Information
-
Patent Grant
-
6241021
-
Patent Number
6,241,021
-
Date Filed
Friday, July 9, 199925 years ago
-
Date Issued
Tuesday, June 5, 200123 years ago
-
Inventors
-
Original Assignees
-
Examiners
- Bagnell; David
- Dougherty; Jennifer R.
Agents
- Imwalle; William M.
- Smith; Marlin R.
-
CPC
-
US Classifications
Field of Search
US
- 166 50
- 166 1176
- 166 313
- 166 380
- 166 2411
-
International Classifications
-
Abstract
A method of completing an uncemented wellbore junction provides a well completion in which a tubular assembly is installed through a wellbore junction and then is left uncemented in the junction. Fluid communication is permitted between the interior of the assembly and a formation surrounding the junction after the completion. The method is especially useful in situations in which the formation surrounding the junction is relatively impermeable or is in a production zone, and the method additionally permits convenient access to a lower portion of a main wellbore for stimulation or abandonment purposes after the completion.
Description
BACKGROUND OF THE INVENTION
The present invention relates generally to subterranean well completions and, in an embodiment described herein, more particularly provides a method of completing an uncemented wellbore junction.
When a junction of intersecting wellbores is completed, it is generally considered desirable to isolate the formation surrounding the wellbore junction from one or more tubulars extending through the junction. This is due to the fact that fluids produced or injected through the tubulars should typically not be commingled with fluids from the formation surrounding the junction and/or should not be injected into the formation.
In order to isolate the formation surrounding the junction from the tubulars, various methods and apparatus have been developed. While being well suited for their intended purpose, they often require a large number of trips into the well, are time-consuming and, therefore, quite expensive in operation.
There exist situations in which it may not be necessary to isolate a tubular extending through a wellbore junction from a formation or zone surrounding the junction. For example, where the formation is relatively impermeable, it may be acceptable to permit fluid communication between the tubular and the formation. As another example, the formation may be a producing zone, in which case it may be desirable to permit fluid communication between the tubular and the formation in order to produce fluid from the formation through the tubular.
In those situations in which it is not necessary to isolate a tubular extending through a wellbore junction from a formation or zone surrounding the junction, the completion may be greatly simplified by eliminating procedures for providing such isolation, such as cementing the tubular within the junction. Additionally, such a simplified completion may also permit cost savings to be realized when the time comes to abandon the well.
SUMMARY OF THE INVENTION
In carrying out the principles of the present invention, in accordance with an embodiment thereof, a method is provided for completing an uncemented wellbore junction.
In broad terms, the method includes the steps of installing a tubular assembly through a wellbore junction and then sealingly engaging each opposite end of the assembly within a respective one of the intersecting wellbores. The sealing engagement of the assembly within the wellbores is accomplished without cementing the assembly within the junction. In this manner, fluid communication is permitted between the assembly and a formation surrounding the junction.
In one aspect of the invention, the tubular assembly is conveyed through a main wellbore and a lower end of the assembly is inserted into a branch wellbore intersecting the main wellbore while the upper end of the assembly remains in the main wellbore. The assembly, thus, extends across the main wellbore. In order to provide fluid communication between the main wellbore above and below the assembly, at least one opening is provided through a sidewall of the assembly.
In another aspect of the invention, a whipstock assembly may be utilized in drilling the branch wellbore and/or in deflecting the tubular assembly into the branch wellbore from the main wellbore. A fluid passage may be opened or formed through the whipstock assembly to facilitate fluid communication through the main wellbore. This may be accomplished before or after the tubular assembly is installed in the junction.
In yet another aspect of the invention, a fluid passage may be formed through the whipstock assembly at the same time one or more openings are provided through the assembly sidewall. For example, a perforating gun may be conveyed into the assembly and fired, thereby perforating the assembly and an upper closure plate of the whipstock at the same time. Alternatively, the whipstock assembly may be provided with a plug which is retrieved prior to installing the tubular assembly. As further alternatives, the whipstock may be provided with an inner core which is drilled through prior to installing the tubular assembly, which is dispersed prior to installing the tubular assembly, or which is dissolved after installing the tubular assembly.
