Note : Les descriptions sont présentées dans la langue officielle dans laquelle elles ont été soumises.
CA 02506348 2005-05-04
JUNCTION ASSEMBLY, SYSTEM AND METHOD FOR PROVIDING A DOWNHOLE
JUNCTION
REFERENCE TO CO-PENDING APPLICATIONS
The entire subject matter of U.S. Provisional application serial number
60/599,937 filed August 9, 2004 and entitled JUNCTION ASSEMBLY, SYSTEM AND
METHOD FOR PROVIDING A DOWNHOLE JUNCTION is incorporated herein by
reference. Applicant claims priority benefit under Title 35, United States
Code of United
States of U.S. application serial number 60/599,937 filed August 9, 2004 and
entitled
JUNCTION ASSEMBLY, SYSTEM AND METHOD FOR PROVIDING A DOWNHOLE
JUNCTION.
The entire subject matter of the Applicant's co-pending PCT application number
1 S PCT/CA03/01052 filed July 10, 2003 and entitled JUNCTION ASSEMBLY, SYSTEM
AND
METHOD FOR PROVIDING A DOWNHOLE JUNCTION is incorporated by reference.
Applicant claims priority benefit under Title 35, United States Code of United
States of PCT
application number PCT/CA03/01052 filed July 10, 2003 and entitled JUNCTION
ASSEMBLY, SYSTEM AND METHOD FOR PROVIDING A DOWNHOLE JUNCTION.
The entire subject matter of the Applicant's co-pending Canadian patent
application serial number 2,418,565 filed February 10, 2003 and entitled
APPARATUS,
SYSTEM AND METHOD FOR PROVIDING A DOWNHOLE JUNCTION is also
incorporated by reference. Applicant claims priority benefit under Title 35,
United States Code
of United States of Canadian patent application serial number 2,418,565 filed
February 10,
2003 and entitled APPARATUS, SYSTEM AND METHOD FOR PROVIDING A
DOWNHOLE JUNCTION
CA 02506348 2005-05-04
FIELD OF INVENTION
The present invention relates to a junction assembly adapted for insertion in
a
borehole, as well as a system and a method for providing a junction in a
borehole.
BACKGROUND OF INVENTION
Directional drilling technology permits the drilling of a lateral, branch or
secondary borehole from a primary, main or mother borehole. Further, greater
than one lateral
borehole may be drilled from the primary borehole resulting in a well referred
to as a
multilateral well.
Typically, the lateral borehole is drilled, and subsequently produced, through
a
gap or window cut or milled through a section of the existing casing string in
the primary
l5 borehole. The resulting junction between the primary and lateral boreholes
may be completed
in any desired manner depending upon the intended use and production of either
or both of the
primary and lateral boreholes. For instance, the Forum on Technical
Advancement - Multi-
Laterals ("TAML") provides a Multi Lateral Well Classification Matrix which
assigns a
"Level" number to a well indicative of its complexity, and particularly, the
complexity of the
junction. In determining the complexity of the junction, the type of support
provided at the
junction including the casing and/or cementing of the junction are considered.
For instance, a
Level 6 junction delivers pressure integrity at the junction using the casing.
United States of America Patent No. 5,388,648 issued February 14, 1995 to
Jordan, Jr. provides a number of methods and devices for completing
multilateral wells and for
sealing the junction between the primary and lateral boreholes. For instance,
to complete and
seal the junctions, ,lordan, Jr. utilizes "deformable means." A deformed or
fully collapsed mold
or device is run into the primary borehole adjacent to the pre-drilled
junction with the lateral
borehole. Once the device is in position, heat and / or pressure are applied
to cause the device
to expand or regain its original shape. As a result, a laterally extending
portion of the device or
mold extends trom the primary borehole into the lateral borehole.
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CA 02506348 2005-05-04
However, previous approaches to the provision, including the drilling and
completion, of the junction between the primary and lateral boreholes have not
been found to
be fully satisfactory.
Thus, there remains a need for an improved junction assembly for insertion in
a
borehole, and an improved system and a method for providing a junction in a
borehole
SUMMARY OF INVENTION
The present invention relates to a junction assembly adapted for insertion in
a
borehole and a system and method for providing a junction in a borehole,
preferably between a
primary borehole and a lateral borehole extending or to extend therefrom.
Further, the present
invention preferably provides for a Level 6 junction as defined by the TAML
Multi Lateral
Well Classification Matrix.
Preferably, the junction provides the ability to control the pressure within
the
lateral borehole at the junction rather than controlling the pressure through
a production liner
extending to the surface. In addition, the junction preferably permits an
amount of downhole
separation of gases from the formation fluids in order to enhance the
performance of the
downhole pumps and to minimize the amount of gas separation required at the
surface.
Further, the junction preferably permits a relatively high kick off and build
angle of the lateral
borehole.
In a first aspect of the invention, the invention is comprised of a junction
assembly adapted for insertion in a borehole. The junction assembly preferably
provides a
junction between a primary borehole and a lateral borehole to be drilled and /
or produced
therefrom. The junction assembly is comprised of a primary conduit and a
lateral conduit
having a conduit junction therebetween. To utilize the junction assembly, the
junction
assembly is positioned within the borehole, such as a primary borehole, at a
desired depth or
location and is oriented at a desired orientation such that the conduit
junction is positioned
adjacent a desired location or in a desired direction such as in the direction
of a desired lateral
borehole.
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Upon extending or passing an object, such as a downhole tool or other
equipment through the borehole, the junction assembly permits or provides for
the passage of
the object from the borehole and through the junction assembly to extend from
the conduit
junction in order to access the lateral borehole or to access the desired
location or direction of
the lateral borehole to be drilled therefrom. For instance, a drilling tool or
equipment may be
passed through the conduit junction in the junction assembly in order to drill
the lateral
borehole in the direction of the conduit junction. As well, once the lateral
borehole is drilled,
other downhole tools or equipment, including liners and production equipment,
may be passed
through the conduit junction of the junction assembly for access to the
lateral borehole. Thus,
the junction assembly assists in forming the junction between a primary
borehole and a lateral
borehole, as well as maintaining the integrity and stability of the junction,
while permitting
access to either or both the primary and lateral boreholes, as desired.
Preferably, the conduit
junction is oriented on the high side of the junction assembly to facilitate
passage of an object
through the junction assembly to the bottom of the primary borehole along the
low side of the
junction assembly.
In a preferred embodiment of the first aspect, the invention is comprised of a
junction assembly adapted for insertion in a borehole, the junction assembly
comprising:
(a) a primary conduit, the primary conduit having an upper end, a lower end,
and
defining a primary conduit bore extending through the primary conduit from the
upper end to the lower end; and
(b) a lateral conduit, wherein the lateral conduit is connected with the
primary
conduit at a conduit junction located between the upper end of the primary
conduit and the lower end of the primary conduit and wherein the lateral
conduit
extends within the primary conduit bore from the conduit junction towards the
upper end of the primary conduit.
3() The conduit junction is fornied or comprised of the interaction,
intersection or
communication between the primary conduit and the lateral conduit. The
intersection may be
provided between any of the elements or components of the primary and lateral
conduits and
may be defined in several manners. First, the primary conduit is preferably
comprised of a
primary conduit wall, the lateral conduit preferably defines a lateral conduit
bore, and the
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CA 02506348 2005-05-04
conduit junction may be comprised of an intersection of the primary conduit
wall and the
lateral conduit bore. Second, the lateral conduit preferably has a lower end
and the conduit
junction may be comprised of an intersection of the primary conduit wall and
the lower end of
the lateral conduit. Third, the lateral conduit is preferably comprised of a
lateral conduit wall
and the conduit junction may be comprised of an intersection of the primary
conduit wall and
the lateral conduit wall.
In each instance, the conduit junction is preferably comprised of a junction
opening. More preferably, the lateral conduit defines a lateral conduit bore
and the lateral
conduit bore communicates with the junction opening. In addition, the lateral
conduit is
preferably connected with the primary conduit at the conduit junction such
that the junction
opening is sealed from the primary conduit bore. This seal or sealed
connection between the
lateral and primary conduits may be provided by any sealing mechanism or means
for sealing
the connected conduits. However, in the preferred embodiment, the lateral
conduit is
connected with the primary conduit at the conduit junction by welding such
that the junction
opening is sealed from the primary conduit bore by welding.
The primary and lateral conduits may have any relative dimensions and
configurations permitting a connection therebetween to provide the conduit
junction and
permitting the lateral conduit to extend within the primary conduit bore from
the conduit
junction towards the upper end of the primary conduit. For instance, an upper
end of the lateral
conduit may be positioned within the primary conduit or extend from the upper
end of the
primary conduit. However, preferably, the upper end of the lateral conduit is
located within the
primary conduit bore. Further, the entire lateral conduit is preferably
contained within the
primary conduit. In the preferred embodiment, the primary conduit is comprised
of a primary
conduit wall, the primary conduit wall has an external dimension, and the
lateral conduit is
contained entirely within the external dimension of the primary conduit wall.
However, although the lateral conduit is preferably completely contained
within
the primary conduit, the dimensions of the lateral conduit are preferably
further selected such
that the lateral conduit does not substantially obstruct the primary conduit
bore. Thus, in the
preferred embodiment, the lateral conduit extends within the primary conduit
bore such that
passage is permitted through the primary conduit bore from the upper end of
the primary
conduit to the lower end of the primary conduit. As a result, an object may be
passed through
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the primary conduit bore between the upper and lower ends of the primary
conduit.
Alternately, an object may be passed from the upper end of the primary conduit
through the
primary conduit bore to an upper end of the lateral conduit and into the
lateral conduit bare.
From the lateral conduit bore, the object may pass through the conduit
junction, preferably
comprised of the junction opening.
Thus, the lateral conduit is preferably further configured to facilitate the
passage
of an object therethrough and to facilitate the passage of the object through
the conduit junction
in a desired direction. For instance, preferably, the lateral conduit has an
upper end and the
lateral conduit is comprised of a build angle section having a length
extending from the conduit
junction to a location between the conduit junction and the upper end of the
lateral conduit. In
addition, preferably, the primary conduit bore defines a longitudinal axis,
the lateral conduit
defines a lateral conduit bore, the lateral conduit bore defines a
longitudinal axis, and the
longitudinal axis of the lateral conduit bore along the build angle section
forms an angle
relative to the longitudinal axis of the primary conduit bore. In the
preferred embodiment, the
conduit junction is comprised of a junction opening and the junction opening
extends along the
length of the build angle section of the lateral conduit. Thus, the lateral
conduit provides a
"kick-off' angle for objects passing out of the conduit junction.
As well, the junction assembly may be utilized with a guide to facilitate the
passage of an object from the primary conduit into the lateral conduit. Thus,
at least one of the
primary conduit and the lateral conduit is preferably comprised of a latching
mechanism for
engaging with a complementary latching mechanism located on a guide for
guiding an object
into the lateral conduit. Although the latching mechanism may be associated
with either the
primary or lateral conduits, in the preferred embodiment, the lateral conduit
is comprised of the
latching mechanism.
Finally, the primary conduit is preferably connectable with a pipe string,
such as
a casing string, for placement in the borehole. Thus, the junction assembly
comprises a portion
of the casing string extending from the surface downhole. More particularly,
an upper end of
the primary conduit is preferably connectable with an upper pipe string, while
a lower end of
the primary conduit is preferably connectable with a lower pipe string. The
connection may be
provided by any means or mechanism for connecting the end of the primary
conduit with the
pipe string. In the preferred embodiment, the primary conduit is comprised of
an upper
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CA 02506348 2005-05-04
connector for connecting the upper end of the primary conduit with an upper
pipe string. In
addition, in the preferred embodiment, the primary conduit is further
comprised of a lower
connector for connecting the lower end of the primary conduit with a lower
pipe string.
In a second aspect of the invention, the invention is comprised of a system or
a
kit for providing a junction in a borehole. Preferably, the system is
comprised of a pipe string
adapted for insertion in the borehole and the junction assembly, as described
above, connected
with the pipe string. Further, the system is preferably comprised of at least
one of an orienting
device and a removable guide, and preferably both the orienting device and the
removable
guide.
The orienting device is adapted for insertion in the pipe string for
indicating an
orientation of the orienting device, wherein the orienting device is further
adapted to selectively
engage the junction assembly such that the orientation of the orienting device
provides an
indication of an orientation of the junction assembly.
The orienting device may be comprised of any device or apparatus capable of
insertion in the junction assembly and which is preferably removable and which
is capable of
indicating or providing to a user or operator the orientation of the orienting
device such that the
orientation of the junction assembly may be determined. Preferably, the
orienting device is
particularly adapted to be inserted in the primary conduit and to engage the
lateral conduit in
order to selectively engage the orienting device with the junction assembly.
In the prefen-ed
embodiment, the orienting device is comprised of a device housing and the
device housing is
adapted to be inserted in the primary conduit and to engage the lateral
conduit in order to
?5 selectively engage the orienting device with the junction assembly.
Further, the orienting device preferably defines a passage therethrough for
conducting a fluid through the orienting device. Thus, a fluid, such as a
bonding agent or a
slurry of a hardenable or settable liquid, including a cementitious slurry,
may be passed through
the junction assembly following the orientation of the junction assembly
utilizing the orienting
device in order to maintain the position of the junction assembly in the
borehole.
In the preferred embodiment, the orienting device is comprised of (a) a device
housing adapted for insertion in the primary conduit, wherein the device
housing comprises a
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CA 02506348 2005-05-04
recess for receiving the lateral conduit such that the device housing engages
the lateral conduit;
and (b) a tubular member extending through the device housing, wherein the
tubular member
defines a passage for conducting a fluid through the orienting device.
In addition, the orienting device is preferably comprised of an orientation
indicator for providing an indication of the orienting device. The orienting
device may be
comprised of one or more apparatuses or sensors capable of sensing and
communicating the
orientation of the orienting device. The selective engagement of the junction
assembly by the
orienting device is such that the orientation of the orienting device provides
an indication of an
orientation of the junction assembly. Preferably, the information concerning
the orientation, as
provided or indicated by the orienting device, is communicated to the surface
for use by an
operator of the system.
The orientation indicator may be mounted, affixed, fastened or otherwise
associated with the orienting device, preferably the device housing, in any
manner permitting
the orientation indicator to perform its function. 1f desired, the orientation
indicator may be
contained within a separate tubular member, pipe joint or sub, such as within
an orienting sub,
which is fastened, connected or mounted with the device housing in a manner
permitting the
orientation indicator to operate and to sense and communicate the orientation
of the orienting
device.
Further, the orienting device is preferably comprised of a stop mechanism for
limiting the extent to which the orienting device may be inserted in the
primary conduit. In
addition, in order to insert and remove the orienting device from the junction
assembly, the
orienting device is preferably connectable with a pipe string in any manner
and by any
connecting means or mechanism. In the preferred embodiment, the tubular member
is
comprised of an upper connector for connecting the orienting device with an
upper pipe string.
The tubular member is further preferably comprised of a lower connector for
connecting the
orienting device with a lower pipe string.
Similarly, the removable guide is preferably adapted for insertion in the pipe
string for guiding an object into the lateral conduit, wherein the guide is
adapted to selectively
engage the junction assembly such that the guide is oriented to guide the
object into the lateral
conduit. The guide is provided to guide or direct objects such as downhole
tools or equipment,
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CA 02506348 2005-05-04
including a drilling tool or production tool or equipment, through the
junction assembly from
the primary borehole to the lateral borehole. Thus, the guide preferably
guides or directs the
object into the lateral conduit towards the conduit junction, and particularly
the junction
opening, so that the object may extend from or pass through the junction
opening to the lateral
borehole.
The removable guide may be comprised of any removable device or apparatus
capable of insertion in the pipe string or casing string, adapted to
selectively engage the
junction assembly and able to guide an object into the lateral conduit.
Preferably, the guide is
comprised of a guide housing and the guide housing is adapted to be inserted
in the primary
conduit and to engage the lateral conduit in order to selectively engage the
guide with the
junction assembly. Further, the guide is preferablycomprised of an upper
surface which is
sloped towards the lateral conduit when the guide is engaged with the junction
assembly.
1n the preferred embodiment, the guide is comprised of a guide housing adapted
for insertion in the primary conduit, wherein the guide housing comprises a
recess for receiving
the lateral conduit such that the guide housing engages the lateral conduit,
wherein the guide
housing has an upper surface and wherein the upper surface is sloped towards
the recess in
order to guide the object into the lateral conduit.
The guide is also further preferably comprised of a latching mechanism for
engagement with a complementary latching mechanism associated with the
junction assembly.
The complementary latching mechanisms inhibit or prevent the movement of the
guide within
the junction assembly following the proper placement of the guide within the
junction
assembly. In order to remove the guide from the junction assembly, the
latching mechanisms
must be released in some manner. Preferably, the guide is released by shearing
of the latching
mechanism or complementary latching mechanism. In the preferred embodiment,
the latching
mechanism of the guide is comprised of a shear mechanism for releasing the
latching
mechanism. In addition, the guide is further preferably comprised of a stop
mechanism for
limiting the extent to which the guide may be inserted in the primary conduit.
The removable guide may be placed within and retrieved from the junction
assembly by any apparatus including a pipe string or other device or means for
running and
retrieving the guide. However, preferably, the guide is further comprised of a
running and
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retrieval mechanism for engagement with a running and retrieval tool for
placement and
retrieval of the guide. Specifically, the running and retrieval tool is
adapted to selectively
engage and disengage the running and retrieval mechanism of the guide.
Although the running
and retrieval mechanism and the running and retrieval tool may have any
compatible or
complementary structures capable of engaging each other, the running and
retrieval mechanism
is preferably comprised of a slot or a pin for engagement with a complementary
slot or a
complementary pin associated with the running and retrieval tool.
In a third aspect of the invention, the invention is comprised of a method for
providing a junction in a borehole. Preferably, the method is performed
utilizing the junction
assembly and system of the within invention as described herein, and
particularly, the preferred
embodiments of the junction assembly and system. However, the method may be
performed
using any junction assembly, system or device suitable for, and capable of,
performing the
within method.
