U.S. patent application number 14/915730 was filed with the patent office on 2016-07-07 for multilateral wellbore stimulation.
The applicant listed for this patent is HALLIBURTON ENERGY SERVICES, INC.. Invention is credited to Douglas Glenn Durst.
Application Number | 20160194930 14/915730 |
Document ID | / |
Family ID | 53403427 |
Filed Date | 2016-07-07 |
United States Patent
Application |
20160194930 |
Kind Code |
A1 |
Durst; Douglas Glenn |
July 7, 2016 |
MULTILATERAL WELLBORE STIMULATION
Abstract
Systems and methods are provided for positioning an isolation
device within a multilateral well to isolate a live wellbore from
other wellbores in the well system. The isolation device can be
changed from an open position to a closed position substantially
contemporaneously to the wellbore becoming a live wellbore. Another
procedure can be performed on the other wellbore of the
multilateral well while the isolation device is in the closed
position. A tubing string or a short or intermediate completion
string can isolate a wellbore from pressure applied to another
wellbore within the multilateral system. The tubing string or the
short or intermediate completion string may also isolate a junction
area of the multilateral well system.
Inventors: |
Durst; Douglas Glenn;
(Houston, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
HALLIBURTON ENERGY SERVICES, INC. |
Houston |
TX |
US |
|
|
Family ID: |
53403427 |
Appl. No.: |
14/915730 |
Filed: |
December 20, 2013 |
PCT Filed: |
December 20, 2013 |
PCT NO: |
PCT/US2013/076966 |
371 Date: |
March 1, 2016 |
Current U.S.
Class: |
166/386 ;
166/50 |
Current CPC
Class: |
E21B 43/12 20130101;
E21B 33/12 20130101; E21B 41/0035 20130101 |
International
Class: |
E21B 33/12 20060101
E21B033/12 |
Claims
1. A wellbore system comprising: a subsurface isolation device
having an open position and a closed position to temporarily close
off an active lateral wellbore in a multilateral well by isolating
the active lateral wellbore from at least one other wellbore in the
multilateral well.
2. The wellbore system of claim 1, wherein the subsurface isolation
device is positionable within a casing string or a liner string of
the active lateral wellbore.
3. The wellbore system of claim 1, wherein the subsurface isolation
device is positionable within a short or an intermediate completion
string, and wherein the short or the intermediate completion string
is positionable within the active lateral wellbore.
4. The wellbore system of claim 1, wherein the subsurface isolation
device is a plug device that is positionable within a liner string
of the active lateral wellbore.
5. The wellbore system of claim 1, further comprising a wellbore
string that includes a sealing assembly, the wellbore string being
positionable within the wellbore system for isolating the at least
one other wellbore from a pressure applied to the active lateral
wellbore.
6. The wellbore system of claim 5, wherein the wellbore string
includes an extension device for shifting the subsurface isolation
device from the open position to the closed position.
7. The wellbore system of claim 5, wherein the wellbore string
includes a short or an intermediate completion string having a seal
assembly on a first end and an anchor device on a second end.
8. A method, comprising: positioning an isolation device within a
multilateral well; performing a procedure on a wellbore of the
multilateral well to cause the wellbore to be a live wellbore;
substantially contemporaneously to the wellbore becoming the live
wellbore, changing the isolation device from an open position to a
closed position at which the isolation device isolates the wellbore
from at least one other wellbore of the multilateral well; and
performing another procedure on the at least one other wellbore of
the multilateral well while the isolation device is in the closed
position.
9. The method of claim 8, wherein isolating the wellbore from the
at least one other wellbore of the multilateral well comprises
preventing production and pressure from the wellbore from exiting
the wellbore and entering the at least one other wellbore.
10. The method of claim 8, wherein performing the procedure on the
wellbore of the multilateral well to cause the wellbore to be the
live wellbore comprises stimulating the wellbore of the
multilateral well.
11. The method of claim 8, wherein positioning the isolation device
within the multilateral well comprises positioning a plug device
within the multilateral well.
12. The method of claim 8, wherein changing the isolation device
from the open position to the closed position comprises removing a
wellbore string having an extension device from the multilateral
well, the extension device shifting the isolation device from the
open position to the closed position.
13. The method of claim 8, further comprising positioning a
wellbore string having a sealing assembly on an end into the
wellbore for isolating the at least one other wellbore from a
pressure applied to the wellbore while performing the procedure on
the wellbore of the multilateral well to cause the wellbore to be
the live wellbore.
14. The method of claim 13, wherein positioning the wellbore string
having the sealing assembly on the end into the wellbore for
isolating the at least one other wellbore from the pressure applied
to the wellbore while performing the procedure on the wellbore of
the multilateral well comprises positioning a short or an
intermediate completion string that also includes an anchor device
on another end within the wellbore.
15. The method of claim 8, further comprising re-opening the
isolation device and allowing production from the wellbore and the
at least one other wellbore to comingle.
16. A multilateral wellbore system, comprising: a wellbore; at
least one other wellbore; and a subsurface isolation device having
an open position and a closed position to isolate the wellbore from
the at least one other wellbore substantially contemporaneous to
the wellbore becoming a live wellbore.
17. The multilateral wellbore system of claim 16, further
comprising a wellbore string having a sealing assembly on an end
for isolating the at least one other wellbore from a pressure
applied to the wellbore while stimulating the wellbore.