In still another aspect of the invention, the tubular assembly may include a screen or a perforated liner. The screen or perforated liner may be positioned adjacent the wellbore junction when the tubular assembly is installed in the well. In this manner, fluid communication is provided through the assembly sidewall without requiring a separate operation to form openings therethrough.
These and other features, advantages, benefits and objects of the present invention will become apparent to one of ordinary skill in the art upon careful consideration of the detailed description of a representative embodiment of the invention hereinbelow and the accompanying drawings.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1
is a schematic partially cross-sectional view of a well wherein initial steps in a first method embodying principles of the present invention have been performed;
FIG. 2
is a schematic partially cross-sectional view of the well wherein further steps in the first method have been performed;
FIG. 3
is a schematic partially cross-sectional view of a second method embodying principles of the present invention;
FIG. 4
is a schematic partially cross-sectional view of a third method embodying principles of the present invention;
FIG. 5
is a schematic partially cross-sectional view of the well wherein further steps in the first method have been performed; and
FIG. 6
is a schematic partially cross-sectional view of a whipstock which may be used in the methods of
FIGS. 1-5
, and a method of providing a flow passage therethrough.
DETAILED DESCRIPTION
Representatively and schematically illustrated in
FIG. 1
is a method
10
of completing a subterranean well which embodies principles of the present invention. In the following description of the method
10
and other apparatus and methods described herein, directional terms, such as “above”, “below”, “upper”, “lower”, etc., are used for convenience in referring to the accompanying drawings. Additionally, it is to be understood that the various embodiments of the present invention described herein may be utilized in various orientations, such as inclined, inverted, horizontal, vertical, etc., without departing from the principles of the present invention.
As depicted in
FIG. 1
, initial steps of the method
10
have already been performed. A main or parent wellbore
12
has been drilled and lined with protective casing
14
and cement
16
. Note that the reference number “
12
” indicates the inner diameter of the casing
14
, since the wellbore is cased. If the wellbore
12
were uncased, the term “wellbore” would more properly refer to the uncased bore of the well. It is to be clearly understood that it is not necessary in the method
10
, or any of the other methods and alternatives thereof described herein for any of the wellbores to be cased.
A branch or lateral wellbore
18
has been drilled extending outwardly from the main wellbore
12
. Such drilling of the lateral wellbore
18
may be accomplished using any conventional practices. In the method
10
as representatively illustrated in
FIG. 1
, a whipstock assembly
20
has been positioned in the wellbore
12
with an upper inclined surface
22
of a whipstock
24
oriented toward a desired location for forming the branch wellbore
18
. One or more cutting tools, such as mills, drill bits, etc. (not shown) have been deflected off of the surface
22
to form an opening or window
26
through the casing
14
, and to drill the branch wellbore
18
.
The whipstock assembly
20
as depicted in
FIG. 1
includes the whipstock
24
, a packer
28
and a plug
30
. The packer
28
anchors the assembly
20
in the wellbore
12
, seals against the casing
14
to prevent debris, etc. from accumulating during the milling and drilling operations described above, and provides fluid isolation. Note that other means may be used for anchoring the whipstock
24
, without departing from the principles of the present invention. The plug
30
similarly provides fluid isolation since, in the representatively illustrated embodiment shown in
FIG. 1
, the whipstock
24
is hollow.
The main wellbore
12
below the whipstock assembly
20
may have been completed prior to installing the assembly in the well. The plug
30
and packer
28
prevent fluid communication with any completed zone therebelow for well control purposes, prevention of fluid loss, prevention of damage to any completed zone or zones, etc. However, after the branch wellbore
18
is drilled, the plug
30
may be retrieved from the whipstock assembly
20
to thereby open a flow passage
32
through the assembly.
