U.S. patent application number 14/446132 was filed with the patent office on 2015-03-05 for systems and methods for restricting fluid flow in a wellbore with an autonomous sealing device and motion-arresting structures.
The applicant listed for this patent is Renzo M. Angeles Boza, Eric R. Grueschow, Krishnan Kumaran, Timothy I. Morrow, Randy C. Tolman. Invention is credited to Renzo M. Angeles Boza, Eric R. Grueschow, Krishnan Kumaran, Timothy I. Morrow, Randy C. Tolman.
Application Number | 20150060056 14/446132 |
Document ID | / |
Family ID | 51355664 |
Filed Date | 2015-03-05 |
United States Patent
Application |
20150060056 |
Kind Code |
A1 |
Kumaran; Krishnan ; et
al. |
March 5, 2015 |
Systems and Methods for Restricting Fluid Flow in a Wellbore with
an Autonomous Sealing Device and Motion-Arresting Structures
Abstract
Systems and methods for restricting fluid flow in a casing
conduit, including 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 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.
Inventors: |
Kumaran; Krishnan; (Raritan,
NJ) ; Tolman; Randy C.; (Spring, TX) ; Angeles
Boza; Renzo M.; (Houston, TX) ; Morrow; Timothy
I.; (Humble, TX) ; Grueschow; Eric R.;
(Houston, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Kumaran; Krishnan
Tolman; Randy C.
Angeles Boza; Renzo M.
Morrow; Timothy I.
Grueschow; Eric R. |
Raritan
Spring
Houston
Humble
Houston |
NJ
TX
TX
TX
TX |
US
US
US
US
US |
|
|
Family ID: |
51355664 |
Appl. No.: |
14/446132 |
Filed: |
July 29, 2014 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
61871675 |
Aug 29, 2013 |
|
|
|
Current U.S.
Class: |
166/250.01 ;
166/101 |
Current CPC
Class: |
E21B 44/005
20130101 |
Class at
Publication: |
166/250.01 ;
166/101 |
International
Class: |
E21B 44/00 20060101
E21B044/00 |
Claims
1. A hydrocarbon well, comprising: a wellbore that extends within a
subterranean formation; a casing string that extends within the
wellbore and has an inner surface, which defines a portion of a
casing conduit; a plurality of motion-arresting structures that are
spaced apart from one another along a portion of a longitudinal
length of the casing string, wherein the plurality of
motion-arresting structures projects from the 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, wherein the
autonomous sealing device: (i) is sized to flow through the
plurality of reduced-area regions when in the contracted
configuration; (ii) is sized to be retained on a selected
motion-arresting structure of the plurality of motion-arresting
structures upon transitioning to the expanded configuration; and
(iii) restricts fluid flow between an uphole portion of the casing
conduit and a downhole portion of the casing conduit upon being
retained on the selected motion-arresting structure.
2. The well of claim 1, wherein the autonomous sealing device is
programmed to transition to the expanded configuration responsive
to being located within a target portion of the casing conduit.
3. The well of claim 1, wherein the autonomous sealing device is
not operatively attached to any of a wireline, a working line, and
tubing.
4. The well of claim 1, wherein the autonomous sealing device is
configured to form a fluid seal with the selected motion-arresting
structure to restrict the fluid flow when the autonomous sealing
device is in the expanded configuration.
5. The well of claim 4, wherein the selected motion-arresting
structure defines a sealing surface that is sized to form the fluid
seal with the autonomous sealing device.
6. The well of claim 1, wherein the autonomous sealing device is
configured to form a fluid seal with the inner surface of the
casing string to restrict the fluid flow when the autonomous
sealing device is in the expanded configuration.
7. The well of claim 1, wherein the autonomous sealing device
includes an expansion mechanism that is configured to transition
the autonomous sealing device to the expanded configuration.
8. The well of claim 7, wherein the expansion mechanism includes at
least one of an explosive charge, a mechanical actuator, an
electric actuator, a hydraulic actuator, a chemical reaction, and a
material that swells upon contact with a wellbore fluid.
9. The well of claim 1, wherein the autonomous sealing device is
further configured to transition from the expanded configuration to
a retracted configuration, wherein, in the retracted configuration,
the autonomous sealing device is sized to flow through the
plurality of reduced-area regions and permits fluid flow between
the uphole portion of the casing conduit and the downhole portion
of the casing conduit.
