Note: Descriptions are shown in the official language in which they were submitted.
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SYSTEMS AND METHODS FOR RESTRICTING FLUID FLOW IN A
WELLBORE WITH AN AUTONOMOUS SEALING DEVICE AND
MOTION-ARRESTING STRUCTURES
Cross Reference To Related Applications
[0001] This application claims the benefit of U.S. Provisional No.
61/871,675, filed
August 29, 2013, the entirety of which is incorporated herein by reference for
all purposes.
Field of the Disclosure
[0002] The present disclosure is directed generally to systems and methods
for restricting
fluid flow within a casing conduit, and more particularly to systems and
methods that utilize
an autonomous sealing device and a plurality of motion-arresting structures to
restrict fluid
flow within the casing conduit.
Background of the Disclosure
[0003] A well may be utilized to produce one or more reservoir fluids, such
as liquid
and/or gaseous hydrocarbons, from a subterranean formation. The well may
include a
wellbore, which extends between a surface region and the subterranean
formation, and a
casing string that extends within the wellbore and defines a casing conduit.
[0004] During construction and/or operation of the well, it may be
desirable to restrict
fluid flow between an uphole portion of the casing conduit and a downhole
portion of the
casing conduit, such as to stimulate the subterranean formation. Illustrative
examples of
stimulation processes include fracturing the formation and acidizing, or acid
treating, the
formation. Often, the stimulating process may be repeated a plurality of times
along a length
of the production casing to stimulate a plurality of zones of the subterranean
formation. As
an illustrative, non-exclusive example, the stimulating may include providing
a stimulant
fluid to the casing conduit, with the stimulant fluid flowing from the casing
conduit into the
subterranean formation to thereby stimulate the subterranean formation, and
with the fluid
flow restriction being utilized to focus the stimulant fluid flow into a
desired portion, region,
and/or zone of the subterranean formation.
[0005] A number of processes have been utilized to stimulate subterranean
formations.
While these processes may be effective under certain conditions, they may be
ineffective
under others. As an illustrative, non-exclusive example, a well may include a
wellbore with a
long horizontal section. This long horizontal section may extend within the
subterranean
formation, and it may be desirable to stimulate a plurality of zones of the
subterranean
formation that may be distributed along the length of the horizontal section.
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[0006] Traditional stimulating processes may include establishing fluid
communication
between the casing conduit and a given zone of the subterranean formation,
providing the
stimulant fluid to the given zone of the subterranean formation to stimulate
the given zone of
the subterranean formation, and then fluidly isolating at least a portion of
the casing conduit
from the subterranean formation. This process may be repeated a plurality of
times along a
length of the horizontal section to stimulate the plurality of zones of the
subterranean
formation.
[0007] Generally, the traditional stimulating processes fluidly isolate the
portion of the
casing conduit from downhole portions of the casing conduit using isolation
plugs or using
traditional isolation balls and seats. It follows that this isolation from the
downhole portions
also isolates the portion of the casing conduit from corresponding regions of
the subterranean
formation that are in fluid communication with the downhole portions.
Isolation plugs may
include and/or be expandable plugs that may be located within the casing
conduit and
subsequently expanded to fill a portion of the casing conduit, thereby
blocking fluid flow
therepast. Traditional isolation balls may include and/or be elastomeric balls
that are sized to
fit within the casing conduit and to seal with a respective seat that is sized
to receive the
isolation ball to block the flow of fluid therepast.
[0008] However, as the length of the well is increased, setting the
required number of
isolation plugs becomes increasingly difficult and/or expensive and may
inhibit economic
and/or efficient stimulating of the subterranean formation. Moreover, the
isolation plugs
must be removed from the casing conduit, typically by time-consuming and/or
expensive
processes that include drilling the isolation plugs from the casing conduit,
prior to production
of the reservoir fluid from the subterranean formation.
[0009] Similarly, traditional isolation balls and seats rely on
progressively smaller balls
and seats to stimulate a desired number of zones of the subterranean
formation. Thus, there is
a practical limit to the number of zones that may be stimulated with isolation
balls and seats
while still permitting sufficient fluid flow rates within the casing conduit.
In addition, the
progressively smaller seats effectively may limit access to portions of the
casing conduit that
are downhole therefrom, as many downhole assemblies simply may be too large to
fit, or
flow, through the seats. Furthermore, these seats often must be removed from
the casing
conduit prior to production of the reservoir fluid from the subterranean
formation, and doing
so increases the overall cost of the stimulation, and subsequent production,
process. Thus,
there exists a need for improved systems and methods for restricting fluid
flow in a casing
conduit.
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Summary of the Disclosure
[0010]
Systems and methods for restricting fluid flow in a casing conduit are
disclosed
herein. The systems include a wellbore that extends within a subterranean
formation, a
casing string that extends within the wellbore and defines a portion of the
casing conduit, a
plurality of motion-arresting structures that project from an inner surface of
the casing string
to define a plurality of reduced-area regions of the casing conduit, and an
autonomous sealing
device that defines a contracted configuration and an expanded configuration.
The
autonomous sealing device is sized to flow past, or through, the plurality of
reduced-area
regions when in the contracted configuration, to be retained on a selected
motion-arresting
structure upon transitioning to the expanded configuration, and to restrict
fluid flow within
the casing conduit upon being retained on the selected motion-arresting
structure.
[0011] In
some embodiments, the autonomous sealing device is configured to form a
fluid seal with the selected motion-arresting structure. In some embodiments,
the selected
motion-arresting structure is defined by the selected transitioning of the
motion-arresting
structure to the expanded configuration. In some embodiments, the selected
motion-arresting
structure defines a sealing surface that is sized to form the fluid seal. In
some embodiments,
the autonomous sealing device is configured to form a fluid seal with an inner
surface of the
casing string. In some embodiments, the autonomous sealing device includes an
expansion
mechanism that is configured to transition the autonomous sealing device to
the expanded
configuration. In some embodiments, the autonomous sealing device is further
configured to
transition from the expanded configuration to a retracted configuration. In
some
embodiments, the autonomous sealing device is configured to release a
supplemental material
into the casing conduit. In some embodiments, the autonomous sealing device is
operatively
attached to a perforation device.
[0012] In
some embodiments, the autonomous sealing device further includes an
autonomous controller. In some embodiments, the autonomous controller is
programmed to
determine a location of the autonomous sealing device within the casing
conduit and to
transition the autonomous sealing device to the expanded configuration based
on the
determined location.
[0013] In
some embodiments, the plurality of motion-arresting structures includes a
plurality of isolation rings. In some embodiments, the plurality of motion-
arresting structures
includes a plurality of stops. In some embodiments, the plurality of motion-
arresting
structures includes a plurality of sliding sleeves. In some embodiments, the
well further
includes a hydraulically actuated sleeve.
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[0014] The
methods include conveying the autonomous sealing device through the casing
conduit, determining that the autonomous sealing device is located within a
target portion of
the casing conduit, expanding the autonomous sealing device to the expanded
configuration,
retaining the autonomous sealing device on a selected motion-arresting
structure, and
restricting fluid flow within the casing conduit with the autonomous sealing
device.
[0015] In
some embodiments, the methods further include supplying a stimulant fluid to
the casing conduit, and the conveying includes conveying the autonomous
sealing device
within the stimulant fluid. In some embodiments, the methods further include
detecting a
variable associated with the autonomous sealing device. In some embodiments,
the
determining is based upon the variable associated with the autonomous sealing
device.
[0016] In
some embodiments, the restricting includes forming a fluid seal between the
selected motion-arresting structure and the autonomous sealing device. In
some
embodiments, the restricting includes forming a fluid seal with the inner
surface of the casing
string. In some embodiments, the methods further include removing the
autonomous sealing
device from the casing conduit. In some embodiments, the removing includes
transitioning
the autonomous sealing device from the expanded configuration to a retracted
configuration.
