Note: Descriptions are shown in the official language in which they were submitted.
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FLUID COMMUNICATION METHOD FOR HYDRAULIC FRACTURING
CROSS REFERENCE TO RELATED APPLICATIONS
[0001] This application claims benefit to U.S. Application No. 16/899,344,
filed June 11, 2020,
which is incorporated by reference in its entirety.
TECHNICAL FIELD
[0002] The present disclosure relates generally solutions for preventing
erosive enlargement of
fluid communication holes in a wellbore casing and in particular, to the
fitting of casing
perforations with wear-resistant inserts to protect against erosion and ensure
consistent
perforation aperture size.
BACKGROUND
[0003] To obtain hydrocarbons such as oil and gas, wellbores are typically
drilled by rotating a
drill bit that is attached at the end of the drill string. Modern drilling
systems frequently employ
a drill string having a bottom hole assembly and a drill bit at an end
thereof. The drill bit is
rotated by a downhole motor of the bottom hole assembly and/or by rotating the
drill string.
Pressurized drilling fluid is pumped through the drill string to power the
downhole motor,
provide lubrication and cooling to the drill bit and other components, and
carry away formation
cuttings.
[0004] A large proportion of drilling activity involves directional drilling,
e.g., drilling
deviated, branch, and/or horizontal wellbores. In directional drilling,
wellbores are usually
drilled along predetermined paths in order to increase the hydrocarbon
production. As the
drilling of the wellbore proceeds through various formations, the downhole
operating conditions
may change, and the operator must react to such changes and adjust parameters
to maintain the
predetermined drilling path and optimize the drilling operations. The drilling
operator typically
adjusts the surface-controlled drilling parameters, such as the weight on bit,
drilling fluid flow
through the drill string, the drill string rotational speed, and the density
and/or viscosity of the
drilling fluid, to affect the drilling operations.
BRIEF DESCRIPTION OF THE DRAWINGS
[0005] In order to describe the manner in which the above-recited and other
advantages and
features of the disclosure can be obtained, a more particular description of
the principles briefly
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described above will be rendered by reference to specific embodiments thereof
which are
illustrated in the appended drawings. Understanding that these drawings depict
only exemplary
embodiments of the disclosure and are not therefore to be considered to be
limiting of its scope,
the principles herein are described and explained with additional specificity
and detail through
the use of the accompanying drawings in which:
[0006] FIG. lA is a schematic diagram of an example drilling environment, in
accordance with
various aspects of the subject technology.
[0007] FIG. 1B is a schematic diagram of an example wireline logging
environment, in
accordance with various aspects of the subject technology.
[0008] FIG. 2 illustrates steps of an example process for constructing a
wellbore casing string,
according to some aspects of the disclosed technology.
[0009] FIG. 3 is a cut-away view of a casing string with multiple casing
sections, according to
some aspects of the disclosed technology.
[0010] FIG. 4A illustrate cut away views example inserts that contain plugs,
according to some
aspects of the disclosed technology.
[0011] FIG. 4B illustrates a cut away view of a wellbore including a casing
section containing
an insert, according to some aspects of the disclosed technology.
[0012] FIG. 5A is a cut away view of a wellbore and a casing string in which a
detonating cord
is configured to remove a casing plug, according to some aspects of the
disclosed technology.
[0013] FIG. 5B is a cut away view of a wellbore and a casing string in which
an explosive
device is configured to remove a casing plug, according to some aspects of the
disclosed
technology.
[0014] FIG. 6A is a cut away view of a casing string in which an erosive
chemical containment
device is configured to remove a casing plug, according to some aspects of the
disclosed
technology.
[0015] FIG. 6B is a cut away view of a casing string in which multiple
chemical containment
devices are configured to facilitate removal of a casing plug, according to
some aspects of the
disclosed technology.
[0016] FIG. 7 is a schematic diagram of an example system embodiment.