10. The well of claim 1, wherein, subsequent to transitioning to
the expanded configuration, the autonomous sealing device is
further configured to at least one of break apart and dissolve to
permit fluid flow between the uphole portion of the casing conduit
and the downhole portion of the casing conduit.
11. The well of claim 1, wherein the autonomous sealing device is
further configured to release a supplemental material into the
casing conduit subsequent to transitioning to the expanded
configuration.
12. The well of claim 11, wherein the well includes a plurality of
autonomous sealing devices, and further wherein each of the
plurality of autonomous sealing devices includes a unique tracer
material that comprises the supplemental material.
13. The well of claim 1, wherein the autonomous sealing device at
least one of includes and is operatively attached to a perforation
device that is configured to create a perforation within the casing
string.
14. The well of claim 1, wherein the plurality of motion-arresting
structures include a plurality of isolation rings that are
operatively attached to the inner surface of the casing string,
wherein the plurality of isolation rings define a plurality of
similarly sized reduced-area regions.
15. The well of claim 1, wherein the plurality of motion-arresting
structures includes a plurality of stops that project from the
inner surface of the casing string.
16. The well of claim 1, wherein each of the plurality of
reduced-area regions of the casing conduit defines a respective
transverse cross-sectional area that is at least 50% and less than
99% of a transverse cross-sectional area of the portion of the
casing conduit that is defined by the inner surface of the casing
string.
17. The well of claim 1, wherein the plurality of motion-arresting
structures includes a plurality of sliding sleeves, wherein each of
the plurality of sliding sleeves is associated with a respective
injection port that extends between the casing conduit and the
wellbore, wherein each of the plurality of sliding sleeves is
configured to selectively restrict fluid flow through the
respective injection port prior to the autonomous sealing device
being retained thereon, and further wherein each of the plurality
of sliding sleeves is configured to selectively permit fluid flow
through the respective injection port responsive to the autonomous
sealing device being retained thereon.
18. The well of claim 1, wherein the well further includes a
hydraulically actuated sleeve that is located uphole from the
selected motion-arresting structure, wherein the hydraulically
actuated sleeve is associated with a sleeve port that extends
between the casing conduit and the wellbore, wherein the
hydraulically actuated sleeve is constructed to selectively
transition from a closed configuration, wherein the hydraulically
actuated sleeve resists a fluid flow through the sleeve port, and
an open configuration, wherein the hydraulically actuated sleeve
permits the fluid flow through the sleeve port responsive to a
pressure differential between a portion of the casing conduit that
is proximal to the hydraulically actuated sleeve and a portion of
the subterranean formation that is proximal to the hydraulically
actuated sleeve exceeding a threshold sleeve actuation
pressure.
19. The well of claim 1, wherein the autonomous sealing device
includes an autonomous controller that is programmed to control the
operation of the autonomous sealing device.
20. The well of claim 19, wherein 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, at least in part, on
the determined location.
21. A method of restricting fluid flow between an uphole portion of
a casing conduit and a downhole portion of the casing conduit,
wherein the casing conduit is partially defined by a casing string
that extends within a wellbore that is defined within a
subterranean formation, and further wherein the casing string
includes a plurality of motion-arresting structures, wherein the
plurality of motion-arresting structures is spaced apart from one
another along a portion of a longitudinal length of the casing
string and project from an inner surface of the casing string to
define a plurality of reduced-area regions of the casing conduit,
the method comprising: conveying an autonomous sealing device
through the casing conduit, wherein the conveying includes
conveying the autonomous sealing device through a portion of the
plurality of reduced-area regions while the autonomous sealing
device is in a contracted configuration; determining that the
autonomous sealing device is located within a target portion of the
casing conduit; responsive to the determining, expanding the
autonomous sealing device to an expanded configuration; retaining
the autonomous sealing device on a selected motion-arresting
structure of the plurality of motion-arresting structures; and
restricting fluid flow between an uphole portion of the casing
conduit and a downhole portion of the casing conduit with the
autonomous sealing device.
22. The method of claim 21, wherein the method further includes
supplying a stimulant fluid to the casing conduit, and further
wherein the conveying includes flowing the autonomous sealing
device within the stimulant fluid.
23. The method of claim 21, wherein the method further includes
detecting a variable associated with the autonomous sealing
device.