[0017] In
some embodiments, the methods further include stimulating the subterranean
formation. In some embodiments, the stimulating includes supplying a stimulant
fluid to the
subterranean formation. In some embodiments, the stimulant fluid is supplied
via a sleeve
port, via an injection port, and/or via a perforation. In some embodiments,
the methods
further include repeating the methods to restrict fluid flow within a
plurality of portions of the
casing conduit. In some embodiments, the methods further include producing a
reservoir
fluid from the subterranean formation.
Brief Description of the Drawings
[0018] Fig. 1
is a schematic representation of illustrative, non-exclusive examples of a
hydrocarbon well that may be utilized with and/or may include the systems and
methods
according to the present disclosure.
[0019] Fig. 2
is a schematic cross-sectional view of illustrative, non-exclusive examples
of a casing string that includes a motion-arresting structure and may be
utilized with an
autonomous sealing device according to the present disclosure.
[0020] Fig. 3
is a schematic cross-sectional view of illustrative, non-exclusive examples
of another motion-arresting structure that may be utilized with an autonomous
sealing device
according to the present disclosure.
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[0021] Fig. 4 is a schematic representation of illustrative, non-exclusive
examples of a
process flow that may be utilized with a flow-arresting structure and an
autonomous sealing
device according to the present disclosure.
[0022] Fig. 5 is another schematic representation of illustrative, non-
exclusive examples
of a process flow that may be utilized with a flow-arresting structure and an
autonomous
sealing device according to the present disclosure.
[0023] Fig. 6 is another schematic representation of illustrative, non-
exclusive examples
of a process flow that may be utilized with a flow-arresting structure and an
autonomous
sealing device according to the present disclosure.
[0024] Fig. 7 is another schematic representation of illustrative, non-
exclusive examples
of a process flow that may be utilized with a flow-arresting structure and an
autonomous
sealing device according to the present disclosure.
[0025] Fig. 8 is another schematic representation of illustrative, non-
exclusive examples
of a process flow that may be utilized with a flow-arresting structure and an
autonomous
sealing device according to the present disclosure.
[0026] Fig. 9 is another schematic representation of illustrative, non-
exclusive examples
of a process flow that may be utilized with a flow-arresting structure and an
autonomous
sealing device according to the present disclosure.
[0027] Fig. 10 is a flowchart depicting methods according to the present
disclosure of
restricting fluid flow between an uphole portion of a casing conduit and a
downhole portion
of the casing conduit.
Detailed Description and Best Mode of the Disclosure
[0028] Figs. 1-9 provide illustrative, non-exclusive examples of
hydrocarbon wells 30
according to the present disclosure and/or of components of hydrocarbon wells
30, such as
motion-arresting structures 100 and/or autonomous sealing devices 150.
Elements that serve
a similar, or at least substantially similar, purpose are labeled with like
numbers in each of
Figs. 1-9, and these elements may not be discussed in detail herein with
reference to each of
Figs. 1-9. Similarly, all elements may not be labeled in each of Figs. 1-9,
but reference
numerals associated therewith may be utilized herein for consistency.
Elements, components,
and/or features that are discussed herein with reference to one or more of
Figs. 1-9 may be
included in and/or utilized with any of Figs. 1-9 without departing from the
scope of the
present disclosure.
[0029] In general, elements that are likely to be included in a given
(i.e., a particular)
embodiment are illustrated in solid lines, while elements that are optional to
a given
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embodiment are illustrated in dashed lines. However, elements that are shown
in solid lines
are not essential to all embodiments, and an element shown in solid lines may
be omitted
from a particular embodiment without departing from the scope of the present
disclosure.
[0030] Fig. 1 is a schematic representation of illustrative, non-exclusive
examples of a
hydrocarbon well 30 that may be utilized with and/or include the systems and
methods
according to the present disclosure and with and/or within which the methods
according to
the present disclosure may be utilized and/or implemented. Hydrocarbon well 30
includes a
wellbore 32 that extends from a surface region 10 and/or within a subterranean
formation 22
that is present within a subsurface region 20. A casing string 40 extends
within wellbore 32
and has an inner surface 42 that defines a portion of a casing conduit 44.
Casing string 40
may include a plurality of sections 43 of casing that may be operatively
attached to one
another with respective casing collars 41 to form the casing string. Fig. 1
illustrates
hydrocarbon well 30 as including a single, continuous, and/or unbranched
wellbore 32.
However, the wellbore shown in Fig. 1 is intended to schematically depict
wellbore 30, and
therefore to include, but not be limited to, such a single, continuous, and/or
unbranched
wellbore. Accordingly, it also is within the scope of the present disclosure
and the schematic
depiction of Fig. 1 that hydrocarbon well 30 may include a plurality of
branches and/or
laterals. Each of these branches and/or laterals, when present, may include a
respective
casing string 40; and the systems and methods according to the present
disclosure may be
located in and/or utilized with any and/or all branches and/or laterals of
hydrocarbon well 30.
[0031] Hydrocarbon well 30, which also may be referred to herein as a well
30, further
includes a plurality of motion-arresting structures 100 that are spaced apart
from one another
along a (longitudinal) length of casing string 40. Motion-arresting structures
100 project
from inner surface 42 to define a plurality of reduced-area regions 102 of
casing conduit 44.
Hydrocarbon well 30 further includes one or more autonomous sealing devices
150 and also
may include a perforation device 170 and/or one or more hydraulically actuated
sleeves 74.
[0032] During the construction, formation, and/or operation of hydrocarbon
well 30, one
or more autonomous sealing devices 150 may be located within casing conduit 44
and a
stimulant fluid 62 may be provided to the casing conduit. This may flow the
autonomous
sealing device within the casing conduit in a downhole direction 38 and/or
toward
subterranean formation 22. Upon reaching a desired, or target, location within
the casing
conduit, the autonomous sealing device may transition from a contracted
configuration 152 to
an expanded configuration 154 and be retained on a selected motion-arresting
structure 100,
thereby fluidly isolating an uphole portion 46 of casing conduit 44 from a
downhole portion
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48 of the casing conduit. This fluid isolation may facilitate performing one
or more
completion and/or stimulation operations within hydrocarbon well 30.
[0033]
Autonomous sealing device 150 may include any suitable structure that may
define contracted configuration 152 and expanded configuration 154. When in
contracted
configuration 152, the autonomous sealing device is adapted, configured,
constructed,
designed, and/or sized to pass through the plurality of reduced-area regions
102 within casing
conduit 44. However, and upon transitioning to expanded configuration 154, the
autonomous
sealing device is adapted, configured, constructed, and/or sized not to pass
through reduced-
area regions 102, to be retained on a selected motion-arresting structure 100,
and/or to restrict
fluid flow between a portion of casing conduit 44 that is uphole from (or
located in an uphole
direction 36 from) the selected motion-arresting structure (i.e., uphole
portion 46 of the
casing conduit) and a portion of the casing conduit that is downhole from (or
located in
downhole direction 38 from) the selected motion-arresting structure (i.e.,
downhole portion
48 of the casing conduit).
[0034] As
discussed in more detail herein, autonomous sealing device 150 may be
adapted, configured, constructed, and/or programmed for autonomous, or
independent,
operation within casing conduit 44. As such, the autonomous sealing device may
not be
attached to a tether, a working line, a wireline, and/or tubing. Illustrative,
non-exclusive
examples of autonomous devices that may be utilized within a wellbore are
disclosed in U.S.
Patent Application Publication No. 2013/0062055; U.S. Patent Application
Publication No.
2013/0255939; and U.S. Patent Application Publication No. 2013/0248174, the
complete
disclosures of which are hereby incorporated by reference.
[0035] As
used herein, the phrases "expanded configuration" and "contracted
configuration" are relative phrases that do not, necessarily, refer to
discrete and/or single
configurations for autonomous sealing device 150.
Instead, these phrases refer to
configurations in which autonomous sealing device 150 is sized to pass through
reduced-area
regions 102 (i.e., contracted configuration 152) and configurations in which
autonomous
sealing device 150 is sized to be retained on motion-arresting structures 100
and/or not to
pass through reduced-area regions 102 (i.e., expanded configuration 154). As
such,
contracted configuration 152 and expanded configuration 154 optionally may
refer to a range
of configurations that is bounded by a fully contracted configuration and a
fully expanded
configuration, respectively.