Referring additionally now to
FIG. 2
, further steps in the method
10
are representatively and schematically illustrated. A liner, casing or other tubular member
34
is installed in the branch wellbore
18
by conveying it through the main wellbore
12
and deflecting it off of the surface
22
and into the branch wellbore. The liner
34
is sealingly engaged with the wellbore
18
using an external casing packer or other sealing device
36
. The liner
34
is then cemented within the wellbore
18
.
An upper polished bore receptacle (PBR)
38
is attached to the liner
34
and packer
36
assembly. Another tubular assembly
40
is conveyed through the main wellbore
12
and a lower end
42
thereof inserted into the branch wellbore
18
. The lower end
42
carries seals
44
externally thereon, which are sealingly engaged with the PBR
38
. In this manner, the lower end
42
of the assembly
40
is sealingly engaged within the branch wellbore
18
. An upper end
46
of the assembly
40
remains in the main wellbore
12
and is sealingly engaged therein by setting a packer or hanger
48
of the assembly in the main wellbore.
It may now be clearly seen that the tubular assembly
40
extends through a junction
50
of the intersecting wellbores
12
,
18
and is sealingly engaged within each of the wellbores. Fluid from a formation or zone (not shown) intersected by the branch wellbore
18
may now be produced through the liner
34
and the tubular assembly
40
. However, at this point fluid communication is not permitted between the interior of the tubular assembly
40
and the main wellbore
12
below the whipstock assembly
20
.
To provide such fluid communication, one or more openings
52
may be formed through a sidewall of the assembly
40
adjacent the junction
50
. For example, a perforating gun
54
may be conveyed into the assembly
40
and fired to form the openings
52
. However, it is to be clearly understood that any other method for forming an opening through the assembly
40
may be utilized without departing from the principles of the present invention. For example, a chemical cutter, torch, mechanical piercing tool, etc. may be used to form the openings
52
.
Note that the whipstock
24
as depicted in
FIG. 2
has an alternate form compared to that shown in FIG.
1
. The whipstock
24
shown in
FIG. 2
has an upper closure plate
56
which initially prevents fluid communication through the whipstock. However, when the perforating gun
54
, or other device, forms the openings
52
through the assembly
40
, openings
58
are also formed through the closure plate
56
, thereby providing a flow passage through the whipstock
24
. In this manner, a separate trip to retrieve the plug
30
from the whipstock assembly
20
is not required, the plug not being used at all in the whipstock assembly as depicted in FIG.
2
.
It will now be readily appreciated by one skilled in the art that fluid communication is now permitted between the main wellbore
12
above the assembly
40
and each of the branch wellbore
18
below the assembly
40
and the main wellbore
12
below the whipstock assembly
20
through the assembly
40
. Fluid communication is also provided between the interior of the assembly
40
and a formation or zone
60
surrounding the junction
50
. The formation
60
may be relatively impermeable, in which case little if any actual fluid flow is experienced between the formation
60
and the wellbores
12
,
18
, or fluid may be produced from, or injected into, the formation in the method
10
if desired. Note that no cement is deposited between the assembly
40
and the wellbores
12
,
18
within the junction
50
.
Referring additionally now to
FIG. 3
, another method
70
of completing a subterranean well is representatively and schematically illustrated. The method
70
is similar in many respects to the method
10
described above and the same reference numbers are used to indicated elements similar to those described previously.
The method
70
differs in one respect from the method
10
in that the whipstock
24
has an alternate construction. The whipstock
24
as shown in
FIG. 3
has a relatively easily drillable or millable inner core
72
. The inner core
72
is relatively easily drillable as compared to the remainder of the whipstock
24
(i.e., the outer case thereof), for example, due to its being made of a softer material. The inner core
72
does, however, prevent fluid communication through a flow passage
74
of the whipstock
24
, until the inner core is drilled through.
The inner core
72
is shown in dashed lines to indicate that it has already been drilled through as the method
70
is depicted in FIG.