Preferably, the method is comprised of the following steps:
(a) positioning a pipe string and a junction assembly connected with the pipe
string
at a desired depth in the borehole;
(b) inserting an orienting device in the pipe string such that the orienting
device
selectively engages the junction assembly;
(c) obtaining an indication of an orientation of the orienting device;
(d) rotating the pipe string and the junction assembly in order to obtain a
desired
orientation of the junction assembly;
(e) maintaining the desired orientation of the junction assembly in the
borehole
while introducing a bonding agent into the borehole through the orienting
device; and
(f) removing the orienting device from the pipe string.
CA 02506348 2005-05-04
Any bonding agent may be used such as a slurry of a hardenable or settable
liquid, such as a cementitious slurry. The bonding agent is conducted through
the orienting
device and passes into the borehole, particularly the primary borehole, and
subsequently into a
space or annulus between the junction assembly and the wall of the primary
borehole. Once the
bonding agent sets or hardens, the junction assembly is fixed in the desired
orientation and the
hardened bonding agent forms or provides a portion of the casing string of the
borehole.
Subsequently, to exit the junction assembly through the junction opening, a
drilling tool may be
required to drill through the portion of the hardened bonding agent adjacent
the junction
opening.
In addition, the method is preferably further comprised of the following
steps:
(g) inserting a guide in the pipe string with a running and retrieval tool
such that the
guide selectively engages the junction assembly; and
(h) inserting an object in the pipe string such that the object is guided into
the lateral
conduit by the guide.
Any object may be guided into the lateral conduit including any drilling,
completion or production equipment or tools. For instance, the object may be
comprised of a
drilling tool for drilling a lateral borehole. The object may also be
comprised of a liner for
lining a lateral borehole.
Finally, the method may be further comprised of the step of removing the guide
from the pipe string with the running and retrieval tool. In the preferred
embodiment, the step
of removing the guide from the pipe string is comprised of shearing a shear
mechanism
associated with the junction assembly.
In another of its aspects, the present invention provides a junction device
for
providing a lateral junction in a borehole, comprising a primary conduit
having an upper end
portion and a lower end portion, each of which is arranged for attachment with
one or more
casing members to form a borehole casing string, the primary conduit forming a
primary
conduit bore, a lateral conduit having a lateral conduit bore, the lateral
conduit being anchored
to the primary conduit so as to be immovable relative thereto, the primary
conduit having a first
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peripheral region encircling a junction opening formed therein, the lateral
conduit having a
second peripheral region encircling the lateral conduit bore, the second
peripheral region being
sealably welded to the first peripheral region so as to form a lateral conduit
path which is
isolated from the primary bore.
Preferably, the first peripheral region includes a first peripheral surface
and the
second peripheral region includes an upstanding flange which extends at least
partway along
the junction opening, the upstanding flange including a second peripheral
surface, the second
peripheral surface lying immediately adjacent the first peripheral surface.
In an embodiment, a continuous weld seam joins the first and second peripheral
regions adjacent the first and second peripheral surfaces, though other
attachment means may
be provided as required.
In an embodiment, attachment means is provided for attaching the lateral
conduit to the primary conduit in advance of the junction opening. In an
embodiment, the
attachment means includes one or more weld joints between the adjacent lateral
and primary
conduits.
In one example, the lateral conduit has an outer surface exposed to the
primary
conduit bore, the primary conduit having an inner surface exposed to the
primary conduit bore
and attachment means is provided for attaching the lateral conduit to the
primary conduit with
the outer and inner faces immediately adjacent one another.
In an embodiment, the primary conduit has an outer surface to communicate
with the borehole and the second peripheral region terminates at or is
substantially flush with
the outer surface within the first peripheral region.
In a further desirable aspect, the primary conduit is operable to maintain a
first
fluid pressure ranging from about 0 to about 10 MPA while the lateral conduit
is operable to
maintain a second fluid pressure ranging from about 30 to 60 MPA, though other
pressures
and/or pressure ranges may be used as needed depending on the specifications
of the pipes, for
instance.
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Preferably, the primary conduit includes a primary longitudinal axis and the
first section of the lateral conduit includes a first longitudinal axis which
is substantially
parallel with but offset from the primary longitudinal axis. The second
section of the lateral
conduit has a second longitudinal axis which is at an angle of less than
ninety degrees relative
to the primacy longitudinal axis.
In another of its aspects, the present invention provides a junction device
for
providing a lateral junction in a borehole, comprising primary conduit means
having an upper
end portion and a lower end portion, first attachment means for attaching the
upper and lower
end portions to one or more casing members to form a borehole casing string,
the primary
conduit means forming a primary conduit bore, the lateral conduit means having
a lateral
conduit bore, the lateral conduit means being anchored to the primary conduit
means so as to be
immovable relative thereto, the primary conduit means having a first
peripheral region
circumscribing a junction opening formed therein, the lateral conduit means
having a second
l5 peripheral region circumscribing the lateral conduit bore, second
attachment means for
sealingly attaching the second peripheral region to the first peripheral
region so as to form a
lateral conduit path which is isolated from the primary bore.
SUMMARY OF DRAWINGS
Embodiments of the invention will now be described with reference to the
accompanying drawings, in which:
Figure 1 is a side view of a preferred embodiment of a junction assembly of
the
within invention;
Figure lA is a side view of an alternative junction assembly;
Figure 2 is a top view of the junction assembly shown in Figure I;
Figure 2A is a top view of the alternative junction assembly shown in Figure
lA;
Figure 3 is a cross-sectional view of the junction assembly taken along lines
3 - 3
of Figure 2;
Figure 3A is a cross-sectional view of the alternative junction assembly taken
along lines 3A - 3A of Figure 2A;
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Figure 4 is a cross-sectional view of the junction assembly taken along lines
4 - 4
of Figure 2;
Figure 4A is a cross-sectional view of the alternative junction assembly taken
along lines 4A - 4A of Figure 2A;
Figure 4B is a cross-sectional view of the alternative junction assembly taken
along lines 4B - 4B of Figure 2A;
Figure 5 is a side view of a preferred embodiment of a removable orienting
device of the within invention;
Figure 6 is a top view of the orienting device as shown in Figure 5;
Figure 7 is a front view of a first embodiment of a removable guide of the
within
mvent~on;
Figure 8 is a cross-sectional view of the guide taken along lines 8 - 8 of
Figure 7;
Figure 9 is a side view of the guide as shown in Figure 7;
Figure 10 is a top view of the guide as shown in Figure 7;
I S Figure 11 is a longitudinal sectional view of the guide taken along lines
11 - 11
of Figure 10 showing a latch;
Figure 12 is a perspective view of a preferred embodiment of an inner latch
member comprising the latch shown in Figure 1 l;
Figure 13 is a perspective view of a preferred embodiment of an outer latch
member comprising the latch shown in Figure 11;
Figure 14 is a side view of the inner and outer latch members shown in Figures
12 and 13;
Figure 15 is a side view of a first removable guide running and retrieving
tool for
use with the first embodiment of the removable guide as shown in Figure 7;
Figure 16 is a front view of a second preferred embodiment of a removable
guide
of the within invention;
Figure 17 is a cross-sectional view of the guide taken along lines 17 - 17 of
Figure 16;
Figure 18 is a side view of the guide as shown in Figure 16;
Figure 19 is a top view of the guide as shown in Figure 16;
Figure 20 is a longitudinal sectional view of the guide taken along lines 20 -
20
of Figure 19;
Figure 21 is a side view of a second removable guide running and retrieving
tool
for use with the second embodiment of the removable guide as shown in Figure
16;
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Figure 22 is a side view of a third removable guide running and retrieving
tool
for alternate use with the second embodiment of the removable guide as shown
in Figure I 6;
Figure 23 is a cross-sectional view of the third running and retrieval tool
taken
along lines 23 - 23 of Figure 22;
Figure 24 is a schematic cross-sectional view of a casing string showing the
configuration schematically of the orienting device and the guide as shown in
Figures 5 and 7
or 16 respectively within the casing string;
Figure 25 is a schematic cross-sectional view of the junction assembly shown
in
Figure l, showing the configuration schematically of the orienting device and
the guide as
shown in Figures 5 and 7 or 16 respectively within the conduit;
Figure 26 is a pictorial view of the junction assembly shown in Figure 1
positioned within a primary borehole.
DETAILED DESCRIPTION
Referring to Figure l, the within invention is comprised of a junction
assembly
(20) for insertion in a borehole for providing a downhole junction, preferably
between a
primary borehole and an existing or intended lateral borehole. More
particularly, the junction
assembly (20) provides a pre-formed junction for placement at a desired
location in the primary
borehole. Once positioned, and preferably cemented, at the desired location in
the borehole,
the junction assembly (20) may be utilized to direct any object such as a
drilling tool or drilling
equipment from the primary borehole in the direction that the lateral borehole
is to be drilled
for the drilling of the lateral borehole. Further, the junction assembly (20)
may be utilized to
direct other objects such as downhole tools or equipment, including production
equipment and
tubing strings, into the lateral borehole in order to produce fluids from the
lateral borehole or
conduct fluids downhole into the lateral borehole.
Further, referring to Figures 1, 5, 7 and 16, the within invention is also
directed
at a system for providing a junction in a borehole, preferably between the
primary borehole and
the lateral borehole. In the preferred embodiment, the system is comprised of
the junction
assembly (20) and at least one, and preferably both, of a removable orienting
device (22) and a
removable guide (24).
CA 02506348 2005-05-04
Referring to Figures 1 - 4, the junction assembly (20) is adapted for
insertion in
the borehole, referred to herein as the primary borehole. In other words, the
outer dimensions
of the junction assembly (20) are selected such that the junction assembly
(20) may be readily
inserted within and passed through the primary borehole to the desired depth.
The junction
assembly (20) is preferably comprised of a primary conduit (28) and a lateral
conduit (30)
connected at a conduit junction (31 ).
The primary conduit (28) may be comprised of any suitable tubular member or
pipe joint and has an upper end (32), a lower end (34) and a primary conduit
bore (36)
extending therethrough between the upper and lower ends (32, 34). Further, the
primary
conduit (28) is comprised of a primary conduit wall (38) which defines the
primary conduit
(28) between the upper and lower ends (32, 34) and defines the bore (36)
therein. Preferably,
the primary conduit (28) is comprised of a single tubular member extending
between the upper
and lower ends (32, 34). However, alternately, the primary conduit (28) may be
comprised of
two or more tubular members connected, affixed, mounted or otherwise attached
together,
either permanently or removably, to form an integral unit between the upper
and lower ends
(32, 34).
The upper end (32) of the primary conduit (28) is adapted for connection with
an
upper pipe string, preferably an upper portion of a casing string, such that
the primary conduit
(28) may be connected with the casing string for lowering and rotating the
primary conduit (28)
within the primary borehole. Further, the upper portion of the casing string
preferably extends
to the surface to permit communication between the surface and the junction
assembly (20). In
other words, objects such as downhole tools and equipment, including drilling
and production
tools, may be passed through the casing string from the surface for insertion
into the primary
conduit (28) through its upper end (32). Conversely, fluids may be pumped from
the primary
conduit (28) out of its upper end (32) and to the surface either within the
casing string itself or
within production tubing or a production string extending therethrough.
The upper pipe string may be comprised of one or more joints, subs or lengths
of
pipe or casing. In the preferred embodiment, the upper pipe string is
comprised of the upper
portion of a casing string (40) as shown in Figure 26. Further, preferably,
the upper portion of
the casing string (40) is comprised of a plurality of joints of casing
connected together and
extending from the upper end (32) of the primary conduit (28) to the surface.
The upper end
16
CA 02506348 2005-05-04
(32) may be permanently or removably connected with the upper pipe string in
any manner and
by any connector or connection mechanism. However, preferably, the primary
conduit (28) is
comprised of an upper connector (33) for connecting the upper end (32) with
the upper pipe
string, In the preferred embodiment, the upper connector (33) is comprised of
a threaded
connection provided between the upper end (32) of the primary conduit (28) and
the adjacent
end of the upper pipe string, being the upper portion of the casing string
(40). In the preferred
embodiment, the upper end (32) of the primary conduit (28) is comprised of a
threaded box
connector for engagement with a compatible threaded pin connector of the
casing string (40).
Similarly, the lower end (34) of the primary conduit (28) is preferably
adapted
for connection with a lower pipe string, preferably a lower portion of a
casing string, such that
the primary conduit (28) may be connected with further portions of a pipe
string which extend
downhole from the primary conduit (28) within the primary borehole. The lower
pipe string
may be comprised of one or more further joints, subs or lengths of pipe or
casing, which may
1 S be connected with further downhole equipment such as a cementing shoe or
cement float for
facilitating the casing of the primary borehole or a downhole pump for
producing fluids from
the primary borehole. Thus, communication is preferably permitted between the
lower portion
of the pipe string and the lower end (34) of the primary conduit (28). For
instance, drilling
tools and equipment may be passed through the primary conduit (28) and the
lower pipe string
from the surface for further drilling of the primary borehole. As well, fluids
may be pumped
from the primary borehole through the lower pipe string, into the primary
conduit (28) and
subsequently to the surface either within the lower pipe string itself or
within production tubing
or a production string extending therethrough.
The lower end (34) may be permanently or removably connected with the lower
pipe string in any manner and by any connector or connection mechanism.
However,
preferably, the primary conduit (28) is comprised of a lower connector (35)
for connecting the
lower end (34) with the lower pipe string, In the preferred embodiment, the
lower connector
(35) is comprised of a threaded connection provided between the lower end (34)
of the primary
conduit (28) and the adjacent end of the lower pipe string. In the preferred
embodiment, the
lower end (34) of the primary conduit (28) is comprised of a threaded box
connector for
engagement with a compatible threaded pin connector of the lower pipe string.
17
CA 02506348 2005-05-04
Thus, preferably, the primary conduit (28) forms a portion or section of a
pipe
string or bottomhole assembly extending downhole from the surface. More
particularly in the
preferred embodiment, the primary conduit (28) forms or comprises a portion of
the casing
string (40) bottomhole assembly, being connected between an upper portion and
a lower
portion of the casing string (40). The outside diameter of the primary conduit
(28), as defined
by the primary conduit wall (38), may be selected to match or be the same as
the outside
diameter of the adjacent upper and lower pipe string or casing string
portions. However, as
described further below, in the preferred embodiment of the junction assembly
(20), the outside
diameter of the primary conduit (28) is typically greater than the outside
diameters of the
adjacent upper and lower pipe string portions to accommodate the further
structural members
or components of the primary conduit (28) therein. For instance, in the
preferred embodiment,
the typical outside diameter of the upper pipe or casing string portion is
about 9 5/8 inches
(about 24. 45 cm). However, the outside diameter of the primary conduit (28)
is preferably
about 10 '/ inches (about 27.31 cm). Thus, where necessary, a connector member
or connector
joint, often referred to as an "upset" or a connector sub, may be connected
between the primary
conduit (28) and the adjacent pipe string to accommodate or provide for the
change in the
outside diameters.
In addition, where a multilateral well is desired, greater than one junction
assembly (20) may be connected together in series either directly or
indirectly and connected
with the casing string (40) for insertion in the primary borehole. For
instance, the upper end
(32) of one primary conduit (28) may be directly connected with the lower end
(34) of a further
primary conduit (28). In this case, a threaded box connector may be provided
by one of the
upper end (32) of the first primary conduit (28) and the lower end (34) of the
further primary
conduit (28) and a threaded pin connector may be provided by the other of the
upper end (32)
of the first primary conduit (28) and the lower end (34) of the further
primary conduit (28).
Alternately, a connector sub or joint, or one or more further sections or
joints of pipe or tubular
members, may be connected between the adjacent ends of the primary conduits
(28).
The junction assembly (20) is further comprised of the lateral conduit (30)
which
is connected with the primary conduit (28) at the conduit junction (31 ).
Preferably, the conduit
junction (31) is located between the upper and lower ends (32, 34) of the
primary conduit (28).
Further, the lateral conduit (30) preferably extends within the primary
conduit bore (36) from
the conduit junction (31 ) towards the upper end (32) of the primary conduit
(28). The conduit
18
CA 02506348 2005-05-04
junction (31 ) is preferably comprised or founed from the intersection of the
structure of the
primary conduit (28) and the structure of the lateral conduit (30). This
intersection may be
described in various manners as discussed further below.
The lateral conduit (30) is preferably rigidly or securely mounted or
connected
within the primary conduit (28) in any manner and by any connecting means or
mechanism.
However, in the preferred embodiment, the lateral conduit (30) is connected
with the primary
conduit (28) at the conduit junction (31) by welding such that a sealed
connection is provided.
The lateral conduit (30) has an upper end (44), a lower end (46) and a lateral
conduit bore (48) extending therethrough between the upper and lower ends (44,
46). Further,
the lateral conduit (30) is comprised of a lateral conduit wall (50) which
defines the lateral
conduit (30) between the upper and lower ends (44, 46) and defines the bore
(48) therein.
Preferably, the lateral conduit (30) is comprised of a single tubular member
or joint of pipe
extending between the upper and lower ends (44, 46). However, alternately, the
lateral conduit
(30) may be comprised of two or more tubular members or joints of pipe
connected, affixed,
mounted or otherwise attached together, either permanently or removably, to
form an integral
unit between the upper and lower ends (44, 46).
Preferably, the upper end (44) of the lateral conduit (30) is located within
the
primary conduit bore (36). Further, in the preferred embodiment, the primary
conduit wall (38)
has an external dimension and the lateral conduit (30) is contained entirely
within the external
dimension of the primary conduit wall (38). However, the lateral conduit (30)
further
preferably extends within the primary conduit bore (36) such that passage is
permitted through
the primary conduit bore (36) from the upper end (32) to the lower end (34) of
the primary
conduit (28). In other words, the primary conduit bore (36) is not
substantially obstructed by
the lateral conduit (30).