DETAILED DESCRIPTION
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[0017] Various embodiments of the disclosure are discussed in detail below.
While specific
implementations are discussed, it should be understood that this is done for
illustration purposes
only. A person skilled in the relevant art will recognize that other
components and
configurations may be used without parting from the spirit and scope of the
disclosure.
[0018] Additional features and advantages of the disclosure will be set forth
in the description
which follows, and in part will be obvious from the description, or can be
learned by practice
of the principles disclosed herein. The features and advantages of the
disclosure can be realized
and obtained by means of the instruments and combinations particularly pointed
out in the
appended claims. These and other features of the disclosure will become more
fully apparent
from the following description and appended claims, or can be learned by the
practice of the
principles set forth herein.
[0019] It will be appreciated that for simplicity and clarity of illustration,
where appropriate,
reference numerals have been repeated among the different figures to indicate
corresponding or
analogous elements. In addition, numerous specific details are set forth in
order to provide a
thorough understanding of the embodiments described herein. However, it will
be understood
by those of ordinary skill in the art that the embodiments described herein
can be practiced
without these specific details. In other instances, methods, procedures and
components have not
been described in detail so as not to obscure the related relevant feature
being described. The
drawings are not necessarily to scale and the proportions of certain parts may
be exaggerated to
better illustrate details and features. The description is not to be
considered as limiting the scope
of the embodiments described herein.
[0020] Subterranean hydraulic fracturing is conducted to increase or
"stimulate" production
from a hydrocarbon well. To conduct a fracturing process, pressure is used to
pump fracturing
fluids, including some that contain propping agents ("proppants"), down-hole
and into a
hydrocarbon formation to split or "fracture" the rock formation along veins or
planes extending
from the well-bore. Once the desired fracture is formed, the fluid flow is
reversed and the liquid
portion of the fracturing fluid is removed. The proppants are intentionally
left behind to stop
the fracture from closing onto itself due to stresses within the formation.
The proppants thus
"prop-apart'', or support the opening of the fracture, yet remain highly
permeable to
hydrocarbon fluid flow since they form a packed bed of particles with
interstitial void space
connectivity.
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[0021] To begin a fracturing process, at least one perforation is made at a
particular down-hole
location through the well into a subterranean formation, e.g. through a wall
of at least one casing
section, to provide fluid communication between the wellbore interior and the
formation.
[0022] One challenge in maintaining fluid communication through the
perforations is that the
size of the perforations (aperture size or aperture diameter) in the wellbore
casing sections
begins to change as the edges erode. These erosions introduce uncertainties in
otherwise
controllable parameters, such as fluid pressure and flow rates. Aspects of the
disclosed
technology address these challenges by providing solutions for preventing
erosion to
perforation edges through the use of erosion resistant inserts. Additionally,
aspects of the
disclosed technology provide techniques for improving the perforation process,
for example, by
providing selectively removable plugs that are disposed within the inserts and
which can be
removed to form fluid communication channels without the use of perforating
guns.
[0023] In some implementations, the disclosed technology encompasses wear-
resistant inserts
that are disposed around the peripheral edge of the perforations to arrest
erosive enlargement
that can occur during hydraulic fracturing treatment. The inserts can be
filled with a selectively
removable plug, for example, that can be removed to open fluid communication
holes
(perforations) between the wellbore interior and the outside formation. Use of
removable plugs
can be used to eliminate the need of running perforating guns inside the
casing, as well as
surface wireline equipment that is required to operate the perforating guns.
[0024] In practice, casing sections of a casing string are prepared before
being run downhole.