3
. Thus, the inner core
72
is drilled through prior to installing a tubular assembly
76
in the wellbores
12
,
18
. Note that, when the tubular assembly
76
is installed, it is conveyed through the main wellbore
12
and deflected into the branch wellbore
18
off of the surface
22
, even though the inner core
72
is drilled through.
Alternatively, the inner core
72
could be drilled through after the tubular assembly
76
is installed in the wellbores
12
,
18
by drilling or milling through a sidewall of the assembly and continuing to cut through the inner core. However, as depicted in
FIG. 3
, openings
52
have been formed through the assembly
76
as described above for the method
10
, i.e., by use of a perforating gun, torch, chemical cutter, etc.
The method
70
differs from the method
10
in another respect in that the assembly
76
may be installed in one trip into the well, instead of two trips to install the liner
34
and assembly
40
as described above. The assembly
76
is sealingly engaged within the wellbore
18
using the external casing packer or other sealing device
36
. The assembly
76
is then cemented within the wellbore
18
below the packer
36
. An upper end
78
of the assembly
76
remains in the main wellbore
12
and is sealingly engaged therein by setting the packer or hanger
48
of the assembly in the main wellbore. It is to be clearly understood, however, that it is not necessary in a method incorporating principles of the present invention for the packer
36
to be included in the assembly
76
or for the assembly to be cemented within the wellbore
18
.
It may now be clearly seen that the tubular assembly
76
extends through the junction
50
of the intersecting wellbores
12
,
18
and is sealingly engaged within each of the wellbores. Fluid from a formation or zone (not shown) intersected by the branch wellbore
18
may now be produced through the tubular assembly
76
. Fluid communication is also permitted between the interior of the tubular assembly
76
and the main wellbore
12
below the whipstock assembly
20
, and between the interior of the tubular assembly
76
and the formation
60
surrounding the junction
50
.
Note that the whipstock
24
as depicted in
FIG. 3
does not necessarily include the inner core
72
, but could alternatively be configured as shown in
FIG. 1
or FIG.
2
. Thus it is not necessary in the method
70
for the whipstock assembly
20
to be configured as shown in FIG.
3
. Other whipstocks, including alternate whipstocks described herein, and other types of deflection devices may be utilized, without departing from the principles of the present invention.
It will now be readily appreciated by one skilled in the art that fluid communication is now permitted between the main wellbore
12
above the assembly
76
and each of the branch wellbore
18
below the assembly
76
and the main wellbore
12
below the whipstock assembly
20
through the assembly
76
. Fluid communication is also provided between the interior of the assembly
76
and the formation or zone
60
surrounding the junction
50
. The formation
60
may be relatively impermeable, in which case little if any actual fluid flow is experienced between the formation
60
and the wellbores
12
,
18
, or fluid may be produced from, or injected into, the formation in the method
70
if desired. Note that no cement is deposited between the assembly
76
and the wellbores
12
,
18
within the junction
50
.
Referring additionally now to
FIG. 4
, another method
80
of completing a subterranean well is representatively and schematically illustrated. The method
80
is similar in many respects to the methods
10
,
70
described above and the same reference numbers are used to indicated elements similar to those described previously.
The method
80
differs in one respect from the methods
10
,
70
in that the whipstock
24
has an alternate construction. The whipstock
24
as shown in
FIG. 4
has a selectively dissolvable inner core
82
. The inner core
82
is selectively dissolvable in that a particular type of fluid will dissolve the inner core when brought into contact with the inner core. For example, the inner core
82
may be readily dissolvable by acid. The inner core
82
does, however, prevent fluid communication through the flow passage
74
of the whipstock
24
, until the inner core is dissolved.
The inner core
82
is shown in dashed lines to indicate that it has already been dissolved as the method
80
is depicted in FIG.
4
. The inner core
82
may be dissolved prior to, during, or after installing a tubular assembly
84
in the wellbores
12
,
18
. Note that, when the tubular assembly
84
is installed, it is conveyed through the main wellbore
12
and deflected into the branch wellbore
18
off of the surface
22
, even though the inner core
82
may have already been dissolved at the time.