The conduit junction (31) may be comprised of an intersection of the primary
conduit wall (38) and the lateral conduit bore (48). Alternately, the conduit
junction (31) may
be described as being comprised of an intersection of the primary conduit wall
(38) and the
lower end (46) of the lateral conduit (30). Finally, the conduit junction (31
) may be also
alternately be described as being comprised of an intersection of the primary
conduit wall (38)
and the lateral conduit wall (50).
19
CA 02506348 2005-05-04
In any event, the conduit junction (31) is preferably comprised of a junction
opening (42). In the preferred embodiment, the primary conduit wall (38)
defines the junction
opening (42) therein. The junction opening (42) may have any shape or
configuration
compatible with its intended function as described herein, however, in the
preferred
embodiment, the junction opening (42) is elongate and is oriented
longitudinally between the
upper and lower ends (32, 34) of the primary conduit (28). Further, in the
preferred
embodiment, the lateral conduit bore (48) communicates with the junction
opening (42).
The upper end (44) of the lateral conduit (30) is preferably positioned within
the
primary conduit (28) for communication with the bore (36) of the primary
conduit (28). Thus,
any object including tools and equipment and any fluids may communicate and
pass between
the bore (36) of the primary conduit (28) and the bore (48) of the lateral
conduit (30) through
the upper end (44) of the lateral conduit (30). The lower end (46) of the
lateral conduit (30) is
adapted to be compatible with the junction opening (42) for engagement
therewith such that the
bore (48) of the lateral conduit (30) communicates with the junction opening
(42). Thus, tools,
equipment and fluids may communicate and pass between the bore (48) of the
lateral conduit
(30) and outside the primary conduit wall ('38) through the lower end (46) of
the lateral conduit
(30) and the junction opening (42).
In other words, tools, equipment and fluid may communicate and pass between
the primary borehole and the lateral borehole by passing through the upper end
(32) of the
primary conduit (28) into the bore (36) of the primary conduit (28), the upper
end (44) of the
lateral conduit (30) into the bore (48) of the lateral conduit (30) and
through the lower end (46)
of the lateral conduit (30) and the junction opening (42) engaged with the
lower end (46).
Further, the connection at the conduit junction (31 ) preferably provides for
the
sealing of the junction opening (42) from the primary conduit bore (36). The
sealing may be
accomplished in any manner. However, in the preferred embodiment, the lower
end (46) of the
lateral conduit (30) is shaped or configured to engage, and preferably
sealingly engage, the
primary conduit wall (38) within the bore (36) of the primary conduit (28)
about the entire
junction opening (42). Although the lateral conduit (30) may be mounted in the
bore (36) of
the primary conduit (28) in any manner, in the preferred embodiment, an upper
portion (52) of
the lateral conduit wall (50) adjacent the upper end (44) of the lateral
conduit (30) is securely
affixed within the bore (36) of the primary conduit (28) to the primary
conduit wall (38) in a
CA 02506348 2005-05-04
position uphole of the junction opening (42) such that the lower end (46) of
the lateral conduit
(30) may engage the junction opening (42).
Specifically, the junction opening (42) is sealed from the primary conduit
bore
(36) by welding. In particular, the upper portion (52) of the lateral conduit
wall (50) is
preferably welded to the primary conduit wall (38). Referring to Figures 2 and
3, a weld hole
or slot (54) is preferably drilled or otherwise formed within the primary
conduit wall (38) along
the portion or section of the primary conduit wall (38) intended to be affixed
or mounted with
the upper portion (52) of the lateral conduit (30). Each weld slot (54) may
have any
configuration, but preferably, each weld slot (54) is about 1 inch (2.54 cm)
long and 3/ inch
(1.905 em) wide and is oriented longitudinally along the primary conduit wall
(38). Further,
the weld slots (54) are preferably spaced apart along the portion of the
primary conduit wall
(38) to engage the upper portion (52) of the lateral conduit wall (50). In the
preferred
embodiment, the weld slots (54) are preferably spaced apart by about 8 inches
(20.32 cm).
Once the lateral conduit wall (50) is positioned adjacent the weld slots (54),
a plug weld (54) is
created in the weld slot (54) to secure the lateral conduit (30) within the
primary conduit (28) as
shown in Figure 3.
Referring to Figures 2 and 4, the lower end (46) of the lateral conduit (38)
is
shaped to be compatible with the junction opening (42). Thus, the lower end
(46) is preferably
elongated or shaped in a manner similar to that of the junction opening (42).
However, the
edge of the elongated lower end (46) of the lateral conduit (30) need not
engage the entire edge
defining the junction opening (42). In other words, the lower end (46) of the
lateral conduit
(30) only needs to be compatible with the junction opening (42) in that the
bore (48) of the
2~ lateral conduit (30) must communicate with the junction opening (42) when
the lateral conduit
(30) is mounted within the primary conduit (28).
For instance, as shown in Figure 2 in the preferred embodiment, the width of
the
junction opening (42) and the width of the lower end (46) of the lateral
conduit (30) are similar.
However, the length of the junction opening (42) is greater than that of the
lower end (46).
Alternately, however, the lengths may also be similar. In any event, in order
to provide a sealed
junction, the complete or entire edge defining the junction opening (42) is
preferably sealing
engaged with the adjacent lateral conduit (30), either the lower end (46) or a
portion of the
lateral conduit wall (50), as shown in Figures 2 and 4. In the preferred
embodiment, a weld
21
CA 02506348 2005-05-04
(58) is provided between the adjacent surfaces of the junction opening (42)
and the lateral
conduit (30).
The lateral conduit (30) is preferably comprised of two portions. First, the
upper
portion (52) adjacent the upper end (44) of the lateral conduit (30) is also
referred to as the "no
build section" of the lateral conduit (30). The upper portion (52) or no build
section of the
lateral conduit (30) preferably has a longitudinal axis which extends parallel
with a longitudinal
axis of the primary conduit bore (36). In use, as described further below, an
uphole end of a
production liner for the lateral borehole may be anchored or hung from the
lateral conduit (30),
particularly the upper portion (52) of the lateral conduit (30).
Second, the lateral conduit (30) is comprised of a lower portion (60), also
referred to as the "build angle section" of the lateral conduit (30), located
downhole of the
upper portion (52) adjacent the lower end (46) of the lateral conduit (30).
The build angle
section (60) thus has a length extending from the conduit junction (31) to a
location 'between
the conduit junction (31 ) and the upper end (44) of the lateral conduit (30).
The lower portion
(60) or build angle section is bent or deflected to provide a desired angle
offset from the
longitudinal axis of the lateral conduit (30) in the upper portion (52) or no
build section. In
other words, the lateral conduit bore (48) defines a longitudinal axis and the
longitudinal axis
of the lateral conduit bore (48) along the build angle section (60) forms an
angle relative to the
longitudinal axis of the primary conduit bore (36). As a result of the bend or
deflection, the
lower portion (60) or build angle section engages or intersects with the
junction opening (42) in
the primary conduit wall (38). Preferably, the junction opening (31) extends
along the length of
the build angle section (60) of the lateral conduit (30).
Another embodiment is shown in figures IA, 2A, 3A, 4A and 4B. In this case,
both the lateral junction opening (42A) in the primary conduit (28A) and the
lateral conduit
bore (48A) in the lateral conduit (30A) are provided with generally
semicircular upper end
sections as shown at (42B, 48B). In this case, the lateral conduit bore
opening (48A) is
relatively closer to the lateral junction opening (42A), compared with the
embodiment shown
in figures 1 and 2. In one example, the lateral conduit bore (48A) may be
within about O.lm of
the lateral junction opening (42A), as opposed to a distance of about lm in
one example of the
embodiment of figures 1 and 2.
22
CA 02506348 2005-05-04
The position of the lateral junction opening (42A) has not, in this particular
example, changed relative to the primary conduit (28A), while the lower end
(46A) of the
lateral conduit (30A) remains unchanged relative to the primary conduit (28A),
compared with
the embodiment shown in figures 1 and 2.
Downstream of the generally semicircular upper end sections (42B, 48B), the
lateral junction opening (42A) and the lateral conduit bore 48A are bordered
by generally
parallel intermediate sections (42C, 48C) and further downstream by generally
converging
sections (42D, 48D) which then generally converge downwardly toward the lower
end (46A) of
the lateral conduit (30A). In addition, the transition point shown at (T)
between the upper
portion (52A) and the lower portion (60A) is, in this case, adjacent the upper
boundary of the
lateral junction opening (42A).
The lower portion (60A) also provides upstanding flange portions (48E) which
are formed by shaping the lower portion (60A) on opposite sides of the lateral
conduit bore
(48A). This provides a location for a weld seam or other attachment means
between the flange
portions (48E) and the adjacent intermediate sections (42C) and the converging
sections (42D).
Referring to Figure 26, the desired angle of the offset in the lower portion
(60) or
build angle section is selected depending upon the desired kick off angle of
the lateral borehole
when utilizing the junction assembly (20) to drill the lateral borehole. Thus,
the kick off angle
of the lateral borehole is preset and incorporated into the design or
configuration of the lateral
conduit (30). Although the lateral conduit (30) may be configured to provide
any desired kick
off angle, preferably a kick off angle of less than or equal to about 15
degrees is provided for.
Specifically, it has been found that the junction assembly (20) may be
configured to safely
achieve about a 15 degree angle over a distance of about 20 feet (6.096 m).
The junction assembly (20A) may, in one example, be operable to provide, in
the
primary conduit (20A) a first fluid pressure ranging from about 0 to about 10
MPA while the
lateral conduit (30A) may be operable to maintain a second fluid pressure
ranging from about
30 to 60 MPA, though other pressures and/or pressure ranges may be used as
needed depending
on the specifications of the pipes, for instance. In one example, the welded
connection
between the primary and lateral conduits (28A, 30A) is sufficient to enable
the junction
opening 42A to withstand pressure limits defined by the pressure ratings of
the primary and
23
CA 02506348 2005-05-04
lateral conduits (30A, 28A). This means that the operating pressures, in this
example, need not
be reduced below the normal operating pressure ratings of the primary and
lateral conduits
because of a reduced pressure rating at the junction opening.
In manufacturing the junction assembly (20), the junction opening (42) and the
weld slots (54) are cut or otherwise formed in the primary conduit wall (38).
The lower portion
(60) of the lateral conduit (30) is bent to achieve a preselected angle and
then the lateral conduit
('30) is installed or positioned within the bore (36) of the primary conduit
(28) such that the
lower end (46) of the lateral conduit (30) extends through and beyond the
junction opening
(42). The upper portion (52) of the lateral conduit (30) is then welded to the
primary conduit
wall (38) to maintain the lateral conduit (30) in position. Further, the edge
of the junction
opening (42) is welded to the adjacent surface of the lateral conduit wall
(50). Subsequently,
the lower end (46) of the lateral conduit (30) is cut at a slant or angle to
provide an elongated
lower end (46) which corresponds with the junction opening (42) in the primary
conduit wall
I S (38). 1n other words, the portion of the lower end (46) which extends out
of or beyond the
junction opening (42) is removed so that the lower end (46) no longer extends
from the primary
conduit (28).
The junction assembly (20) may have any desired dimensions compatible with
insertion in the primary borehole and compatible with the downhole tools or
equipment
intended to be passed through to the lateral borehole. However, in the
preferred embodiment,
the primary conduit (28) has an outer diameter of about 10.75 inches (27.305
cm) and an inner
diameter of about 9.76 inches (24.79 cm). Further, the lateral conduit (30)
has an outer
diameter of about 5 inches (12.7 cm). With respect to length, in the preferred
embodiment, the
primary conduit (28) has a length of about 13 meters, while the lateral
conduit (30) has a length
of about 9 meters. The lateral conduit (30) is preferably substantially
centrally mounted within
the primary conduit (28) between the upper and lower ends (32, 34) of the
primary conduit
(28). Thus, preferably, about 2 meters is provided between the upper end (32)
of the primary
conduit (28) and the upper end (44) of the lateral conduit (30). Similarly,
about 2 meters is
provided between the lower end (34) of the primary conduit (28) and the lower
end (46) of the
lateral conduit (30). Finally, with respect to the lateral conduit (30), the
upper portion (52) or
no build section is preferably about 3 meters in length, while the lower
portion (60) or build
angle section is preferably about 6 meters in length depending upon the
desired kick off angle.
24
CA 02506348 2005-05-04
As described further below, once the junction assembly (20) is positioned and
oriented within the primary borehole, it is preferable that the position of
the junction assembly
(20) in the primary borehole be maintained in some manner during subsequent
downhole
operations. In the preferred embodiment, the junction assembly (20) is
cemented in position
within the primary borehole by conducting an unset cementitious slurry into
the annulus
between the primary conduit wall (38) and the wall of the primary borehole.
During this
operation, it is desirable that the cementitious slurry not be permitted to
flow into the primary
conduit (28) through the junction opening (42) and the bore (48) of the
lateral conduit (30).
Thus, any mechanism, device or method may be used to inhibit or prevent this
undesirable flow
of the cementitious slurry.
For instance, the outside or outer surface of the primary conduit wall (38)
may be
wrapped with a material, such as a shrink wrapping, about the area of the
junction opening (42)
in order to prevent the passage of any fluid therethrough. Once in position, a
drilling tool may
I 5 be used to drill through the shrink wrapping to permit communication
between the bore (36) of
the primary conduit (28) and the bore (48) of the lateral conduit (30).
However, preferably, prior to placing the junction assembly (20) within the
primary borehole, the bore (48) of the lateral conduit (30) is filled with a
material capable of
plugging the bore (48) to inhibit the passage of fluid theretlm-ough. Once in
position, once
again, the plug would either be removed or a drilling tool would be used to
drill through the
material to permit communication between the bore (36) of the primary conduit
(28) and the
bore (48) of the lateral conduit (30). For example, the plugging material may
be comprised of a
cementitious material. In the prefen-ed embodiment, the bore (48) is plugged
or blocked by an
aluminum and rubber inflatable packer having a layer of hardened cement on
either side.
Referring to Figures 5, 6, 24 and 25, the orienting device (22) is adapted for
insertion in the primary conduit (28) to engage the lateral conduit (30) for
facilitating the
orienting of the junction assembly (20) in the borehole. Further, the
orienting device (22)
preferably facilitates the completion of the primary borehole, particularly
the cementing of the
junction assembly (20) in the primary borehole at a desired orientation. The
orienting device
(22) is configured or adapted for insertion in the pipe string, particularly
the casing string (40),
and for selectively engaging the junction assembly (20) such that the
orientation of the
orienting device (22) provides an indication of an orientation of the junction
assembly (20).
CA 02506348 2005-05-04
Further, the orienting device (22) is preferably removable such that the
orienting device (22)
may be removed from the junction assembly (20) following its use.
The orienting device (22) is particularly adapted to engage the lateral
conduit
(30) when inserted within the bore (36) of the primary conduit (28) in order
to selectively
engage the orienting device (22) with the junction assembly (20). The
orienting device (22) is
specifically adapted to engage the lateral conduit (30) in a manner such that
rotation of the
junction assembly (20) within the primary borehole correspondingly rotates the
orienting
device (22) contained therein. More particularly, the junction assembly (20),
and particularly
the primary conduit (28). may be rotated within the primary borehole by
rotation of the upper
pipe string connected with the upper end (32) of the primary conduit (28).
Throughout this
operation, the orienting device (22) provides an indication of the orientation
of the orienting
device, which necessarily provides an indication of the orientation of the
junction assembly
(20) as a result of the engagement of the orienting device (22) with the
junction assembly (20).
As a result, the junction assembly (20) may be rotated such that the conduit
junction (31), and
particularly the junction opening (42), are oriented in a desired direction.
The orienting device (22) may be inserted within the primary conduit (28) in
any
manner and by any mechanism or apparatus. However, preferably, a pipe string
or any suitable
tubular string is connected with an end of the orienting device (22) for
inserting the orienting
device (22) through the primary borehole for insertion in the primary conduit
(28). Once the
orienting device (22) is positioned in the primary conduit (28), the upper
portion of the casing
string (40) connected with the upper end (32) of the primary conduit (28), as
described above,
may be rotated from the surface in order to rotate the primary conduit (28),
and the orienting
device (22) inserted therein, downhole. In the preferred embodiment, the upper
portion of the
casing string (40) is rotated at the surface using a standard or conventional
rotary table or rig
table.
Further, where desired to complete the primary borehole, a hardenable or
settable slurry, such as a cementitious slurry, or a bending agent may be
conducted through the
pipe or tubular string connected with the end of the orienting device (22). In
order to permit
the cementitious slurry to access the annulus between the casing string (40)
and the junction
assembly (20) and the wall of the primary borehole, the orienting device (22)
preferably defines
a passage therethrough for conducting the slurry. Thus, the slurry may be
conducted through
26
CA 02506348 2005-05-04
the orienting device (22) while the orienting device (22) remains in the
primary conduit (28) in
order to maintain the desired orientation of the junction assembly (20) in the
primary borehole
during the completion operation. Specifically, the slurry is preferably
conducted through the
orienting device (22) and out of the lower end (34) of the primary conduit
(28) for subsequent
passage into the annulus.
The orienting device (22) may be comprised of any apparatus or device capable
of engaging the lateral conduit (30) in the described manner while permitting
the flow of a fluid
therethrough. However, preferably, the orienting device (22) is comprised of a
device housing
(62) having an upper end (64), a lower end (66) and a device housing wall (68)
extending
therebetween. The device housing (G2), and particularly the device housing
wall (68), is
shaped or configured for receipt in the primary conduit (28) adjacent the
upper portion (52) or
no build section of the lateral conduit (30).
Thus, to permit the lateral conduit (30) to be closely or securely received by
the
orienting device (22), the device housing (62) has a recess (70) as shown in
Figure 6. In the
preferred embodiment, the device housing wall (68) defines a longitudinally
oriented C-shaped
recess (70) which extends the complete length of the device housing (62)
between the upper
and lower ends (44, 46). The recess (64) is particularly configured to be
compatible with the
outer dimensions of the lateral conduit wall (50). As a result, rotation of
the primary conduit
(28) causes the lateral conduit (30) to act upon and engage the recess (70) of
the device housing
(62) to cause a corresponding rotation of the device housing (62).