This process includes the creation of perforations in the wall of various
casing sections, and the
installation of wear-resistant sealed inserts around the edges of the
perforations. The inserts may
be constructed of different types of wear-resistant materials, for example,
including but not
limited to: tool steels, metal nitrides, metal carbides. hard chromium,
cemented tungsten
carbide, or ceramics. Moreover, the inserts may be coated or hard-faced with
powders or
particulates, including diamond, through various processes such as thermal
spray coating,
chemical vapor deposition, or electroplating. Regardless of the material
selected or process
employed, the key requirement for the insert is surface hardness, which should
be equal to or
above 40 Rockwell C (40 HRC, approximately 400 Vickers scale). Depending on
the desired
implementation, inserts may be affixed by various means, including but not
limited to: welding,
brazing, adhesives, threads, shrink-fits, press-fits, glass-to-metal seals,
and/or ceramic-to-metal
seals, and the like. In some instances, the inserts can be disposed in
particular angular pattern
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and/or longitudinal spading to fit specific extraction needs or scenarios. For
example, the
angular pattern may simply be zero degrees (i.e., all inserts are co-linear
down the length of the
casing) or may be some other phasing such as 2 @ 180 degrees, 3 @ 120 degrees,
6 @ 60
degrees, and so forth. Moreover, the longitudinal spacing may be a few inches
within a single
perforation cluster up to several feet to enable separation of one cluster to
another.
[0025] Once the inserts have been installed, a removable plugging material can
be inserted to
seal an interior volume of the casing string. As discussed in further detail
below, plugs can be
made of different materials, and can be installed in different configurations,
depending on the
desired removal process that is to be implemented.
[0026] The disclosure now turns to FIGS. lA and 1B provide a brief
introductory description
of the larger systems that can be employed to practice the concepts, methods,
and techniques
disclosed herein. A more detailed description of the methods and systems for
implementing the
improved semblance processing techniques of the disclosed technology will then
follow.
[0027] FIG. IA shows an illustrative drilling environment 100. Within
environment 100,
drilling platform 102 supports derrick 104 having traveling block 106 for
raising and lowering
drill string 108. Kelly 110 supports drill string 108 as it is lowered through
rotary table 112.
Drill bit 114 is driven by a downhole motor and/or rotation of drill string
108. As bit 114 rotates,
it creates a borehole 116 that passes through various formations 118. Pump 120
circulates
drilling fluid through a feed pipe 122 to kelly 110, downhole through the
interior of drill string
108, through orifices in drill bit 114, back to the surface via the annulus
around drill string 108,
and into retention pit 124. The drilling fluid transports cuttings from the
borehole into pit 124
and aids in maintaining borehole integrity.
[0028] Downhole tool 126 can take the form of a drill collar (i.e., a thick-
walled tubular that
provides weight and rigidity to aid the drilling process) or other
arrangements known in the art.
Further, downhole tool 126 can include various sensor and/or telemetry
devices, including but
not limited to: acoustic (e.g., sonic, ultrasonic, etc.) logging tools and/or
one or more magnetic
directional sensors (e.g., magnetometers, etc.). In this fashion, as bit 114
extends the borehole
through formations 118, the bottom-hole assembly (e.g., directional systems,
and acoustic
logging tools) can collect various types of logging data. For example,
acoustic logging tools can
include transmitters (e.g., monopole, dipole, quadrupole, etc.) to generate
and transmit acoustic
signals/waves into the borehole environment. These acoustic signals
subsequently propagate in
and along the borehole and surrounding formation and create acoustic signal
responses or
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waveforms, which are received/recorded by evenly spaced receivers. These
receivers may be
arranged in an array and may be evenly spaced apart to facilitate capturing
and processing
acoustic response signals at specific intervals. The acoustic response signals
are further
analyzed to determine borehole and adjacent formation properties and/or
characteristics.
[0029] For purposes of communication, a downhole telemetry sub 128 can be
included in the
bottom-hole assembly to transfer measurement data to surface receiver 130 and
to receive
commands from the surface. In some implementations, mud pulse telemetry may be
used for
transferring tool measurements to surface receivers and receiving commands
from the surface;
however, other telemetry techniques can also be used, without departing from
the scope of the
disclosed technology. In some embodiments, telemetry sub 128 can store logging
data for later
retrieval at the surface when the logging assembly is recovered. These logging
and telemetry
assemblies consume power, which must often be routed through the directional
sensor section
of the drill string, thereby producing stray EM fields which interfere with
the magnetic sensors.