[0036] With
this in mind, it is within the scope of the present disclosure that contracted
configuration 152 and/or expanded configuration 154 may be defined in any
suitable manner
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and/or may define any suitable configuration, or relative configuration, for
autonomous
sealing device 150 such that the autonomous sealing device may pass through
reduced-area
regions 102 while in the contracted configuration but is retained on motion-
arresting
structures 100 (i.e., may/can not pass through reduced-area regions 102) when
in the
expanded configuration. As an illustrative, non-exclusive example, contracted
configuration
152 may define a contracted volume and expanded configuration 154 may define
an
expanded volume that is greater than the contracted volume. As another
illustrative, non-
exclusive example, contracted configuration 152 may define a contracted
characteristic
dimension (or diameter and/or cross-sectional area transverse to the
longitudinal axis of the
corresponding portion of the casing conduit within which the motion-arresting
structure is
located) and expanded configuration 154 may define an expanded characteristic
dimension
(or diameter and/or cross-sectional area transverse to the longitudinal axis
of the
corresponding portion of the casing conduit within which the motion-arresting
structure is
located) that is greater than the contracted characteristic dimension. As
additional
illustrative, non-exclusive examples, contracted configuration 152 and/or
expanded
configuration 154 may define respective cylindrical and/or spherical
configurations, profiles,
and/or surface profiles.
[0037] Autonomous sealing device 150 may include an expansion mechanism 158
that
may be configured to transition (or provide a motive force for transitioning)
the autonomous
sealing device to expanded configuration 154 and/or from contracted
configuration 152 to
expanded configuration 154. Expansion mechanism 158 may include any suitable
structure.
As illustrative, non-exclusive examples, expansion mechanism 158 may include
and/or be an
explosive charge, a mechanical actuator, an electric actuator, a hydraulic
actuator, a chemical
reaction, and/or a material that swells upon contact with a wellbore fluid.
[0038] As a more specific but still illustrative, non-exclusive example,
autonomous
sealing device 150 and/or expansion mechanism 158 may include a reservoir
chamber 190
and an expansion chamber 192. Under these conditions, expansion mechanism 158
may be
configured to direct an expansion fluid from reservoir chamber 190 to
expansion chamber
192 to swell the autonomous sealing device and/or to transition the autonomous
sealing
device to the expanded configuration. When autonomous sealing device 150
includes
reservoir chamber 190 and expansion chamber 192, the autonomous sealing device
further
may include a check valve 194 that is configured to at least temporarily
retain the expansion
fluid within the expansion chamber subsequent to the autonomous sealing device
transitioning to the expanded configuration.
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[0039] Autonomous sealing device 150 further may be configured to
transition from
expanded configuration 154 to a retracted configuration 156, which also may be
referred to
herein as a spent configuration 156 and/or a post-expansion configuration 156.
Upon
transitioning to retracted configuration 156, the autonomous sealing device
may be
configured to permit fluid flow between uphole portion 46 and downhole portion
48 and/or
may be configured to pass through reduced-area regions 102. As an
illustrative, non-
exclusive example, retracted configuration 156 may define a retracted
configuration volume
that is less than the expanded configuration volume. As another illustrative,
non-exclusive
example, retracted configuration 156 may define a retracted configuration
characteristic
dimension, or diameter, that is less than the expanded characteristic
dimension, or diameter.
[0040] It is within the scope of the present disclosure that autonomous
sealing device 150
may transition from expanded configuration 154 to retracted configuration 156
in any
suitable manner, at any suitable timing, and/or responsive to any suitable
conditions or
actuator. As illustrative, non-exclusive examples, the autonomous sealing
device may shrink,
retract, break apart, and/or dissolve to transition to, or toward, the
retracted configuration. As
a more specific but still illustrative, non-exclusive example, the autonomous
sealing device
may be a frangible autonomous sealing device that is formed, at least
partially, from a
frangible material, and the autonomous sealing device further may include a
fragmentation
charge 196 that is configured to be actuated to break apart the frangible
autonomous sealing
device and thereby transition the frangible autonomous sealing device to the
retracted
configuration.
[0041] Autonomous sealing device 150 further may include a supplemental
material 198,
and the autonomous sealing device may be configured to release the
supplemental material
within casing conduit 44. This may include releasing the supplemental material
subsequent
to transitioning to the expanded configuration, upon transitioning to the
contracted
configuration, upon breaking apart within the casing conduit, and/or upon
dissolving within
the casing conduit. Illustrative, non-exclusive examples of supplemental
material 198
include any suitable gel breaker, paraffin inhibitor, corrosion inhibitor,
and/or tracer material.
It also is within the scope of the present disclosure that the systems and/or
methods may
utilize supplemental material and/or mechanisms or devices for delivering
and/or releasing
supplemental material that are not attached to, are not included in, and/or do
not form a
portion of an autonomous sealing device 150.
[0042] Hydrocarbon well 30 and/or casing conduit 44 thereof may include
and/or contain
a plurality of autonomous sealing devices 150 that each may contain a
respective volume of
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supplemental material 198. Under these conditions, each of the respective
volumes of
supplemental material 198 may include a respective (or unique) tracer material
that may be
readily distinguished from the tracer material that may be included in a
remainder of the
respective volumes of supplemental sealing material. In addition, the systems
and methods
disclosed herein may be configured to detect the presence of the respective
tracer materials
within a reservoir fluid 24 that is produced from hydrocarbon well 30, thereby
providing
information regarding which region(s) of subterranean formation 22 are
producing the
reservoir fluid and/or which autonomous sealing device(s) are restricting
fluid flow between
respective uphole and downhole portions of the casing conduit.
[0043] Autonomous sealing device 150 may be configured to form a fluid seal
with the
selected motion-arresting structure 100 upon transitioning to expanded
configuration 154 and
to thereby restrict the fluid flow between uphole portion 46 and downhole
portion 48. As an
illustrative, non-exclusive example, motion-arresting structures 100 may
define a sealing
surface 112 that may be designed, constructed, shaped, and/or sized to form
the fluid seal
with the autonomous sealing device. Under these conditions, and when
autonomous sealing
device 150 is in expanded configuration 154, an outer diameter of the
autonomous sealing
device may be less than an inner diameter of casing conduit 44. Additionally
or alternatively,
and when autonomous sealing device 150 is in expanded configuration 154, the
outer
diameter of the autonomous sealing device may be equal to the inner diameter
of the casing
conduit and/or the autonomous sealing device may be designed, constructed,
shaped, and/or
sized to form the fluid seal with inner surface 42 of casing string 40. This
is discussed in
more detail herein with reference to Fig. 2.
[0044] Autonomous sealing device 150 may be constructed, configured, and/or
programmed to transition from contracted configuration 152, to expanded
configuration 154,
and/or to retracted configuration 156 based upon any suitable criteria and/or
responsive to
any suitable event. As an illustrative, non-exclusive example, the autonomous
sealing device
may transition (or be transitioned) to expanded configuration 154 responsive
to being located
within a target, and/or otherwise selected, portion of casing conduit 44 (such
as a portion of
casing conduit 44 that is uphole from, directly uphole from, and/or within a
threshold
distance of the selected motion-arresting structure 100). As another
illustrative, non-
exclusive example, the autonomous sealing device may transition (or be
transitioned) to
expanded configuration 154 responsive to flowing a target, or desired,
distance along a
(longitudinal) length of (and/or within) casing conduit 44. As yet another
illustrative, no-
exclusive example, autonomous sealing device 150 may transition (or be
transitioned) to
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retracted configuration 156 subsequent to stimulation of a target region of
subterranean
formation 22, responsive to (or upon) being located within casing conduit 44
for at least a
threshold period of time, and/or responsive to (or upon) production of
reservoir fluid 24 from
subterranean formation 22.