The device housing (62) may have any dimensions compatible with insertion of
the device housing (62) within the primary conduit (28) and receipt of the
lateral conduit (30)
within the C-shaped recess (70). However, in the preferred embodiment, the
outside diameter
of the device housing (62) is preferably about 8.625 inches (21.91 cm) such
that the orienting
device (22) may readily pass through the inside diameter of the casing string
(40) as shown in
Figure 24, wherein the casing string (40) has an outside diameter of about
9.625 inches (24.45
cm) and an inside diameter of about 8.835 inches (22.44 em). Further, the
outside diameter of
the device housing (62) is preferably about 8.625 inches (21.91 cm) such that
the orienting
device (22) may readily seat within the primary conduit (28) as shown in
Figure 25, wherein
the primary conduit wall (38) has an outside diameter of about 10.75 inches
(27.31 cm). As
well, the C-shaped recess (70) preferably defines a portion of a circle having
an inside diameter
27
CA 02506348 2005-05-04
of about 5.012 inches ( 12.73 cm) for ready receipt of the lateral conduit
(30) as shown in
Figure 25, wherein the lateral conduit (30) has an outside diameter of about 5
inches ( 12.7 cm).
The device housing (62) may have any length compatible with the junction
assembly (20). However, in the preferred embodiment, the device housing (62)
is preferably
about 24 inches (about 60.96 cm) in length. In the preferred embodiment, the
device housing
(62) is inserted within the primary conduit (28) adjacent the lateral conduit
(30) such that the
device housing (62) is adjacent the upper portion (52) of the lateral conduit
(30). If required or
desired to ensure proper placement of the orienting device (22) in the primary
conduit (28), the
orienting device (22) may be further comprised of a stop mechanism (71) for
limiting the extent
to which the device housing (62) may be inserted in the primary conduit (28).
Preferably, the
stop mechanism is comprised of a stop block or stop plate (71) or other
structure which is
associated with the orienting device (22) in order to inhibit or prevent the
insertion of the
device housing (62) within the primary conduit (28) beyond or past the desired
position
I S adjacent the upper portion (52) of the lateral conduit (30). However,
preferably an amount of
movement of the orienting device (22) relative to the lateral conduit (30) is
permissible while
still maintaining the orientation of the primary conduit (28).
The stop block or stop plate (71 ) may be positioned within or associated with
the
C-shaped recess (70) of the device housing (62). However, in the preferred
embodiment, the
orienting device (22) is further comprised of a tubular member (72) which
extends through the
device housing (62) and the stop block (71) is associated with the tubular
member (72) and
particularly an upper end (74) of the tubular member (72) as described further
below. The stop
block or stop plate (71 ) is positioned along the upper end (74) of the
tubular member (72) such
that the stop block (71) abuts or engages the upper end (44) of the lateral
conduit (30) when the
device housing (62) is in the desired position within the primary conduit
(28). In the preferred
embodiment, the stop block is positioned along the tubular member (72) at a
distance of about
4 feet (about 1.22 m) above or uphole of the upper end (64) of the device
housing (62). Thus,
the stop block or plate (71 ) preferably prevents further downhole movement of
the orienting
device (22) within the primary conduit (28) and defines a "maximum downhole
position."
As stated, preferably an amount of movement of the orienting device (22)
relative to the lateral conduit (30) is permissible while still maintaining
the orientation of the
primary conduit (28). In the preferred embodiment, a maximum upward or uphole
movement
28
CA 02506348 2005-05-04
of the orienting device (22) of about 1.5 to 2 meters is permitted from the
maximum downhole
position before the orienting device (22) fully disengages the lateral conduit
(30). Thus, in the
event that the pipe string connected with the orienting device (22) is
reciprocated for any reason
during use, caution must be exercised to ensure that a maximum upward movement
of about
1.5 meters is not exceeded. Otherwise, the orienting device (22) may become
disengaged from
the lateral conduit (30). Where reciprocation of the casing string is
required, the pipe string
with the attached orienting device (22) and the casing string are preferably
moved
simultaneously or concurrently.
Preferably, the orienting device (22) is further comprised of a tubular member
(72) which extends through the device housing (62). The tubular member (72)
preferably
defines the passage for conducting the fluid through the orienting device
(22). The tubular
member (72) may be comprised of two or more members or units connected
together to provide
an integral tubular member (72). However, preferably, the tubular member (72)
is comprised
1 S of a single member having an upper end (74) and a lower end (76). The
tubular member (72) is
oriented longitudinally within the device housing (62) such that the upper end
(74) of the
tubular member (72) extends from the upper end (64) of the device housing (62)
and such that
the lower end (76) of the tubular member (72) extends from the lower end (66)
of the device
housing (62).
As indicated above, a pipe string or tubular string, and particularly an upper
portion of the pipe string or upper pipe string, is preferably engagable with
the upper end (74)
of the tubular member (72) in a manner permitting fluid communication
therebetween. Thus,
in the preferred embodiment, the upper end (74) of the tubular member (72) is
comprised of an
upper connector (81 ) for connecting the orienting device (22) with the upper
pipe string. In the
preferred embodiment, the upper connector (81) is comprised of a threaded
connection
provided between the upper end (74) of the tubular member (72) and the
adjacent upper portion
of the pipe string. As shown in Figure S, the upper end (74) preferably
provides a threaded box
connector. Similarly, the lower end (76) of the tubular member (72) is
preferably configured to
be threadably connectable with a pipe string or tubular string, and preferably
a lower portion of
a pipe string or a lower pipe string. Thus, in the preferred embodiment, the
lower end (76) of
the tubular member (72) is comprised of a lower connector (83) for connecting
the orienting
device (22) with the lower pipe string. In the preferred embodiment, the lower
connector (83)
is comprised of a threaded connection provided between the lower end (76) of
the tubular
29
CA 02506348 2005-05-04
member (72) and the adjacent lower portion of the pipe string. As shown in
Figure 5, the lower
end (76) preferably provides a threaded pin connector.
Further, in the preferred embodiment, each of the upper and lower portions of
the pipe string is comprised of one or more lengths or joints of a 2 7/8
inches (7.3025 cm)
tubular pipe. The length of the upper portion of the pipe string is selected
such that the pipe
string preferably extends from the surface to the upper end (74) of the
orienting device (22)
when the stop block or stop plate (71 ) is engaged or abutted with the upper
end (44) of the
lateral conduit (30). The lower portion of the pipe string extends from the
lower end (76) of
the orienting device (22) to a lowermost or downhole end. In the preferred
embodiment, the
length of the lower portion of the drill string is selected such that when the
stop block or stop
plate (71) is engaged or abutted with the upper end (44) of the lateral
conduit (30), the
lowermost or downhole end of the lower portion of the pipe string is a spaced
distance above or
uphole of the cement floats at the downhole end of the casing string.
Preferably, a minimum
I S distance of about 1 meter is provided between the downhole end of the pipe
string and the
cement floats.
Further, the tubular member (72) is preferably securely mounted or affixed
within the device housing (62). In the preferred embodiment, the device
housing (62) is
comprised of a plurality of longitudinally spaced apart reinforcement members
(78) which
extend axially between the inner surface of the housing wall (68) and the
adjacent surface of
the tubular member (72) and which are rigidly or securely affixed thereto in
order to securely
mount the tubular member (72) within the device housing (62). Further, in
order to facilitate
the passing of the orienting device (22) through the primary borehole, the
device housing (62)
may define one or more circulation holes (80) which extend through the device
housing (62)
between the upper and lower ends (64, 66).
Accordingly, in use or operation, a lower portion of a pipe string is
threadably
connected with the lower end (76) of the tubular member (72). Similarly, an
upper portion of a
pipe string is threadably connected with the upper end (74) of the tubular
member (72). The
orienting device (22) is then lowered through the primary borehole from the
surface by the
upper portion of the pipe string until the device housing (62) is seated
within the primary
conduit (28) adjacent the lateral conduit (30), preferably by abutment of the
upper end (44) of
the lateral conduit (30) with the stop block (71 ). In this position, the
lowermost or downhole
CA 02506348 2005-05-04
end of the lower portion of the pipe string is configured to extend to a
desired distance
downhole within the primary borehole. Specifically, as discussed above, the
lowermost end
preferably terminates above a cement float associated with the casing string.
However,
alternately, the downhole end may include a stinger for engaging a downhole
cementing shoe.
More particularly, in the preferred embodiment, the distance from the upper
end
(44) of the lateral conduit (30) to the surface or the depth of the upper end
(44) beneath the
surface is known. This distance is referred to herein as the "lateral conduit
depth." Preferably,
the depth of the lowermost or downhole end of the lower portion of the pipe
string connected
with the orienting device (22) is monitored relative to the lateral conduit
depth as the orienting
device (22) is lowered within the primary borehole by the pipe string. Once
the lowermost or
downhole end of the lower portion of the pipe string achieves the lateral
conduit depth, the
operator may need to determine if the lowermost end has entered the lateral
conduit (30) or has
paused by the lateral conduit (30) through the primary conduit (28).
In the preferred embodiment, a preset plug or packer (not shown) is present
inside the lateral conduit (30) about 1 meter from the upper end (44) of the
lateral conduit (30).
Therefore, to determine the location of the lowermost end of the lower portion
of the pipe
string, the pipe string is further lowered within the primary borehole. If
further downward
movement of the pipe string is prevented when the lowermost end achieves a
depth about 1
meter greater than the lateral conduit depth, then the lowermost end has
entered the lateral
conduit (30). Otherwise, the lowermost end is passing through the primary
conduit (28).
Where the lowermost end of the lower portion of the pipe string has
undesirably
entered the lateral conduit (30), it may be assumed that the lateral conduit
(30) is located on the
low side of the casing string. Therefore, to re-position the lowermost end,
the pipe string is
raised upwardly about 1 meter and the casing string is rotated from the
surface, preferably 180
degrees, to attempt to move the lateral conduit (30) to the high side of the
casing string. Upon
subsequent lowering of the pipe string, if the lowermost end again enters the
lateral conduit
(30), this process should be repeated at 90 degree rotations of the casing
string until the
lowermost end passes through the primary conduit (28).
The orienting device (22) is then further lowered through the primary borehole
until the lower end (66) of the device housing (62) contacts or abuts the
upper end (44) of the
31
CA 02506348 2005-05-04
lateral conduit (30). The orienting device (22) is then permitted to rest upon
the lateral conduit
(30) so that the pipe string weight decreases. The pipe string is then rotated
from the surface,
preferably to the right or clockwise, in order to rotate the orienting device
(22) downhole.
Rotation continues until the rotation torque increases, further rotation is
prevented and / or the
drill string weight increases, indicating that the lateral conduit (30) has
been aligned with the
C-shaped recess (70) of the device housing (62). The orienting device (22) is
then further
lowered by the pipe string and the lateral conduit (30) is inserted within the
C-shaped recess
(70) of the device housing (62). In this position, in the preferred
embodiment, the lowermost or
downhole end of the lower portion of the pipe string terminates about 1 meter
above a cement
float associated with the casing string.
Once the orienting device (22) is in position within the primary conduit (28),
the
orienting device (22) provides an indication of the orientation of the
orienting device (22)
downhole within the primary borehole. To achieve a desired orientation of the
junction
assembly (20) within the primary borehole, the upper portion of the casing
string (40)
connected with the upper end (32) of the primary conduit (28) is rotated from
the surface to
rotate the primary conduit (28) downhole. During this operation, the orienting
device (22)
indicates the variations in the orientation of the orienting device (22) which
provides an
indication of the orientation of the junction assembly (20). When the desired
orientation of the
junction assembly (20) downhole is achieved, rotation of the casing string
(40) from the surface
ceases. Typically, the junction assembly (20) will be preferably oriented such
that the junction
opening (42), and thus the lateral conduit (30), are located on the high side
of the primary
borehole or the casing string, as shown in Figure 26, or is otherwise adjacent
the desired
direction of the existing or intended lateral borehole. Positioning of the
lateral conduit (30) on
the high side facilitates passage of subsequent objects, tools or equipment
through the primary
conduit (28), past the lateral conduit (30), as the objects, tools and
equipment will tend to travel
along the low side.
In order to provide an indication of the orientation of the orienting device
(22),
and thus the junction assembly (20) downhole, the orienting device (22) is
preferably further
comprised of an orientation indicator or device (82) which is capable of
sensing and
communicating the orientation of the orienting device (22), preferably to a
user or operator at
the surface. Specifically, the orientation indicator (82) may be comprised of
any type or
configuration of sensor, sensors or sensing apparatus capable of sensing or
determining the
32
CA 02506348 2005-05-04
orientation of the orienting device (22) downhole and communicating the sensed
information or
data concerning the orientation of the orienting device (22) to the surface.
Thus, the orientation
indicator (82) is selected to be compatible for use with or within the
particular orientation of
the primary borehole. In the preferred embodiment, the orientation indicator
(82) is comprised
of a gyroscope or other surveying sensors and equipment.
Further, the orientation indicator (82) may be associated with any member or
component of the orienting device (22). In the preferred embodiment, the
orientation indicator
(82) is associated with the device housing (62) in order to sense and
communicate the
orientation of the device housing (62) and particularly the orientation of the
C-shaped recess
(70) having the lateral conduit (30) engaged therein. The orientation
indicator (82) may be
associated with the device housing (f2) at any location and in any manner
permitting the
functioning of the orientation indicator (82). For instance, the orientation
indicator (82) may be
contained within a separate tubular member, pipe joint or sub, such as within
an orienting sub
(not shown), which is fastened, connected or mounted with the device housing
(62) in a manner
permitting the orientation indicator (82) to sense and communicate the
orientation of the device
housing (62). In this case, the orienting sub including the orientation
indicator (82) is
preferably mounted with the upper end (64) of the device housing (62) in a
manner permitting
fluid communication between the tubular member (72) and the adjacent upper
portion of the
pipe string.
Once the junction assembly (20) is rotated to achieve the desired orientation
in
the primary borehole, a casing material or bonding agent, preferably a
cementitious slurry, is
conducted from the surface through the upper portion of the pipe string
connected with the
tubular member (72) of the orienting device (22), through the tubular member
(72) and out of
the tubular member (72) into the lower portion of the pipe string for passage
to the bottom of
the primary borehole. As indicated above, a cementing shoe or cement float may
be located
downhole of the junction assembly (20) to facilitate the completion, and
particularly the casing,
of the primary borehole. For instance, a spring loaded ball cement float may
be provided to
pern~it one-way communication of the cementitious slurry through the cement
float in order to
conduct the slurry into the annulus between the casing string and the junction
assembly (20)
and the wall of the primary borehole. Thus, the cementitious slurry is
permitted to harden or
set to provide a portion of the casing of the primary borehole. Once the
primary borehole is
33
CA 02506348 2005-05-04
cemented, the orienting device (22) is removed from the primary conduit (28)
by removal or
withdrawal of the upper portion of the pipe string from the surface.
When greater than one junction assembly (20) is connected together for
insertion
in the primary borehole to provide a multilateral well, the orientation of
each of the junction
assemblies (20) relative to each other is predetermined and fixed upon
connection of the
junction assemblies (20) in series prior to insertion. Once at the desired
distance downhole in
the primary borehole, the orienting device (22) is inserted in the uppermost
or uphole junction
assembly (20). Use of the orienting device (22) to orient the uppermost
conduit (22) will
therefore result in the proper orientation of any junction assemblies (20)
downhole of the
uppermost junction assembly (20). Further, the lower portion of the pipe
string is connected
with the uppermost orienting device (22). The lower portion of the pipe string
extends through
each of the lower junction assemblies (20) to the desired location downhole.
Thus, again,
cementing may be completed through the upper portion of the pipe string
connected with the
tubular member (72) of the uppermost orienting device (22) and through the
tubular member
(72) and the lower portion of the pipe string. Following cementing, the
orienting device (22) is
removed by removal of the pipe string from the surface.
Where necessary to maintain the desired hydrostatic pressure in the primary
borehole during the completion or cementing operation, the primary borehole
may need to be
sealed at the surface. For this purpose, a packer, such as a hydro-cement bag,
may be
positioned at the surface at the top of the casing string within the primary
borehole. Thus, the
hydrostatic pressure assists or facilitates the expulsion of the cementitious
slurry through the
downhole cement float and into the annulus.
Referring to Figures 7 - 11 of the first embodiment of the removable guide
(24)
and to Figures 16 - 20 of the second preferred embodiment of the removable
guide (24), the
removable guide (24) is adapted for insertion in the primary conduit (28)
adjacent the lateral
conduit (30) for directing or guiding downhole tools and equipment, such as a
drilling tool,
fmm the primary conduit (28) into the lateral conduit (30). Therefore, the
guide (24) is
configured to be receivable within the primary conduit (28). Further, the
guide (24) is
removable such that the guide (24) may be removed from the primary conduit
(28) following
the desired downhole operation.
34
CA 02506348 2005-05-04
The guide (24) is adapted to direct a downhole tool inserted through the upper
end (32) of the primary conduit (28) towards or in the direction of the upper
end (44) of the
lateral conduit (30) when the guide (24) is positioned within the primary
conduit (28) adjacent
the lateral conduit (30). Although the guide (24) may be comprised of any
structure capable of
guiding the downhole tool in the described manner, in the preferred
embodiment, the guide
(24) is comprised of an upper surface (84) sloped in a direction towards the
upper end (32) of
the lateral conduit (30).
More particularly, as indicated, the guide (24) may be comprised of any
apparatus or device receivable in the primary conduit (28) and capable of
directing a downhole
tool from the primary conduit (28) into the lateral conduit (30). However,
preferably, the guide
(24) is comprised of a guide housing (86) having an upper end (88), a lower
end (90) and a
guide housing wall (92) extending therebetween. The upper end (88) is
comprised of a guide
plate (94) which defines the upper surface (84). The lower end (90) is
comprised of a base
plate (96). Further, the guide housing (86), and particularly the guide
housing wall (92), is
shaped or configured for receipt in the primary conduit (28) adjacent the
upper portion (52) or
no build secoon of the lateral conduit (30).