[0030] At the surface, surface receiver 130 can receive the uplink signal from
downhole
telemetry sub 128 and can communicate the signal to data acquisition module
132. Module 132
can include one or more processors, storage mediums, input devices, output
devices, software,
and the like as described in further detail below. Module 132 can collect,
store, and/or process
the data received from tool 126 as described herein.
[0031] At various times during the drilling process, drill string 108 may be
removed from the
borehole as shown in example environment 101, illustrated in FIG. 1B. Once
drill string 108
has been removed, logging operations can be conducted using a downhole tool
134 (i.e., a
sensing instrument tool) suspended by a conveyance 142. In one or more
embodiments, the
conveyance 142 can be a cable having conductors for transporting power to the
tool and
telemetry from the tool to the surface. Downhole tool 134 may have pads and/or
centralizing
springs to maintain the tool near the central axis of the borehole or to bias
the tool towards the
borehole wall as the tool is moved downhole or uphole.
[0032] Downhole tool 134 can include various directional and/or acoustic
logging instruments
that collect data within borehole 116. A logging facility 144 includes a
computer system, such
as those described with reference to FIGs. 5 and 6, discussed below. In one or
more
embodiments, the conveyance 142 of downhole tool 134 can be at least one of
wires, conductive
or non-conductive cable (e.g., slickline, etc.), as well as tubular
conveyances, such as coiled
tubing, pipe string, or downhole tractor. Downhole tool 134 can have a local
power supply, such
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as batteries, downhole generator and the like. When employing non-conductive
cable, coiled
tubing, pipe string, or downhole tractor, communication can be supported
using, for example,
wireless protocols (e.g. EM, acoustic, etc.), and/or measurements and logging
data may be
stored in local memory for subsequent retrieval.
[0033] Although FIGS. lA and 1B depict specific borehole configurations, it is
understood that
the present disclosure is equally well suited for use in wellbores having
other orientations
including vertical wellbores, horizontal wellbores, slanted wellbores,
multilateral wellbores and
the like. While FIGS. lA and 1B depict an onshore operation, it should also be
understood that
the present disclosure is equally well suited for use in offshore operations.
Moreover, the present
disclosure is not limited to the environments depicted in FIGS. lA and 1B, and
can also be used
in either logging-while-drilling (LWD) or measurement while drilling (MWD)
operations.
[0034] FIG. 2 illustrates steps of an example process 200 for constructing a
wellbore casing
string, according to some aspects of the disclosed technology. Process 200
begins with step 202
in which at least one aperture (perforation) is inserted into at least one
side wall of a casing
section. In some embodiments, the size (e.g., diameter) and placement of the
aperture is based
on the intended drilling application, such as based on formation or wellbore
characteristics in
which the casing string is deployed. In some approaches, the aperture size can
be optimized
based on characteristics of the hydraulic fracturing setup. By knowing the
size and number of
apertures in a particular casing section, fluid distribution (e.g., fluid
pressure, velocity, and/or
flow rate) can be more accurately controlled during the hydraulic fracturing
process.
[0035] In step 204, an insert is affixed around a periphery of the aperture.
The insert can be
composed of an erosion resistant material, such as a tungsten carbide
material, or other material
that can resist erosion caused by the ingress/egress of various drilling
fluids and hydrocarbons
through the aperture in the casing wall. The insert may he affixed using
different means,
including but not limited to: welding, brazing, adhesives, threads, shrink-
fits, press-fits, glass-
to-metal seals, and/or ceramic-to-metal seals, and the like.