18. The multilateral wellbore system of claim 16, wherein the
subsurface isolation device is positioned within a casing string or
a liner string of the wellbore.
19. The multilateral wellbore system of claim 16, wherein the
subsurface isolation device is positioned within a short or an
intermediate completion string including a sealing assembly on a
first end and an anchor device on a second end and positionable
within the wellbore.
20. The multilateral wellbore system of claim 16, wherein the
subsurface isolation device includes a valve for positioning the
subsurface isolation device in the open position and the closed
position.
Description
TECHNICAL FIELD
[0001] The present disclosure relates generally to methods and
assemblies for the stimulation of multiple lateral wellbores of a
subterranean wellbore in a multilateral well system, and more
particularly (although not necessarily exclusively), to methods and
assemblies for stimulating and isolating one or more wellbores in a
multilateral well system.
BACKGROUND
[0002] A well can be a multilateral well. A multilateral well can
have multiple lateral wellbores that branch off a wellbore. The
wellbore can be drilled vertically, directionally, or at an
inclined angle, and the lateral wellbores can be drilled
horizontally, or otherwise deviated, off the wellbore. Multilateral
wellbores can have an increased productive capacity and higher
recoverable reserves. Once a first lateral wellbore is considered
to be an active or a live wellbore, for example by perforation or
stimulation, the entire well, including the first lateral wellbore
and any other lateral wellbores, can all be considered to be in a
"live well" scenario. To address this scenario, operators can
introduce procedures and well control equipment to stabilize the
first lateral wellbore and other wellbores prior to stimulating any
additional wellbores. For example, the first lateral wellbore can
be overbalanced with heavy weighted muds or fluids. The use of
heavy weighted muds or fluids can damage the stimulated or "live"
first lateral wellbore and can diminish its capacity to produce
desired production at a sufficient or economical rate or require
extensive remediation to improve reservoir performance. In another
example, a hydraulic workover unit or high pressure-snubbing unit
can be used to drill, complete, and stimulate additional lateral
wellbores without overbalancing the first lateral wellbore. These
additional workover units and ancillary surface components can add
to the scale and cost in developing unconventional wells and can be
uneconomical for many markets, such as shale oil and gas, and tight
oil and gas.
BRIEF DESCRIPTION OF THE DRAWINGS
[0003] FIG. 1 is a cross-sectional view of a multilateral well
system with a first isolation device within a liner string of a
wellbore and a second isolation device within a liner string of a
lateral wellbore according to one aspect.
[0004] FIG. 2A is a cross-sectional view of a multilateral well
system with an isolation device within a casing string of a
wellbore and a tubing assembly shown by side view disposed within
the wellbore according to one aspect.
[0005] FIG. 2B is a cross-sectional view of the multilateral well
system of FIG. 2A with the isolation device in the casing string in
a closed position and a tubing assembly shown by side view disposed
within a lateral wellbore according to one aspect.
[0006] FIG. 3A is a cross-sectional view of a multilateral well
system with a first isolation device in a liner string of a
wellbore, a second isolation device in a lateral wellbore, and an
intermediate tubing assembly shown by side view disposed within the
wellbore according to one aspect.
[0007] FIG. 3B is a cross-sectional view of the multilateral well
system of FIG. 3A with the first isolation device in the liner
string in a closed position and a tubing assembly shown by side
view disposed within a lateral wellbore according to one
aspect.
[0008] FIG. 4A is a cross-sectional view of a multilateral well
system with an isolation device within a short or intermediate
completion string shown by side view and a tubing assembly shown by
side view disposed within a wellbore according to one aspect.
[0009] FIG. 4B is a cross-sectional view of the multilateral well
system of FIG. 4A having the isolation device within the short or
intermediate completion string shown by side view in a closed
position and a tubing assembly shown by side view disposed within a
lateral wellbore according to one aspect.
[0010] FIG. 5 is a cross-sectional view of a multilateral well
system with an isolation device within a liner string of a wellbore
and a tubing assembly including an extension device shown by side
view disposed within the wellbore according to one aspect.
[0011] FIG. 6 is a cross-sectional view of a multilateral well
system with a retrievable plug device positioned within a liner
string of a wellbore and a tubing assembly shown by side view
disposed within the wellbore according to one aspect.
DETAILED DESCRIPTION
[0012] Certain aspects and features of the present disclosure
relate to methods and systems for isolating a lateral wellbore from
additional lateral wellbores in a multilateral well system, when
the lateral wellbore is considered to be a live wellbore. The
lateral wellbore can be considered to be a live wellbore after a
procedure, such as stimulation or perforation, is performed on the
wellbore. The live lateral wellbore can be temporarily isolated or
closed off from any additional lateral wellbores by an isolation
device that is in a closed position. Production and pressure from
the live lateral wellbore can remain within the live lateral
wellbore and not enter a main wellbore or other lateral wellbores
when the isolation device is in the closed position. The live
lateral wellbore is isolated from the rest of the multilateral well
system and any associated pressure or producing constituents of the
live lateral wellbore are not in communication with the rest of the
multilateral well system with the isolation device in the closed
position.
[0013] Isolating the live lateral wellbore can allow work to be
performed on the rest of the multilateral well system without the
live lateral wellbore being able to communicate back to the surface
and avoiding an uncontrolled well scenario. For example, additional
lateral wellbores can be safely drilled, completed, and stimulated
with the isolation device in the closed position. The isolation
device can also be in an open position, in which the live lateral
wellbore is accessible and production and pressure from the live
lateral wellbore is not isolated from any additional lateral
wellbores.