Thus, to permit the lateral conduit (30) to be closely received by the guide
(24),
the guide housing (86) preferably has a recess (98) as shown in Figures 8 and
10 and Figures 17
and 19 of the first and second embodiments respectively. Although the recess
(98) may have
any shape compatible with the lateral conduit (30) and capable of receiving
the lateral conduit
(30) therein, the guide housing wall (92) preferably defines a longitudinally
oriented C-shaped
recess (98) which extends the complete length of the guide housing (86)
between the guide
plate (94) and the base plate (96). The C-shaped recess (98) is configured to
be compatible
with the outer dimensions of the lateral conduit wall (50). As a result, the
directing of the
downhole tool from the primary conduit (28) into the lateral conduit (30) is
facilitated.
Further, as shown in Figures 7 and 9 and Figures 16 and 18 of the first and
second embodiments respectively, the guide plate (94) defines the upper
surface (84) of the
guide (24) which is shaped or configured to guide or direct an object coming
into contact with
the upper surface (84) into the upper end (44) of the lateral conduit (30)
positioned within the
C-shaped recess (94). More particularly, the upper surface (84) is sloped in a
direction towards
the C-shaped recess (98). Thus, the upper surface (84) is angled downwards
towards the C-
CA 02506348 2005-05-04
shaped recess (98). In addition, the upper surface (84) is preferably both
angled and ovaled to
provide a bowl-like surface in order to guide or direct the object in the
desired direction
regardless of the specific portion or area of the upper surface (84) that it
contacts.
Further, the guide (24) is preferably comprised of a stop mechanism for
limiting
the extent to which the guide (24) may be inserted in the primary conduit
(28). Although any
mechanism or means for limiting the movement may be used, the stop mechanism
is preferably
comprised of a stop collar ( 100) which ensures or assists with the proper
placement of the
upper end (44) of the lateral conduit (30) within the C-shaped recess (98) of
the guide housing
(86). In particular, the C-shaped recess (98) includes the stop collar (100)
or other stop
mechanism for inhibiting, and preferably preventing, the insertion of the
upper end (44) within
the C-shaped recess (98) past a desired position.
In the preferred embodiment, the stop collar ( 100) provides a lip or ridge
extending about the C-shaped recess (98) at a desired position between the
upper and lower
ends (88, 90) of the guide housing (86). The stop collar ( 100) is configured
to engage the upper
end (44) of the lateral conduit (30) when the lateral conduit (30) is received
within the C-
shaped recess (98). The engagement of the stop collar (100) with the upper end
(44) of the
lateral conduit (30) prevents further travel or movement of the lateral
conduit (30) towards the
upper end (88) of the guide housing (86) past the stop collar ( 100).
Conversely, the
engagement of the stop collar (100) with the upper end (44) of the lateral
conduit (30) inhibits
or prevents any further downward movement of the guide (24) within the primary
conduit (28).
Thus, the stop collar (100) assists with maintaining the proper positioning of
the guide (24)
within the primary conduit (28).
It is also preferable that any upward movement of the guide (24) relative to
the
lateral conduit (30) be inhibited and preferably prevented. Thus, the guide
(24) is preferably
further comprised of a guide latching mechanism (102) associated with the
guide housing (86).
Preferably, the latching mechanism ( 102) is associated with the C-shaped
recess (98) of the
guide housing (86). Any latch mechanism ( 102) may be used which is capable of
engaging the
lateral conduit (30) within the C-shaped recess (98) to inhibit the movement
of the lateral
conduit (30) therein.
36
CA 02506348 2005-05-04
Although the latching mechanism ( 102) may be used to inhibit or prevent
movement of the lateral conduit (30) relative to the guide housing (86) in
either or both an
upwards and downwards direction, in the preferred embodiment, the latching
mechanism
prevents further upward movement of the guide (24) relative to the lateral
conduit (30) while
the stop collar ( 100) prevents further downward movement of the guide (24)
relative to the
lateral conduit (30). Thus, the latching mechanism (102) and the stop collar
(100) together
maintain the desired position of the lateral conduit (30) within the C-shaped
recess (98) of the
guide housing (86).
As will be described in further detail below in relation to each of the first
and
second embodiments of the guide (24), the latch mechanism (102) is preferably
comprised of a
latch ( 104) which extends through the guide housing wall (92) into the C-
shaped recess (98) for
engagement with the upper end (44) of the lateral conduit (30).
In order to provide a more secure engagement, the lateral conduit (30), and
particularly its upper end (44), is also preferably comprised of a latching
mechanism (106)
which is complementary to the latching mechanism ( 102) of the guide (24).
Thus, the lateral
conduit latching mechanism ( 106) and the guide latching mechanism ( 102) are
selected to be
compatible or complementary with each other to secure the guide (24) with the
lateral conduit
(30). In the preferred embodiment, the lateral conduit latching mechanism (
106) is comprised
of the upper end (44) of the lateral conduit (30) defining an indentation (
106) oriented axially
about the lateral conduit wall (50) for receipt of the latch (104) therein.
The stop collar (100)
and the latching mechanism ( 102) are configured so that the latch ( 104)
extends from the guide
housing wall (92) for receipt in the indentation ( 106) at the upper end (44)
of the lateral conduit
(30) when the upper end (44) engages or abuts against the stop collar ( 100).
The guide housing (86) may have any dimensions compatible with insertion of
the guide housing (86) within the primary conduit (28) and receipt of the
lateral conduit (30)
within the C-shaped recess (98). However, in the preferred embodiment, the
outside diameter
of the guide housing (62) is preferably about 8.625 inches (21.91 cm) such
that the guide (24)
may readily pass through the inside diameter of the casing string (40) as
shown in Figure 24,
wherein the casing string (40) has an outside diameter of about 9.625 inches
(24.45 cm) and an
inside diameter of about 8.835 inches (22.44 cm). Further, the outside
diameter of the guide
housing (86) is preferably about 8.625 inches (21.91 cm) such that the guide
(24) may readily
37
CA 02506348 2005-05-04
pass within the primary conduit (28) as shown in Figure 25, wherein the
primary conduit wall
(38) has an outside diameter of about 10.75 inches (27.31 cm).
As well, the C-shaped recess (98) preferably defines a portion of a circle
having
an inside diameter of about 5.012 inches ( 12.73 cm) for ready receipt of the
lateral conduit (30)
as shown in Figure 25, wherein the lateral conduit (30) has an outside
diameter of about 5
inches ( 12.7 cm).
In use or operation, when the lateral conduit (30) is positioned within the C-
shaped recess (98) as described, the object may pass from the primary borehole
through the
upper end (32) of the primary conduit (28) for contact with the upper surface
(84) of the guide
(24), which directs the object towards the C-shaped recess (98). The object
then passes into the
C-shaped recess (98) and subsequently the upper end (44) of the lateral
conduit (30) which is
received therein. The object is then permitted to pass through the bore (48)
of the lateral
conduit (30) and out of its lower end (46) and through the junction opening
(42) in the primary
conduit wall (38).
In order to facilitate the passing of the guide (24) through the primary
borehole,
the guide housing (86) may define one or more circulation holes (108),
particularly in either or
both of the guide and base plates (94, 96), which permit circulation of fluids
through the guide
housing (86) between the upper and lower ends (88, 90).
The guide (24) may be conducted through the primary borehole and positioned
and removed from the primary conduit (28) using any mechanism or method
compatible with
this function. Preferably, the guide (24) is connected with a pipe string or a
tubular string
which extends from the surface into the primary borehole. Although the guide
(24) may be
connected with the pipe string in any manner permitting the placement and
subsequent retrieval
of the guide (24), the guide (24) is preferably comprised of a running and
retrieval mechanism
(109) for engagement with a running and retrieval tool. Any compatible or
complementary
rumiing and retrieval mechanisms and running and retrieval tools may be used.
However, three
complementary running and retrieval mechanisms and tools are described herein.
Specifically, a first running and retrieval tool ( 110), as shown in Figure
15, is
provided for use with the first embodiment of the removable guide (24) as
shown in Figures 7 -
38
CA 02506348 2005-05-04
1 I . A second running and retrieval tool ( 111 ), as shown in Figure 21, and
a third running and
retrieval tool ( 113), as shown in Figures 22 - 23, are provided for use with
the second preferred
embodiment of the removable guide (24). Each removable running and retrieval
tool ( 110,
111, 113) is adapted for engagement with the running and retrieval mechanism
(109)
comprised of the particular structure of the guide housing (86) such that the
guide (24) may be
placed within and retrieved from the primary conduit (28). Further, the first
running and
retrieval tool (110) is also used to operate the latching mechanism (102) of
the first
embodiment of the removable guide (24).
Except where indicated to the contrary, the structure and operation of the
first
running and retrieval tool (110) with respect to the first embodiment of the
guide (24) will
primarily be described first, followed by the second and third running and
retrieval tools ( I I 1,
113) with respect to the second embodiment of the guide (24).
Referring to Figure 15, fox use with the first embodiment of the guide (24),
the
first nimling and retrieval tool ( 110) is comprised of an elongated member (
112) having an
upper end ( 114) and a lower end ( 116). The upper end ( 114) is adapted for
engagement with a
pipe string or other tubular string for lowering the first running and
retrieval tool ( 110) through
the primary borehole. Although the upper end ( 114) may be engaged or
connected with the
pipe string by any fastening or connection mechanism, preferably a threaded
connection is
provided therebetween. Preferably, the upper end ( 114) of the elongated
member ( 1 12) of the
first running and retrieval tool ( 110) is comprised of a threaded box
connector for connection
with a threaded pin connector on the adjacent end of the pipe string. The
lower end ( 116) of
the elongated member ( 112) of the first ntnning and retrieval tool ( 110) is
adapted for
engagement with the guide housing (86).
More particularly, the lower end ( 116) of the elongated member ( 112) of the
first
running and retrieval tool ( 110) is preferably adapted and configured for
insertion within the
guide housing (86) through the upper surface (84) in a manner such that the
lower end (116)
engages the guide housing (86) to permit the placement of the guide (24)
within, and the
subsequent removal of the guide (24) from, the primary conduit (28). In
addition, the lower
end ( 1 16) releasably engages the guide housing (86) so that the first
running and retrieval tool
( I 10) may be removed or disengaged from the guide housing (86) when the
guide (24) is in
position within the primary conduit (28) to permit the use of the guide (24)
as described above.
39
CA 02506348 2005-05-04
Further, the lower end (116) of the elongated member (112) of the first
running
and retrieval tool ( 110) is also preferably adapted to operate or act upon
the latching
mechanism (102) of the guide (24). Specifically, in both the first and second
embodiments of
the guide (24), the latch (104) of the latching mechanism (102) extends
through the guide
housing (86) within the C-shaped recess (98) through a compatible opening
(118) in the guide
housing (86). The latch (104) is preferably biased outwardly, being in a
direction to extend
from the opening ( 118) into the C-shaped recess (98) for engagement with the
lateral conduit
(30). In the first embodiment of the guide (24), the lower end (116) of the
first running and
retrieval tool ( 1 10) is adapted to disengage the latching mechanism ( 102)
by withdrawing the
latch ( 104) within the guide housing (86) through the opening ( 118) in the C-
shaped recess
(98).
More particularly, referring to Figure 15, the lower end ( 116) of the
elongated
1 S member ( 1 12) of the first running and retrieval tool ( 1 I 0) is
comprised of a key ( 120) for
insertion within the guide housing (86) of the first embodiment of the guide
(24) as described
further below. The key ( 120) extends axially or radially from the elongated
member ( 112) at,
adjacent or in proximity to the lower end ( 116). Although the key ( 120) may
have any shape or
configuration compatible with the latching mechanism ( 102) and capable of
insertion in the
guide housing (86), the key ( 120) is preferably comprised of an upwardly
facing shoulder ( 122)
and a downwardly facing shoulder ( 124).
The upwardly facing shoulder (122) faces or extends towards the upper end
( 1 14) of the elongated member ( 112) and is preferably a square shoulder
such that the shoulder
( 122) is substantially perpendicular to the elongated member ( 122). This
configuration is
prefewed to prevent or inhibit further movement of the elongated member ( 112)
in an upward
or uphole direction when the upwardly facing shoulder (122) contacts or
engages a portion of
the guide housing (86) as described in further detail below. Further, the
upwardly facing
shoulder ( 122) is provided for engaging the latch ( 104) to withdraw the
latch ( 104) from the C-
shaped recess (98) into the guide housing (86).
The downwardly facing shoulder ( 124) faces or extends towards the lower end
( 116) of the elongated member ( 112) and is preferably a sloped or angled
shoulder such that the
shoulder ( 124) is sloped or angled inwardly towards the lower end ( 116) as
shown in Figure I 5.
CA 02506348 2005-05-04
This configuration is preferred to permit further movement of the elongated
member ( I 12) in
an downward or downhole direction when necessary upon engagement or contact of
the
downwardly facing shoulder (124) with a portion of the guide housing (86).
Finally, for the purpose outlined below, the key (120) further defines a pin
hole
( 126) for receipt of a shear pin (not shown ) therein. The shear pin is
received in the pin hole
( 126) when the key ( 120) is in a desired position within the guide housing
(86), wherein the
latch (104) is withdrawn, to prevent movement of the elongated member (1 12)
relative to the
guide housing (86) and engagement of the latching mechanism (102) when running
or
positioning the first embodiment of the guide (24) within the primary conduit
(28). Once the
guide (24) is properly positioned, the shear pin is sheared or broken to
permit the removal of
the first running and retrieval tool (110) and to permit the latch (104) to
extend into the C-
shaped recess (98) to engage the indentation (106) in the upper end (44) of
the lateral conduit
(30).
Referring to the first embodiment of the guide (24) in Figures 7 -'l 1, the
guide
housing (86) is preferably hollow and comprises the running and retrieval
mechanism ( 109).
Specifically, the running and retrieval mechanism ( 109) of the first
embodiment of the guide
(24) is comprised of a tubular guide member (128) mounted within the guide
housing (86)
adjacent the C-shaped recess (98). The tubular guide member ( 128) may be
mounted within
the guide housing (86) by any mechanism or method, however, preferably the
tubular guide
member ( 128) is welded within the guide housing wall (92) adjacent the C-
shaped recess (98).
The tubular guide member (128) has an upper end (130), a lower end (132) and a
guide
member wall ( 134). Further, the tubular guide member ( 128) is sized and
configured for ready
receipt of the elongated member (1 12) of the first running and retrieval tool
(110) therein. In
other words, the elongated member (112) is insertable within the tubular guide
member (128).
The length of the tubular guide member (128) is preferably selected such that
the lower end
( 116) of the elongated member ( 112) of the first running retrieval tool (
110) may extend from
the lower end (132) of the tubular guide member (128) while the upper end
(114) of the
elongated member ( 112) extends from the upper end ( 130) of the tubular guide
member ( 128).
In addition, the tubular guide member ( 128) is preferably mounted within the
guide housing wall (92) such that the upper end (130) of the guide member
(128) is adjacent
and extends to the upper end (88) of the guide housing (86). In order to
permit access to the
41
CA 02506348 2005-05-04
upper end ( 130) of the tubular guide member ( 128) by the first running and
retrieval tool ( 110),
the upper surface (84) of the guide (24) defines an upper surface opening (
136). The upper
surface opening (136) communicates with the upper end (130) of the tubular
guide member
( l28).
S
Preferably, in the first embodiment of the guide (24), the guide member wall
( 134) is mounted with the inside or inner surface of the guide housing wall
(92), preferably by
welding. Preferably, the welding or mounting extends along the guide member
wall ( 134)
between the upper and lower ends ( 130, 132) of the guide member ( 128). Where
additional
stabilization of the tubular guide member ( 128) within the guide housing (86)
is desired or
required, one or more reinforcement plates ( 138) or members may be mounted
about the
circumference of the guide member wall ( 134) between the guide member wall (
134) and the
inner surface of the guide housing wall (92). Each reinforcement plate (138)
is placed or
positioned such that the reinforcement plate ( 138) does not interfere with
the movement of the
elongated member ( 112) and key ( 120) of the first running and retrieval tool
( 110) through the
tubular guide member ( 128) as described herein.
To permit the insertion of the lower end ( 116) of the elongated member ( 112)
of
the first running and retrieval tool (110) with the key (120) attached thereto
into the tubular
guide member ( 128), the tubular guide member ( 128) defines two slots
therein. A first long
slot (140) provides a channel extending longitudinally through the guide
member wall (134) for
the entire length of the guide member (128) between its upper and lower ends
(130, 132).
Thus, the long slot ( 140) has an upper end ( 142) co-terminous with the upper
end ( 130) of the
guide member (128). To permit access of the key (120) to the upper end (142)
of the long slot
( 140), the upper surface opening ( 136) is configured to accommodate or
permit the passage of
the key ( 120) therethrough, as shown in Figures 7 and 10. Further, the long
slot ( 140) has a
lower end ( 144) co-terminous with the lower end ( 132) of the guide member (
128). Thus, the
key ( 120) may pass from the upper end ( 142) of the long slot ( 140), through
the long slot ( 140)
and out the lower end ( 144).
A second short slot ( 146) provides a channel extending longitudinally
parallel to
the long slot (140) through the guide member wall (134) from the lower end
(132) of the guide
n Member ( 128) for a portion of the length of the guide member (128). The
short slot ( 146) does
not extend to the upper end ( 130) of the guide member ( 128). Thus, the short
slot ( 146) has an
42
CA 02506348 2005-05-04
upper end (148) which terminates within the guide member wall (134) and a
lower end (150)
which is co-terminous with the lower end ( 132) of the guide member ( I 28).
Thus, after passing
out of the lower end ( 144) of the long slot ( 140), the key ( 120) may pass
within the lower end
( 150) of the short slot ( 146).
