a body having at least one bore
extending axially therein; and a protrusion extending laterally
from the body, the protrusion having an engaging surface in fluid
communication with the at least one bore of the body.
11. The retrieval tool of claim 11, the engaging surface of the
protrusion being sloped, and an angle between the engaging surface
and the central longitudinal axis being from 20.degree. to
85.degree..
12. The retrieval tool of claim 11, the engaging surface of the
protrusion being curved, and a radius of curvature of the engaging
surface being from 0.5 cm to 10 cm.
13. The retrieval tool of claim 10, the at least one bore including
a first axial bore extending through at least a portion of the
body, and a radial bore extending from the axial bore into the
protrusion, the protrusion further including a second axial bore
from the radial bore to the engaging surface.
14. The retrieval tool of claim 13, further comprising: a path of
fluid communication extending through the first axial bore, the
radial bore, and the second axial bore.
15. The retrieval tool of claim 10, the protrusion including a bore
extending to the engaging surface, the bore being configured to be
at least partially obstructed when the protrusion engages a
corresponding slot in a deflection member.
16. A method of moving a downhole tool, comprising: running a
retrieval tool into a wellbore, the retrieval tool including: a
body having a first end portion and a second end portion; and a
protrusion extending laterally from the body proximate the second
end portion, a path of fluid communication extending from the first
end portion of the body, through the body and the protrusion, to an
engaging surface of the protrusion; flowing fluid into the body of
the retrieval tool and at least partially through the path of fluid
communication; and engaging the protrusion with a downhole tool
within the wellbore, wherein engaging the protrusion with downhole
tool includes causing a pressure change in the fluid being flowed
into the body of the retrieval tool.
17. The method of claim 16, wherein engaging the protrusion with
the downhole tool includes engaging the engaging surface of the
protrusion with an upper surface of the downhole tool to at least
partially obstruct the path of fluid communication.
18. The method of claim 16, wherein a magnitude of the pressure
change in the fluid being flowed into the body of the retrieval
tool is between 100 kPa and 5000 kPa.
19. The method of claim 16, wherein causing the pressure change
includes increasing a pressure in the fluid being flowed into the
body of the retrieval tool.
20. The method of claim 18, further comprising: orienting the
retrieval tool such that the protrusion is aligned with a slot in
the downhole tool.
Description
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] This application claims the benefit of, and priority to,
U.S. patent application Ser. No. 61/906,280 filed on Nov. 19, 2013
and titled "Retrieval Tool and Methods of Use," which application
is expressly incorporated herein by this reference in its
entirety.
BACKGROUND
[0002] A whipstock is a downhole tool designed to aid in the
formation of a secondary (e.g., deviated) borehole off a primary
wellbore. The whipstock is run into the primary wellbore and
oriented with a directional measurement tool. Once oriented, the
whipstock is secured in place with a packer or a mechanical anchor.
The whipstock includes a sloped surface that causes a mill to
deflect from the central longitudinal axis of the primary wellbore
toward the wellbore wall so that the mill may initiate drilling of
the secondary wellbore. Some whipstocks are retrievable, and may be
moved within, or removed from, the primary wellbore using a
retrieval tool such as a "fishing hook." The whipstock may include
a slot and the fishing hook may include a mating feature that can
be positioned within the slot.
SUMMARY
[0003] A retrieval tool is disclosed in accordance with some
embodiments of the present disclosure. The retrieval tool may
include a body having a first end portion and a second end portion.
A protrusion may extend laterally from the body, and may include an
engaging surface. At least one bore may define a path of fluid
communication extending from the first end portion of the body to
the engaging surface of the protrusion.
[0004] In another embodiment, a retrieval tool may include a body
having at least one bore extending axially therein. A protrusion
may extend laterally from the body and may have an engaging surface
in fluid communication with the at least one bore of the body.
[0005] In some embodiments a retrieval tool may include a body
having two end portions. A protrusion may extend laterally from the
body proximate one end portion of the body. The protrusion may have
an engaging surface, two opposing side surfaces, and an outer
surface. A distance between the two opposing side surfaces may be
greater proximate the outer surface than proximate the body. A path
of fluid communication may extend from a first end portion of the
body, through the body and the protrusion, to the engaging surface
of the protrusion.
[0006] In another embodiment of the present disclosure, a retrieval
tool may include a body having a first end portion and a second end
portion. A first axial bore may extend fully or partially through
the body between the first end portion and the second end portion.
A protrusion may extend laterally from the body proximate the
second end portion of the body. The protrusion may have an engaging
surface, two opposing side surfaces, and an outer surface, and a
distance between the two opposing side surfaces may be greater
proximate the outer surface than proximate the body. A lateral bore
may be located proximate the second end portion of the body and
extend through the protrusion from the first axial bore toward the
outer surface of the protrusion. A second axial bore may be located
in the protrusion and extend at least partially through the
protrusion from the lateral bore to the engaging surface of the
protrusion.
[0007] A method for moving a downhole tool is also disclosed. An
example method may include running a retrieval tool into a
wellbore. The retrieval tool may include a body having first and
second end portions. A protrusion may extend laterally from the
body proximate the second end portion, and a path of fluid
communication may extending from the first end portion of the body,
through the body and the protrusion, to an engaging surface of the
protrusion. Fluid may be pumped or otherwise flowed into the body
of the retrieval tool. Fluid may flow at least partially through
the path of fluid communication. The protrusion may be engaged with
a downhole tool in a way that causes a pressure change in the fluid
in the body of the retrieval tool.