[0036] In step 206, a plug is placed within the insert. In some approaches,
the plug is selectively
removable, and serves to provide a temporary seal in the casing wall, for
example, while the
casing string is run into the wellbore, and wellbore completion operations
completed. Once
fracturing/production is commenced, the various plugs in the one or more
different casing
sections can be selectively removed to permit fluid communication with the
formation. Opening
of fluid channels can involve the removal of the plug in various ways. As
such, the plug is
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comprised of materials that break or disintegrate when exposed to heat,
chemicals, and/or
mechanical shock. As discussed in further detail below, the plug can be one or
more of a ceramic
disc, for example, that can be shattered with mechanical shock (e.g., caused
by an explosive
device), or from pressure, heat, dissolution, or corrosive attack caused by a
chemical reaction.
[0037] FIG. 3 is a cut-away view of a casing string 300 with multiple casing
sections 302 (e.g.,
casing sections 302A and 302B), according to some aspects of the disclosed
technology. Casing
string 300 includes sections 302 that are joined by fitting 304. As further
illustrated, each casing
section (302A, 302B) includes one or more plugged apertures (perforations) 306
(e.g., 306A,
306B, 306C, and 306D) that permit communication between an interior volume of
casing string
300 and the exterior. It is understood that casing string 300 can have a
greater number of casing
sections, fittings and/or plugged apertures, without departing from the scope
of the disclosed
technology.
[0038] As discussed in further detail below, plugged apertures 306 include an
insert/plug
combination that functions to seal the interior volume of casing string 300.
Depending on the
desired deployment, the plug material may be designed for removal via a
variety of different
means, including the use of explosive charges, chemical reactions, or the
application of
pressure, for example, that results from a chemical reaction. Additional
details relating to plug
removal are provided in conjunction with FIGs. 5A-6B, discussed below.
[0039] FIG. 4A illustrates cut away views (400, 401) of example inserts that
contain plugs,
according to some aspects of the disclosed technology. In example view 400, an
interior volume
of insert 402 is entirely filled with a plugging material (plug) 404. As
discussed above, plug
404 can be made of a material that is designed to break or shatter in response
to mechanical
shock (e.g., a ceramic or ceramic composite material). However, in other
embodiments, plug
404 can be comprised of materials designed to melt in response to thermal
stress, or dissolve
when exposed to corrosive chemicals, e.g., chemical cutters. For example, plug
404 may be
comprised of a calcium composite or dolomite that is configured to dissolve
when contacted by
an acid, such as hydrochloric acid, acetic acid, or the like. In example view
401, plug 406 is
configured to have an empty interior volume 408.
[0040] FIG. 4B illustrates a cut away view of a wellbore 403 including a
casing section 410
having an insert 402, according to some aspects of the disclosed technology.
In the example of
FIG. 4B, the exterior of casing section 410 is surrounded by concrete 410
that, in turn, is
adjacent to a formation 407. In this example, it is understood that casing
section 410 can
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represent only a single casing section from among multiple sections forming a
casing string
extending down wellbore 403.
[0041] Casing section 410 includes an insert 402 that is configured to prevent
erosion of casing
section 410 once fluid communication has been established between wellbore 403
and
formation 407. To establish this communication, plug 404 can be selectively
removed from
insert 402, for example, to permit fracturing fluids to be pumped out of
wellbore 403 and into
formation 407, as well as to permit hydrocarbons to flow back into wellbore
403 from formation
407. As discussed in further detail below with respect to FIGs. 5A-6B, plug
404 may be
selectively removed using signals sent from the surface that are designed to
cause the removal
of plug 404. e.g., via mechanical force, heat, pressure and/or chemical
erosion, etc.
[0042] FIG. 5A is a cut away view a wellbore 500 utilizing a casing string 504
in which a
detonating cord 516 is configured to remove a casing plug 508, according to
some aspects of
the disclosed technology. In the example of FIG. 5A, a centralizer 514 is
disposed on an outside
surface of casing string 504, within cement layer 506. In this configuration.
centralizer 514 is
configured to house plug 512, as well as a detonating cord 516, which can be
used to selectively
remove exterior plug 512 and casing plug 508, for example, to permit fluid
communication
between wellbore 500 and formation 510.