Each of the long and short slots ( 140, 146) may be located about the
circumference of the tubular guide member ( 128) at any spaced apart
locations. However,
preferably, for ease of use of the first running and retrieval tool (110), the
long and short slots
(140, 146) are positioned at opposed locations on either side of the guide
member (128)
adjacent the C-shaped recess (80) in the guide housing (86) as shown in
Figures 7 and 10. The
latching mechanism (102) is preferably associated with the short slot (146)
such that the key
(120) acts upon the latch (104) as it travels within the short slot (146). In
particular, referring
to Figures 9 and 11, the latching mechanism (102) is mounted within the guide
housing (86)
adjacent the tubular guide member ( 128), and more particularly, adjacent the
short slot ( 146).
In each of the first and second embodiments of the guide (24), the latching
mechanism (102) is comprised of the latch (104), a latch mount (152) and a
spring (154) for
biasing the latch ( 102) in the desired manner. However, in the first
embodiment of the guide
(24), the latch mount ( 152) is mounted with the inner surface of the guide
housing wall (92)
adjacent the tubular guide member (128). The latch mount (152) may be affixed
or mounted
with the guide housing wall (92) in any manner, however, preferably the latch
mount (152) is
welded to the guide housing wall (92). The spring (154) is preferably a leaf
spring comprised
of spring steel having two opposed ends. One end is mounted with the latch
mount ( I 52) by
any fastener or fastening mechanism, preferably one or more screws or bolts (
156). As a fail-
safe or safety feature, the end of the spring steel ( 154) may be mounted with
the latch mount
(152) by one or more shearing screws or bolts (156) to permit shearing of the
latch (102) from
within the guide housing (86) when necessary to remove the guide (24). The
other opposed
end of the spring steel (154) is attached or mounted with the innermost
surface of the latch
( 104) in any manner, but preferably as described below by a fastener or
fastening mechanism
such as one or more screws or bolts ( I 58).
The latch mount (152) is positioned, and the components of the latching
mechanism ( 102) are configured, so that the latch ( 104) is positioned
adjacent the short slot
(146) such that it may be acted upon by the key (120) and so that the latch
(104) is biased
43
CA 02506348 2005-05-04
outwardly through the opening ( 118) in the guide housing wall (92) within the
C-shaped recess
(98) by the spring steel (154).
Referring to Figures 12 - 14, the latch ( 140) preferably has the same
configuration in both the first and second embodiments of the guide (24).
However, as
described below, the shapes or configurations of various components or
surfaces of the latch
( 104) are provided to interact with the key ( 120) of the first running and
retrieval tool ( 110).
Accordingly, these particular components or surfaces may be modified where the
latch is not
intended for use with the first running and retrieval tool (110).
The latch ( 104) is preferably comprised of an inner portion ( 160) and an
outer
portion ( 162) which are affixed or mounted together, preferably by welding,
to form the latch
( 104). Alternately, the latch ( 104) may be comprised of a single member or
component or
greater than two members or portions affixed together to provide an integral
unit. In the first
l 5 embodiment of the guide (24), the inner portion ( I 60) comprises the
portion of the latch ( I 04)
acted upon by the key ( 120). Further, the outer portion ( 162) is affixed or
mounted with the
spring steel (154) and may also comprise a portion of the latch (104) acted
upon by the key
( 120). The outer portion ( 162) comprises the portion of the latch ( l04)
which extends from the
opening (118) in the guide housing wall (92) for engagement with the
indentation (106) in the
upper end (44) of the lateral conduit (30).
The outer portion ( 162) has an inner surface ( 164) for mounting or attaching
with the spring ( 154) and an opposed outer surface ( 166). Further, the outer
portion ( 162) has
an upper surface (168) and an opposed lower surface (170). As indicated, the
inner surface
( 164) is mounted or otherwise attached with the spring ( 154) for biasing the
latch ( 104). The
outer surface ( 166) is sized and configured to extend through the compatible
opening ( 118) in
the guide housing wall (92). The inner surface (164) is comprised of opposed
side flanges
( 172) which are configured to prevent the outer portion ( 162) of the latch (
102) liom
completely passing through the opening ( 118) in the guide housing wall (92).
In other words,
the side flanges (172) on the inner surface (164) engage the guide housing
wall (92) and
prevent the passage of the inner surface ( 164) through the opening ( 118).
The outer surface (166) is adapted to engage the indentation (106) in the
lateral
conduit (30). Therefore, the outer surface (166) is sized and shaped to be
compatible with the
44
CA 02506348 2005-05-04
lateral conduit (30). Accordingly, the outer surface (166) preferably provides
a C-shaped
recess ( 174) for securely engaging the indentation ( 106) in the upper end
(44) of the lateral
conduit (30).
Finally, the upper surface ( 168) of the outer portion ( 162) is preferably
substantially perpendicular to the inner and outer surfaces ( 164, 166). The
lower surface ( 170)
of the outer portion ( 162) is sloped or angled inwardly from the outer
surface ( 166) to the inner
surface ( 164). In the first embodiment of the guide (24), the lower surface (
170) is sloped or
angled to provide a portion of a sloped or angled shoulder which engages the
upwardly facing
shoulder ( 122) of the key ( 120) as the key ( 120) travels upwardly or in an
uphole direction
through the short slot (146).
The inner portion ( 160) also has an inner surface ( 176) and an opposed outer
surface ( 178) for engaging the inner surface ( 164) of the outer portion (
164) of the latch ( 104).
Specifically, the outer surface ( 178} defines a lip or ridge ( 184) for
seating of the outer portion
( 162) thereon. Preferably, the outer surface ( 178) of the inner portion (
160) is welded with the
inner surface ( 164) of the outer portion ( 162) such that the inner portion (
160) is adjacent the
location or position of the mounting of the end of the spring steel ( 154)
with the outer portion
( 162 ).
Further, the inner portion ( 160) has an upper surface ( 180) and an opposed
lower
surface ( 182). The upper surface ( 180) of the inner portion ( 160) is
preferably substantially
perpendicular to the inner and outer surfaces ( 176, 178). When the inner and
outer portions
( I 60, 162) are mounted together, the upper surfaces ( 180, 168) of the inner
and outer portions
( 160, 162) terminate adjacent to each other. The lower surface (182) of the
inner portion (160)
is preferably sloped or angled inwardly from the outer surface ( 178) to the
inner surface ( 176).
In the first embodiment of the guide (24), the lower surface ( 182) is
preferably sloped or angled
to provide a portion of a sloped or angled shoulder which engages the upwardly
facing shoulder
(122) of the key (120) as the key (120) travels upwardly or in an uphole
direction through the
short slot ( 146). When the inner and outer portions ( 160, 162) are mounted
together, the sloped
or angled lower surface ( 182) of the inner portion ( 160) is continuous with
the sloped or angled
lower surface ( 170) of the outer portion ( 162) to provide an integral
abutment or engagement
surface for the key ( 120).
CA 02506348 2005-05-04
In the first embodiment of the guide (24), to actuate the latching mechanism
(102) and to utilize the first running and retrieval tool (110), the lower end
(116) of the
elongated member ( 112) of the first running and retrieval tool ( 110) with
the key ( 120) attached
thereto is inserted within the upper end (142) of the long slot (140) of the
tubular guide
member ( 128) through the upper surface opening ( 136) in the guide housing
(86). The key
( 120) is passed through the length of the long slot ( 140) and out of the
lower end ( 144) of the
long slot ( 140). Upon passing out of the lower end ( 144) of the long slot (
140), the lower end
( 116) of the elongated member ( 112) preferably engages or abuts against the
base plate (96) of
the guide housing (86) to signal to the operator that the key ( 120) has
passed from the long slot
(140).
The elongated member (112) of the first running and retrieval tool (110) is
then
turned or rotated, preferably to the right or in a clockwise direction
relative to the guide
housing (86), until the key ( 120) is adjacent the lower end ( 150) of the
short slot ( 146). In the
preferred embodiment, the key ( 120) rotates about 270 degrees. To aid with
the proper
positioning of the key ( 120) below the short slot ( 146), a stop plate ( 186)
may be mounted
within the guide housing wall (92) adjacent the lower end ( 150) of the short
slot ( 146) to inhibit
or prevent further rotation of the key ( 120) to the right or in the clockwise
direction.
Once positioned below the short slot (146), the elongated member (112) of the
inning and retrieval tool ( 110) is moved up or in an uphole direction to move
the key ( 120)
into the short slot ( 146) through its lower end ( 150). As the key ( 120)
travels through the short
slot ( 146) from the lower end (150) to the upper end (148), the upwardly
facing shoulder (122)
on the key ( 120) engages or contacts one or both of the angled or sloped
lower surface ( 182) of
the inner portion ( 160) and the angled or sloped lower surface ( 170) of the
outer portion ( 162)
which causes the latch ( 104) to be moved inwardly against the biasing of the
spring steel ( 154)
to withdraw the outer surface ( 166) of the outer portion ( 162) from the C-
shaped recess (98) in
the guide housing (86) through the opening ( 118) therein. Thus, the latching
mechanism ( 102)
is disengaged.
Once the locking mechanism ( 102) is disengaged, preferably a shear pin (not
shown) is passed through the guide housing (86) for insertion through the pin
hole (126) in the
key (120). Thus, the key (120) and the latching mechanism (102) are held or
maintained in the
disengaged condition. Thus, the shear pin is preferably provided to minimize
the possible
46
CA 02506348 2005-05-04
disconnection of the key ( 120) from the latching mechanism ( 102) or movement
of the key
( 120) out of the disengaged condition while placing the guide (24) in the
primary borehole.
The guide (24) is then inserted through the primary borehole and within the
primary conduit
(28) using a pipe string connected with the upper end (114) of the elongated
member (112) of
the first running and retrieval tool ( 110). The upper end (44) of the lateral
conduit (30) is
inserted within the C-shaped recess (98) of the guide housing (86) until the
upper end (44)
contacts the stop collar ( 100).
More particularly, the guide (24) is passed through the primary borehole until
the
lower end (90) of the guide housing (86), defined by the base plate (96),
contacts or abuts the
upper end (44) of the lateral conduit (30). Upon contact, the shear pin as
described above may
shear. The guide (24) is then permitted to rest upon the lateral conduit (30)
so that the pipe
string weight decreases. The pipe string is then rotated, preferably to the
right or clockwise, in
order to rotate the guide (24) downhole. Rotation continues until the rotation
torque increases
and / or the pipe string weight increases, indicating that the lateral conduit
(30) has been
aligmed with the C-shaped recess (98) of the guide housing (86). The guide
(24) is then further
lowered by the pipe string and the lateral conduit (30) is inserted within the
C-shaped recess
(98) of the guide housing (86) until the upper end (44) of the lateral conduit
(30) contacts the
stop collar ( 100).
Once the upper end (44) of the lateral conduit (30) contacts the stop collar (
100),
a further downward force, or force in a downhole direction, is applied through
the elongated
member ( 112) of the first running and retrieval tool ( 110). This further
downward force causes
the shearing of the shear pin within the pin hole (126) of the key (120), thus
permitting
movement of the key ( 120) within the short slot ( 146).
As the downward force is applied, the key ( 120) is moved within the short
slot
( 146) from its upper end ( 148) towards its lower end ( 150) and subsequently
passes out of the
lower end ( 150) of the short slot ( 146). When the key ( 120) no longer
engages the lower
surfaces ( 182, 170) of the inner and outer portions ( 160, 162) of the latch
( 104), the biasing of
the spring steel ( I 54) causes the latch ( 104) to move outwardly such that
the outer surface ( I 66)
of the outer portion (162) of the latch (104) engages the upper end (44) of
the lateral conduit
(30) within the indentation (106). Thus, the latching mechanism ( 102) is
engaged.
47
CA 02506348 2005-05-04
To remove the first running and retrieval tool (110) while leaving the guide
(24)
within the primary conduit (28), once the key ( 120) exits the lower end (
150) of the short slot
( 146), the elongated member ( 112) of the first running and retrieval tool (
I 10) is turned or
rotated, preferably to the left or in a counterclockwise direction relative to
the guide housing
(86), until the key ( 120) is adjacent the lower end ( 144) of the long slot (
140). As indicated
above, in the preferred embodiment, the key ( 120) rotates about 270 degrees.
Upon passing out
of the lower end ( 150) of the short slot ( 146), the lower end ( 116) of the
elongated member
( l 12) preferably engages or abuts against the base plate (96) of the guide
housing (86) to signal
to the operator that the key ( 120) has passed from the short slot ( 146).
Following rotation, to
aid with the proper positioning of the key ( 120) below the long slot ( 140),
a further stop plate
( 188) may be mounted within the guide housing wall (92) adjacent the lower
end (144) of the
long slot ( 140) to inhibit or prevent further rotation of the key ( 120) to
the left or in the
counterclockwise direction.
l5 Once positioned below the long slot (140), the elongated member (112) of
the
first running and retrieval tool ( 110) is moved up or in an uphole direction
to move the key
( 120) into the long slot ( 140) through its lower end ( 144). The key ( 120)
travels through the
long slot ( 140) from its lower end ( 144) to its upper end ( 142) and out the
upper end ( 142)
through the upper surface opening ( 136) in the guide housing (86). The first
running and
retrieval tool ( 110) may then be removed to the surface to permit the
insertion of downhole
tools or equipment through the primary borehole.
When it is desired to remove the guide (24) from the junction assembly (20),
the
operation as described above is repeated. The first running and retrieval tool
( 110) is
connected with the pipe string and passed through the primary borehole to the
guide (24) until
the lower end (116) of the elongated member (112) contacts the guide plate
(94) of the upper
end (88) of the guide housing (86). The first running and retrieval tool (110)
is then rotated,
preferably to the right or clockwise, until the key ( 120) is aligned with the
upper surface
opening (136) in the guide (24). The key (120) of the first running and
retrieval tool (110) is
then passed through the long slot ( 140), rotated to the right and then moved
within the short
slot ( 146) to act upon the latch ( 102) and actuate the latching mechanism (
102) to the
disengaged position or condition. Once in the disengaged condition, a further
upward force, or
force in an uphole direction, is applied through the elongated member ( 112)
of the first running
and retrieval tool ( 110). This causes the key ( 120) to engage or abut
against the upper end
48
CA 02506348 2005-05-04
( 148) of the short slot ( 146), which moves the guide housing (86) in an
upwards or uphole
direction to disengage the lateral conduit (30) from within the C-shaped
recess (98). The guide
(24) may then be removed to the surface.
Rotation of the pipe or tubular string and the attached first running and
retrieval
tool ( I 10) within the casing string during placement and removal of the
guide (24) are not
desirable. Further, it is preferable that the casing string be held at the
surface in an unlocked
position permitting rotation of the casing string within the borehole during
placement and
removal of the guide (24). Finally, if necessary, fluids may be pumped through
the guide (24)
during the removal process in order to flush any debris, such as drilling
cuttings, from the long
and short slots (140, 146) and thereby facilitate entry of the key (120) into
and passage through
the slots ( 140, 146).
Referring to Figures 16 - 20 of the second preferred embodiment of the guide
(24), the guide housing (86) does not include the tubular guide member (128)
and the
associated structure for use with the first running and retrieval tool ( 110).
An alternate running
and retrieval mechanism ( 109) is provided for use with the second and third
running and
retrieval tools (111, 113).
In the second embodiment of the guide (24), the guide housing (86) is also
preferably hollow and includes one or more reinforcement plates (138) or
members as required
to brace or support the structure of the guide housing (86). Preferably, the
guide housing (86)
includes at least one central reinforcement plate ( 138) extending across the
guide housing (86)
between the inner surface of the C-shaped recess (98) and the inner surface of
the opposed
guide housing wall (92). Further, the central reinforcement plate (138) is
positioned within the
guide housing (86) such that it does not interfere with the guide latching
mechanism (102) and
the associated opening (118) in the C-shaped recess (98).
As described above, the latching mechanism (102) of the guide (24) is
comprised
of the latch ( 104), the latch mount ( 152) and the spring ( 154) for biasing
the latch ( 104) in the
desired manner. However, the latching mechanism ( 102) in the second
embodiment of the
guide (24) does differ in some respects from that of the first embodiment of
the guide (24)
described above. In particular, referring to Figures 16 - 20, the latch mount
( I 52) is mounted
either directly or indirectly with the inner surface of the guide housing wall
(92). More
49
CA 02506348 2005-05-04
particularly, the latch mount (152) is preferably mounted with or adjacent the
C-shaped recess
(98) at a location or position permitting the latch ( 104) to extend through
the opening ( 118)
therein.
In the preferred embodiment, as shown in Figure 19, a reinforcement plate (
138)
is mounted with the inner surface of the guide housing wall (92) across a
portion of the C-
shaped recess (98). Further, the latch mount ( 152) is comprised of a latch
plate ( 189) affixed or
mounted with the reinforcement plate (138) by at least one, and preferably
four, bolts or screws
( 190). The latch plate ( 189) is mounted with the reinforcement plate ( 138)
a spaced distance
therefrom to provide a space or pocket between the adjacent surfaces of the
latch plate ( 189)
and the reinforcement plate ( 138). The space or pocket is of a sufficient
size to permit one end
of the leaf spring ( 154) to be received therebetween. Once the end of the
leaf spring ( 154) is
received therebetween, one or more shearing pins ( I 91 ) or screws or other
shearing members
are mounted between the latch plate ( 189) and the reinforcement plate ( 138)
by passing or
extending through the end of the spring ( 154) in order to secure the spring (
154) in position.
As described further below, the latching mechanism ( 102) is preferably
comprised of a shear mechanism for releasing the latching mechanism ( 102)
when it is desired
to remove the guide (24) from the conduit junction (20). Although any shear
mechanism may
be used, the shear mechanism is preferably comprised of the shear pins ( 191 )
mounted between
the latch plate ( 189) and the reinforcement plate ( 138) to permit shearing
of the latch (104)
from within the latch mount ( 152) when necessary to remove the guide (24).