[0008] In accordance with another method, a retrieval tool may be
run into a wellbore. The retrieval tool may include a body having a
first end portion and a second end portion. A protrusion may extend
laterally from the body proximate the second end portion of the
body. A path of fluid communication may extend from the first end
portion of the body, through the body and the protrusion, to an
engaging surface of the protrusion. The protrusion may engage a
corresponding slot in a deflection member. An upper surface of the
deflection member defining the slot may contact the engaging
surface of the protrusion and at least partially obstruct the path
of fluid communication therethrough when the protrusion engages the
slot.
BRIEF DESCRIPTION OF THE DRAWINGS
[0009] So that the recited features may be understood in detail, a
more particular description, briefly summarized above, may be had
by reference to one or more embodiments, some of which are
illustrated in the appended drawings. It is to be noted, however,
that the appended drawings are illustrative embodiments, and are,
therefore, not to be considered limiting of its scope. Moreover,
while the drawings may be considered to be to scale for some
embodiments of the present disclosure, the scale of the drawings is
intended to be illustrative and not limiting of the present
disclosure.
[0010] FIG. 1 is a perspective view of an illustrative downhole
retrieval tool, according to one or more embodiments of the present
disclosure.
[0011] FIG. 2 is a cross-sectional view of the retrieval tool of
FIG. 1, according to one or more embodiments of the present
disclosure.
[0012] FIG. 3 is a perspective view of an illustrative deflection
member, according to one or more embodiments of the present
disclosure.
[0013] FIG. 4 is a cross-sectional view of a system for using a
retrieval tool to retrieve a deflection member, according to one or
more embodiments of the present disclosure.
[0014] FIG. 5 is a cross-sectional view of a retrieval tool sliding
along a sloped surface of a deflection member, according to one or
more embodiments of the present disclosure.
[0015] FIG. 6 is a cross-sectional view of the retrieval tool of
FIG. 5 when engaging the deflection member, according to one or
more embodiments of the present disclosure.
DETAILED DESCRIPTION
[0016] Embodiments described herein generally relate to systems,
devices, and methods for retrieving remote tooling. More
particularly, some embodiments of the present disclosure relate to
retrieving tooling within a wellbore. More particularly still, some
embodiments may relate to confirming an engagement between a
retrieval tool and a deflection member such as a whipstock.
[0017] FIG. 1 is a perspective view of an illustrative downhole
retrieval tool 100, according to one or more embodiments. The
retrieval tool 100 may include a body 110 having a first end
portion 112 and a second end portion 114. In this embodiment, the
first end portion 112 may be an upper end portion, while the second
end portion 114 may be a lower end portion.
[0018] As shown, the body 110 may be elongated and/or substantially
cylindrical. The body 110 may have any suitable cross-sectional
shape, however, including a circle, an ellipse, an oval, a square,
a rectangle, a trapezoid, any other regular or irregular geometric
shape, or any combination of the foregoing. Moreover, the size
and/or shape of the cross-sectional shape of the body 110 may be
constant or may change over the length of the body 110.
[0019] According to some embodiments, the body 110 may have one or
more protrusions or hooks (one is shown as protrusion 120)
extending therefrom. As shown in FIG. 1, some embodiments
contemplate the one or more protrusions 120 being located proximate
the second end portion 114. The one or more protrusions 120 may
extend laterally or radially from the body 110 in some embodiments
of the present disclosure.
[0020] The one or more protrusions 120 may operate as a hook or
other engagement mechanism for engaging a downhole tool that is to
be moved in a wellbore. When the operator believes a protrusion 120
is engaged with a slot in the downhole tool, an upward force can be
applied to the retrieval tool 100. An increased weight measurement
at the surface may also be used to confirm engagement. The increase
in the weight measurement may be detected due to the weight of the
downhole and/or the resistance from the downhole tool being
anchored or stuck in place in the wellbore. When engagement is
confirmed, an increased upward force can be applied to release the
downhole tool so that it is free to move within the wellbore.
[0021] Once the downhole tool has been released, it may be
difficult, in some embodiments, to confirm the protrusion 120 of
the retrieval tool 100 remains engaged in the slot of the downhole
tool. This may be due to the weight of the downhole tool being a
small fraction of the weight measured at the surface (e.g., 2% of
the total weight). In addition, friction between a drill string and
a casing or wellbore wall may cause the measured weight to
fluctuate. As such, an operator may be unaware that the protrusion
120 of the retrieval tool 100 has disengaged the slot of the
downhole tool until the retrieval tool 100 reaches the surface. The
trip up to the surface is a time consuming and costly procedure,
which may be for naught if the downhole tool is not retrieved.
[0022] In some embodiments, the retrieval tool 100 and/or the
protrusions 120 may be configured to provide increased sensitivity
to determine when the downhole tool disengages from the protrusion
120. The increased sensitivity may operate using fluid pressure
changes, in some embodiments of the present disclosure.