[0045] It is within the scope of the present disclosure that autonomous
sealing device 150
may transition among and/or between contracted configuration 152, expanded
configuration
154, and/or retracted configuration 156 at any suitable transition rate. As an
illustrative, non-
exclusive example, autonomous sealing device 150 may be configured to
partially transition
to expanded configuration 154 prior to being retained on the selected motion-
arresting
structure 100 and to complete the transition to the expanded configuration
subsequent to
being retained on the selected motion-arresting structure. As another
illustrative, non-
exclusive example, autonomous sealing device 150 also may be configured to
completely
transition to expanded configuration 154 prior to being retained on the
selected motion-
arresting structure.
[0046] The transitioning of autonomous sealing device 150 among the various
configurations thereof may be controlled, regulated, and/or initiated in any
suitable manner.
As an illustrative, non-exclusive example, expansion mechanism 158 may be a
passive
structure that is configured to control the transitioning of the autonomous
sealing device
responsive to temperatures and/or pressures within casing conduit 44 and/or
responsive to a
residence time of the autonomous sealing device within the casing conduit.
[0047] As another illustrative, non-exclusive example, the transition may
be actively
controlled, such as via an autonomous controller 160 that is adapted,
configured, and/or
programmed to control the operation of the autonomous sealing device. As an
illustrative,
non-exclusive example, autonomous controller 160 may be programmed to
determine a
location of autonomous sealing device 150 within casing conduit 44 and/or may
transition the
autonomous sealing device to expanded configuration 154 based upon the
determined
location and/or when the determined location corresponds to a target location
within the
casing conduit. The location of the autonomous sealing device may be and/or
may be
determined based upon a distance that the autonomous sealing device has
traveled within the
casing conduit and/or a depth of the autonomous sealing device below a ground
surface.
Additionally or alternatively, the autonomous controller also may be
programmed to time the
transition to the expanded configuration such that the autonomous sealing
device is retained
on the selected motion-arresting structure while passing through motion-
arresting structures
that may be uphole from the selected motion-arresting structure.
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[0048] Additionally or alternatively, autonomous controller 160 may be
programmed to
determine a variable associated with the autonomous sealing device and/or to
transition the
autonomous sealing device to the expanded configuration based upon the
determined
variable. Illustrative, non-exclusive examples of the variable associated with
the autonomous
sealing device include a velocity of the autonomous sealing device within the
casing conduit,
a speed of the autonomous sealing device within the casing conduit, an
acceleration of the
autonomous sealing device within the casing conduit, a deceleration of the
autonomous
sealing device within the casing conduit, a pressure proximal to the
autonomous sealing
device within the casing conduit, a location of the autonomous sealing device
along the
length of the casing string, and/or a number of casing collars 41 that the
autonomous sealing
device has traveled past while located within the casing conduit.
[0049] It is within the scope of the present disclosure that autonomous
controller 160 may
include one or more sensors and/or detectors. These sensors and/or detectors
may be
configured to determine, measure, and/or detect any suitable variable
associated with
autonomous sealing device 150, illustrative, non-exclusive examples of which
are disclosed
herein.
[0050] Motion-arresting structures 100 may include any suitable structure
that defines
reduced-area regions 102 and/or that is configured to retain autonomous
sealing device 150
subsequent to the autonomous sealing device transitioning to expanded
configuration 154. In
addition, motion-arresting structures 100 also may be formed in any suitable
manner. As an
illustrative, non-exclusive example, the casing string may include and/or be a
monolithic
structure that includes one or more sections of casing 43 and motion-arresting
structures 100.
Under these conditions, motion-arresting structures 100 may be formed from
casing string 40
(or section(s) of casing 43 thereof). This may include forming the motion-
arresting structure
with, or concurrently with, the casing string (such as by molding, rolling,
and/or extruding the
motion-arresting structures with the casing string) and/or deforming the
casing string to form
the motion-arresting structures (such as by indenting and/or dimpling the
casing string).
[0051] As another illustrative, non-exclusive example, motion-arresting
structures 100
may be formed separately from casing string 40 (and/or sections of casing 43
thereof) and/or
may be operatively attached to the casing string. As an illustrative, non-
exclusive example,
casing collars 41 may include and/or define motion-arresting structures 100.
Under these
conditions, motion-arresting structures 100 also may be referred to herein as
motion-arresting
casing collar assemblies 101. As another illustrative, non-exclusive example,
motion-
arresting structures 100 may extend through holes in casing string 40 and thus
into casing
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conduit 44. As yet another illustrative, non-exclusive example, motion-
arresting structures
100 may be welded or otherwise secured to the inner surface of the casing
conduit.
[0052] Hydrocarbon well 30 and/or casing string 40 thereof may include any
suitable
number of motion-arresting structures 100. As illustrative, non-exclusive
examples, the
hydrocarbon well may include at least 2, at least 4, at least 6, at least 10,
at least 15, at least
20, at least 25, at least 30, at least 35, at least 40, at least 45, at least
50, at least 55, at least
60, at least 70, at least 80, at least 90, at least 100, at least 125, at
least 150, at least 200, or at
least 250 motion-arresting structures 100.
[0053] The plurality of motion-arresting structures 100 may be spaced apart
along the
length of casing string 40 at any suitable spacing, or relative spacing. As an
illustrative, non-
exclusive example, an average distance between a given motion-arresting
structure and the
next adjacent motion-arresting structure (i.e., the next motion-arresting
structure in an uphole
or downhole direction) may be at least 10 meters, at least 15 meters, at least
20 meters, at
least 30 meters, at least 40 meters, at least 50 meters, at least 60 meters,
at least 70 meters, at
least 80 meters, at least 90 meters, or at least 100 meters. Additionally or
alternatively, the
average distance between adjacent motion-arresting structures also may be less
than 300
meters, less than 250 meters, less than 200 meters, less than 175 meters, less
than 150 meters,
less than 140 meters, less than 130 meters, less than 120 meters, less than
110 meters, less
than 100 meters, less than 90 meters, less than 80 meters, less than 70
meters, less than 60
meters, less than 50 meters, less than 40 meters, or less than 30 meters.
[0054] Reduced-area regions 102 may define any suitable cross-sectional
area (or
transverse cross-sectional area) relative to the cross-sectional area (or
transverse cross-
sectional area) of casing conduit 44 (or the cross-sectional area that is
defined by inner
surface 42 of casing string 40). As illustrative, non-exclusive examples, the
transverse cross-
sectional area of reduced-area regions 102 may be at least 50%, at least 55%,
at least 60%, at
least 65%, at least 70%, at least 75%, at least 80%, at least 85%, at least
90%, or at least 95%
of the transverse cross-sectional area of the portion of the casing conduit
that is defined by
inner surface 42 of casing string 40. As another illustrative, non-exclusive
example, the
transverse cross-sectional area of reduced-area regions 102 may be less than
99%, less than
98%, less than 97%, less than 96%, less than 95%, less than 94%, less than
93%, less than
92%, less than 91%, less than 90%, less than 89%, less than 88%, less than
87%, less than
86%, or less than 85% of the transverse cross-sectional area of the portion of
the casing
conduit that is defined by the inner surface of the casing string.
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[0055] It is within the scope of the present disclosure that the plurality
of reduced-area
regions may define a respective plurality of similar, or even identical,
transverse cross-
sectional areas. However, it is also within the scope of the present
disclosure that the
plurality of reduced-area regions may not define a respective plurality of
similar transverse
cross-sectional areas and/or that a transverse cross-sectional area of a first
portion of the
plurality of reduced area regions may be different from a transverse cross-
sectional area of a
second portion of the plurality of reduced area regions.
[0056] As an illustrative, non-exclusive example, a first reduced-area
region may have a
first transverse cross-sectional area that is less than a transverse cross-
sectional area of the
remaining reduced-area regions. In addition, a second reduced-area region may
have a
second transverse cross-sectional area that is greater than a transverse cross-
sectional area of
the remaining reduced-area regions. Under these conditions, a ratio of the
first transverse
cross-sectional area to the second transverse cross-sectional area may be at
least a threshold
area ratio. Illustrative, non-exclusive examples of the threshold area ratio
include threshold
area ratios of at least 0.55, at least 0.6, at least 0.65, at least 0.7, at
least 0.75, at least 0.8, at
least 0.85, at least 0.9, at least 0.95, at least 0.96, at least 0.97, at
least 0.98, or at least 0.99.