The inner core
82
may be dissolved before installing the assembly
84
by, for example, circulating a fluid, such as acid, through a tubing string, such as a coiled tubing string, positioned adjacent the inner core. The inner core
82
may be dissolved during installation of the assembly
84
by, for example circulating the fluid through the assembly
84
as it is positioned adjacent the inner core. The inner core may be dissolved after installation of the assembly
84
by, for example, circulating the fluid through a screen or perforated liner
86
interconnected in the assembly. Note that, when the assembly
84
is properly installed in the wellbores
12
,
18
, the screen
86
is preferably, but not necessarily, positioned within or adjacent the junction
50
as shown in FIG.
4
.
The method
80
differs from the method
10
in another respect in that the assembly
84
may be installed in one trip into the well, instead of two trips to install the liner
34
and assembly
40
as described above. The assembly
84
is sealingly engaged within the wellbore
18
using the external casing packer or other sealing device
36
. The assembly
84
is then cemented within the wellbore
18
below the packer
36
. An upper end
88
of the assembly
84
remains in the main wellbore
12
and is sealingly engaged therein by setting the packer or hanger
48
of the assembly in the main wellbore. It is to be clearly understood, however, that it is not necessary in a method incorporating principles of the present invention for the packer
36
to be included in the assembly
84
or for the assembly to be cemented within the wellbore
18
.
It may now be clearly seen that the tubular assembly
84
extends through the junction
50
of the intersecting wellbores
12
,
18
and is sealingly engaged within each of the wellbores. Fluid from a formation or zone (not shown) intersected by the branch wellbore
18
may now be produced through the tubular assembly
84
. Fluid communication is also permitted between the interior of the tubular assembly
84
and the main wellbore
12
below the whipstock assembly
20
, and between the interior of the tubular assembly
84
and the formation
60
surrounding the junction
50
.
Note that the whipstock
24
as depicted in
FIG. 4
does not necessarily include the inner core
82
, but could alternatively be configured as shown in
FIG. 1
,
FIG. 2
or FIG.
3
. Thus it is not necessary in the method
80
for the whipstock assembly
20
to be configured as shown in FIG.
4
. Other whipstocks, including alternate whipstocks described herein, and other types of deflection devices may be utilized, without departing from the principles of the present invention.
It will be readily appreciated by one skilled in the art that fluid communication is now permitted between the main wellbore
12
above the assembly
84
and each of the branch wellbore
18
below the assembly
84
and the main wellbore
12
below the whipstock assembly
20
through the assembly
84
. Fluid communication is also provided between the interior of the assembly
84
and the formation or zone
60
surrounding the junction
50
. The formation
60
may be relatively impermeable, in which case little if any actual fluid flow is experienced between the formation
60
and the wellbores
12
,
18
, or fluid may be produced from, or injected into, the formation in the method
80
if desired. Note that no cement is deposited between the assembly
84
and the wellbores
12
,
18
within the junction
50
.
It will also be readily appreciated that the above methods
10
,
70
,
80
facilitate convenient abandonment of the well. For example, the tubular assembly
40
,
76
or
84
is not cemented within the junction
50
and is, therefore, much easier to retrieve from the well than if it were cemented therein. To abandon the well in the method
10
, abandonment operations may be performed in the branch wellbore
18
, then the assembly
40
may be cut below the window
26
using conventional techniques, or the assembly
40
may be disengaged from the PBR
38
. The packer
48
may then be released and the assembly
40
retrieved from the well.
The whipstock
24
may be retrieved, if desired for abandonment of the lower main wellbore
12
, using a conventional overshot. The remainder of the whipstock assembly
20
may be retrieved by disengaging the packer
28
from the wellbore
12
. Note that, if the whipstock is hollow, such as the whipstock
24
shown in
FIGS. 1
,
3
&
4
, and the whipstock
90
shown in
FIG. 6
, it may not be necessary to retrieve the whipstock. Note, also, that these retrieval operations may be performed if desired prior to stimulating the well below the whipstock assembly
20
.