[0023] FIG. 2, for instance, is a cross-sectional view of the
retrieval tool 100 shown in FIG. 1, according to one or more
embodiments. The body 110 of the retrieval tool 100 may have one or
more axial openings, channels, or bores (one is shown as axial bore
140) formed at least partially therethrough. In some embodiments,
the axial bore 140 may extend from the first end portion 112 of the
body 110 to the second end portion 114 of the body 110. In another
embodiment, the axial bore 140 may extend from the first end
portion 112 toward the second end portion 114 of the body (e.g., to
the protrusion 120). In still another embodiment, the axial bore
140 may extend from a location proximate the first end portion 112
of the body 110 to either the protrusion 120 or the second end
portion 140 of the body 110. A length of the axial bore 140 may
therefore vary, and in some embodiments may have a length that is
between 50% and 100% of the length of the body 110. For instance,
the length of the axial bore 140 may include lower and/or upper
limits that include any of 50%, 60%, 70%, 80%, 90%, or 100% of a
length of the body 110, or values therebetween. In other
embodiments, the length of the axial bore 140 may be less than 50%
the length of the body 110.
[0024] A cross-sectional shape of the axial bore 140 may be a
circle, an ellipse, an oval, a square, a rectangle, some other
regular or irregular geometric shape, or any combination of the
foregoing. A cross-sectional area of a cross-section of the axial
bore 140 may vary in different embodiments, and in some embodiments
may be between 1 cm.sup.2 and 20 cm.sup.2. More particularly, in
some embodiments the cross-sectional area of the axial bore 140 may
be within a range having lower and/or upper limits including any
from 1 cm.sup.2, 2 cm.sup.2, 4 cm.sup.2, 6 cm.sup.2, 8 cm.sup.2, 10
cm.sup.2, 15 cm.sup.2, or 20 cm.sup.2. For example, the
cross-sectional area of the axial bore 140 may be from 1 cm.sup.2
to 4 cm.sup.2, from 2 cm.sup.2 to 6 cm.sup.2, from 5 cm.sup.2 to 10
cm .sup.2, from 8 cm.sup.2 to 15 cm.sup.2, from 10 cm.sup.2 to 20
cm.sup.2, at least 1 cm.sup.2, or up to 20 cm.sup.2. In other
embodiments, the cross-sectional area of the axial bore 140 may be
less than 1 cm.sup.2 or more than 20 cm.sup.2. Moreover, while the
cross-sectional area of the axial bore 140 may remain about
constant along a length of the axial bore 140, other embodiments
contemplate that the shape and/or size of the axial bore 140 may
vary along its length.
[0025] In some embodiments, the axial bore 140 may be substantially
parallel to, co-axial with, or otherwise aligned with a central
longitudinal axis 142 of the body 110. The axial bore 140 may be
angled or offset relative to the central longitudinal axis 142. A
bore may be considered "axial" when aligned to have at least a
component of the direction of the bore extend in a direction
parallel to the central longitudinal axis 142. A bore may be
considered to be lateral/radial when at least a component of the
direction of the bore extends in a direction perpendicular to the
longitudinal axis 142.
[0026] According to some embodiments, the axial bore 140 may be
blocked or obstructed proximate the second end portion 114 of the
body 110. In FIG. 2, for instance, a plug 144 or other seal may
fully or partially block the axial bore 140 at or near the second
end portion 114 of the body 110. When the axial bore 140 is blocked
or otherwise obstructed, the axial bore 140 may not be in fluid
communication with the environment immediately proximate the second
end portion 114, or the axial bore 140 may have reduced fluid
communication with the environment. When present, the plug 144 may
be positioned at least partially within the axial bore 140 and
secured to the body 110 in any suitable manner, including via a
threaded connection, a friction fit, an adhesive, through the use
of mechanical fasteners (e.g., screws, pins, clips, etc.), or in
other manners. In some embodiments, the plug 144 may be positioned
around the axial bore 140 (e.g., coupled to the end of the second
end portion 114) to obstruct flow out of the axial bore 140.
[0027] In some embodiments, one or more radial or lateral bores
(four are shown as lateral bores 150) may be formed through the
body 110. In some embodiments, the lateral bores 150 may be
proximate the first end portion 112 of the body 110. The lateral
bores 150 may be axially and/or circumferentially offset from one
another along the longitudinal axis 142 of the body 110. A central
longitudinal axis 152 through one or more of the lateral bores 150
may be substantially perpendicular to the central longitudinal axis
142 of the body 110, although in other embodiments the central
longitudinal axis 152 and the lateral bores 150 may extend at other
angles relative to the central longitudinal axis 142. For instance,
in some embodiments, the central longitudinal axis 152 may be
oriented at an angle that is between 10.degree. and 90.degree.
relative to the central longitudinal axis.
[0028] According to some embodiments, the lateral bores 150 may
provide a path of fluid communication from the axial bore 140 to an
outer surface 116 of the body 110. In some embodiments, fluid may
flow into the axial bore 140 of the retrieval tool 100 (e.g.,
through an opening of the axial bore 140 at the first end portion
112). For instance, fluid may be pumped or otherwise flowed down
through a drill string (e.g., drill pipe 412 of FIG. 4) from the
surface and into the axial bore 140 of the retrieval tool 100. At
least a portion of the fluid entering the axial bore 140 may flow
from the axial bore 140 and through one or more of the lateral
bores 150 to the outer surface 116 of the body 110. When the
retrieval tool 100 is within a wellbore, the fluid flowing through
one or more of the lateral bores 150 may flow into an annulus
formed between the outer surface of the retrieval tool 100 and a
casing or wellbore wall, as discussed in more detail herein.