[0057] Perforation device 170 may be operatively attached to, included in,
and/or form a
portion of autonomous sealing device 150 and may include any suitable
structure that may be
configured to create a perforation within casing string 40. As an
illustrative, non-exclusive
example, perforation device 170 may include and/or be a perforation gun that
includes one or
more perforation charges. It also is within the scope of the present
disclosure that the
systems and/or methods disclosed herein may utilize one or more perforation
devices 170 that
are not attached to, are not included in, and/or do not form a portion of an
autonomous
sealing device 150.
[0058] Illustrative, non-exclusive examples of the operation of perforation
device 170
within hydrocarbon well 30 are discussed in more detail herein. As
illustrative, non-
exclusive examples, perforation device 170 may be configured to create the
perforation prior
to, concurrent with, and/or subsequent to autonomous sealing device 150 being
retained on
the selected motion-arresting structure 100. Additionally or alternatively,
the perforation
device 170 may be configured to create the perforation responsive to the
pressure proximal to
the autonomous sealing device exceeding a threshold perforating pressure.
[0059] Casing string 40 may include and/or be any suitable structure that
defines the
portion of casing conduit 44. As an illustrative, non-exclusive example, and
as discussed, the
casing string may include a plurality of sections of casing 43 that are
operatively attached to
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one another via a plurality of casing collars 41. Under these conditions, a
distance between
adjacent casing collars (or a length of sections of casing 43) may be at least
5 meters, at least
6 meters, at least 7 meters, at least 8 meters, at least 9 meters, at least 10
meters, at least 11
meters, at least 12 meters, or at least 13 meters. Additionally or
alternatively, the distance
between adjacent casing collars also may be less than 20 meters, less than 19
meters, less
than 18 meters, less than 17 meters, less than 16 meters, less than 15 meters,
less than 14
meters, or less than 13 meters. As another illustrative, non-exclusive
example, the casing
string may include and/or be a continuous, or at least substantially
continuous, casing string,
such as may be formed by a continuous, or at least substantially continuous,
length of tubing.
[0060] It is within the scope of the present disclosure that casing string
40 may be formed
from any suitable material. As illustrative, non-exclusive examples, the
casing string may be
a metallic casing string, a non-metallic casing string, and/or a polymeric
casing string.
[0061] It is also within the scope of the present disclosure that casing
string 40 may
define any suitable (longitudinal) length. As illustrative, non-exclusive
examples, the length
of the casing string may be at least 1000 meters, at least 1500 meters, at
least 2000 meters, at
least 2500 meters, at least 3000 meters, at least 3500 meters, at least 4000
meters, at least
4500 meters, or at least 5000 meters. Additionally or alternatively, the
length of the casing
string also may be less than 10,000 meters, less than 9000 meters, less than
8000 meters, less
than 7000 meters, less than 6000 meters, less than 5000 meters, less than 4500
meters, less
than 4000 meters, less than 3500 meters, or less than 3000 meters.
[0062] The portion of the length of the casing string that includes motion-
arresting
structures 100 may include at least 25%, at least 30%, at least 35%, at least
40%, at least
45%, at least 50%, at least 55%, at least 60%, at least 65%, at least 70%, at
least 75%, at least
80%, at least 85%, or at least 90% of the (total) length of the casing string.
Additionally or
alternatively, the portion of the length also may be less than 100%, less than
95%, less than
90%, less than 85%, less than 80%, or less than 75% of the (total) length of
the casing string.
[0063] Subterranean formation 22 may include any suitable structure that
may include
and/or contain reservoir fluid 24. As illustrative, non-exclusive examples,
subterranean
formation 22 may include and/or be a hydrocarbon formation, a hydrocarbon
reservoir,
and/or an oil shale formation. In addition, reservoir fluid 24 may include any
suitable fluid,
illustrative, non-exclusive examples of which include a liquid, such as oil,
and/or a gas, such
as natural gas.
[0064] Fig. 2 is a schematic cross-sectional view of illustrative, non-
exclusive examples
of a casing string 40 and/or of a casing collar 41 that includes a motion-
arresting structure
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100 and that may be utilized with an autonomous sealing device 150 according
to the present
disclosure. As illustrated in solid lines in Fig. 2, motion-arresting
structure 100 includes an
isolation ring 110 that is configured to receive autonomous sealing device 150
and that
defines a reduced-area region 102 of a casing conduit 44. Isolation ring 100
may define a
sealing surface 112 that is configured to form a fluid seal with autonomous
sealing device
150, as indicated at 185. Additionally or alternatively, the autonomous
sealing device may be
configured to form the fluid seal with an inner surface 42 of casing string
40, as indicated at
180.
[0065] Isolation ring 110 further may include a sealing device seat 114
that is sized to
receive autonomous sealing device 150 when the autonomous sealing device is in
expanded
configuration 154 and/or to define at least a portion of sealing surface 112.
Sealing device
seat 114 may be shaped and/or contoured to complement a shape of autonomous
sealing
device 150 and thereby to enhance the fluid seal between the isolation ring
and the
autonomous sealing device.
[0066] Isolation ring 110 also may include and/or define a contoured
surface 116.
Contoured surface 116 may be shaped to permit and/or facilitate flow of
autonomous sealing
device 150 past motion-arresting structure 100 when the autonomous sealing
device is in a
contracted and/or retracted configuration (as discussed herein). Additionally
or alternatively,
contoured surface 116 also may include, be, and/or function as sealing surface
112 and/or as
sealing device seat 114.
[0067] As illustrated in dashed lines in Fig. 2, isolation ring 110 further
may include
and/or be a sliding sleeve 130 that is configured to transition between a
closed configuration
137 and an open configuration 138. This may include transitioning responsive
to retaining
autonomous sealing device 150 and/or responsive to establishing at least a
threshold pressure
differential between an uphole portion 46 of casing conduit 44 and a downhole
portion 48 of
the casing conduit.
[0068] When in closed configuration 137, sliding sleeve 130 may be
configured to
restrict, block, and/or occlude a fluid flow through an injection port 132
that is associated
therewith. However, and upon transitioning to open configuration 138, sliding
sleeve 130
may permit the fluid flow through the injection port (i.e., from the casing
string to the
subterranean formation, or vice versa). As used herein, the fluid conduit from
the casing
string to the subterranean formation additionally or alternatively referred to
as an injection
conduit 132, an injection passage 132, and/or a casing port 132, a casing-to-
wellbore 132,
and/or a casing-to-wellbore passage 132.
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[0069] Fig. 3
is a schematic cross-sectional view of an illustrative, non-exclusive
example of another motion-arresting structure 100 that may be utilized with an
autonomous
sealing device 150 according to the present disclosure. Motion-arresting
structure 100 of Fig.
3 includes a plurality of (discrete) stops 120, which also may be referred to
herein as pins 120
and/or as projections 120, that project into a casing conduit 44 and/or from
an inner surface
42 of a casing string 40 to define a reduced-area region 102. Stops 120 are
sized to retain
autonomous sealing device 150 thereon when the autonomous sealing device is in
expanded
configuration 154. However, stops 120 may not include sealing surface 112 of
Fig. 2. Thus,
autonomous motion-arresting structure 150 may be configured to form the fluid
seal with
inner surface 42, as indicated at 180.
[0070] Figs.
4-9 are illustrative, non-exclusive examples of hydrocarbon wells 30 that
include flow-arresting structures 100 and autonomous sealing devices 150
according to the
present disclosure and/or of process flows that may be utilized with the flow-
arresting
structures and the autonomous sealing devices. The flow-arresting structures
and/or the
autonomous sealing devices of Figs. 4-9 may include and/or be the flow-
arresting structures
and/or the autonomous sealing devices of Figs. 1-3 and the process flows that
are described
herein with reference to Figs. 4-9 may be utilized with hydrocarbon well 30 of
Fig. 1 without
departing from the scope of the present disclosure.
[0071] Figs.
