Note: Descriptions are shown in the official language in which they were submitted.
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MULTILATERAL WELLBORE STIMULATION
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
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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.
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[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
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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 avoding 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.
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[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
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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
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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
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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
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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
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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
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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
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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.
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[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
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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.
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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.
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[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
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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
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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
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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.
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[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
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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.
[0045] Example 1: 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.
[0046] Example 2: 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.
[0047] Example 3: 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.
[0048] Example 4: 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.
[0049] Example 5: 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.
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[0050] Example 6: 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.
[0051] Example 7: 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.
[0052] Example 8: 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.
[0053] Example 9: 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.
[0054] Example 10: 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.
[0055] Example 11: 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.
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[0056] Example 12: 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.
[0057] Example 13: 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.
[0058] Example 14: 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.
[0059] Example 15: 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.
[0060] Example 16: 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.
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[0061] Example 17: 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.
[0062] Example 18: 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.
[0063] Example 19: 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.
[0064] Example 20: 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.