Referring additionally now to
FIG. 5
, the method
10
is depicted in somewhat alternate form, utilizing the tubular assembly
76
instead of the tubular assembly
40
. To facilitate abandonment of the well or stimulation operations, access to the main wellbore
12
on each side of the junction
50
is desired. To accomplish this result, the tubular assembly
76
is severed within the branch wellbore
18
, the packer
48
is unset and the upper end
78
of the tubular assembly is retrieved from the well. If the well is to be abandoned, preferably suitable abandonment operations are performed in the branch wellbore
18
prior to severing the tubular assembly
76
and retrieving the upper end
78
of the tubular assembly from the well. The tubular assembly
76
may be severed by any known method, such as, by chemical cutter, mechanical cutter, explosive cutter, etc. Additionally, if the tubular assembly
40
is used in the method in place of the tubular assembly
76
, the lower end
42
and seals
44
thereof may be disengaged from the PBR
38
, with no need to cut the tubular assembly
40
. A portion of the tubular assembly
76
is shown in
FIG. 5
in dashed lines to indicate that it has been retrieved from the well.
If the whipstock
24
is provided with a flow passage therethrough, as described above, it may not be necessary to retrieve the whipstock in order to perform abandonment or stimulation operations in the main wellbore
12
below the whipstock. However, if it is desired to retrieve the whipstock
24
, an overshot may be used as described above, or another type of retrieval tool may be used to disengage the whipstock from the packer
28
. Alternatively, the whipstock
24
and packer
28
could be retrieved together from the well by unsetting the packer. The whipstock
24
is shown in dashed lines in
FIG. 5
to indicate that it has been retrieved from the well.
It will be readily appreciated that, with the upper portion of the tubular assembly
76
and the whipstock
24
retrieved from the well, access is now provided to the main wellbore
12
below the junction
50
for stimulation or abandonment operations therein. Note that the whipstock
24
and the upper portion of the tubular assembly
76
may be reinstalled in the well if desired. If the tubular assembly
40
is used in the method
10
, then reinstallation of the tubular assembly is made more convenient due to the presence of the PBR
38
in the branch wellbore
18
.
Referring additionally now to
FIG. 6
, an alternate whipstock
90
embodying principles of the present invention is representatively and schematically illustrated. The whipstock
90
may be used in place of the whipstock
24
in any of the methods
10
,
70
,
80
described above.
The whipstock
90
has a plug
92
positioned in the flow passage
74
blocking fluid flow therethrough. The plug
92
is preferably dispersible upon contact with fluid in the well. For example, the plug
92
may be made of a compressed salt and sand mixture which is capable of resisting a pressure differential applied thereacross, but which is structurally compromised when placed in contact with fluid in the well. An example of such a dispersible plug structure is provided in U.S. Pat. No. 5,479,986, the disclosure of which is incorporated herein by this reference. However, it is to be clearly understood that other dispersible plug structures may be used in the whipstock
90
without departing from the principles of the present invention.
Barrier members
94
isolate the plug
92
from fluid in the well. The barrier members
94
may be made of an elastomeric material, ceramic material, or other type of material. To expose the plug
92
to the fluid in the well, at least one of the barrier members
94
may be pierced or broken, for example, by impacting it with a wireline or slickline conveyed piercing tool
96
. However, many other ways of exposing the plug
92
to fluid in the well may be utilized as well. For example, a port or a fluid conduit may be opened to permit fluid communication with the plug, etc. Thus, it will be readily appreciated that any manner of providing contact between the plug
92
and fluid in the well may be used, without departing from the principles of the present invention.
Of course, a person skilled in the art would, upon consideration of the foregoing detailed description readily appreciate that many additions, substitutions, deletions and other changes may be made to the specific embodiments described above, and these changes are contemplated by the principles of the present invention. Accordingly, the foregoing detailed description is to be clearly understood as being given by way of illustration and example only, the spirit and scope of the present invention being limited solely by the appended claims.