4-5 are schematic representations of illustrative, non-exclusive examples of a
process flow that may be utilized with a hydrocarbon well 30 according to the
present
disclosure that includes a flow-arresting structure 100 that includes sliding
sleeves 130. In
Fig. 4, sliding sleeves 130 are in a closed configuration 137 and restrict
fluid flow through
injection conduits 132 that are associated therewith. As illustrated in dash-
dot lines,
autonomous sealing device 150 may flow with stimulant fluid 62 through a first
motion-
arresting structure 100 while in a contracted configuration 152.
Subsequently, the
autonomous sealing device may transition to an expanded configuration 154 and
be retained
on a second motion-arresting structure 100 (as illustrated in solid lines).
[0072] The
autonomous sealing device forms a fluid seal with the second motion-
arresting structure, thereby restricting fluid flow from an uphole portion 46
of a casing
conduit 44 to a downhole portion 48 of the casing conduit. This may permit
pressurization of
the uphole portion of the casing conduit. Then, and as illustrated in Fig. 5,
sliding sleeve 130
of the second motion-arresting structure may transition to an open
configuration 138 (such as
responsive to the pressure within the uphole portion of the casing conduit
exceeding a
threshold stimulating pressure), thereby permitting stimulant fluid 62 to flow
through
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injection conduit 132 and into subterranean formation 22, such as to stimulate
and/or fracture
the subterranean formation.
[0073] Figs. 4-5 illustrate hydrocarbon well 30 including two motion-
arresting structures
100. However, it is within the scope of the present disclosure that any
suitable number of
motion-arresting structures may be present within hydrocarbon well 30. Thus,
the above-
described process may be repeated any suitable number of times to transition
any suitable
number of sliding sleeves 130 from the closed configuration to the open
configuration and
thereby to stimulate and/or fracture any suitable number of regions, zones,
and/or portions of
subterranean formation 22.
[0074] Figs. 6-7 are schematic representations of illustrative, non-
exclusive examples of
another process flow that may be utilized with a hydrocarbon well 30 according
to the present
disclosure that includes an autonomous sealing device 150 that includes and/or
is operatively
attached to a perforation device 170. As illustrated in dash-dot lines in Fig.
6, autonomous
sealing device 150 and perforation device 170 may flow with stimulant fluid 62
through a
first motion-arresting structure 100 while autonomous sealing device 150 is in
a contracted
configuration 152. Subsequently, the autonomous sealing device may transition
to an
expanded configuration 154 and be retained on a second motion-arresting
structure 100 (as
illustrated in solid lines).
[0075] The autonomous sealing device forms a fluid seal with the second
motion-
arresting structure, thereby restricting fluid flow from an uphole portion 46
of a casing
conduit 44 to a downhole portion 48 of the casing conduit. This may permit
pressurization of
the uphole portion of the casing conduit. Then, and as illustrated in Fig. 7,
perforation device
170 may create one or more perforations 172 within a casing string 40 that
defines casing
conduit 44 (such as responsive to the pressure within the uphole portion of
the casing conduit
exceeding a threshold perforating pressure). This may permit stimulant fluid
62 to flow
through perforations 172 into subterranean formation 22, such as to stimulate
and/or fracture
the subterranean formation.
[0076] Figs. 6-7 illustrate hydrocarbon well 30 with only two motion-
arresting structures
100. However, and as discussed herein with reference to Figs. 4-5, hydrocarbon
well 30 may
include any suitable number of motion-arresting structures 100 and the above-
described
process may be repeated any suitable number of times to simulate and/or
fracture any suitable
number of regions, zones, and/or portions of subterranean formation 22.
[0077] Figs. 8-9 are schematic representations of illustrative, non-
exclusive examples of
another process flow that may be utilized with a hydrocarbon well 30 according
to the present
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disclosure that includes a motion-arresting structure 100, an autonomous
sealing device 150,
and a hydraulically actuated sleeve 74. In Fig. 8, hydraulically actuated
sleeve 74 is in a
closed configuration 77 and restricts fluid flow through a sleeve port 76 that
is associated
therewith. As illustrated in dash-dot lines, autonomous sealing device 150 may
flow with
stimulant fluid 62 through a first motion-arresting structure 100 while in a
contracted
configuration 152. Subsequently, the autonomous sealing device may transition
to an
expanded configuration 154 and be retained on a second motion-arresting
structure 100 (as
illustrated in sold lines).
[0078] The autonomous sealing device forms a fluid seal with the second
motion-
arresting structure, thereby restricting fluid flow from an uphole portion 46
of a casing
conduit 44 to a downhole portion 48 of the casing conduit. This may permit
pressurizing of
the uphole portion of the casing conduit. Then, and as illustrated in Fig. 9,
hydraulically
actuated sleeve 74 may transition to an open configuration 78 (such as
responsive to the
pressure within the uphole portion of the casing conduit exceeding a threshold
stimulating
pressure and/or a pressure differential between the uphole portion of the
casing conduit and
the subterranean formation exceeding a threshold pressure differential),
thereby permitting
stimulant fluid 62 to flow through sleeve port 76 and into subterranean
formation 22, such as
to stimulate and/or fracture the subterranean formation.
[0079] Figs. 8-9 illustrate hydrocarbon well 30 as including only two
motion-arresting
structures 100 and a single hydraulically actuated sleeve 74. However, and as
discussed
herein with reference to Figs. 4-7, hydrocarbon well 30 may include any
suitable number of
motion-arresting structures 100 and/or hydraulically actuated sleeves 74 and
the above-
described process may be repeated any suitable number of times to stimulate
and/or fracture
any suitable number of regions, zones, and/or portions of subterranean
formation 22.
[0080] Fig. 10 is a flowchart depicting methods according to the present
disclosure of
restricting fluid flow between an uphole portion of a casing conduit and a
downhole portion
of the casing conduit. The casing conduit is partially defined by a casing
string that extends
within a wellbore that is defined within a subterranean formation. In
addition, the casing
string includes, contains, and/or is operatively attached to a plurality of
motion-arresting
structures that are spaced apart from one another along a (longitudinal)
length of the casing
string. The motion-arresting structures project from an inner surface of the
casing string to
define a plurality of reduced-area regions of the casing conduit.
[0081] Methods 200 may include locating an autonomous sealing device within
the
casing conduit at 205 and/or supplying a stimulant fluid to the casing conduit
at 210.
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Methods 200 include conveying the autonomous sealing device within the casing
conduit at
215 and may include detecting a variable associated with the autonomous
sealing device at
220. Methods 200 further include determining that the autonomous sealing
device is located
within a target portion of the casing conduit at 225, expanding the autonomous
sealing device
at 230, retaining the autonomous sealing device on a selected motion-arresting
structure at
235, and restricting fluid flow between an uphole portion of the casing
conduit and a
downhole portion of the casing conduit at 240. Methods 200 further may include
stimulating
the subterranean formation at 245, repeating the methods at 250, removing the
autonomous
sealing device from the casing conduit at 255, and/or producing a reservoir
fluid from the
subterranean formation at 260.
[0082] Locating the autonomous sealing device within the casing conduit at
205 may
include locating any suitable autonomous sealing device, such as autonomous
sealing device
150 of Figs. 1-9, within the casing conduit in any suitable manner. As an
illustrative, non-
exclusive example, the locating at 205 may include placing the autonomous
sealing device
within the casing conduit and/or lubricating the autonomous sealing device
into the casing
conduit. Additionally or alternatively, the locating at 205 also may include
transferring the
autonomous sealing device from a surface region into the casing conduit.
[0083] Supplying the stimulant fluid to the casing conduit at 210 may
include supplying
any suitable stimulant fluid, illustrative, non-exclusive examples of which
are disclosed
herein, to the casing conduit. This may include pumping the stimulant fluid
into the casing
conduit. It is within the scope of the present disclosure that, when methods
200 include the
supplying at 210, the supplying at 210 may include (at least substantially)
continuously
supplying the stimulant fluid to the casing conduit during a remainder of
methods 200 and/or
supplying the stimulant fluid to the casing conduit during at least the
conveying at 215, the
determining at 225, the expanding at 230, the retaining at 235, and/or the
restricting at 240.
