U.S. patent application number 13/873016 was filed with the patent office on 2014-10-30 for scale prevention treatment method, system, and apparatus for wellbore stimulation.
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 Lucas Kurtis FONTENELLE, Holly Ann Grider, Eli Allen SCHNOOR, Nathan Carl SCHULTHEISS, Todd Anthony STAIR.
Application Number | 20140318762 13/873016 |
Document ID | / |
Family ID | 51788259 |
Filed Date | 2014-10-30 |
United States Patent
Application |
20140318762 |
Kind Code |
A1 |
FONTENELLE; Lucas Kurtis ;
et al. |
October 30, 2014 |
Scale Prevention Treatment Method, System, and Apparatus for
Wellbore Stimulation
Abstract
A method of servicing a wellbore comprising placing a wellbore
servicing apparatus into a wellbore, wherein the wellbore servicing
apparatus contains a plurality of mobilized template-assisted
crystallization beads and contacting a fluid comprising
scale-forming ions with at least a portion of the template-assisted
crystallization beads. A method of servicing a wellbore, comprising
contacting a fluid comprising scale-forming ions with a quantity of
template-assisted crystallization beads in a vessel to form a
treated fluid, wherein the template-assisted crystallization beds
are mobile within the vessel and placing the treated fluid into a
wellbore, a subterranean formation, or a combination thereof.
Inventors: |
FONTENELLE; Lucas Kurtis;
(Houston, TX) ; SCHNOOR; Eli Allen; (Kingwood,
TX) ; Grider; Holly Ann; (Houston, TX) ;
SCHULTHEISS; Nathan Carl; (Kingwood, TX) ; STAIR;
Todd Anthony; (Duncan, OK) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
HALLIBURTON ENERGY SERVICES, INC. |
Houston |
TX |
US |
|
|
Assignee: |
Halliburton Energy Services,
Inc.
Houston
TX
|
Family ID: |
51788259 |
Appl. No.: |
13/873016 |
Filed: |
April 29, 2013 |
Current U.S.
Class: |
166/90.1 ;
166/118; 166/179; 166/227; 166/242.1 |
Current CPC
Class: |
C09K 8/52 20130101; E21B
33/129 20130101; E21B 37/06 20130101 |
Class at
Publication: |
166/90.1 ;
166/242.1; 166/179; 166/118; 166/227 |
International
Class: |
E21B 43/00 20060101
E21B043/00; E21B 43/08 20060101 E21B043/08; E21B 33/129 20060101
E21B033/129 |
Claims
1. A wellbore servicing apparatus, comprising: a housing; a mandrel
within the housing; an annular space between an outer
circumferential surface of the mandrel and an inner circumferential
surface of the housing; a plurality of mobilized template-assisted
crystallization beads within the annular space; a flowpath between
an interior and an exterior of the wellbore servicing apparatus
that is in fluid communication with the annular space such that a
fluid may flow through the annular space and contact the
template-assisted crystallization beads.
2. The wellbore servicing apparatus of claim 1, wherein the
template-assisted crystallization beads are configured to induce a
turbulent flow of a wellbore fluid as the wellbore fluid passes
through the annular space.
3. The wellbore servicing apparatus of claim 1, wherein the housing
comprises helical coiled tubing, a screen, or both.
4. The wellbore servicing apparatus of claim 1, wherein the mandrel
comprises helical coiled tubing, a screen, or both.
5. The wellbore servicing apparatus of claim 3, wherein the mandrel
comprises helical coiled tubing, a screen, or both.
6. The wellbore servicing apparatus of claim 1, further comprising
one or more packer elements.
7. The wellbore servicing apparatus of claim 5, further comprising
one or more packer elements.
8. The wellbore servicing apparatus of claim 6, wherein the one or
more packer elements further comprise a plurality of sealing
elements and a slip-wedge system.
9. The wellbore servicing apparatus of claim 7, wherein the one or
more packer elements further comprise a plurality of sealing
elements and a slip-wedge system.
10. The wellbore servicing apparatus of claim 6 configured as a
production packer.
11. The wellbore servicing apparatus of claim 9 configured as a
production packer.
12. A fluid treatment system comprising: a fluid source; a vessel
in fluid communication with the fluid source and receiving fluid
therefrom, wherein the vessel contains a plurality of mobilized
template-assisted crystallization beads; and a wellhead in fluid
communication with the vessel and receiving a treated fluid
therefrom.