24. The method of claim 23, wherein the variable associated with
the autonomous sealing device includes at least one of 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, a depth of
the autonomous sealing device below a ground surface, and a number
of casing collars that the autonomous sealing device has traveled
past while located within the casing conduit.
25. The method of claim 23, wherein the determining is based, at
least in part, on the variable associated with the autonomous
sealing device.
26. The method of claim 21, wherein the expanding includes
automatically expanding without receiving an external input by the
autonomous sealing device.
27. The method of claim 21, wherein the restricting includes
forming a fluid seal with the selected motion-arresting
structure.
28. The method of claim 21, wherein the restricting includes
forming a fluid seal with the inner surface of the casing
string.
29. The method of claim 21, wherein the method further includes
removing the autonomous sealing device from the casing conduit.
30. The method of claim 29, wherein the removing includes
transitioning the autonomous sealing device from the expanded
configuration to a retracted configuration to permit the removing,
wherein, in the retracted configuration, the autonomous sealing
device is sized to be conveyed through the plurality of
reduced-area regions.
31. The method of claim 29, wherein the removing includes at least
one of shrinking the autonomous sealing device, retracting the
autonomous sealing device, breaking apart the autonomous sealing
device, and dissolving the autonomous sealing device to permit the
removing.
32. The method of claim 21, wherein the method further includes
stimulating the subterranean formation.
33. The method of claim 32, wherein the stimulating includes
supplying a stimulant fluid to the subterranean formation.
34. The method of claim 33, wherein the plurality of
motion-arresting structures includes a plurality of sliding
sleeves, wherein each of the plurality of sliding sleeves is
associated with a respective injection port that extends between
the casing conduit and the wellbore, wherein each of the plurality
of sliding sleeves is configured to selectively restrict fluid flow
through the respective injection port prior to the autonomous
sealing device being retained thereon, wherein each of the
plurality of sliding sleeves is configured to selectively permit
fluid flow through the respective injection port responsive to the
autonomous sealing device being retained thereon, and further
wherein the supplying includes translating a sliding sleeve that is
associated with the selected motion-arresting structure to permit
the fluid flow through the injection port that is associated with
the selected motion-arresting structure.
35. The method of claim 33, wherein the casing string includes a
hydraulically actuated sleeve that is located uphole from the
selected motion-arresting structure, wherein the hydraulically
actuated sleeve is associated with a sleeve port that extends
between the casing conduit and the wellbore, wherein the
hydraulically actuated sleeve is constructed to selectively
transition from a closed configuration, wherein the hydraulically
actuated sleeve resists a fluid flow through the sleeve port, and
an open configuration, wherein the hydraulically actuated sleeve
permits the fluid flow through the sleeve port, responsive to a
pressure differential between a portion of the casing conduit that
is proximal to the hydraulically actuated sleeve and a portion of
the subterranean formation that is proximal to the hydraulically
actuated sleeve exceeding a threshold sleeve actuation pressure,
and further wherein the supplying includes transitioning the
hydraulically actuated sleeve from the closed configuration to the
open configuration to permit the fluid flow through the sleeve
port.
36. The method of claim 33, wherein the autonomous sealing device
is operatively attached to a perforation device, and further
wherein the stimulating includes perforating the casing string to
permit the supplying.
37. The method of claim 21, wherein the autonomous sealing device
is a first autonomous sealing device, wherein the selected
motion-arresting structure is a first selected motion-arresting
structure, wherein the downhole portion of the casing conduit is a
first downhole portion of the casing conduit, wherein the uphole
portion of the casing conduit is a first uphole portion of the
casing conduit, and further wherein the method includes repeating
at least the conveying, the determining, the expanding, the
retaining, and the restricting 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.
38. The method of claim 21, wherein the method further includes
producing a reservoir fluid from the subterranean formation.
Description
CROSS REFERENCE TO RELATED APPLICATIONS
[0001] This application claims the benefit of U.S. Provisional No.
61/871,675, filed Aug. 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.
[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.
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.
[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.
[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 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 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 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.
[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 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 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.
[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 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.
[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 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 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.
[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 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 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. 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 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
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 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 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.
[0100] 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.
[0101] 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 (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.
[0102] 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.
[0103] 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.
[0104] 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., "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.
[0105] 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.
[0106] 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 control
with respect to the reference in which the term is defined and/or
the incorporated disclosure was present originally.
[0107] 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
[0108] The systems and methods disclosed herein are applicable to
the oil and gas industry.
[0109] 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.
* * * * *