The other opposed end of the spring ( I 54) may be attached or mounted with
the
innermost surface of the latch ( 104) in any manner. However, preferably, the
spring ( 154) is
mounted by welding the end of the spring ( 154) with the latch (104). As
stated, the latch
mount (152) is positioned, and the components of the latching mechanism (102)
are
configured, so that the latch ( 104) is biased outwardly through the opening (
118) in the guide
housing wall (92) within the C-shaped recess (98) by the spring ( 154).
In addition, referring to Figures 16, 18 and 20 of the second preferred
embodiment of the guide (24), the upper end (88) of the guide housing (86) is
comprised of a
fishing neck portion ( 192) or fishneck portion which is configured for use
with the second and
third running and retrieval tools (111, 113). Although any conventional or
known fishing neck
CA 02506348 2005-05-04
may be used so long as it is compatible with the desired fishing tool, the
preferred fishing neck
portion ( 192) is described below.
In the second preferred embodiment of the guide (24), the running and
retrieval
mechanism ( 109) is comprised of the fishing neck portion ( 192). As described
further below,
the fishing neck portion ( 192) is comprised of at least one of a slot or pin
for engagement with
a complementary slot or a complementary pin associated with the running and
retrieval tools
( 1 11, 113) in order to install and remove the guide (24). A fishing neck
portion ( 192) may also
be mounted with the first embodiment of the guide (24) where desired to permit
placement and
removal of the first embodiment of the guide (24) by any of the first, second
and third running
and retrieval tools (110, 111, 113). In this case, the guide (24) is
preferably installed using
either the second or third running and retrieval tools (111, 113), while the
first running and
retrieval tool ( 110) is preferably used to remove the guide (24).
Specifically, if a fishing neck portion (192) is mounted with the first
embodiment of the guide (24), the guide (24), including the long and short
slots ( 140, 146), is
preferably packed with grease prior to placement or positioning within the
primary conduit
(28). The grease packing is provided to minimize or prevent any debris, such
as drilling
cuttings, liom settling inside the guide (24) which may affect the removal of
the guide (24)
once drilling is complete. Use of the first running and retrieval tool ( 110)
would disturb the
grease packing and permit debris to enter the slots (140, 146). Thus, the
second or third
running and retrieval tool (111, 113) is preferably used in order to minimize
any disturbance to
the grease packing in the guide (24) during placement.
However, in the first embodiment of the guide (24), the latching mechanism
( 102) is engaged upon placement of the guide (24) in the primary conduit
(28). The key (120)
of the Frst running and retrieval tool ( I 10) is required to actuate the
latching mechanism ( 102)
to the disengaged condition or position to permit removal of the guide (24).
Accordingly, the
first running and retrieval tool ( 110) is preferably used to remove the guide
(24). However, the
second and third running and retrieval tools (111, 113) may be used as back-
ups to remove the
guide (24) upon failure of the first running and retrieval tool ( 110) or
following unsuccessful
attempts to use the first running and retrieval tool ( 110) for any reason.
51
CA 02506348 2005-05-04
Referring to Figures 16, 18 and 20, the upper end (88) of the guide housing
(86)
is comprised of the fishing neck portion (192). The fishing neck portion (192)
of the guide (24)
is comprised of a tubular extension which is integrally formed with the upper
end (88) of the
guide housing (86) or which is connected, attached or otherwise mounted,
permanently or
removably, in any manner with the upper end (88) of the guide housing (86). In
the second
embodiment, the ftshing neck portion (192) is preferably welded to the upper
end (88) of the
guide housing (86) such that the upper end (88) is comprised of the fishing
neck portion ( 192).
More particularly, the fishing neck (190) is comprised of a tubular member
(200) having an
upper end (202) defining an upper end of the fishing neck portion (192), a
lower end (204)
defining a lower end of the fishing neck portion ( 192) and a wall (206)
extending therebetween.
The lower end (204) of the fishing neck portion ( 192) is fitted within the
upper end (88) of the
guide housing (86) and welded in position.
Further, the wall (206) of the tubular member (200) defines a cut-away portion
(208) such that the tubular member (200) is substantially C-shaped on cross-
section as shown
in Figure 19. Further, the cut-away portion (208) is preferably sized and
configured to be
compatible with the size and configuration of the C-shaped recess (98) of the
guide housing
(86). In addition, the lower end (204) of the tubular member (200) is welded
with the upper
end (88) of the guide housing (86) such that the cut-away portion (208) is
aligned with the C
shaped recess (98).
The outer diameter of the fishing neck portion ( 192), and particularly the
outer
diameter of the wall (206), is preferably compatible with the outer diameter
of the guide
housing wall (92). In the preferred embodiment, the wall (206) of the tubular
member (200)
has an outer surface (210) defining an outer diameter of about 8 inches (about
20.32 cm) and an
inner surface (212) defining an inner diameter of about 6 inches (about 15.24
cm), which
provides a wall thickness or width of about 2 inches (about 5.08 cm). At least
two J-shaped
slots (214) are defined by the inner surface (212) of the wall (206) and
extend from the upper
end (202) towards the lower end (204) of the wall (206). In the preferred
embodiment, two J-
shaped slots (214) are preferably arranged on either side of the cut-away
portion (208) a spaced
distance apart. More preferably, the J-shaped slots (214) are spaced about 180
degrees apart
such that the J-shaped slots (214) are positioned within opposed sides of the
wall (206). The J-
shaped slots (214) are configured for use with the second running and
retrieval tool ( 111 ).
52
CA 02506348 2005-05-04
Preferably, each J-shaped slot (214) has a first longitudinal leg (216)
extending
from the upper end (202) of the wall (206) towards the lower end (204), an
axial leg (218)
extending perpendicularly from the lowermost or downhole end of the first
longitudinal leg
(206) and a second longitudinal leg (220) opposed to the first longitudinal
leg (216) extending
in an upwards or uphole direction from the axial leg (218) to form a J-shape.
The second
longitudinal leg (220) does not extend to the upper end (202) but terminates
at a slot shoulder
(221 ) providing an engagement surface for the second running and retrieval
tool ( 111 ) as
described below. The axial leg (218) of each J-shaped slot (214) extends from
the first
longitudinal leg (216) in the same direction. In the preferred embodiment, the
axial leg (218)
of each J-shaped slot (214) extends from the first longitudinal leg (216) to
the right or in a
clockwise direction when viewed from the upper end (202) of the fishing neck
portion ( 192).
Each leg (216, 218, 220) of the J-shaped slot (214) may have any length.
However, in the preferred embodiment, the first longitudinal leg (216) has a
length of about 6
inches (about 15.24 cm), the axial leg (218) has a length of about 2 inches
(about 5.08 cm) and
the second longitudinal leg (220) has a length of about 4 inches (about 10.16
em).
In addition, the fishing neck portion (192) is preferably comprised of at
least two
pins (223) extending inwardly from the inner surface (212) of the wall (206)
of the tubular
member (200). The pins (223) are configured for use with the third running and
retrieval tool
( 1 13). Preferably, two pins (223) are preferably arranged on either side of
the cut-away portion
(208) a spaced distance apart. More preferably, as shown in Figure 19, the
pins (223) are
spaced about 180 degrees apart such that the pins (223) are positioned on and
extend inwardly
from opposed sides of the inner surface (212) of the wall (206). The pins
(223) are provided to
engage the third running and retrieval tool ( 113).
Referring to Figure 21, the second running and retrieval tool (111) is
configured
for engagement with the J-shaped slots (214) of the fishing neck portion (
192). The second
running and retrieval tool ( 111 ) is comprised of an elongated member (222)
having an upper
end (224) and a lower end (226). The upper end (224) is adapted for engagement
with a pipe
string or tubular string, for lowering the second running and retrieval tool (
111 ) through the
primary borehole. Although the upper end (224) may be engaged or connected
with the pipe
string by any fastening or connection mechanism, preferably a threaded
connection is provided
therebetween. In the preferred embodiment, the upper end (224) of the
elongated member
53
CA 02506348 2005-05-04
(222) of the second running and retrieval tool ( 111 ) is comprised of a
threaded box connector
for connection with a threaded pin connector on the adjacent end of the pipe
string.
The lower end (226) may have any shape or configuration compatible with its
passage within the fishing neck portion (192). Where desired, the upper end
(202) of the
fishing neck portion ( 192) may have an inwardly sloped surface to guide or
direct the lower end
(226) of the elongated member (222) within the tubular member (200). Further,
the outer
diameter of the elongated member (222) is selected to fit within the inner
diameter of the wall
(206) of the fishing neck portion ( 192). If desired, to assist in
centralizing the elongated
member (222) within the tubular member (200) of the fishing neck portion (
192), the elongated
member (222) may be comprised of one or more centralizing members (230)
mounted about
the circumference of the elongated member (222) and extending axially from the
elongated
member (222) to contact the inner surface (212) of the wall (206) of the
fishing neck portion
( 192).
l5
Finally, the elongated member (222) is comprised of one or more pins (232) or
members shaped or configured for receipt within the J-shaped slots (214) of
the fishing neck
portion ( 192). The number of pins (232) is selected to be compatible with the
number of J-
shaped slots (214) such that a single pin (232) is provided for receipt in
each J-shaped slot
(214). Thus, in the preferred embodiment, the elongated member (222) is
comprised of two
pins (232). The pins (232) are adapted and configured for insertion within and
passage through
the J-shaped slots (214) for abutment or engagement with the slot shoulder
(221). Each pin
(232) extends axially outwardly from the elongated member (222) for receipt in
its respective J-
shaped slot (214). Further, the two-pins (232) are arranged on either side of
the elongated
member (222) a spaced distance apart. In the preferred embodiment, the pins
(232) are spaced
about 180 degrees apart such that the pins (232) are positioned on opposed
sides of the
elongated member (222) and compatible with the positioning of the J-shaped
slots (214) within
the fishing neck portion ( 192).
Finally, for the purpose outlined below, the elongated member (222) may define
a pin hole (not shown) for receipt of a shear pin (not shown ) therein. The
shear pin is received
in the pin hole when the pins (232) are in a desired position within the J-
shaped slots (214), and
particularly when the pins (232) engage or abut against the slot shoulders
(221 ), to prevent
movement of the elongated member (222) relative to the fishing neck portion (
192) when
54
CA 02506348 2005-05-04
running or positioning the guide (24) within the primary conduit (28). Onee
the guide (24) is
properly positioned, the shear pin is sheared or broken to perniit the removal
of the second
running and retrieval tool ( 111 ).
To utilize the second running and retrieval tool (111), the lower end (226) of
the
elongated member (222) of the second running and retrieval tool ( 111 ) is
inserted within the
upper end (202) of the fishing neck portion (192) such that the pins (232) are
aligned with and
pass into the first longitudinal leg (216) of the J-shaped slots (214) at the
upper end (202) of the
wall (206). Each pin (232) is passed downwards through the length of the first
longitudinal leg
(216) of its respective J-shaped slot (214) until the pin (232) abuts against
its lowermost end,
intersecting with the axial leg (218).
The elongated member (222) of the second running and retrieval tool ( 111 ) is
then turned or rotated, preferably to the right or in a clockwise direction
relative to the wall
(206). This rotation moves the pin (232) from one end of the axial leg (218)
of the J-shaped
slot (214) to the other opposed end until the pin (232) abuts against the
opposed end of the
axial leg (218), intersecting with the second longitudinal leg of the J-shaped
slot (214).
Finally, the elongated member (222) of the second running and retrieval tool
( 111 ) is moved up or in an uphole direction to move the pin (232) through
the second
longitudinal leg (220) of the J-shaped slot (214) from its lowermost end to
abut or engage
against the slot shoulder (221 ). In this position, preferably a shear pin
(not shown) is passed
through the wall (206) of the tubular member (200) of the fishing neck portion
( 192) for
insertion through a pin hole (not shown) in the elongated member (222). Thus,
the shear pin is
preferably provided to minimize the possible disconnection of the elongated
member (222)
from the fishing neck portion (192) or movement of the pin (232) out of
engagement with the
slot shoulder (221 ) while placing the guide (24) in the primary borehole. The
guide (24) is then
inserted through the primary borehole and within the primary conduit (28)
using a pipe string or
tubular string connected with the upper end (224) of the elongated member
(222) of the second
running and retrieval tool (111).
More particularly, the guide (24) is passed through the primary borehole until
the
lower end (90) of the guide housing (86), defined by the base plate (96),
contacts or abuts the
upper end (44) of the lateral conduit (30). Upon contact, the shear pin as
described above may
CA 02506348 2005-05-04
shear. The guide (24) is then permitted to rest upon the lateral conduit (30)
so that the pipe
string weight decreases. The pipe string is then rotated, preferably to the
right or clockwise, in
order to rotate the guide (24) downhole. Rotation continues until the rotation
torque increases
and / or the pipe string weight increases, indicating that the lateral conduit
(30) has been
aligned with the C-shaped recess (98) of the guide housing (86). The guide
(24) is then further
lowered by the pipe string and the lateral conduit (30) is inserted within the
C-shaped recess
(98) of the guide housing (86) until the upper end (44) of the lateral conduit
(30) contacts the
stop collar ( 100).
Once the upper end (44) of the lateral conduit (30) contacts the stop collar (
100),
a further downward force, or force in a downhole direction, may be applied
through the
elongated member (222) of the second running and retrieval tool ( 111 ). This
further downward
force causes the shearing of the shear pin within the pin hole of the
elongated member (222),
thus permitting movement of the pins (232) within the J-shaped slot (214).
To remove the second running and retrieval tool (111) while leaving the guide
(24) within the primary conduit (28), a further downward or downhole force is
applied through
the elongated member (222) to cause each of the pins (232) to move in a
downwards or
downhole direction within the second longitudinal leg (220) of its respective
J-shaped slot
(214) away from the slot shoulder (221 ) towards the axial leg (218). Once the
pin (232) abuts
the end of the second longitudinal leg (222) intersecting the axial leg (218),
the elongated
member (222) of the second running and retrieval tool (111) is turned or
rotated, preferably to
the left or in a counterclockwise direction relative to the wall (206) of the
fishing neck ( 190), so
that the pin (232) travels through the axial leg (218) towards the first
longitudinal leg (216).
Once the pin (232) abuts the end of the axial leg (218) intersecting the first
longitudinal leg
(216), an upward or uphole force is applied through the elongated member (222)
to cause each
of the pins (232) to move in a upwards or uphole direction within the first
longitudinal leg
(216) away from axial leg (218) towards the upper end (202) of the tubular
member (200) of
the fishing neck portion ( 192) in order to disengage and remove the pins
(232) from the J-
shaped slots (214). The second running and retrieval tool (111) may then be
removed to the
surface to permit the insertion of downhole tools or equipment through the
primary borehole.
If required or desired to use the second running and retrieval tool ( 11 I )
to
remove the guide (24) from the junction assembly (20), the operation as
described above is
56
CA 02506348 2005-05-04
repeated. The second running and retrieval tool ( 111 ) is connected with the
pipe string and
passed through the primary borehole to the guide (24) until lower end (226) of
the elongated
member (222) enters the upper end (202) of the fishing neck portion ( 192).
Upon further
downward movement, the pins (232) of the elongated member (222) contact or
abut the upper
end (202) of the fishing neck portion ( 190). The second running and retrieval
tool ( 111 ) is then
rotated, preferably to the right or clockwise, until the pins (232) are
aligned with the J-shaped
slots (214). When the pins (232) and slots (214) are aligned, further rotation
may be inhibited
or the pipe string weight may increase, signaling the alignment to the
operator. The pins (232)
of the second running and retrieval tool (111) are then passed through the
first longitudinal legs
(216) of the J-shaped slots (214) by moving the elongated member (222) in a
downward or
downhole direction. The elongated member (222) is then rotated to the right to
pass the pins
(232) through the axial legs (218). Finally, the elongated member (222) is
moved upward or in
an uphole direction to pass or move the pins (232) through the second
longitudinal legs (220)
for abutment against the slot shoulders (221). The guide (24) may then be
removed to the
surface by further upward or uphole movement of the second running and
retrieval tool ( 11 I ),
which will result in shearing of the shear pins ( 191 ) to permit shearing of
the latch ( I 04) from
within the guide housing (86).
Referring to Figure 22, the third running and retrieval tool (113) is
configured
for engagement with the pins (223) of the fishing neck portion (192). The
third running and
retrieval tool ( 113) is also comprised of an elongated member (234) having an
upper end (236)
and a lower end (238). The upper end (236) is adapted for engagement with a
pipe string or
tubular string, for lowering the third running and retrieval tool (113)
through the primary
borehole. Although the upper end (236) may be engaged or connected with the
pipe string by
any fastening or connection mechanism, preferably a threaded connection is
provided
therebetween. In the preferred embodiment, the upper end (236) of the
elongated member
(234) of the third running and retrieval tool ( 113) is comprised of a
threaded box connector for
connection with a threaded pin connector on the adjacent end of the pipe
string.
The lower end (238) may have any shape or configuration compatible with its
passage within the fishing neck portion ( 192). Further, the outer diameter of
the elongated
member (234) is selected to fit within the inner diameter of the wall (206) of
the fishing neck
portion ( 192). To assist in centralizing the elongated member (234) within
the tubular member
(200) of the fishing neck portion (192), the elongated member (234) may be
comprised of one
57
CA 02506348 2005-05-04
or more centralizing members (240) mounted about the circumference of the
elongated member
(234) and extending axially from the elongated member (234) to contact the
inner surface (212)
of the wall (206) of the fishing neck portion ( 192).
Finally, the elongated member (234) is comprised of one or more slots (242)
configured for receiving the pins (223) of the fishing neck portion (192). The
slots (242) are
defined by or within an outer surface (244) of the elongated member (234) in a
manner such
that each slot (242) extends to the lower end (238) of the elongated member
(234) to perniit
entry of a pin (223) therein. The number of slots (242) is selected to be
compatible with the
number of pins (223) such that a single slot (242) is provided for receiving
each pin (223).