[0014] The isolation device can include a closure component that
can move between an open position and a closed position. The
closure component can include a valve, a flapper, a ball, a
chemical pill, or other suitable closure components. The isolation
device can also be a plug device that can be positioned within the
wellbore to isolate or close off the lateral wellbore. The plug
device can be a retrievable plug device that can be temporarily
positioned within the wellbore to isolate a lateral wellbore. The
plug device can be removed from the wellbore to allow access to the
lateral wellbore. In another aspect, the plug device can remain in
the wellbore and can include a closure component such as a valve, a
flapper, a ball, a chemical pill, or other suitable closure
component. The plug device can be positioned within the wellbore by
passing the plug device through a tubing assembly, for example a
completion string.
[0015] The lateral wellbore can be re-accessed at a later time by
re-opening the isolation device or, in another aspect, by removing
the plug device. For example, after a second lateral wellbore is
stimulated, the isolation device can be re-opened, thereby
providing access to the first live lateral wellbore. The production
of the first live lateral wellbore and the production of the second
lateral wellbore can be comingled when the isolation device
positioned in the first lateral wellbore is in the open position.
In another aspect, the second lateral wellbore, and any additional
lateral wellbores, can include additional isolation devices to
isolate additional lateral wellbores selectively. Isolation devices
can allow the first lateral wellbore and any additional lateral
wellbores to be produced individually or collectively by
positioning the isolation devices within each lateral wellbore and
controlling the isolation devices among an open or a closed
position.
[0016] The closure component of the isolation device can be
pivotally mounted and can be displaced between an open and a closed
position by mechanical means. For example, the closure component
can be displaced from the open to the closed position by a wellbore
string being removed from the wellbore, or by a wireline, coil
tubing, or e-line intervention. In another example, the closure
component can be displaced between the open and the closed position
by a hydraulic or pulsation method and by hydraulic communication.
In other examples, the closure component can be displaced between
the open and the closed position by a remote method, including but
not limited to by way of radio frequency identification means, by
wireless telemetry, and by acoustic telemetry. The closure
component of the isolation device can be displaced between the open
position and the closed position multiple times. In an example, the
closure component can be a chemical pill or other suitable
substance that can create a removable barrier. The isolation device
can also or alternatively be a plug device that is retrievable from
within a wellbore. The plug device can be considered in the closed
position when positioned within the wellbore and in the open
position when removed from the wellbore.
[0017] The isolation device can also be positioned in a variety of
locations in a multilateral wellbore. For example, the isolation
device can be positioned in a casing string of the wellbore, in a
short or an intermediate completion string within the wellbore, or
in a liner string of the wellbore. Or the isolation device can be a
self-contained device, for example a plug device, that can be
positioned within and removed from the wellbore.
[0018] Wellbore strings, for example, tubing assemblies, tubing
strings and completion strings, can be run into the wellbore to
perform various procedures on a first lateral wellbore. For
example, a tubing string can be positioned in the wellbore to
stimulate or perforate a first lateral wellbore. The wellbore
string can also isolate at least a portion of a wellbore and any
additional lateral wellbores from a pressure or other downhole
activity applied to the first lateral wellbore during the
procedure. For example, a fracturing string with a seal member or
sealing assembly can be latched or landed into a receptacle within
the wellbore and coupled back to the surface. The sealing assembly
can be any suitable sealing means. The receptacle can be a polish
bore receptacle or other suitable receptacle for receiving a
wellbore string. The fracturing string can be used to stimulate the
first lateral wellbore while the isolation device is in the open
position. The fracturing string can also isolate a portion of a
wellbore and any additional lateral wellbores from a pressure
applied to the first lateral wellbore during stimulation. In
another example, a short or intermediate completion string with a
seal member or sealing assembly and an anchor device, such as a
packer assembly, can be latched or landed into the wellbore. The
first lateral wellbore can be stimulated using a casing string and
the short or intermediate completion string can isolate any
additional lateral wellbores and a portion of the wellbore, such as
a junction between the wellbore and an additional lateral wellbore,
from a pressure or other downhole activity applied to the first
lateral wellbore during stimulation.
[0019] After the first lateral wellbore has been stimulated, the
tubing assembly can be removed and the first lateral wellbore can
be temporarily isolated or closed off by moving the isolation
device into the closed position or by introducing a plug device
into the wellbore. While the first lateral wellbore can then be
considered to be a live wellbore, the isolation device in the
closed position can prevent production or pressure from the first
lateral wellbore from entering other areas of the wellbore,
including any additional lateral wellbores. A diverter device, such
as a whipstock or deflector, can be positioned within the wellbore
and a tubing assembly can be positioned within the wellbore for
stimulating a second lateral wellbore. The tubing assembly can
include a fracturing string or a short or intermediate completion
string, as described above. The tubing assembly can isolate the
first lateral wellbore from the pressure applied to the second
lateral wellbore during stimulation. The tubing assembly and
diverter device can be removed after the second lateral wellbore
and any additional lateral wellbores have been stimulated. The
second lateral wellbore can also include an isolation device that
can isolate the second lateral wellbore after it has been
stimulated. The isolation device positioned within the first
lateral wellbore can be re-opened to allow the production and
pressure of the first lateral wellbore and the production and
pressure of the second lateral wellbore to be commingled.