Claims
- 1. A method of completing a subterranean well, the method comprising the steps of:installing a tubular assembly through a wellbore junction of the well at which first and second wellbores intersect, a first opposite end of the assembly extending within the first wellbore, and a second opposite end of the assembly extending within the second wellbore; sealingly engaging each of the first and second opposite ends of the assembly with respective ones of the first and second wellbores, without cementing the assembly within the junction; and permitting fluid communication between the interior of the tubular assembly and a formation surrounding the wellbore junction while the first and second opposite ends of the tubular assembly are respectively and sealingly engaged within the first and second wellbores.
- 2. The method according to claim 1, wherein the sealingly engaging step further comprises engaging the second opposite end with a polished bore receptacle within the second wellbore.
- 3. The method according to claim 2, further comprising the step of installing the polished bore receptacle in the second wellbore attached to a tubular member.
- 4. The method according to claim 3, further comprising the step of cementing the tubular member within the second wellbore.
- 5. The method according to claim 1, further comprising the step of forming at least one opening through the tubular assembly proximate the wellbore junction.
- 6. The method according to claim 5, wherein the forming step is performed by perforating the assembly after the installing step.
- 7. The method according to claim 5, wherein the forming step further comprises forming a fluid passage through a whipstock.
- 8. The method according to claim 7, wherein the step of forming the fluid passage through the whipstock further comprises piercing an upper closure plate of the whipstock.
- 9. The method according to claim 1, wherein the sealingly engaging step further comprises setting a packer attached to the assembly in the second wellbore.
- 10. The method according to claim 1, wherein the sealingly engaging step further comprises cementing the assembly within the second wellbore.
- 11. The method according to claim 1, further comprising the step of providing a fluid passage through a whipstock positioned in the first wellbore adjacent the wellbore junction.
- 12. The method according to claim 11, wherein the providing step comprises cutting through an inner core of the whipstock.
- 13. The method according to claim 12, wherein the cutting step is performed prior to the installing step.
- 14. The method according to claim 11, wherein the providing step is performed by dissolving an inner core of the whipstock.
- 15. The method according to claim 14, wherein the dissolving step is performed prior to the installing step.
- 16. The method according to claim 14, wherein the dissolving step is performed after the installing step.
- 17. The method according to claim 14, wherein the dissolving step is performed by circulating a fluid through the assembly.
- 18. The method according to claim 14, wherein the dissolving step is performed by contacting the inner core with an acidic fluid.
- 19. The method according to claim 1, further comprising the step of opening a fluid passage through a whipstock positioned adjacent the wellbore junction.
- 20. The method according to claim 19, wherein the opening step is performed by retrieving a plug blocking fluid flow through the passage.
- 21. The method according to claim 19, wherein the opening step is performed by dispersing a plug structure blocking fluid flow through the passage.
- 22. The method according to claim 21, wherein the dispersing step is performed by providing contact between the plug structure and fluid in the well.
- 23. The method according to claim 22, wherein the providing step is performed by piercing a barrier member isolating the plug structure from contact with the fluid.
- 24. The method according to claim 21, further comprising the step of constructing the plug structure of a mixture of sand and salt.
- 25. The method according to claim 1, wherein the installing step further comprises positioning a screen portion of the assembly within the wellbore junction.
- 26. The method according to claim 25, further comprising the step of dissolving an inner core of a whipstock positioned adjacent the wellbore junction by circulating a fluid through the screen portion.
- 27. A method of completing a subterranean well, the method comprising the steps of:sealingly engaging first and second opposite ends of a tubular assembly within respective ones of first and second wellbores intersecting at a wellbore junction of the well; and permitting fluid communication between the interior of the tubular assembly and a formation surrounding the wellbore junction while the first and second opposite ends of the tubular assembly are respectively and sealingly engaged within the first and second wellbores.
- 28. The method according to claim 27, wherein the permitting step is performed by providing at least one opening through the assembly proximate the wellbore junction.