[0084] Conveying the autonomous sealing device within the casing conduit at
215 may
include conveying while the autonomous sealing device is in a contracted
configuration
and/or conveying the autonomous sealing device through at least a portion of
the plurality of
reduced-area regions. As an illustrative, non-exclusive example, the conveying
at 215 may
include hydraulically conveying, such as by flowing the autonomous sealing
device with the
stimulant fluid that is provided during the supplying at 210. As another
illustrative, non-
exclusive example, the conveying at 215 also may include mechanically
conveying, such as
by tractoring the autonomous sealing device into, along, and/or through the
casing conduit.
As yet another illustrative, non-exclusive example, the conveying at 215 may
include
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conveying the autonomous sealing device along the (longitudinal) length of the
casing string
under the influence of gravity.
[0085] It is within the scope of the present disclosure that the conveying
at 215 may
include conveying at any suitable speed and/or velocity, including relatively
high speeds
and/or velocities. As illustrative, non-exclusive examples, the conveying at
215 may include
conveying at a speed and/or velocity of at least 2 meters per second (m/s), at
least 4 m/s, at
least 6 m/s, at least 8 m/s, at least 10 m/s, at least 12 m/s, at least 14
m/s, at least 16 m/s, at
least 18 m/s, at least 20 m/s, at least 22 m/s, at least 24 m/s, at least 26
m/s, at least 28 m/s, or
at least 30 m/s.
[0086] Detecting the variable associated with the autonomous sealing device
at 220 may
include detecting any suitable variable that may be associated with the
autonomous sealing
device. This may include detecting with any suitable detector and/or utilizing
any suitable
autonomous controller, such as autonomous controller 160 of Fig. 1.
Illustrative, non-
exclusive examples of the variable associated with the autonomous sealing
device are
disclosed herein. When methods 200 include the detecting at 220, it is within
the scope of
the present disclosure that the determining at 225 may be based, at least in
part, on the
detecting at 220 and/or based, at least in part, on the variable associated
with the autonomous
sealing device.
[0087] Determining that the autonomous sealing device is located within the
target
portion of the casing conduit at 225 may include determining in any suitable
manner. As an
illustrative, non-exclusive example, the determining at 225 may include
determining that the
variable associated with the autonomous sealing device is equal to, is greater
than, and/or is
less than a threshold value. As more specific but still illustrative, non-
exclusive examples,
the determining at 225 may include determining that the autonomous sealing
device has
reached a target depth within the subterranean formation, determining that the
autonomous
sealing device has traversed a target (longitudinal) length of the casing
conduit and/or of the
casing string, determining that the autonomous sealing device has been
conveyed through a
target number of reduced-area regions, and/or determining that the autonomous
sealing
device has been conveyed past a target number of casing collars (such as
casing collar 41 of
Figs. 1-9).
[0088] Expanding the autonomous sealing device at 230 may include expanding
the
autonomous sealing device based, at least in part, on the determining at 225
and/or expanding
the autonomous sealing device responsive to the determining at 225. The
expanding at 230
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may include automatically expanding, such as by expanding without the
autonomous sealing
device receiving an external input.
[0089] It is within the scope of the present disclosure that the expanding
at 230 may
include completely expanding prior to the retaining at 235. However, it is
also within the
scope of the present disclosure that the expanding at 230 may include
partially expanding
prior to the retaining at 235, with complete expansion to the expanded state
being
accomplished subsequent to the retaining at 235.
[0090] The expanding at 235 may be initiated such that the autonomous
sealing device is
retained on the selected motion-arresting structure. As such, initiation of
the expanding at
235 may be based, at least in part, on the velocity and/or acceleration of the
autonomous
sealing device within the casing conduit and/or upon a distance between the
autonomous
sealing device and the selected motion-arresting structure.
[0091] It is within the scope of the present disclosure that the expanding
at 235 may be
accomplished in any suitable manner. As an illustrative, non-exclusive
example, the
expanding at 235 may include triggering an expansion mechanism, such as
expansion
mechanism 158 of Fig. 1, illustrative, non-exclusive examples of which are
disclosed herein.
[0092] Retaining the autonomous sealing device on the selected motion-
arresting
structure at 235 may include retaining the autonomous sealing device on any
suitable motion-
arresting structure, such as motion-arresting structure 100 of Figs. 1-9. As
an illustrative,
non-exclusive example, and subsequent to the expanding at 230, the autonomous
sealing
device may no longer be sized to pass through the plurality of reduced area
regions, causing
the autonomous sealing device to be retained on the selected motion-arresting
structure. As
another illustrative, non-exclusive example, the retaining at 235 may include
ceasing a
motion of the autonomous sealing device along the (longitudinal) length of the
casing string.
As additional illustrative, non-exclusive examples, the retaining at 235 may
include
mechanically, physically, and/or directly contacting the autonomous sealing
device with the
selected motion-arresting structure to retain the autonomous sealing device on
the selected
motion-arresting structure.
[0093] Restricting fluid flow between the uphole portion of the casing
conduit and the
downhole portion of the casing conduit at 240 may include restricting,
blocking, limiting,
occluding, and/or eliminating the fluid flow with the autonomous sealing
device. This may
include forming a fluid seal between the autonomous sealing device and the
selected motion-
arresting structure and/or forming a fluid seal between the autonomous sealing
device and the
inner surface of the casing string. As an illustrative, non-exclusive example,
the restricting at
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240 may include fluidly isolating the uphole portion of the casing conduit
from the downhole
portion of the casing conduit. This may include resisting fluid flow from the
uphole portion
of the casing conduit into the downhole portion of the casing conduit and/or
resisting fluid
flow from the downhole portion of the casing conduit into the uphole portion
of the casing
conduit.
[0094] Stimulating the subterranean formation at 245 may include
stimulating the
subterranean formation in any suitable manner. As illustrative, non-exclusive
examples, the
stimulating may include fracturing the subterranean formation and/or acid
treating the
subterranean formation. This may include supplying the stimulant fluid to the
subterranean
formation, and it is within the scope of the present disclosure that the
stimulant fluid may be
supplied to the subterranean formation subsequent to the retaining at 235,
responsive to the
retaining at 235, and/or responsive to a pressure within the casing conduit
exceeding a
threshold stimulating pressure.
[0095] As an illustrative, non-exclusive example, the stimulating at 245
may include
translating a sliding sleeve at 246. This may include opening an injection
conduit, such as
injection conduit 132 of Figs. 1-2 and 4-5, that is associated with the
sliding sleeve, such as
sliding sleeve 130 of Figs. 1-2 and 4-5, to establish fluid communication, via
the injection
port, between the casing conduit and the subterranean formation. Additionally
or
alternatively, this also may include opening a sleeve port, such as sleeve
port 76 of Figs. 1
and 8-9, that is associated with a hydraulically actuated sleeve, such as
hydraulically actuated
sleeve 74 of Figs. 1 and 8-9.
[0096] As yet another illustrative, non-exclusive example, the stimulating
at 245 also
may include perforating the casing string at 247. As an illustrative, non-
exclusive example,
the autonomous sealing device may be operatively attached to and/or may
include a
perforation device, such as perforation device 170 of Figs. 1 and 5-6, and the
perforating at
247 may include creating a perforation within the casing string to establish
fluid
communication, via the perforation, between the casing conduit and the
subterranean
formation.
[0097] Repeating the methods at 250 may include repeating any suitable
portion of
methods 200. As an illustrative, non-exclusive example, the autonomous sealing
device may
be a first autonomous sealing device, the selected motion-arresting structure
may be a first
selected motion-arresting structure, the downhole portion of the casing
conduit may be a first
downhole portion of the casing conduit, and the uphole portion of the casing
conduit may be
a first uphole portion of the casing conduit. Under these conditions, the
repeating at 250 may
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include repeating at least the conveying at 215, the determining at 225, the
expanding at 230,
the retaining at 235, and the restricting at 240 to retain a second (or
subsequent) autonomous
sealing device on a second (or subsequent) selected motion-arresting structure
that is uphole
from the first motion-arresting structure and to restrict fluid flow between a
second (or
subsequent) uphole portion of the casing conduit and a second (or subsequent)
downhole
portion of the casing conduit.