[0043] FIG. 5B is a cut away view of a wellbore 501 utilizing a casing string
in which an
explosive device 518 (e.g., shape charge and/or detonating cord) are
configured to remove an
interior casing plug 509, and exterior plug 513. according to some aspects of
the disclosed
technology. Similar to the example of FIG. 5A, a centralizer 514 is disposed
on an outside
surface of casing string 504, within cement layer 506. In this configuration.
centralizer 514 is
configured to house explosive device 518, which can be used to selectively
remove exterior
plug 513 and casing plug 509, for example, to permit fluid communication
between wellbore
501 and formation 510.
[0044] FIG. 6A is a cut away view of a wellbore 600 utilizing a casing string
604 in which an
erosive chemical containment device 620 is configured to remove a casing plug,
according to
some aspects of the disclosed technology. In this configuration, chemical
containment device
620 is configured to be selectively activated, for example, using a remotely
activate chemical
release device 612, that is disposed adjacent to chemical containment device
620. For example,
activation of the remotely activated chemical release device 621 can cause
chemical
containment device 620 to rupture, thereby exposing casing plug 609 and
exterior plug 612 to
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chemically induced pressure, heat, or erosion (e.g., using an acid). As such,
removal of casing
plug 609 and exterior plug 615 can be remotely controlled in order to
facilitate fluid
communication between wellbore 600 and formation 610.
[0045] FIG. 6B is a cut away view of a wellbore 601 utilizing a casing string
in which multiple
chemical containment devices 618A, 618B are configured to facilitate removal
of plugs 609,
615, according to some aspects of the disclosed technology.
[0046] In this configuration, chemical containment devices 618A, 618B are
configured to be
selectively activated, for example, using a remotely activate chemical release
device 622.
Activation of chemical release device 622 can cause chemical containment
devices 618A, 618B
to rupture to permit a mixing of the chemicals contained therein. In some
aspects, mixing of the
contents of chemical containment devices 618A, 618B can be used to cause heat
(e.g., through
a thermal chemical reaction) and/or pressure (e.g., through an acid/base
reaction) that is
sufficient to break (or dissolve) plugs 609 and/or 615.
[0047] In some aspects, an acidic chemical cutter, such as bromine tri-
fluoride may be used to
corrode or dissolve the plug; however, it is understood that other chemicals
or chemical
combinations may be used, without departing from the scope of the disclosed
technology. By
way of example, an acid such as hydrochloric acid, acetic acid and/or formic
acid may be used
to dissolve calcium carbonate or dolomite type plugs. It is understood that
the selection of
chemical cutter can be based on a material of the plug used, which may vary,
depending on the
desired implementation.
[0048] FIG. 7 illustrates an exemplary computing system 700 for use with
example tools and
systems (e.g., tool 126). The more appropriate embodiment will be apparent to
those of ordinary
skill in the art when practicing the present technology. Persons of ordinary
skill in the art will
also readily appreciate that other system embodiments are possible.
[0049] Specifically, FIG. 7 illustrates system architecture 700 wherein the
components of the
system are in electrical communication with each other using a bus 705. System
architecture
700 can include a processing unit (CPU or processor) 710, as well as a cache
712, that are
variously coupled to system bus 705. Bus 705 connects various system
components including
system memory 715, (e.g., read only memory (ROM) 720 and random-access memory
(RAM)
725), to processor 710. System architecture 700 can include a cache of high-
speed memory
connected directly with, in close proximity to, or integrated as part of the
processor 710. System
architecture 700 can copy data from the memory 715 and/or the storage device
730 to the cache
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712 for quick access by the processor 710. In this way, the cache can provide
a performance
boost that avoids processor 710 delays while waiting for data. These and other
modules can
control or be configured to control the processor 710 to perform various
actions. Other system
memory 715 may be available for use as well. Memory 715 can include multiple
different types
of memory with different performance characteristics. Processor 710 can
include any general-
purpose processor and a hardware module or software module, such as module 1
(732), module
2 (734), and module 3 (736) stored in storage device 730, configured to
control processor 710
as well as a special-purpose processor where software instructions are
incorporated into the
actual processor design. Processor 710 may essentially be a completely self-
contained
computing system, containing multiple cores or processors, a bus, memory
controller, cache,
etc. A multi-core processor may be symmetric or asymmetric.