Additional isolation devices can be positioned in additional
lateral wellbores of the multilateral wellbore and the additional
lateral wellbores can be stimulated and isolated in this same
manner.
[0020] These illustrative aspects and examples are given to
introduce the reader to the general subject matter discussed here
and are not intended to limit the scope of the disclosed concepts.
The following sections describe various additional features and
examples with reference to the drawings in which like numerals
indicate like elements, and directional descriptions are used to
describe the illustrative aspects but, like the illustrative
aspects, should not be used to limit the present disclosure.
[0021] FIG. 1 depicts by cross-section an example of a multilateral
well system that includes a bore that is a main wellbore 102
extending through a surface 104 and various earth strata. The main
wellbore 102 is a wellbore from which at least one lateral wellbore
extends. A "main wellbore" may itself also be a lateral wellbore. A
first lateral wellbore 106 extends substantially horizontally from
the main wellbore 102. A second lateral wellbore 108 is positioned
above the first lateral wellbore 106 and extends substantially
horizontally from the main wellbore 102.
[0022] The main wellbore 102 includes a casing string 110 cemented
at an upper portion of the main wellbore 102. A liner string 112 of
the main wellbore 102 includes a receptacle 114, which may be a
polish bore receptacle or other type of receptacle, positioned
above the liner hanger 116. The liner hanger 116 can also be an
anchor. The liner string 112 can be cemented or non-cemented, and
can be part of a completion string. A liner string 118 of the first
lateral wellbore 106 is hung from a liner hanger 116 and extends
into the first lateral wellbore 106. The liner string 118 can be
cemented or non-cemented and can be a part of a completion string.
The liner string 118 extends along a length of the first lateral
wellbore 106. An isolation device 124 is positioned within the
liner string 112 of the main wellbore 102. The isolation device 124
includes a closure component 126, shown in FIG. 1 in the open
position. The isolation device 124 can be positioned in other
locations within the main wellbore 102, including within the casing
string 110 of the main wellbore 102, within the intermediate casing
string, within a separate completion string positioned within the
main wellbore 102, or other suitable locations.
[0023] Another liner string 120 can be hung from an anchor, such as
the open hole type anchor 122, positioned within a second lateral
wellbore 108. The liner string 120 extends along a length of the
second lateral wellbore 108. Another isolation device 128 is
positioned in the liner string 120 of the second lateral wellbore
108. Either of the first lateral wellbore 106 or the second lateral
wellbore 108 can be stimulated first using a tubing assembly
positioned within the respective lateral wellbore. For example, if
the first lateral wellbore 106 is stimulated first, the isolation
device 124 can be closed after the first lateral wellbore 106 is
stimulated by positioning the closure component 126 in the closed
position.
[0024] With the isolation device 124 in the closed position, the
second lateral wellbore 108 can be stimulated without being
considered in a "live well" scenario. The isolation device 128
positioned within the second lateral wellbore 108 can also isolate
the second lateral wellbore 108 from the remainder of the wellbore
when in the closed position. The production of the first lateral
wellbore 106 and the production of second lateral wellbore 108 can
be comingled after the stimulation of the second lateral wellbore
108 by moving the isolation device 124 into the open position and
retaining the isolation device 128 in the open position. In the
alternative, the isolation device 128 positioned within the second
lateral wellbore 108 can be moved into the closed position to
isolate production and pressure from the second lateral wellbore
108 from the remainder of the wellbore. Additional lateral
wellbores can also include isolation device for selectively
isolating the lateral wellbores after stimulation or
perforation.
[0025] FIG. 2A depicts by cross-section an example of a
multilateral well system with an isolation device 204 positioned in
a casing string 206 of a main wellbore 208. A first lateral
wellbore 210 extends substantially horizontally from the main
wellbore 208. A second lateral wellbore 212 extends substantially
horizontally from the main wellbore 208 above the first lateral
wellbore 210. The isolation device 204 is positioned below a
junction between the main wellbore 208 and the second lateral
wellbore 212. The isolation device 204 includes a closure component
214 that is a flapper or another type of component, shown in FIG.
2A in an open position. The closure component 214 can be retained
in the open position by an internal sleeve or other device, though
in other aspects other suitable closure components can be used. The
closure component 214 can also be positioned in a closed position.
In the closed position the closure component 214 extends across the
diameter of the casing string 206 isolating or closing off the
first lateral wellbore 210. A receptacle 216 is positioned in the
liner string 218 of the main wellbore 208, between a liner hanger
217 and the isolation device 204. The liner hanger 217 can also be
an anchor. In another aspect, the receptacle 216 can be positioned
above the isolation device 204.
[0026] A tubing string 220 is positioned within the main wellbore
208 and extends to the surface of the main wellbore 208. The tubing
string 220 includes a seal member or sealing assembly 222 that is
latched or landed into the receptacle 216. The first lateral
wellbore 210 can be stimulated or fractured by the tubing string
220. The pressure applied to the first lateral wellbore 210 during
stimulation can be isolated by the tubing string 220 that extends
to the surface of the main wellbore 208. After the first lateral
wellbore 210 is stimulated, the tubing string 220 can be removed
and the closure component 214 can be closed. With the closure
component 214 closed, the isolation device 204 is in the closed
position and production and pressure from the first lateral
wellbore 210 cannot exit the first lateral wellbore 210. An
additional isolation device can also be positioned within the
second lateral wellbore 212 to isolate or close off the second
lateral wellbore 212 after it is stimulated.