13. The fluid treatment system of claim 12, wherein the
template-assisted crystallization beads are configured to induce a
turbulent flow of the fluid as the fluid passes through the
vessel.
14. The fluid treatment system of claim 12, wherein the mobilized
template-assisted crystallization beads form a fluidized bed upon
flow of the fluid there through.
15. The fluid treatment system of claim 14, wherein the fluid is
received proximate the bottom of the vessel, flows upward through
the plurality of mobilized template-assisted crystallization beads
thereby forming the fluidized bed, exits proximate the top of the
vessel, and flows to the wellhead.
16. A wellbore servicing system, comprising: a first flowpath,
comprising: a first conduit from a fluid source to a vessel; a
chamber of the vessel; and a second conduit from the chamber within
the vessel to a wellbore, a second flowpath, comprising: a space
within the wellbore and exterior to a wellbore servicing apparatus;
a chamber of the wellbore servicing apparatus; and a flowbore of
the wellbore servicing apparatus, and a plurality of mobilized
template-assisted crystallization beads within the chamber of the
vessel, within the chamber of the wellbore servicing apparatus, or
a combination thereof.
17. The system of claim 16, wherein the first flowpath is in fluid
communication with the second flowpath.
18. The fluid treatment system of claim 17, wherein the mobilized
template-assisted crystallization beads are configured to induce a
turbulent flow of a fluid.
19. The fluid treatment system of claim 17, wherein the mobilized
template-assisted crystallization beads form a fluidized bed upon
flow of a fluid there through.
20. The fluid treatment system of claim 16, wherein the wellbore
servicing apparatus further comprises one or more packer elements.
Description
CROSS-REFERENCE TO RELATED APPLICATION
[0001] This application is related to commonly owned U.S. patent
application Ser. No. ______, [Attorney Docket No. HES
2012-IP-065499U1] entitled "Scale Prevention Treatment Method,
System, and Apparatus for Wellbore Stimulation," filed on the same
date as the present application and incorporated by reference
herein.
STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT
[0002] Not applicable.
THE NAMES OF THE PARTIES TO A JOINT RESEARCH AGREEMENT
[0003] Not applicable.
REFERENCE TO A MICROFICHE APPENDIX
[0004] Not applicable.
INCORPORATION-BY-REFERENCE OF MATERIAL SUBMITTED ON A COMPACT
DISC
[0005] Not applicable.
BACKGROUND
[0006] Suitable fluid supplies are sometimes required to prepare
wellbore servicing fluids employed in the performance of various
wellbore servicing operations. Water supplies may be provided from
various sources, such as municipal water, surface water, and
flowback water from the wellbore. The water obtained from such
sources of water, which will be used in the preparation of a
wellbore servicing fluid may include ions, such as scale-forming
ions. For instance, flowback water from a subterranean formation
may carry with it entrained scale-forming ions from the formation
such as, for example, calcium, hydroxide, sulfate, and magnesium.
Relatively high concentrations of scale-forming ions may lead to
damage to wellbore servicing equipment, for example, through
corrosion and/or the formation of scale (e.g., calcite scale,
barite scale, magnesium carbonate scale, and the like) on the inner
flow surfaces of such wellbore servicing equipment. Accordingly,
there is a need for effectively lowering the concentration of ions,
such as scale-forming ions, within fluid streams used in the
preparation of a wellbore servicing fluid.
SUMMARY
[0007] Disclosed herein is a method of servicing a wellbore
comprising placing a wellbore servicing apparatus into a wellbore,
wherein the wellbore servicing apparatus contains a plurality of
mobilized template-assisted crystallization beads, and contacting a
fluid comprising scale-forming ions with at least a portion of the
template-assisted crystallization beads.
[0008] Also disclosed herein, is a method of servicing a wellbore,
comprising contacting a fluid comprising scale-forming ions with a
quantity of template-assisted crystallization beads in a vessel to
form a treated fluid, wherein the template-assisted crystallization
beds are mobile within the vessel, and placing the treated fluid
into a wellbore, a subterranean formation, or a combination
thereof.