[0050] To enable user interaction with the computing system architecture 700,
input device 745
can represent any number of input mechanisms, such as a microphone for speech,
a touch-
sensitive screen for gesture or graphical input, keyboard, mouse, motion
input, and so forth. An
output device 742 can also be one or more of a number of output mechanisms. In
some
instances, multimodal systems can enable a user to provide multiple types of
input to
communicate with the computing system architecture 700. The communications
interface 740
can generally govern and manage the user input and system output. There is no
restriction on
operating on any particular hardware arrangement and therefore the basic
features here may
easily be substituted for improved hardware or firmware arrangements as they
are developed.
[0051] Storage device 730 is a non-volatile memory and can be a hard disk or
other types of
computer readable media which can store data that are accessible by a
computer, such as
magnetic cassettes, flash memory cards, solid state memory devices, digital
versatile disks,
cartridges, random access memories (RAMs) 735, read only memory (ROM) 720, and
hybrids
thereof.
[0052] Storage device 730 can include software modules 732, 734, 736 for
controlling the
processor 710. Other hardware or software modules are contemplated. The
storage device 730
can be connected to the system bus 705. In one aspect, a hardware module that
performs a
particular function can include the software component stored in a computer-
readable medium
in connection with the necessary hardware components, such as the processor
710, bus 705,
output device 742, and so forth, to carry out various functions of the
disclosed technology.
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[0053] Embodiments within the scope of the present disclosure may also include
tangible
and/or non-transitory computer-readable storage media or devices for carrying
or having
computer-executable instructions or data structures stored thereon. Such
tangible computer-
readable storage devices can be any available device that can be accessed by a
general purpose
or special purpose computer, including the functional design of any special
purpose processor
as described above. By way of example, and not limitation, such tangible
computer-readable
devices can include RAM, ROM, EEPROM, CD-ROM or other optical disk storage,
magnetic
disk storage or other magnetic storage devices, or any other device which can
be used to carry
or store desired program code in the form of computer-executable instructions,
data structures,
or processor chip design. When information or instructions are provided via a
network or
another communications connection (either hardwired, wireless, or combination
thereof) to a
computer, the computer properly views the connection as a computer-readable
medium. Thus,
any such connection is properly termed a computer-readable medium.
Combinations of the
above should also be included within the scope of the computer-readable
storage devices.
[0054] Computer-executable instructions include, for example, instructions and
data which
cause a general-purpose computer, special purpose computer, or special purpose
processing
device to perform a certain function or group of functions. Computer-
executable instructions
also include program modules that are executed by computers in stand-alone or
network
environments. Generally, program modules include routines, programs,
components, data
structures, objects, and the functions inherent in the design of special-
purpose processors, etc.
that perform particular tasks or implement particular abstract data types.
Computer-executable
instructions, associated data structures, and program modules represent
examples of the
program code means for executing steps of the methods disclosed herein. The
particular
sequence of such executable instructions or associated data structures
represents examples of
corresponding acts for implementing the functions described in such steps.
[0055] Other embodiments of the disclosure may be practiced in network
computing
environments with many types of computer system configurations, including
personal
computers, hand-held devices, multi-processor systems, microprocessor-based or
programmable consumer electronics, network PCs, minicomputers, mainframe
computers, and
the like. Embodiments may also be practiced in distributed computing
environments where
tasks are performed by local and remote processing devices that are linked
(either by hardwired
links, wireless links, or by a combination thereof) through a communications
network. In a
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distributed computing environment, program modules may be located in both
local and remote
memory storage devices.