[0029] A cross-sectional shape of the lateral bores 150 may be a
circle, an ellipse, an oval, a square, a rectangle, some other
regular or irregular geometric shape, or any combination of the
foregoing. A cross-sectional area of each lateral bore 150 may
range from 0.1 cm.sup.2 to 15 cm.sup.2 in some embodiments. More
particularly, some embodiments contemplate the cross-sectional area
of at least a portion of the lateral bores 150 being within a range
having lower and/or upper limits that include any of 0.1 cm .sup.2,
0.5 cm.sup.2, 1 cm.sup.2, 1.5 cm.sup.2, 2 cm.sup.2, 4 cm.sup.2, 6
cm.sup.2, 8 cm.sup.2, 10 cm.sup.2, 15 cm.sup.2, or values
therebetween. For example, the cross-sectional area of one or more
of the lateral bores 150 may be from 0.1 cm.sup.2 to 1 cm.sup.2,
from 1 cm.sup.2 to 3 cm.sup.2, from 3 cm.sup.2 to 5 cm.sup.2, from
5 cm.sup.2 to 10 cm.sup.2, at least 0.1 cm.sup.2, or up to 15
cm.sup.2. In other embodiments, the cross-sectional area of a
lateral bore 150 may be less than 0.1 cm.sup.2 or more than 15
cm.sup.2. The cross-sectional shape and/or area of each lateral
bore 150 may be the same or may be different. At least some of the
lateral bores 150 may have a nozzle 154 therein. In some
embodiments, a nozzle 154 may be configured to control and/or
measure the flow rate, direction, pressure, or other characteristic
of the fluid flowing through the lateral bore 150.
[0030] The protrusion 120 proximate the second end portion 114 of
the body 110 may include opposing upper and lower surfaces 122,
124, opposing side surfaces 126 (see FIG. 1), and an outer surface
128. The upper surface 122 (or "engaging" surface) may be
substantially planar (as shown), concave, convex, otherwise
contoured, or include some combination of the foregoing. In some
embodiments, the upper surface 122 may be substantially planar and
sloped away from the second end portion 114 of the body 110.
Accordingly, an axial distance between the upper surface 122 of the
protrusion 120 and the second end portion 114 of the body 110 may
increase as a lateral or radial distance between the upper surface
122 of the protrusion 120 and the central longitudinal axis 142 of
the body 110 increases. In some embodiments, at least a portion of
the upper surface 122 may be angled and non-perpendicular relative
to the longitudinal axis 142. The illustrated angle 130 between the
upper surface 122 of the protrusion 120 and the central
longitudinal axis 142 through the body 110 may be between
10.degree. and 89.5.degree. in some embodiments. More particularly,
the angle 130 may be within a range having lower and/or upper
limits including any of 10.degree., 20.degree., 30.degree.,
40.degree., 50.degree., 60.degree., 70.degree., 75.degree.,
80.degree., 85.degree., 89.5.degree., or values therebetween. For
example, the angle 130 may be from 20.degree. to 40.degree., from
40.degree. to 60.degree., from 50.degree. to 70.degree., from
60.degree. to 80.degree., from 20.degree. to 85.degree., at least
10.degree., or up to 89.5.degree.. In other embodiments, the angle
130 may be less than 10.degree. or more than 89.5.degree.. For
instance, the angle 130 may be 90.degree..
[0031] In some embodiments, the upper surface 122 of the protrusion
120 may planar, while in other embodiments the upper surface 122
may be curved or otherwise contoured. For instance, the upper
surface 122 may curve away from the second end portion 114 of the
body 110 such that the axial distance between the upper surface 122
of the protrusion 120 and the second end portion 114 of the body
110 may increase as a lateral or radial distance between the upper
surface 122 of the protrusion 120 and the central longitudinal axis
142 of the body 110 increases. In some embodiments, the radius of
curvature (not shown) of the upper surface 122 may range from 0.25
cm to 20 cm. For instance, the radius of curvature of the upper
surface 122 may be within a range having lower and/or upper limits
including any of 0.5 cm, 1 cm, 2 cm, 3 cm, 4 cm, 6 cm, 8 cm, 10 cm,
15 cm, 20 cm, or values therebetween. For example, the radius of
curvature may be from 0.5 cm to 2 cm, from 1 cm to 3 cm, from 2 cm
to 5 cm, from 4 cm to 10 cm, from 0.5 cm to 10 cm, at least 0.5 cm,
or up to 20 cm. In other embodiments, the radius of curvature of
the upper surface 122 may be less than 0.5 cm or more than 20
cm.
[0032] A width of the protrusion 120 (i.e., between the opposing
side surfaces 126) may, in some embodiments, be constant. In other
embodiments, the width of the protrusion 120 may vary. For
instance, the width of the protrusion 120 may increase as the
lateral or radial distance from the central longitudinal axis 142
of the body 110 increases. As such, the width of the protrusion 120
may be greater proximate the outer surface 128 of the protrusion
120 than proximate the outer surface 116 of the body 110. In some
embodiments, the protrusion 120 may have a "dovetail-shaped"
profile. Optionally, the outer surface 128 of the protrusion 120
may be substantially planar and substantially parallel to the
central longitudinal axis 142, although the outer surface 128 may
also be contoured or shaped in other manners in other
embodiments.
[0033] One or more lateral or radial bores 160 (one of which is
shown in FIG. 2) may be formed at least partially through the body
110 proximate the second end portion 114 and/or the protrusion 120
of the body 110. The radial bores 160 may also be formed at least
partially through the protrusion 120 in some embodiments. In some
embodiments, the one or more radial bores 160 may extend about
perpendicular relative to the body central longitudinal axis 142 of
the body. Accordingly, and as shown in FIG. 2, a central
longitudinal axis 162 through the radial bore 160 may be
substantially perpendicular relative to the central longitudinal
axis 142 of the body 110. In other embodiments, however, the
central longitudinal axis 162 of the one or more radial bores 160
may angled at a non-perpendicular angle relative to the central
longitudinal axis 142.