[0027] In another example, the tubing string 220 can include an
extension positioned below the seal member or sealing assembly 222.
The extension and seal member or sealing assembly 222 can be
latched or landed into the receptacle 216. The extension can cause
the closure component 214 to move from the open position to the
closed position as the tubing string 220 is removed from the main
wellbore 208. The extension can also protect the receptacle 216 and
isolation device 204 from damage. For example, the extension can
protect the receptacle 216 and the isolation device 204 during
stimulation of the first lateral wellbore 210.
[0028] In another example, a completion string, such as a short or
intermediate completion string, can be run into the main wellbore
208 instead of the tubing string 220. The completion string can
include a seal member or sealing assembly that is latched or landed
into the receptacle 216. The completion string can also include an
anchor device, such as a packer assembly, that can set the
completion string within the main wellbore 208 above the junction
between the main wellbore 208 and the second lateral wellbore 212.
The first lateral wellbore 210 can be stimulated using the casing
string of the main wellbore 208 and the first lateral wellbore 210.
The completion string can isolate the junction and the second
lateral wellbore from a pressure applied to the first lateral
wellbore 210 during stimulation.
[0029] FIG. 2B depicts by cross-section the multilateral well
system of FIG. 2A with the closure component 214 of the isolation
device 204 in a closed position. A diverter device 230, shown by
side view, can be run into the main wellbore 208 and latched or
landed into a latch coupling 232 just below the junction between
the second lateral wellbore 212 and the main wellbore 208. In
another example, the diverter device 230 can be landed or latched
into another type of anchor or locating device. A tubing string 236
with a seal member or sealing assembly 238 can be latched or landed
into a receptacle 240 positioned within the liner string 242 of the
second lateral wellbore 212. The tubing string 236 can extend to
the surface of the main wellbore 208. The second lateral wellbore
212 can be safely stimulated by the tubing string 236 without being
considered in a "live well" scenario with the isolation device 204
in the closed position, isolating the live first lateral wellbore
210 from the second lateral wellbore 212. The first lateral
wellbore 210 and the junction between the second lateral wellbore
212 and the main wellbore 208 can be isolated from the pressure
applied to the second lateral wellbore 212 during stimulation by
the tubing string 236.
[0030] After the second lateral wellbore 212 has been stimulated,
the isolation device 204 can be re-opened. With the isolation
device 204 in the open position, production from the first lateral
wellbore 210 and the second lateral wellbore 212 can be comingled.
The isolation device 204 can be opened shortly after the
stimulation of the second lateral wellbore 212 or at a later time.
The second lateral wellbore 212 can also include an additional
isolation device that can isolate or close off the second lateral
wellbore 212, as desired, after stimulation.
[0031] In another example, a completion string, such as a short or
intermediate completion string, can be run into the second lateral
wellbore 212 instead of the tubing string 236. The completion
string can include a seal member or sealing assembly that is
latched or landed into the receptacle 240. The completion string
can also include an anchor device, such as a packer assembly, that
can set the completion string within the main wellbore 208 above
the junction between the main wellbore 208 and the second lateral
wellbore 212. The second lateral wellbore 212 can be stimulated
using the casing string of the main wellbore 208 and the second
lateral wellbore 212. The completion string can isolate the
junction and the first lateral wellbore 210 from a pressure applied
to the second lateral wellbore 212 during stimulation.
[0032] FIG. 3A depicts by cross-section an example of a
multilateral well system with an isolation device 400 positioned in
liner string 402 of a main wellbore 406 above the liner hanger 403
of a first lateral wellbore 404. The isolation device 400 includes
a closure component 408 that is a flapper or another type of
component, shown in FIG. 3A in an open position. The closure
component 408 can also be positioned in a closed position. In the
closed position, the closure component 408 extends across the
diameter and is sealed against the liner string 402. A receptacle
410 is positioned in the liner string 402 above the isolation
device 400. A short or intermediate completion string 412 is
positioned within the main wellbore 406. The short or intermediate
completion string 412 includes a packer assembly 414 that is set
above the junction between a second lateral wellbore 416 and the
main wellbore 406. The short or intermediate completion string 412
also includes a seal member or sealing assembly 418. The seal
member or sealing assembly 418 is landed or latched into the
receptacle 410. The first lateral wellbore 404 can be stimulated by
fracturing using a casing string 401 of the main wellbore 406 and
the first lateral wellbore 404. The short or intermediate
completion string 412 can isolate the second lateral wellbore 416
and the junction between the main wellbore 406 and the second
lateral wellbore 416 from the pressure applied to the first lateral
wellbore 404 during stimulation.
[0033] In another aspect, a tubing string can be latched or landed
into the receptacle 410 and extend to the surface of the main
wellbore 406. The tubing string can provide pressure isolation
during stimulation of the first lateral wellbore 404. After the
first lateral wellbore 404 is stimulated, the short or intermediate
completion string 412 can be removed and the closure component 408
can be closed. The first lateral wellbore 404 can be considered a
live wellbore after being stimulated. Production and pressure
within the live first lateral wellbore 404 can be isolated from the
rest of the multilateral wellbore by the closed isolation device
400. With the live first lateral wellbore 404 isolated, the second
lateral wellbore 416 can be safely stimulated without being in a
"live-well" scenario. In some examples, an extension can extend
below the seal member or sealing assembly 418 and pass over the
isolation device 400. The extension can protect the isolation
device 400 from damage during stimulation or during the performance
of other downhole activities on the first lateral wellbore 404.
