U.S. patent application number 16/899344 was filed with the patent office on 2021-12-16 for fluid communication method for hydraulic fracturing.
This patent application is currently assigned to HALLIBURTON ENERGY SERVICES,INC.. The applicant listed for this patent is HALLIBURTON ENERGY SERVICES,INC.. Invention is credited to James Marshall BARKER, Ronald Glen DUSTERHOFT.
Application Number | 20210388691 16/899344 |
Document ID | / |
Family ID | 1000004924984 |
Filed Date | 2021-12-16 |
United States Patent
Application |
20210388691 |
Kind Code |
A1 |
BARKER; James Marshall ; et
al. |
December 16, 2021 |
FLUID COMMUNICATION METHOD FOR HYDRAULIC FRACTURING
Abstract
Aspects of the disclosed technology provide techniques for
facilitating hydrocarbon extraction from a wellbore. In some
aspects, the disclosed technology encompasses a novel casing string
that includes at least one casing section, an aperture disposed on
a surface of the casing section, and an insert affixed around a
periphery of the aperture. The casing string can further include 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, e.g., adjacent to a geologic formation.
Inventors: |
BARKER; James Marshall;
(Mansfield, TX) ; DUSTERHOFT; Ronald Glen; (Katy,
TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
HALLIBURTON ENERGY SERVICES,INC. |
Houston |
TX |
US |
|
|
Assignee: |
HALLIBURTON ENERGY
SERVICES,INC.
Houston
TX
|
Family ID: |
1000004924984 |
Appl. No.: |
16/899344 |
Filed: |
June 11, 2020 |
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 33/1208 20130101;
E21B 17/1085 20130101 |
International
Class: |
E21B 33/12 20060101
E21B033/12; E21B 17/10 20060101 E21B017/10 |
Claims
1. A casing string configured for facilitating hydrocarbon
extraction from a wellbore, the casing string comprising: 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.
2. The casing string of claim 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.
3. The casing string of claim 1, wherein the insert comprises a
carbide composite.
4. The casing string of claim 1, wherein the plug is configured to
be removed from the insert by an explosive device.
5. The casing string of claim 1, wherein the plug is configured to
be removed from the insert by heat.
6. The casing string of claim 1, wherein the plug is configured to
dissolve upon contact with a chemical cutter.
7. The casing string of claim 6, wherein the chemical solution
comprises bromine tri-fluoride.
8. The casing string of claim 6, wherein the chemical solution
comprises an acid.
9. The casing string of claim 1, wherein the plug comprises
zinc.
10. The casing string of claim 1, wherein the plug comprises
aluminum.
11. The casing string of claim 1, wherein the plug comprises
ceramic, calcium carbonate, or dolomite.
12. A method for constructing a casing string configured for
facilitating hydrocarbon extraction from a wellbore, the casing
string comprising: 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.
13. The method of claim 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.
14. The method of claim 12, wherein the insert comprises a carbide
composite.
15. The method of claim 12, wherein the plug is configured to be
removed from the insert by an explosive device.
16. The method of claim 12, wherein the plug is configured to be
removed from the insert by heat.
17. The method of claim 12, wherein the plug is configured to
dissolve upon contact with a chemical cutter.
18. The method string of claim 17, wherein the chemical solution
comprises bromine tri-fluoride.
19. The method string of claim 17, wherein the chemical solution
comprises an acid.
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.
Description
TECHNICAL FIELD
[0001] 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
[0002] 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.
[0003] 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
[0004] 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
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:
[0005] FIG. 1A is a schematic diagram of an example drilling
environment, in accordance with various aspects of the subject
technology.
[0006] FIG. 1B is a schematic diagram of an example wireline
logging environment, in accordance with various aspects of the
subject technology.
[0007] FIG. 2 illustrates steps of an example process for
constructing a wellbore casing string, according to some aspects of
the disclosed technology.
[0008] FIG. 3 is a cut-away view of a casing string with multiple
casing sections, according to some aspects of the disclosed
technology.
[0009] FIG. 4A illustrate cut away views example inserts that
contain plugs, according to some aspects of the disclosed
technology.
[0010] 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.
[0011] 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.
[0012] 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.
[0013] 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.
[0014] 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.
[0015] FIG. 7 is a schematic diagram of an example system
embodiment.
DETAILED DESCRIPTION
[0016] 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.
[0017] 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.
[0018] 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.
[0019] 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.
[0020] 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.
[0021] 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.
[0022] 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.
[0023] 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 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.
[0024] 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.
[0025] The disclosure now turns to FIGS. 1A 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.
[0026] FIG. 1A 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.
[0027] 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
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.
[0028] 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.
[0029] 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.
[0030] 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.
[0031] 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 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.
[0032] Although FIGS. 1A 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. 1A 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. 1A and 1B, and can also be used in
either logging-while-drilling (LWD) or measurement while drilling
(MWD) operations.
[0033] 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.
[0034] 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 be 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.
[0035] 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 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.
[0036] 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.
[0037] 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.
[0038] 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.
[0039] 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 represent only a
single casing section from among multiple sections forming a casing
string extending down wellbore 403.
[0040] 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.
[0041] 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.
[0042] 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.
[0043] 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 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.
[0044] 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.
[0045] 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.
[0046] 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.
[0047] 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.
[0048] 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 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.
[0049] 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.
[0050] 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.
[0051] 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.
[0052] 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.
[0053] 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.
[0054] 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 distributed computing
environment, program modules may be located in both local and
remote memory storage devices.
[0055] 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 of" a set indicates that one member of the set or
multiple members of the set satisfy the claim.
STATEMENTS OF THE DISCLOSURE
[0056] 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.
[0057] 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.
[0058] Statement 3: the casing string of any of statements 1-2,
wherein the insert comprises a carbide composite.
[0059] 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.
[0060] Statement 5: the casing string of any of statements 1-4,
wherein the plug is configured to be removed from the insert by
heat.
[0061] Statement 6: the casing string of any of statements 1-5,
wherein the plug is configured to dissolve upon contact with a
chemical cutter.
[0062] Statement 7: the casing string of any of statements 1-6,
wherein the chemical solution comprises bromine tri-fluoride.
[0063] Statement 8: the casing string of any of statements 1-7,
wherein the chemical solution comprises an acid.
[0064] Statement 9: the casing string of any of statements 1-8,
wherein the plug comprises zinc.
[0065] Statement 10: the casing string of any of statements 1-9,
wherein the plug comprises aluminum.
[0066] Statement 11: the casing string of any of statements 1-10,
wherein the plug comprises ceramic and calcium carbonate.
[0067] 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.
[0068] 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.
[0069] Statement 14: the method of any of statements 12-13, wherein
the insert comprises a carbide composite.
[0070] 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.
[0071] Statement 16: the method of any of statements 12-15, wherein
the plug is configured to be removed from the insert by heat.
[0072] Statement 17: the method of any of statements 12-16, wherein
the plug is configured to dissolve upon contact with a chemical
cutter.
[0073] Statement 18: the method of any of statements 12-17, wherein
the chemical solution comprises bromine tri-fluoride.
[0074] Statement 19: the method of any of statements 12-18, wherein
the chemical solution comprises an acid.
[0075] 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.
* * * * *