[0034] In some embodiments, the one or more radial bores 160 may
provide a path of fluid communication from the axial bore 140 to
the exterior of the body 110 through the outer surface 128, upper
surface 122, or lower surface 124 of the protrusion 120, or through
some combination thereof. Optionally, the radial bore 160 may be
permanently, fully, partially, or selectively blocked proximate the
outer surface 128 of the protrusion 120. For instance, a plug 164
may block or obstruct the radial bore 160. The plug 164 may be
positioned at least partially within the radial bore 160 (or around
the radial bore 160) and secured to the protrusion 120 via a
threaded connection, a friction fit, an adhesive, a mechanical
fastener, another mechanism, or some combination thereof. In some
embodiments, the plug 164 may be formed integrally with the
protrusion 120. In the same or other embodiments, the radial bore
160 may not extend fully through the protrusion 120.
[0035] Another opening, channel, or port (e.g., axial bore 170) may
further be formed through the protrusion 120 in some embodiments.
As shown, the axial bore 170 may extend at least partially between
the upper surface 122 of the protrusion 120 and the lower surface
124 of the protrusion 120. Although other orientations are
contemplated, a central longitudinal axis 172 of the axial bore 170
may be substantially parallel to the central longitudinal axis 142
of the body 110 and/or about perpendicular relative to the central
longitudinal axis 162 of the one or more radial bores 160. In some
embodiments, the axial bore 170 may intersect the one or more
radial bores 160. The axial bore 170 may be blocked or otherwise
obstructed proximate the lower surface 124 of the protrusion 120.
For instance, a plug 174 may block, restrict, or otherwise obstruct
the axial bore 170 at the lower surface 124 as shown in FIG. 2. The
plug 174 may be located at least partially within the axial bore
170 (or located around the axial bore 170) and secured therein via
a threaded connection, a friction fit, an adhesive, a mechanical
fasteners, other mechanism, or some combination thereof. The plug
174 may also be integrally formed with the protrusion 120, or the
axial bore 170 may not extend fully through the protrusion 120 to
the lower surface 124.
[0036] Cross-sectional shapes of the radial bore 160 and/or the
axial bore 170 may be a circle, an ellipse, an oval, a square, a
rectangle, other regular or irregular geometric shapes, or some
combination of the foregoing. Moreover the cross-sectional shape
and/or area of the radial bores 160 and/or the axial bores 170 may
vary along their respective lengths. In some embodiments, a
cross-sectional area of at least a portion of the radial bore 160
and/or the axial bore 170 may range from 0.1 cm.sup.2 to 15
cm.sup.2. For instance, the cross-sectional areas may be within a
range having lower and/or upper limits including any of 0.1
cm.sup.2, 0.5 cm.sup.2, 1 cm.sup.2, 1.5 cm.sup.2, 2 cm.sup.2, 4
cm.sup.2, 6 cm.sup.2, 8 cm.sup.2, 10 cm.sup.2, 15 cm.sup.2, or
values therebetween. For example, the cross-sectional area of a
radial bore 160 and/or axial bore 170 may be from 0.1 cm.sup.2 to 1
cm.sup.2, from 1 cm.sup.2 to 3 cm.sup.2, from 3 cm.sup.2 to 5
cm.sup.2, from 5 cm.sup.2 to 10 cm.sup.2, at least 0.1 cm.sup.2, or
less than 15 cm.sup.2. In still other embodiments, the
cross-sectional area of a radial bore 160 and/or axial bore 170 may
be less than 0.1 cm.sup.2 or more than 15 cm.sup.2.
[0037] FIG. 3 is a perspective view of an illustrative deflection
member 300 according to one or more embodiments. The deflection
member 300 is illustrative of a so-called "whipstock," but can
represent any type of deflection member that may be positioned
within a vertical, deviated, or other wellbore or borehole.
[0038] In accordance with some embodiments, the deflection member
300 may be anchored against a casing in a wellbore, or the
deflection member 300 may be anchored against the interior wall of
the wellbore. The deflection member 300 may include a body 310
having a sloped front surface 320. The sloped front surface 320 may
be oriented at an angle with respect to a central longitudinal axis
312 of the deflection member 300. The particular slope of the
sloped front surface 320 may be fixed or may vary along its length.
The slope may also vary between embodiments. According to various
embodiments, the slope may be between 1.degree. and 45.degree.. For
instance, the slope may be within a range having lower and/or upper
limits including any of 1.degree., 5.degree., 10.degree.,
15.degree., 20.degree., 25.degree., 30.degree., 40.degree.,
45.degree., or values therebetween. For instance, the slope of the
sloped front surface 320 may be from 1.degree. to 5.degree., from
5.degree. to 10.degree., from 10.degree. to 15.degree., from
15.degree. to 20.degree., from 20.degree. to 30.degree., from
30.degree. to 45.degree., at least 1.degree., or up to 45.degree..
In other embodiments, the slope of the sloped front surface 320 may
be less than 1.degree. or more than 45.degree.. In some
embodiments, the slope of the sloped front surface 320 may be
measured as degrees per 100 feet (30.5 m). The sloped front surface
320 may be used to redirect a cutting tool such as a drill bit or
mill. As an example, when a mill or drill bit is advanced within a
wellbore and contacts the deflection member 300, the sloped front
surface 320 may cause the mill or drill bit to deflect from the
central longitudinal axis of the wellbore toward the wellbore wall
so that the mill or drill bit may initiate milling of a window
through a casing and/or drilling of a deviated borehole.