[0034] FIG. 3B depicts by cross-section the multilateral well
system of FIG. 3A and an example of stimulating the second lateral
wellbore 416. A diverter device 420 can be run into the main
wellbore 406 and latched or landed into a latch coupling 421 that
is proximate and below the junction between the second lateral
wellbore 416 and the main wellbore 406. In another example, the
diverter device 420 can be latched or landed into another suitable
latch assembly or anchor device. A short or intermediate completion
string 424 with a seal member or sealing assembly 426 can be run
into the second lateral wellbore 416 and latched or landed into a
receptacle 428 positioned within the liner string 430 of the second
lateral wellbore 416. The short or intermediate completion string
424 can be set by a packer assembly 422 in the main wellbore 406.
The second lateral wellbore 416 can be stimulated using the casing
string 401 of the main wellbore 406 and the second lateral wellbore
416. The short or intermediate completion string 424 can isolate
the junction and the first lateral wellbore 404 from the pressure
applied to the second lateral wellbore 416 during stimulation.
[0035] After the second lateral wellbore 416 has been stimulated,
the short or intermediate completion string 424 can be removed and
the closure component 408 of the isolation device 400 can be
re-opened. Production and pressure from the first lateral wellbore
404 and the second lateral wellbore 416 can be comingled with the
closure component 408 in the open position. The closure component
408 can be opened shortly, such as substantially contemporaneously,
after the stimulation of the second lateral wellbore 416 or at a
later time. In another example, the second lateral wellbore 416 can
include an isolation device that can isolate the second lateral
wellbore 416 after it is stimulated, allowing additional lateral
wellbores to be stimulated without being considered in a
"live-well" scenario.
[0036] In another example, a tubing string with a seal member or
sealing assembly can be latched or landed into the receptacle 428
instead of the short or intermediate completion string 424. The
tubing string can extend to the surface of the main wellbore 406.
The second lateral wellbore 416 can be stimulated by the tubing
string. The tubing string can also isolate a pressure applied to
the second lateral wellbore 416 during stimulation.
[0037] FIG. 4A depicts by cross-section an example of a
multilateral well system with a short or intermediate completion
string 500, shown in side view, that includes an isolation device
502 that is positioned within a main wellbore 505. The short or
intermediate completion string 500 includes a packer assembly 508
that is positioned above the isolation device 502 in the short or
intermediate completion string 500. A receptacle 510 is positioned
above the packer assembly 508. A seal member or sealing assembly
509 is positioned below the isolation device 502. The isolation
device 502 includes a closure component 512 that is a flapper or
another type of component, shown in FIG. 4A in an open position.
The closure component 512 can also be in a closed position and can
isolate a first lateral wellbore 504. The seal member or sealing
assembly 509 is latched or landed into a receptacle 514 in the
liner string 516 of the main wellbore 505 above the liner hanger
507 of the first lateral wellbore 504. A tubing string 518 can
extend from the surface of the main wellbore 505 and a seal member
or sealing assembly 517 of the tubing string 518 can be latched or
landed into the receptacle 510 of the short or intermediate
completion string 500. The first lateral wellbore 504 can be
stimulated by the tubing string 518. The pressure applied to the
first lateral wellbore 504 during stimulation can be isolated by
the tubing string 518. Once stimulated, the live first lateral
wellbore 504 can be isolated by closing the closure component 512.
Additional lateral wellbores can be safely stimulated with the live
first lateral wellbore 504 isolated from the rest of the
multilateral wellbore.
[0038] In another example, a completion string, such as a short or
intermediate completion string, can be run into the main wellbore
505 instead of the tubing string 518. The completion string can
include a seal member or sealing assembly that is latched or landed
into the receptacle 510. The completion string can also include a
packer assembly or other anchor device that can set the completion
string within the main wellbore 505 above a junction between the
main wellbore 505 and a second lateral wellbore 506. The first
lateral wellbore 504 can be stimulated using the casing string of
the main wellbore 505 and the first lateral wellbore 504. The
completion string can isolate the pressure applied to the first
lateral wellbore 504 during stimulation.
[0039] In another example, an isolation device can be positioned
within the second lateral wellbore 506. The second lateral wellbore
506 can be stimulated prior to stimulating the first lateral
wellbore 504. The isolation devices that close off the second
lateral wellbore 506 and the first lateral wellbore 504,
respectively, can be separately opened and closed to control the
comingling of the production and pressure from the respective
wellbores. The isolation devices can be closed during any time of
the life of the well. For example, an isolation device within a
lateral wellbore can be closed if the lateral wellbore's production
declines to a point that it no longer is making sufficient
contribution or because the lateral wellbore's production decline
is diminishing production from other portions of the wellbore. The
isolation device can also be closed in the event that the lateral
wellbore begins to produce unwanted excess production, such as
water. The isolation device can be closed in the event that one
desires to re-enter and workover a portion of the remainder of the
multilateral wellbore.