- 29. The method according to claim 27, wherein the permitting step is performed by providing an absence of cement between the assembly and each of the first and second wellbores in the wellbore junction.
- 30. The method according to claim 27, wherein the sealingly engaging step further comprises engaging the second opposite end with a polished bore receptacle within the second wellbore.
- 31. The method according to claim 30, further comprising the step of providing access to the first wellbore on each side of the wellbore junction by releasing an anchoring device releasably securing the first opposite end of the tubular assembly in the first wellbore, and disengaging the tubular assembly from the polished bore receptacle.
- 32. The method according to claim 30, further comprising the step of installing the polished bore receptacle in the second wellbore attached to a tubular member.
- 33. The method according to claim 32, further comprising the step of cementing the tubular member within the second wellbore.
- 34. The method according to claim 27, wherein the permitting step further comprises forming at least one opening through the tubular assembly proximate the wellbore junction.
- 35. The method according to claim 34, wherein the forming step is performed by perforating the assembly after the sealingly engaging step.
- 36. The method according to claim 34, wherein the forming step further comprises forming a fluid passage through a whipstock.
- 37. The method according to claim 36, wherein the step of forming the fluid passage through the whipstock further comprises piercing an upper closure plate of the whipstock.
- 38. The method according to claim 37, further comprising the step of providing access to the first wellbore on each side of the wellbore junction by retrieving from the first wellbore at least a portion of the tubular assembly extending across the first wellbore, releasing the whipstock from an anchoring device anchoring the whipstock in the first wellbore, and retrieving the whipstock from the first wellbore.
- 39. The method according to claim 27, wherein the sealingly engaging step further comprises setting a packer attached to the assembly in the second wellbore.
- 40. The method according to claim 27, wherein the sealingly engaging step further comprises cementing the assembly within the second wellbore.
- 41. The method according to claim 27, further comprising the step of providing a fluid passage through a whipstock positioned in the first wellbore adjacent the wellbore junction.
- 42. The method according to claim 41, wherein the providing step comprises cutting through an inner core of the whipstock.
- 43. The method according to claim 42, wherein the cutting step is performed prior to the sealingly engaging step.
- 44. The method according to claim 41, wherein the providing step is performed by dissolving an inner core of the whipstock.
- 45. The method according to claim 44, wherein the dissolving step is performed prior to the sealingly engaging step.
- 46. The method according to claim 44, wherein the dissolving step is performed after the sealingly engaging step.
- 47. The method according to claim 44, wherein the dissolving step is performed by circulating a fluid through the assembly.
- 48. The method according to claim 44, wherein the dissolving step is performed by contacting the inner core with an acidic fluid.
- 49. The method according to claim 27, further comprising the step of opening a fluid passage through a whipstock positioned adjacent the wellbore junction.
- 50. The method according to claim 49, wherein the opening step is performed by retrieving a plug blocking fluid flow through the passage.
- 51. The method according to claim 49, wherein the opening step is performed by dispersing a plug structure blocking fluid flow through the passage.
- 52. The method according to claim 51, wherein the dispersing step is performed by providing contact between the plug structure and fluid in the well.
- 53. The method according to claim 52, wherein the providing step is performed by piercing a barrier member isolating the plug structure from contact with the fluid.
- 54. The method according to claim 51, further comprising the step of constructing the plug structure of a mixture of sand and salt.
- 55. The method according to claim 27, further comprising the step of positioning a screen portion of the assembly within the wellbore junction.
- 56. The method according to claim 55, further comprising the step of dissolving an inner core of a whipstock positioned adjacent the wellbore junction by circulating a fluid through the screen portion.
- 57. The method according to claim 27, further comprising the step of providing access to the first wellbore on each side of the wellbore junction by severing the tubular assembly in the second wellbore, releasing an anchoring device releasably securing the first opposite end of the tubular assembly in the first wellbore, and retrieving the tubular assembly from the first wellbore.
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