[0039] According to some embodiments of the present disclosure, the
deflection member 300 may include or define a slot 330. As shown in
the illustrated embodiment, the slot 330 may be fully or partially
defined in the sloped front surface 320 of the deflection member
300. The slot 330 may be defined by a first, upper, or entry
portion 332 and a second, lower, or engaging portion 334. The entry
portion 332 of the slot 330 may be sized and shaped to have the
protrusion 120 of the retrieval tool 100 be inserted
laterally/radially therein. The engaging portion 334 of the slot
330 may be sized and shaped to have the protrusion 120 move or
slide axially thereto (e.g., in a direction about parallel to the
central longitudinal axis 312 of the deflection member 300). The
side surfaces of the deflection member 300 that define the engaging
portion 334 of the slot 330 may, however, restrict, and potentially
prevent, the protrusion 120 from being laterally or radially
removed from the slot 330 through the engaging portion 334 (e.g.,
in a direction about perpendicular to the central longitudinal axis
312 of the deflection member 300).
[0040] FIG. 4 illustrates an example downhole system in which
embodiments of the present disclosure may be practiced, and FIGS. 5
and 6 illustrate an example manner of using a retrieval tool 100 to
engage and/or move a deflection member 300 while in a wellbore 400.
FIG. 4 is a cross-sectional view of a retrieval tool 100 being run
into the wellbore 400 toward the deflection member 300, according
to one or more embodiments. The illustrated wellbore 400 is shown
as being substantially vertical; however, it should be appreciated
that the wellbore 400 may be horizontal, inclined, angled,
deviated, or may extend at other orientations or in other
manners.
[0041] The retrieval tool 100 may be run into the wellbore 400
using a drilling rig 410. The drilling rig 410 may run the
retrieval tool 100 into the wellbore using a drill string including
coiled tubing, drill pipe 412, a BHA, or other components, as shown
in FIG. 4. As the retrieval tool 100 is run into the wellbore 400,
a pump 414 at the surface may cause drilling fluid to flow through
the drill pipe 412 and into the retrieval tool 100. The drilling
fluid may be used to power one or more downhole motors 420 (e.g.,
turbine motors, positive displacement motors, etc.) and/or one or
more orienting tools to selectively align the protrusion 120 on the
retrieval tool 100 with a slot (e.g., slot 330 of FIG. 3) of the
deflection member 300.
[0042] With reference to FIGS. 2 and 4, drilling fluid may flow
into the axial bore 140 of the retrieval tool 100 through a first
end portion 112 of the body 110. A first portion of the drilling
fluid may flow from the axial bore 140 in the body 110, through the
lateral bores 150, and into the annulus 404 formed between an
exterior of the body 110 of the retrieval tool 100 and the internal
surface of the casing 402 (or wall of the wellbore 400). A second
portion of the drilling fluid may flow from the axial bore 140 in
the body 110, through the radial bore 160 in the body 110 and
protrusion 120, through the axial bore 170 in the protrusion 120,
and out the upper surface 122 of the protrusion 120. Fluid flowing
out of the upper surface 122 may flow into the annulus 404.
[0043] A pressure of the fluid in the drill pipe 412 and/or
retrieval tool 100 may be measured by a pressure sensor 416 coupled
to a standpipe 418 at the surface (e.g., on the drilling rig 410).
It should be appreciated with the benefit of the present disclosure
that the pressure of the fluid measured by the pressure sensor 416
at the standpipe 418 may be substantially the same as the pressure
of the fluid in the drill pipe 412 and/or in the retrieval tool
100, or potentially proportional thereto. In another embodiment,
the pressure of the fluid in the drill pipe 412 and/or retrieval
tool 100 may be measured by a downhole component, such as a
measurement-while-drilling tool 422. The fluid may have a first
pressure before the protrusion 120 of the retrieval tool 100
engages the slot 330 of the deflection member 300.
[0044] FIG. 5 is a cross-sectional view of the second end portion
114 of the retrieval tool 100 as the retrieval tool 100 slides
along the sloped front surface 320 of the deflection member 300,
according to one or more embodiments. With reference to FIGS. 4 and
5, the retrieval tool 100 may be run into the wellbore 400 until
the retrieval tool 100 contacts the deflection member 300. An
operator at the drilling rig 410 may determine that contact has
occurred when the weight of the downhole assembly (including the
retrieval tool 100) decreases at the surface. As shown, the
retrieval tool 100 may be oriented such that the outer surface 128
of the protrusion 120 is in contact with the sloped front surface
320 of the deflection member 300. The retrieval tool 100 may
continue to move with respect to the deflection member 300 until
the protrusion 120 is aligned with the entry portion 332 of the
slot 330.