Thus, the elongated member (234) preferably defines two slots (242). The pins
(223) are
adapted and configured for insertion within and passage through the slots
(242) as described
below. Further, the two-slots (242) are arranged on either side of the
elongated member (234) a
spaced distance apart. In the preferred embodiment, the slots (242) are spaced
about 180
degrees apart such that the slots (242) are positioned on opposed sides of the
elongated member
(234) and compatible with the positioning of the pins (223) on the fishing
neck portion ( 192).
Referring to Figures 22 and 23, as stated, each of the slots (242) is defined
by the
outer surface (244) of the elongated member (234) of the third running and
retrieval tool ( 113)
and extends from the lower end (238) thereof. The slots (242) may have any
configuration
compatible with their intended function as described herein. For instance, the
slots (242) may
be J-shaped, similar to the slots (214) defined by the fishing neck portion (
192). However,
preferably, each slot (242) has a V-shape or configuration. Thus, preferably,
each V-shaped
slot (242) has a first spiral leg (246) and a second longitudinally oriented
or straight leg (248).
The first spiral leg (246) extends from the lower end (238) of the elongated
member (234) in a
diagonal direction or at an angle with respect to a longitudinal axis of the
elongated member
(234) to an upper end (250) of the V-shaped slot (242). The second straight
leg (248) extends
from the first spiral leg (246) at the upper end (250) of the V-shaped slot
(242) towards the
lower end (236) of the elongated member (234) in a longitudinally oriented
direction or a
direction parallel to the longitudinal axis of the elongated member (234). The
second straight
leg (248) does not extend fully to the lower end (238) but terminates at a
slot shoulder (252)
which provides an engagement surface for the pin (223) of the fishing neck
portion (192).
Preferably about a 45 degree angle is provided between the first spiral leg
(246) and the second
straight leg (248).
58
CA 02506348 2005-05-04
Finally, for the elongated member (234) may define a pin hole (not shown) for
receipt of a shear pin (not shown ) therein. The shear pin is received in the
pin hole when the
pins (223) are in a desired position within the V-shaped slots (242), and
particularly when the
pins (223) engage or abut against the slot shoulders (252), to prevent
movement of the
elongated member (234) relative to the fishing neck portion ( 192) when
running or positioning
the guide (24) within the primary conduit (28). Once the guide (24) is
properly positioned, the
shear pin is sheared or broken to permit the removal of the third running and
retrieval tool
(1 13).
To utilize the third running and retrieval tool (113), the lower end (238) of
the
elongated member (234) of the third running and retrieval tool (113) is
inserted within the
upper end (202) of the fishing neck portion (192) such that the pins (223) are
aligned with the
first spiral leg (246) of the V-shaped slots (242) at the lower end (238) of
the elongated
member (234). The elongated member (234) is moved in a downward or downhole
direction
such that each pin (223) moves upwards through the length of the first spiral
leg (246) of its
respective V-shaped slot (242) until the pin (223) abuts against the upper end
(250) of the slot
(242).
The elongated member (234) of the third running and retrieval tool ( 113) is
then
turned or rotated, preferably to the right or in a clockwise direction
relative to the wall (206),
until further movement is prevented. This rotation moves the pin (223) to
align it with the
second straight leg (248) of the V-shaped slot (242). The elongated member
(234) is then
moved in an upward or uphole direction such that the pin (223) moves downward
through the
length of the second straight leg (248) until the pin (223) abuts against or
engages the slot
shoulder (252). During this upward movement, neither the pipe string connected
with the third
running and retrieval tool ( 113) nor the guide (24) should turn or rotate. If
any rotation is
noted, the pins (223) are still located within the first spiral leg (246) and
not the second straight
leg (248).
When the pin (223) is in abutment with the slot shoulder (252), preferably a
shear pin (not shown) is passed through the wall (206) of the tubular member
(200) of the
fishing neck portion (192) for insertion through a pin hole (not shown) in the
elongated
member (234). Thus, the shear pin is preferably provided to minimize the
possible
disconnection of the elongated member (234) from the fishing neck portion (
192) or movement
59
CA 02506348 2005-05-04
of the pin (223) out of engagement with the slot shoulder (252) while placing
the guide (24) in
the primary borehole. The guide (24) is then inserted through the primary
borehole and within
the primary conduit (28) using the pipe string or tubular string connected
with the upper end
(236) of the elongated member (234) of the third running and retrieval tool (
113).
More particularly, the guide (24) is passed through the primary borehole until
the
lower end (90) of the guide housing (86), defined by the base plate (96),
contacts or abuts the
upper end (44) of the lateral conduit (30). Upon contact, the shear pin as
described above may
shear. The guide (24) is then permitted to rest upon the lateral conduit (30)
so that the pipe
string weight decreases. The pipe string is then rotated, preferably to the
right or clockwise, in
order to rotate the guide (24) downhole. Rotation continues until the rotation
torque increases
and / or the pipe string weight increases, indicating that the lateral conduit
(30) has been
aligned with the C-shaped recess (98) of the guide housing (86). The guide
(24) is then further
lowered by the pipe string and the lateral conduit (30) is inserted within the
C-shaped recess
(98) of the guide housing (86) until the upper end (44) of the lateral conduit
(30) contacts the
stop collar ( 100).
Once the upper end (44) of the lateral conduit (30) contacts the stop collar (
100),
a further downward force, or force in a downhole direction, may be applied
through the
elongated member (234) of the third running and retrieval tool ( 113). This
further downward
force causes the shearing of the shear pin within the pin hole of the
elongated member (234),
thus permitting movement of the pins (223) within the V-shaped slot (242).
To remove the third running and retrieval tool (113) while leaving the guide
(24)
within the primary conduit (28), a further downward or downhole force is
applied through the
elongated member (234) to cause each of the pins (223) to move in a upwards or
uphole
direction within the second straight leg (248) of its respective V-shaped slot
(242) away from
the slot shoulder (252) towards the upper end (250) of the slot (242). Once
the pin (223) abuts
the upper end (250) of the slot (242), the elongated member (234) of the third
running and
retrieval tool ( I I 3) is then turned or rotated, preferably to the left or
in a counter-clockwise
direction relative to the wall (206), until further movement is prevented.
This rotation moves
the pin (223) to align it with the first spiral leg (246) of the V-shaped slot
(242). An upward or
uphole force is then applied through the elongated member (234) to cause each
of the pins
(223) to move in a downwards or in a downward direction through the length of
the first spiral
CA 02506348 2005-05-04
leg (246) until the pin (223) exits the slot (242) at the lower end (238) of
the elongated member
(234). During this upward movement of the elongated member (234), rotation or
turning of the
pipe string connected with the third running and retrieval tool ( 113) or the
guide (24) confirms
that the pin (223) is in the first spiral leg (246). The third running and
retrieval tool (113) may
then be removed to the surface to permit the insertion of downhole tools or
equipment through
the primary borehole.
If required or desired to use the third running and retrieval tool ( 113) to
remove
the guide (24) from the junction assembly (20), the operation as described
above is repeated.
The third running and retrieval tool (113) is connected with the pipe string
and passed through
the primary borehole to the guide (24) until lower end (238) of the elongated
member (234)
enters the upper end (202) of the fishing neck portion ( 192). Upon further
downward
movement, the pins (223) of the fishing neck portion (192) contact or abut the
lower end (238)
of the elongated member (234). The third running and retrieval tool (113) is
then rotated,
preferably to the right or clockwise, until the pins (223) are aligned with
the V-shaped slots
(242). When the pins (223) and slots (242) are aligned, further rotation may
be inhibited or the
pipe string weight or torque may increase, signaling the alignment to the
operator. The pins
(223) of the fishing neck portion (192) are then passed through the first
spiral legs (246) of the
V-shaped slots (242) by moving the elongated member (234) in a downward or
downhole
direction. Spiral movement of the pipe string should be noted at the surface
as the pins (223)
pass through the spiral legs (246). The elongated member (234) is then rotated
to the right to
align the pins (232) with the second straight legs (248). Finally, the
elongated member (232) is
moved upward or in an uphole direction to pass or move the pins (223) through
the second
straight legs (248) for abutment against the slot shoulders (252). No spiral
movement or
rotation should be evident during this upward movement of the elongated member
(234). The
gmide (24) may then be removed to the surface by further upward or uphole
movement of the
third running and retrieval tool ( 113), which will result in shearing of the
shear pins ( 191 ) to
permit shearing of the latch (104) from within the guide housing (86).
Rotation of the pipe string and the attached second or third running and
retrieval
tool ( 113) within the casing string during placement and removal of the guide
(24) are not
desirable. Further, it is preferable that the casing string be held at the
surface in an unlocked
position permitting rotation of the casing string within the borehole during
placement and
removal of the guide (24). Finally, if necessary, fluids may be pumped through
the fishing
61
CA 02506348 2005-05-04
neck portion ( 192) and the guide (24) during the removal process in order to
flush any debris,
such as drilling cuttings, from the J-shaped slots (214) or pins (223) and
thereby facilitate the
engagement with the running and retrieval tool ( 111, 113).
In the second preferred embodiment of the removable guide (24), either the
second or third running and retrieval tool (l 1 l, 113) may be used for
placement of the guide
(24). However, the third running and retrieval tool (113) is preferably used
to remove the guide
(24), while the second running and retrieval tool (111) is used only as a back-
up in the event of
failure of the third running and retrieval tool (113). The third running and
retrieval tool (1 13)
is preferred due to the configuration of the V-slot (242), including the
spiral and straight legs
(246, 248), which provides a visual cue or indication to the operator, through
rotation of the
pipe string at the surface, of the status of the tool (113) within the fishing
neck portion (192)
downhole.
As described previously, and referring to Figure 26, the within invention is
also
directed at a method for providing a junction in a borehole, preferably
between the primary
borehole and an existing or intended lateral borehole. First, the upper end
(32) of the primary
conduit (28) is connected with an upper pipe string or upper portion of a
casing string (40).
The lower end (34) of the primary conduit (28) may also be connected with a
lower pipe string
or a lower portion of the casing string (40). The casing string (40) and the
junction assembly
(20) connected with the casing string (40) are then positioned at a desired
depth in the primary
borehole by lowering the upper portion of the casing string (40) from the
surface to a desired
depth. The desired depth is either adjacent a lateral borehole already formed
or drilled in the
formation or adjacent the location of a lateral borehole to be drilled from
the primary borehole.
Once at the desired depth, the orienting device (22) is inserted in the upper
portion of the casing string (40) and lowered through the casing string (40)
until the orienting
device (22) selectively engages the junction assembly (20). The method is then
comprised of
obtaining an indication of an orientation of the orienting device (22). The
junction assembly
(20) and the casing string (40) are then rotated in the primary borehole in
order to obtain a
desired orientation of the junction assembly (20), and particularly a desired
orientation of the
junction opening (42) relative to a desired direction of the lateral borehole.
Further, once in the
desired orientation, the position of the junction assembly (20) within the
primary borehole is
preferably maintained to maintain the desired orientation of the junction
assembly (20) in the
62
CA 02506348 2005-05-04
primary borehole during subsequent operations. For instance, the desired
orientation is
maintained while introducing a bonding agent into the primary borehole through
the orienting
device (22). Specifically, the orienting device (22) permits the conducting of
a eementitious
slurry therethrough in order to case or cement the primary borehole in the
annulus between the
wall of the primary borehole and the junction assembly (20) and attached
casing string. The
orienting device (22) is then removed from the junction assembly (20) and the
casing string
(40) to the surface.
The guide (24) is then inserted in the upper portion of the casing string
(40),
preferably by a running and retrieval tool, and lowered downhole such that the
guide (24)
selectively engages the junction assembly (20). An object is then inserted in
the casing string
(40) and lowered to the junction assembly (20) such that the object is guided
into the lateral
conduit (30) by the guide (24). For instance, where drilling of a lateral
borehole is required or
desired, the object may be comprised of a drilling tool. The drilling tool is
inserted through the
upper end (32) of the primary conduit (28) for direction into the upper end
(44) of the lateral
conduit (30) such that the drilling tool extends through the junction opening
(42) in the primary
conduit wall (38) for drilling the lateral borehole. Where completion of a
lateral borehole is
required or desired, the object may be comprised of a liner for lining the
lateral borehole.
Finally, the method may be comprised of the step of removing the guide (24)
from the junction assembly (20) and the casing string (40), preferably by
using the running and
retrieval tool. In the preferred embodiment, the guide removal step is
comprised of shearing a
shearing mechanism associated with the junction assembly (20).
In order to provide a Level 6 junction, a lateral production tubing or
production
string (194) is preferably hung from the upper end (44) of the lateral conduit
(30), using a liner
hanger or packer, for extension within the lateral borehole. Specifically, the
lateral production
string (194) is preferably hung within or from the upper portion (52) or no
build section of the
lateral conduit (30). Further, the lateral production string (194) is
preferably sized to be
compatible with the lateral conduit (30) and is preferably slotted or
perforated at the surface for
placement in the lateral borehole. In order to seal the junction between the
primary and lateral
boreholes, the hanger for the lateral production string (194) is preferably
adapted for sealing the
lateral production string ( 194) with the lateral conduit (30).
63
CA 02506348 2005-05-04
Preferably, the lateral production string (194) ends or terminates at the
upper
end (44) of the lateral conduit (30) and does not extend to the surface. Thus,
fluids from the
lateral borehole may flow or pass within the lateral production string ( 194)
for communication
tlwough the lateral conduit (30) into the primary conduit (28) and thus the
primary borehole.
S Within the primary borehole, any gases are permitted to separate from the
liquids and rise
within the primary borehole to the surface. The gases may then be vented or
collected from the
primary borehole at the surface. Any liquids from the lateral borehole passing
out of the lateral
production string ( 194) are permitted to fall within the primary borehole to
the bottom of the
primary borehole.
A primary production tubing or string ( 196) preferably extends from the
surface
through the primary conduit (28) to a downhole pump ( 198) positioned at the
bottom of the
primary borehole. Liquids within the primary borehole, including those liquids
separating from
the fluids passing out of the lateral production string ( 194), are pumped
from the primary
1 S borehole to the surface by the downhole pump ( 198). Thus, when producing
the well, only a
single production tubing, being the primary production string ( 196) requiring
a single downhole
pump, extends to the surface.
However, where desired, the lateral production string (194) can extend from
the
lateral conduit (30) to the surface so that fluids from the lateral borehole
and the primary
borehole may be produced to the surface separately through the lateral
production string ( 194)
and the primary production string ( 196) respectively.
The specific configuration of the junction assembly (20) and the system of the
2S within invention provides a number of advantageous features.
First, as discussed above, the lateral production string (194) need not be run
to
the surface. Rather, the lateral production string ( 194) may terminate at the
lateral conduit (30)
within the junction assembly (20). The junction assembly (20) may thus be used
to control the
i0 pressure within the lateral borehole rather than controlling the pressure
within the lateral
borehole at the surface via a lateral production string extending to the
surface. Further, the
sealing of the junction within the junction assembly (20) inhibits or prevents
any leakage from
the lateral borehole into the primary borehole other than through the lateral
conduit (30)of the
64
CA 02506348 2005-05-04
junction assembly (20). As a result, where necessary, the lateral borehole may
be sealed off
from the primary borehole by insertion of a plug within the lateral conduit
(30).
Second, in a conventional lateral well, a pump is typically located within the
lateral production string for pumping fluids from the lateral borehole
directly to the surface
through the lateral production string. In this instance, the downhole pump in
the lateral
borehole is directly in contact with the fluids as they are produced.
Accordingly, the pumps
contact the downhole gases in the production fluids and the gases are pumped
to the surface
along with the liquids in the productions fluids. The pump may cavitate due to
the presence of
the gases, resulting in the pumping of less liquids. Further, as the gases are
pumped to the
surface, the gases may need to be separated from the liquids at the surface
before the liquids
can be transferred.
However, using the junction assembly (20), a pump need not be placed within
the lateral production string (194) in the lateral borehole. The production
fluids from the lateral
borehole are permitted to flow freely into the primary borehole through the
junction assembly
(20). As the fluids enter the primary borehole, the gases start to separate
from the liquids and
rise to the surface. Liquids fall to the bottom of the primary borehole where
they are pumped to
the surface by a pump through the primary production string ( 196). Thus, the
pump is
primarily pumping liquids from the primary borehole, decreasing the likelihood
of cavitation.
Since there is a decreased likelihood of pump cavitation, the pump may be able
to deliver
higher pumping rates of produced liquids. Further, there is a likelihood that
less gas separation
may be required at the surface.
Third, the junction assembly (20) incorporates a preset kickoff angle in the
lateral conduit (30). As the angle is preset and formed in the lateral conduit
(30), a relatively
high kickoff angle may be provided. As indicated above, up to a I S degree
angle can be
achieved relatively safely over a 20 foot distance. This may allow the
remaining build angle to
be safer and also allow the drill to achieve a relatively shallower lateral
borehole.
Fourth, the orienting device (22) allows the junction assembly (20) to be
oriented in the primary borehole while cementing is taking place. The
cementing may be
conducted through the orienting device (22) at the same time that the
orienting device (22)
maintains the junction assembly (20) in the desired orientation. Further, the
orienting device
CA 02506348 2005-05-04
(22) permits a limited amount of upward and downward motion during cementing
while
maintaining the orientation.
Fifth, the guide (24) is configured such that the guide (24) may be oriented
without the need for any separate orienting or directional equipment. Once the
junction
assembly (20) is cemented in place, the guide (24) mechanically locks into
place within the
junction assembly (20) and guides the drill bit or other downhole tools or
equipment into the
lateral production string (194) hung from the lateral conduit (30). The guide
(24) only permits
passage into the lateral borehole.
Sixth, use of the junction assembly (20) may be relatively more economical. No
milling of steel may be required to drill the lateral borehole. Further, only
one downhole pump
and production string to the surface is required. As well, gas separation
costs at the surface
may be lessened.
While the present invention has been described for what are presently
considered
the preferred embodiments, the invention is not so limited. To the contrary,
the invention is
intended to cover various modifications and equivalent arrangements included
within the spirit
and scope of the appended claims. The scope of the following claims is to be
accorded the
broadest interpretation so as to encompass all such modifications and
equivalent structures and
functions.
66