[0056] The various embodiments described above are provided by way of
illustration only and
should not be construed to limit the scope of the disclosure. For example, the
principles herein
apply equally to optimization as well as general improvements. Various
modifications and
changes may be made to the principles described herein without following the
example
embodiments and applications illustrated and described herein, and without
departing from the
spirit and scope of the disclosure. Claim language reciting at least one or a
set indicates that
one member of the set or multiple members of the set satisfy the claim.
STATEMENTS OF THE DISCLOSURE
[0057] Statement 1: a casing string configured for facilitating hydrocarbon
extraction from a
wellbore, the casing string including: at least one casing section, an
aperture disposed on a
surface of the of the at least one casing section, an insert affixed around a
periphery of the
aperture; and a plug disposed within the insert, wherein the plug is
configured to be selectively
removable to allow fluid communication between an interior volume of the
casing string and
an exterior of the casing string adjacent to a geologic formation.
[0058] Statement 2: the casing string of statement 1, wherein the insert is
configured to prevent
erosion of the internal edge of the aperture in order to maintain a diameter
of the aperture.
[0059] Statement 3: the casing string of any of statements 1-2, wherein the
insert comprises a
carbide composite.
[0060] Statement 4: the casing string of any of statements 1-3, wherein the
plug is configured
to be removed from the insert by an explosive charge.
[0061] Statement 5: the casing string of any of statements 1-4, wherein the
plug is configured
to be removed from the insert by heat.
[0062] Statement 6: the casing string of any of statements 1-5, wherein the
plug is configured
to dissolve upon contact with a chemical cutter.
[0063] Statement 7: the casing string of any of statements 1-6, wherein the
chemical solution
comprises bromine tri-fluoride.
[0064] Statement 8: the casing string of any of statements 1-7, wherein the
chemical solution
comprises an acid.
[0065] Statement 9: the casing string of any of statements 1-8, wherein the
plug comprises zinc.
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[0066] Statement 10: the casing string of any of statements 1-9, wherein the
plug comprises
aluminum.
[0067] Statement 11: the casing string of any of statements 1-10, wherein the
plug comprises
ceramic and calcium carbonate.
[0068] Statement 12: a method for constructing a casing string configured for
facilitating
hydrocarbon extraction from a wellbore, the casing string including: inserting
an aperture in at
least one casing section, wherein the aperture is disposed on a surface of the
of the at least one
casing section; affixing an insert around a periphery of the aperture; and
placing a plug within
the insert, wherein the plug is configured to be selectively removable to
allow fluid
communication between an interior volume of the casing string and an exterior
of the casing
string adjacent to a geologic formation.
[0069] Statement 13: the method of statement 12, wherein the insert is
configured to prevent
erosion of the internal edge of the aperture in order to maintain a diameter
of the aperture.
[0070] Statement 14: the method of any of statements 12-13, wherein the insert
comprises a
carbide composite.
[0071] Statement 15: the method of any of statements 12-14, wherein the plug
is configured to
be removed from the insert by an explosive charge.
[0072] Statement 16: the method of any of statements 12-15, wherein the plug
is configured to
be removed from the insert by heat.
[0073] Statement 17: the method of any of statements 12-16, wherein the plug
is configured to
dissolve upon contact with a chemical cutter.
[0074] Statement 18: the method of any of statements 12-17, wherein the
chemical solution
comprises bromine tri-fluoride.
[0075] Statement 19: the method of any of statements 12-18, wherein the
chemical solution
comprises an acid.
[0076] Statement 20: a wellbore casing section, comprising: at least one
aperture disposed on a
surface of the casing section; an insert affixed around a periphery of the
aperture; and a plug
disposed within the insert, wherein the plug is configured to be selectively
removable to
facilitate communication between an interior volume of the casing section and
an exterior of
the casing section.
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