[0045] FIG. 6 is a cross-sectional view of the second end portion
114 of the retrieval tool 100 after the protrusion 120 has engaged
with the slot 330 of the deflection member 300, according to one or
more embodiments. When the protrusion 120 is aligned with the entry
portion 332 of the slot 330, the protrusion 120 may be moved
laterally/radially, and inserted into the entry portion 332 of the
slot 330. Once the protrusion 120 has entered the entry portion 332
of the slot 330, the retrieval tool 100 may be pulled axially
(e.g., back or toward the surface) causing the protrusion 120 to
move or slide from the entry portion 332 of the slot 330 at least
partially into the engaging portion 334 of the slot 330. In some
embodiments, a dovetail connection may be made between the
protrusion 120 and the engaging portion 334 of the slot 330, which
can restrict, and potentially prevent, the protrusion 120 from
laterally disengaging the slot 330 while an axial force (e.g.,
toward the surface) is applied to the retrieval tool 100. The axial
force may be provided by, for instance, suspending the retrieval
tool 100 within the wellbore 400 of FIG. 4. Optionally, if weight
or a push force is applied to the retrieval tool 100, the
protrusion 120 may slide axially in a downhole direction, from the
engaging portion 334 of the slot 330, into the entry portion 332 of
the slot 330.
[0046] When the protrusion 120 is within the engaging portion 334
of the slot 330 and an axial and/or upward force is applied, the
upper surface 122 of the protrusion 120 may optionally abut, mate
with, or otherwise contact or engage an upper surface 336 of the
deflection member 300. The upper surface 336 may at least partially
define or border the slot 330. The upper surface 122 of the
protrusion 120, and/or the upper surface 336 of the deflection
member 300, may include a seal, a gasket, or the like. As a result,
when the upper surface 122 of the protrusion 120 contacts the upper
surface 336 of the deflection member 300, fluid flow may be at
least partially blocked or obstructed through the axial bore 170 of
the protrusion 120 proximate the upper surface 122 of the
protrusion 120. Such obstruction may restrict, or even prevent,
fluid from flowing therethrough into the annulus 404, which in turn
may cause the fluid in the drill pipe 412 (see FIG. 4) and/or
retrieval tool 100 to increase to a second pressure. In some
embodiments, the pressure may increase by between 10 kPa and 10,000
kPa. For instance, the magnitude of the pressure increase may be
within a range having lower and/or upper limits including any of 10
kPa, 100 kPa, 500 kPa, 750 kPa, 1,000 kPa, 1,250 kPa, 1,500 kPa,
1,750 kPa, 2,000 kPa, 2,500 kPa, 5,000 kPa, 10,000 kPa, or values
therebetween. For example, the magnitude of the pressure may
increase be between 500 kPa and 1,000 kPa, between 1,000 kPa and
1,500 kPa, between 1,500 kPa and 2,000 kPa, between 2,000 kPa and
5,000 kPa, between 100 kPa and 5,000 kPa, at least 10 kPa, or up to
10,000 kPa. In some embodiments, the magnitude of the pressure
increase may be less than 10 kPa, or more than 10,000 kPa. With
reference to FIG. 4, the increase in pressure may be measured by
the pressure sensor 416 at the surface and/or by downhole equipment
(e.g., the measurement while drilling tool 422). In another
embodiment, the measurement-while-drilling tool 422, a pressure
sensor within the body 110 of the retrieval tool 100, or another
component may be capable of measuring the pressure in the body
110.
[0047] With continued reference to FIGS. 4 and 6, a measured
increase in pressure may indicate that the protrusion 120 of the
retrieval tool 100 is fully and/or properly engaged with the slot
330 of the deflection member 300. Once engagement is confirmed, an
increased axial force may be applied to release the deflection
member 300 from its anchored position, and the retrieval tool 100
and deflection member 300 may be moved axially within the wellbore
400. If the measured pressure of the fluid subsequently decreases
(e.g., to about the first pressure), this may indicate that the
protrusion 120 of the retrieval tool 100 has disengaged from the
slot 330 of the deflection member 300. When an operator detects a
decrease in pressure, the user may avoid continuing to apply the
axial force. For instance, an operator may stop pulling the
retrieval tool 100 back toward the surface as the deflection member
300 may be left in the wellbore 400 in such a scenario. Rather, the
operator may advance the retrieval tool 100 in the wellbore 400 and
attempt to re-engage the protrusion 120 of the retrieval tool 100
with the slot 330 of the deflection member 300. In some
embodiments, the pressure of the fluid in the drill pipe 412 and/or
the retrieval tool 100 may continue to be measured as the retrieval
tool 100 and deflection member 300 move within the wellbore 400. In
such an embodiment, the measured pressure may indicate an elevated
pressure from the time the protrusion 120 of the retrieval tool 100
engages the slot 330 of the deflection member 300, until such time
as the deflection member 300 is moved to a desired location (e.g.,
removed from the wellbore 400).
[0048] While embodiments of the present disclosure relate to
detecting engagement between a retrieval tool and a deflection
member by measuring an increase in drilling fluid pressure, a
person having ordinary skill in the art will appreciate, in view of
the disclosure herein, that embodiments disclosed herein may be
modified to operate in other manners. For instance, a pressure drop
may be detected. A seal may be located on an upper surface of a
protrusion to restrict fluid flow out of the protrusion. Upon
engaging the upper surface of the protrusion with upper surface of
a slot in the deflection member, the seal may be broken or
weakened. The deflection member may allow fluid flow out of the
protrusion and into the annulus such that a pressure drop may
occur. If the protrusion is disengaged from the slot, the seal may
again form to increase pressure. Accordingly, a disengagement of
the retrieval tool and deflection member may be detected.