[0098] Additionally, the stimulating at 245 may include stimulating a first
region of the
subterranean formation and the repeating at 250 may include repeating the
stimulating at 245
to stimulate a second (or subsequent) region of the subterranean formation
that is uphole from
the first region of the subterranean formation.
[0099] It is within the scope of the present disclosure that the repeating
at 250 may
include repeating any suitable portion of methods 200 any suitable number of
times to restrict
fluid flow between any suitable number of uphole portions of the casing
conduit and a
corresponding number of downhole portions of the casing conduit and/or to
stimulate any
suitable number of regions of the subterranean formation. As illustrative, non-
exclusive
examples, the repeating at 250 may include repeating at least 2, at least 4,
at least 6, at least
10, at least 15, at least 20, at least 25, at least 30, at least 35, at least
40, at least 45, at least
50, at least 55, at least 60, at least 70, at least 80, at least 90, at least
100, at least 125, at least
150, at least 200, or at least 250 times.
[00100] Removing the autonomous sealing device from the casing conduit at 255
may
include removing the autonomous sealing device in any suitable manner. As an
illustrative,
non-exclusive example, and subsequent to the restricting at 240, the
stimulating at 245,
and/or the repeating at 250, the autonomous sealing device may be configured
to transition
(from the expanded configuration) to a retracted configuration and, in the
retracted
configuration, the autonomous sealing device may be sized to be removed from
the casing
conduit and/or to pass through the plurality of reduced-area regions (in an
uphole and/or
downhole direction). As another illustrative, non-exclusive example, the
removing at 255
also may include flowing the autonomous sealing device to the surface region.
As yet
another illustrative, non-exclusive example, the removing at 255 may include
shrinking,
retracting, breaking apart, and/or dissolving the autonomous sealing device to
permit and/or
to accomplish the removing at 255.
[00101] Producing the reservoir fluid from the subterranean formation at 260
may include
producing any suitable reservoir fluid, illustrative, non-exclusive examples
of which are
disclosed herein, in any suitable manner. This may include producing without
drilling
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(and/or otherwise removing) a bridge plug from the casing conduit and/or
producing without
drilling (and/or otherwise removing) an isolation ball (or a plurality of
differently sized
isolation balls) from the casing conduit.
[00102] As discussed, the systems and methods disclosed herein are
illustrative, non-
exclusive examples; and it is within the scope of the present disclosure that
autonomous
sealing devices and motion-arresting structures according to the present
disclosure may be
utilized with and/or within any suitable systems and/or methods. As
illustrative, non-
exclusive examples, hydrocarbon wells 30 according to the present disclosure
further may
include and/or otherwise utilize one or more perforation guns, chemical
treatment devices,
and/or data recording devices that are not directly coupled to or integrated
with an
autonomous sealing device or motion-arresting structure. As additional
illustrative, non-
exclusive examples, methods 200 according to the present disclosure further
may include
perforating a casing string with the perforation gun, chemically treating any
suitable portion
of hydrocarbon well 30 and/or of subsurface region 20, and/or collecting
and/or recording
any suitable data and/or process parameter that is related to hydrocarbon well
30 and/or to
subsurface region 20. Furthermore, such methods may do so in conjunction with
and/or
independent of the utilization of the specific configuring and/or locating of
the motion-
arresting structures.
[00103] In the present disclosure, several of the illustrative, non-
exclusive examples have
been discussed and/or presented in the context of flow diagrams, or flow
charts, in which the
methods are shown and described as a series of blocks, or steps. Unless
specifically set forth
in the accompanying description, it is within the scope of the present
disclosure that the order
of the blocks may vary from the illustrated order in the flow diagram,
including with two or
more of the blocks (or steps) occurring in a different order and/or
concurrently. It is also
within the scope of the present disclosure that the blocks, or steps, may be
implemented as
logic, which also may be described as implementing the blocks, or steps, as
logics. In some
applications, the blocks, or steps, may represent expressions and/or actions
to be performed
by functionally equivalent circuits or other logic devices. The illustrated
blocks may, but are
not required to, represent executable instructions that cause a computer,
processor, and/or
other logic device to respond, to perform an action, to change states, to
generate an output or
display, and/or to make decisions.
[00104] As used herein, the term "and/or" placed between a first entity and a
second entity
means one of (1) the first entity, (2) the second entity, and (3) the first
entity and the second
entity. Multiple entities listed with "and/or" should be construed in the same
manner, i.e.,
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"one or more" of the entities so conjoined. Other entities may optionally be
present other
than the entities specifically identified by the "and/or" clause, whether
related or unrelated to
those entities specifically identified. Thus, as a non-limiting example, a
reference to "A
and/or B," when used in conjunction with open-ended language such as
"comprising" may
refer, in one embodiment, to A only (optionally including entities other than
B); in another
embodiment, to B only (optionally including entities other than A); in yet
another
embodiment, to both A and B (optionally including other entities). These
entities may refer
to elements, actions, structures, steps, operations, values, and the like.
[00105] As used herein, the phrase "at least one," in reference to a list of
one or more
entities should be understood to mean at least one entity selected from any
one or more of the
entity in the list of entities, but not necessarily including at least one of
each and every entity
specifically listed within the list of entities and not excluding any
combinations of entities in
the list of entities. This definition also allows that entities may optionally
be present other
than the entities specifically identified within the list of entities to which
the phrase "at least
one" refers, whether related or unrelated to those entities specifically
identified. Thus, as a
non-limiting example, "at least one of A and B" (or, equivalently, "at least
one of A or B," or,
equivalently "at least one of A and/or B") may refer, in one embodiment, to at
least one,
optionally including more than one, A, with no B present (and optionally
including entities
other than B); in another embodiment, to at least one, optionally including
more than one, B,
with no A present (and optionally including entities other than A); in yet
another
embodiment, to at least one, optionally including more than one, A, and at
least one,
optionally including more than one, B (and optionally including other
entities). In other
words, the phrases "at least one," "one or more," and "and/or" are open-ended
expressions
that are both conjunctive and disjunctive in operation. For example, each of
the expressions
"at least one of A, B and C," "at least one of A, B, or C," "one or more of A,
B, and C," "one
or more of A, B, or C" and "A, B, and/or C" may mean A alone, B alone, C
alone, A and B
together, A and C together, B and C together, A, B and C together, and
optionally any of the
above in combination with at least one other entity.
[00106] In the event that any patents, patent applications, or other
references are
incorporated by reference herein and (1) define a term in a manner that is
inconsistent with
and/or (2) are otherwise inconsistent with, either the non-incorporated
portion of the present
disclosure or any of the other incorporated references, the non-incorporated
portion of the
present disclosure shall control, and the term or incorporated disclosure
therein shall only
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control with respect to the reference in which the term is defined and/or the
incorporated
disclosure was present originally.
[00107] As used herein the terms "adapted" and "configured" mean that the
element,
component, or other subject matter is designed and/or intended to perform a
given function.
Thus, the use of the terms "adapted" and "configured" should not be construed
to mean that a
given element, component, or other subject matter is simply "capable of"
performing a given
function but that the element, component, and/or other subject matter is
specifically selected,
created, implemented, utilized, programmed, and/or designed for the purpose of
performing
the function. It is also within the scope of the present disclosure that
elements, components,
and/or other recited subject matter that is recited as being adapted to
perform a particular
function may additionally or alternatively be described as being configured to
perform that
function, and vice versa.
Industrial Applicability
[00108] The systems and methods disclosed herein are applicable to the oil and
gas
industry.
[00109] It is believed that the disclosure set forth above encompasses
multiple distinct
inventions with independent utility. While each of these inventions has been
disclosed in its
preferred form, the specific embodiments thereof as disclosed and illustrated
herein are not to
be considered in a limiting sense as numerous variations are possible. The
subject matter of
the inventions includes all novel and non-obvious combinations and
subcombinations of the
various elements, features, functions and/or properties disclosed herein.
Similarly, where the
claims recite "a" or "a first" element or the equivalent thereof, such claims
should be
understood to include incorporation of one or more such elements, neither
requiring nor
excluding two or more such elements.
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