[0040] FIG. 4B depicts by cross-section the multilateral well
system of FIG. 4A and an example of stimulating the second lateral
wellbore 506. After the first lateral wellbore 504 has been
stimulated, a diverter device 520, can be run into the main
wellbore 505 and positioned just below the junction between the
main wellbore 505 and the second lateral wellbore 506. A tubing
string 522 can be latched or landed into a receptacle 524 in the
liner string 526 of the second lateral wellbore 506. The tubing
string 522 can extend to the surface of the main wellbore 505. The
second lateral wellbore 506 can be stimulated by the tubing string
522. In another aspect, a completion string, such as a short or
intermediate completion string, can be latched or landed into the
second lateral wellbore 506 and the second lateral wellbore 506 can
be stimulated using the casing. The first lateral wellbore 504 and
the junction can be isolated from a pressure applied to the second
lateral wellbore 506 during stimulation by the tubing string 522
extending to the surface the main wellbore 505. After the second
lateral wellbore 506 has been stimulated, the closure component 512
of the isolation device 502 within the main wellbore 505 can be
re-opened allowing access to the first lateral wellbore 504. With
the closure component 512 open, production of the first lateral
wellbore 504 and production of the second lateral wellbore 506 can
be comingled.
[0041] FIG. 5 depicts by cross-section an example of a multilateral
well system with an isolation device 600 positioned in the liner
string 602 of a main wellbore 604 of a multilateral wellbore having
a first lateral wellbore 606 and a second lateral wellbore 608. In
another aspect, additional isolation devices can be positioned
within a liner string of additional lateral wellbores. The
isolation device 600 is positioned between a receptacle 610 within
the liner string 602 and a liner hanger 612. In another aspect, the
isolation device 600 can be positioned elsewhere in the liner
string. The isolation device 600 includes a closure component 614
that is a flapper or another type of component, shown in FIG. 5 in
an open position. The closure component 614 can also be in a closed
position. In the closed position, the closure component 614 extends
across the diameter of the liner string 602 and can be sealed
against the liner string 602. The first lateral wellbore 606 can be
isolated from the rest of the multilateral well system, including
the main wellbore 604 and any additional lateral wellbores, when
the closure component 614 of the isolation device 600 is in the
closed position.
[0042] A short or intermediate completion string 616 is positioned
within the main wellbore 604 and is set above a junction between
the main wellbore 604 and the second lateral wellbore 608 by a
packer assembly 618. The short or intermediate completion string
616 can also be an intermediate completion string. The short or
intermediate completion string 616 includes a seal member or
sealing assembly 620 that is latched or landed into the receptacle
610. The short or intermediate completion string 616 also includes
an extension 622 below the seal member or sealing assembly 620. The
extension 622 extends a sufficient length to pass over the
isolation device 600. The extension 622 can protect the isolation
device 600 from damage, for example, from erosion. The first
lateral wellbore 606 can be stimulated or fractured down a casing
string 624 of the main wellbore 604. The junction and the second
lateral wellbore 506 can be isolated from a pressure applied to the
first lateral wellbore 606 during stimulation by the short or
intermediate completion string 616. In another aspect, a tubing
string that extends from the surface of the main wellbore 604 can
be used in place of the short or intermediate completion string 616
and the first lateral wellbore 606 can be stimulated by the tubing
string. After the first lateral wellbore 606 is stimulated, the
short or intermediate completion string 616 can be removed and the
closure component 614 can be closed. The extension 622 can shift
the closure component 614 from the open position to the closed
position as it is pulled out of the liner string 602. The second
lateral wellbore 608 can be stimulated in any suitable manner as
described with respect to various aspects of this disclosure.
[0043] FIG. 6 depicts by cross-section an example of a multilateral
well system with an isolation device that is a plug device 702,
shown by side view, that is passed through a completion string 704
positioned within a liner string 712 of the main wellbore 706.
After a first lateral wellbore 714 has been stimulated or
perforated the completion string 704 can be set in the main
wellbore 706 by a packer assembly 708 positioned above a junction
between the main wellbore 706 and a second lateral wellbore 707.
The completion string 704 can be latched or landed into a
receptacle 710 positioned within a liner string 712 of the main
wellbore 706. The plug device 702 can be passed through the
completion string 704 by wireline or coil tubing or other suitable
conveyance means that can be run through the completion string 704.
With the plug device 702 positioned within the liner string 712
restricting or blocking access to the now live first lateral
wellbore 714, the first lateral wellbore 714 can be isolated from
the rest of the multilateral wellbore. For example, the first
lateral wellbore 714 can be isolated from the main wellbore 706 and
the second lateral wellbore 707. The second lateral wellbore 707,
or any additional lateral wellbores, can be stimulated in any
suitable manner as described with respect to various aspects of
this disclosure when the plug device 702 is positioned to isolate
the first lateral wellbore 714. In another aspect, the second
lateral wellbore 707 can be stimulated and a plug device can be
inserted into the second lateral wellbore 707 to isolate the live
second lateral wellbore 707 from the rest of the multilateral well
system. Additional lateral wellbores can also be isolated after
stimulation or perforation by inserting a plug device in the manner
disclosed above. The plug device 702 can also remain in the
wellbore and can include a closure component that can be moved from
an open position to a closed position to selectively isolate the
first lateral wellbore. For example, the plug device 702 can
include a barrier component, such as a flapper, a ball, or another
type of closure component. In another example, the plug device 702
can include a chemical barrier or chemical pill that can
selectively restrict access to the first lateral wellbore 714.