[0049] In the description herein, various relational terms are
provided to facilitate an understanding of various aspects of some
embodiments of the present disclosure. Relational terms such as
"bottom," "below," "top," "above," "back," "front," "left,"
"right," "rear," "forward," "up," "down," "horizontal," "vertical,"
"clockwise," "counterclockwise," "upper," "lower," "uphole,"
"downhole," and the like, may be used to describe various
components, including their operation and/or illustrated position
relative to one or more other components. Relational terms do not
indicate a particular orientation for each embodiment within the
scope of the description or claims. For example, a component of a
downhole tool that is described as a lower element may be further
from the surface relative to an upper element while within a
vertical wellbore, but may have a different orientation during
assembly, when removed from the wellbore, or in a lateral or other
deviated borehole. Accordingly, relational descriptions are
intended solely for convenience in facilitating reference to
various components, but such relational aspects may be reversed,
flipped, rotated, moved in space, placed in a diagonal orientation
or position, placed horizontally or vertically, or similarly
modified. Certain descriptions or designations of components as
"first," "second," "third," and the like may also be used to
differentiate between identical components or between components
which are similar in use, structure, orientation, or operation.
Such language is not intended to limit a component to a singular
designation. As such, a component referenced in the specification
as the "first" component may be the same or different than a
component that is referenced in the claims as a "first"
component.
[0050] Furthermore, while the description or claims may refer to
"an additional" or "other" element, feature, aspect, component, or
the like, it does not preclude there being a single element, or
more than one, of the additional or other element. Where the claims
or description refer to "a" or "an" element, such reference is not
be construed that there is just one of that element, but is instead
to be inclusive of other components and understood as "at least
one" of the element. It is to be understood that where the
specification states that a component, feature, structure,
function, or characteristic "may," "might," "can," or "could" be
included, that particular component, feature, structure, or
characteristic is provided in some embodiments, but is optional for
other embodiments of the present disclosure. The terms "couple,"
"coupled," "connect," "connection," "connected," "in connection
with," and "connecting" refer to "in direct connection with," or
"in connection with via one or more intermediate elements or
members." Components that are "integral" or "integrally" formed
include components made from the same piece of material, or sets of
materials, such as by being commonly molded or cast from the same
material, or machined from the same one or more pieces of material
stock. Components that are "integral" should also be understood to
be "coupled" together.
[0051] Although various example embodiments have been described in
detail herein, those skilled in the art will readily appreciate in
view of the present disclosure that many modifications are possible
in the example embodiments without materially departing from the
present disclosure. Accordingly, any such modifications are
intended to be included in the scope of this disclosure. Likewise,
while the disclosure herein contains many specifics, these
specifics should not be construed as limiting the scope of the
disclosure or of any of the appended claims, but merely as
providing information pertinent to one or more specific embodiments
that may fall within the scope of the disclosure and the appended
claims. Any described feature may be used in combination with any
other feature described herein, even when described with respect to
different embodiments. Features and aspects of methods described
herein may be performed in any order.
[0052] A person having ordinary skill in the art should realize in
view of the present disclosure that equivalent constructions do not
depart from the spirit and scope of the present disclosure, and
that various changes, substitutions, and alterations may be made to
embodiments disclosed herein without departing from the spirit and
scope of the present disclosure. Equivalent constructions,
including functional "means-plus-function" clauses are intended to
cover the structures described herein as performing the recited
function, including both structural equivalents that operate in the
same manner, and equivalent structures that provide the same
function. It is the express intention of the applicant not to
invoke means-plus-function or other functional claiming for any
claim except for those in which the words `means for` appear
together with an associated function. Each addition, deletion, and
modification to the embodiments that falls within the meaning and
scope of the claims is to be embraced by the claims.
[0053] While embodiments disclosed herein may be used in oil, gas,
or other hydrocarbon exploration or production environments, such
environments are merely illustrative. Systems, tools, assemblies,
methods, tool retrieval systems, and other components of the
present disclosure, or which would be appreciated in view of the
disclosure herein, may be used in other applications and
environments. In other embodiments, retrieval tools, systems,
methods, and components, or other embodiments discussed herein or
which would be appreciated in view of the disclosure herein, may be
used outside of a downhole environment, including in connection
with other systems, including within automotive, aquatic,
aerospace, hydroelectric, manufacturing, other industries, or even
in other downhole environments. The terms "well," "wellbore,"
"borehole," and the like are therefore also not intended to limit
embodiments of the present disclosure to a particular industry. A
wellbore or borehole may, for instance, be used for oil and gas
production and exploration, water production and exploration,
mining, utility line placement, or myriad other applications.
[0054] Certain embodiments and features may have been described
using a set of numerical values that may provide lower and/or upper
limits. It should be appreciated that a range may be defined by an
upper limit, a lower limit, or between a combination of any two
values. Numbers, percentages, ratios, measurements, or other values
stated herein are intended to include the stated value as well as
other values that are about or approximately the stated value, as
would be appreciated by one of ordinary skill in the art
encompassed by embodiments of the present disclosure. A stated
value should therefore be interpreted broadly enough to encompass
values that are at least close enough to the stated value to
perform a desired function or achieve a desired result. The stated
values include at least experimental error and variations that
would be expected by a person having ordinary skill in the art, as
well as the variation to be expected in a suitable manufacturing or
production process. A value that is about or approximately the
stated value and is therefore encompassed by the stated value may
further include values that are within 10%, within 5%, within 1%,
within 0.1%, or within 0.01% of a stated value.
[0055] The Abstract included with this disclosure is provided to
allow the reader to quickly ascertain the general nature of some
embodiments of the present disclosure. The Abstract is submitted
with the understanding that it will not be used to interpret or
limit the scope or meaning of the claims.
* * * * *