[0044] In some aspects, methods and systems are provided for
stimulating and isolating one or more wellbores in a multilateral
well system according to one or more of the following examples.
EXAMPLE 1
[0045] A wellbore system includes a subsurface isolation device
that has an open position and a closed position to temporarily
close off an active lateral wellbore in a multilateral well by
isolating the active lateral wellbore from at least one other
wellbore in the multilateral well.
EXAMPLE 2
[0046] The wellbore system of Example 1 can feature the subsurface
isolation device being positionable within a casing string or a
liner string of the active lateral wellbore.
EXAMPLE 3
[0047] The wellbore system of any of Examples 1 to 2 can feature
the subsurface isolation device being positionable within a short
or an intermediate completion string and the short or the
intermediate completion string as positionable within the active
lateral wellbore.
EXAMPLE 4
[0048] The wellbore system of any of Examples 1 to 3 can feature
the subsurface isolation device being a plug device that is
positionable within a liner string of the active lateral
wellbore.
EXAMPLE 5
[0049] The wellbore system of any of Examples 1 to 4 can include a
wellbore string that includes a sealing assembly. The wellbore
string can be positionable within the wellbore system for isolating
the at least one other wellbore from a pressure applied to the
active lateral wellbore.
EXAMPLE 6
[0050] The wellbore system of Example 5 can feature the wellbore
string having an extension device for shifting the subsurface
isolation device from the open position to the closed position.
EXAMPLE 7
[0051] The wellbore system of Example 5 can feature the wellbore
string having a short or an intermediate completion string
including a seal assembly on a first end and an anchor device on a
second end.
EXAMPLE 8
[0052] A method including positioning an isolation device within a
multilateral well and performing a procedure on a wellbore of the
multilateral well to cause the wellbore to be a live wellbore.
Substantially contemporaneously to the wellbore becoming the live
wellbore, the isolation device can be changed from an open position
to a closed position at which the isolation device isolates the
wellbore from at least one other wellbore of the multilateral well.
Another procedure can be performed on the at least one other
wellbore of the multilateral well while the isolation device is in
the closed position.
EXAMPLE 9
[0053] The method of Example 8 can include isolating the wellbore
from the at least one other wellbore of the multilateral well by
preventing production and pressure from the wellbore from exiting
the wellbore and entering the at least one other wellbore.
EXAMPLE 10
[0054] The method of any of Examples 8 to 9 can include performing
the procedure on the wellbore of the multilateral well to cause the
wellbore to be the live wellbore by stimulating the wellbore of the
multilateral well.
EXAMPLE 11
[0055] The method of any of Examples 8 to 10 can include
positioning the isolation device within the multilateral well by
positioning a plug device within the multilateral well.
EXAMPLE 12
[0056] The method of any of Examples 8 to 11 can include changing
the isolation device from the open position to the closed position
by removing a wellbore string having an extension device from the
multilateral well, the extension device shifting the isolation
device from the open position to the closed position.
EXAMPLE 13
[0057] The method of any of Examples 8 to 12 can include
positioning a wellbore string having a sealing assembly on an end
into the wellbore for isolating the at least one other wellbore
from a pressure applied to the wellbore while performing the
procedure on the wellbore of the multilateral well to cause the
wellbore to be the live wellbore.
EXAMPLE 14
[0058] The method of Example 13 can include positioning the
wellbore string having the sealing assembly on the end into the
wellbore for isolating the at least one other wellbore from the
pressure applied to the wellbore while performing the procedure on
the wellbore of the multilateral well by positioning a short or an
intermediate completion string that also includes an anchor device
on another end within the wellbore.
EXAMPLE 15
[0059] The method of any of Examples 8 to 14 can include re-opening
the isolation device and allowing production from the wellbore and
the at least one other wellbore to comingle.
EXAMPLE 16
[0060] A multilateral wellbore system includes a wellbore, at least
one other wellbore, and a subsurface isolation device having an
open position and a closed position. The subsurface isolation
device can isolate the wellbore from the at least one other
wellbore substantially contemporaneous to the wellbore becoming a
live wellbore.
EXAMPLE 17
[0061] The multilateral wellbore system of Example 16 can feature a
wellbore string having a sealing assembly on an end for isolating
the at least one other wellbore from a pressure applied to the
wellbore while stimulating the wellbore.
EXAMPLE 18
[0062] The multilateral wellbore system of any of Examples 16 to 17
can feature the subsurface isolation device being positioned within
a casing string or a liner string of the wellbore.
EXAMPLE 19
[0063] The multilateral wellbore system of any of Examples 16 to 18
can feature the subsurface isolation device being positioned within
a short or an intermediate completion string that includes a
sealing assembly on a first end and an anchor device on a second
end and positionable within the wellbore.
EXAMPLE 20
[0064] The multilateral wellbore system of any of Examples 16 to 19
can feature the subsurface isolation device including a valve for
positioning the subsurface isolation device in the open position
and the closed position.
[0065] The foregoing description of certain aspects, including
illustrated aspects, has been presented only for the purpose of
illustration and description and is not intended to be exhaustive
or to limit the disclosure to the precise forms disclosed. Numerous
modifications, adaptations, and uses thereof will be apparent to
those skilled in the art without departing from the scope of the
disclosure.
* * * * *