[0009] Further disclosed herein, is a wellbore servicing apparatus
comprising a housing, a mandrel within the housing, an annular
space between an outer circumferential surface of the mandrel and
an inner circumferential surface of the housing, a plurality of
mobilized template-assisted crystallization beads within the
annular space, a flowpath between an interior and an exterior of
the wellbore servicing apparatus that is in fluid communication
with the annular space such that a fluid may flow through the
annular space and contact the template-assisted crystallization
beads.
[0010] Further disclosed herein, is a fluid treatment system
comprising a fluid source, a vessel in fluid communication with the
fluid source and receiving fluid therefrom, wherein the vessel
contains a plurality of mobilized template-assisted crystallization
beads, and a wellhead in fluid communication with the vessel and
receiving a treated fluid therefrom.
[0011] Further disclosed herein, is a wellbore fluid treatment
method comprising contacting a wellbore servicing fluid or
component thereof with a plurality of mobilized template-assisted
crystallization beads such that turbulent fluid flow is
induced.
[0012] The foregoing has outlined rather broadly the features and
technical advantages of the present disclosure in order that the
detailed description that follows may be better understood.
Additional features and advantages of various embodiments of the
disclosure will be described hereinafter that form the subject of
the claims of the disclosure. It should be appreciated by those
skilled in the art that the conception and the specific embodiments
disclosed may be readily utilized as a basis for modifying or
designing other structures for carrying out the same purposes of
the present disclosure. It should also be realized by those skilled
in the art that such equivalent constructions do not depart from
the spirit and scope of the disclosure as set forth in the appended
claims.
BRIEF DESCRIPTION OF THE DRAWINGS
[0013] For a more complete understanding of the present disclosure
and the advantages thereof, reference is now made to the following
brief description, taken in connection with the accompanying
drawings and detailed description:
[0014] FIG. 1 is a simplified schematic view of a wellbore and a
surface wellbore fluid treatment system for the treatment of a
wellbore servicing fluid according to an embodiment of the
disclosure;
[0015] FIG. 2A is a simplified schematic view of a surface wellbore
fluid treatment system according to an embodiment of the
disclosure;
[0016] FIG. 2B is a simplified schematic view of a fluid treatment
unit according to an embodiment of the disclosure;
[0017] FIG. 3 is a flowchart of a method according to an embodiment
of the disclosure;
[0018] FIG. 4A is a simplified schematic view of a wellbore
servicing apparatus according to an embodiment of the
disclosure;
[0019] FIG. 4B is a cross-sectional view of the wellbore servicing
apparatus of FIG. 4A;
[0020] FIG. 4C is a cut-away view of the wellbore servicing
apparatus of FIG. 4A;
[0021] FIG. 5A is a simplified schematic view of an integrated
wellbore fluid treatment system according to an embodiment of the
disclosure.
[0022] FIG. 5B is a flowchart of a method according to an
embodiment of the invention.
DETAILED DESCRIPTION
[0023] In the drawings and description that follow, like parts are
typically marked throughout the specification and drawings with the
same reference numerals, respectively. In addition, similar
reference numerals may refer to similar components in different
embodiments disclosed herein. The drawing figures are not
necessarily to scale. Certain features of the invention may be
shown exaggerated in scale or in somewhat schematic form and some
details of conventional elements may not be shown in the interest
of clarity and conciseness. The present invention is susceptible to
embodiments of different forms. Specific embodiments are described
in detail and are shown in the drawings, with the understanding
that the present disclosure is not intended to limit the invention
to the embodiments illustrated and described herein. It is to be
fully recognized that the different teachings of the embodiments
discussed herein may be employed separately or in any suitable
combination to produce desired results.
[0024] Unless otherwise specified, use of the terms "connect,"
"engage," "couple," "attach," or any other like term describing an
interaction between elements is not meant to limit the interaction
to direct interaction between the elements and may also include
indirect interaction between the elements described.
[0025] Unless otherwise specified, use of the terms "up," "upper,"
"upward," "up-hole," "upstream," or other like terms shall be
construed as generally from the formation toward the surface or
toward the surface of a body of water; likewise, use of "down,"
"lower," "downward," "down-hole," "downstream," or other like terms
shall be construed as generally into the formation away from the
surface or away from the surface of a body of water, regardless of
the wellbore orientation. Use of any one or more of the foregoing
terms shall not be construed as denoting positions along a
perfectly vertical axis.
[0026] Unless otherwise specified, use of the term "subterranean
formation" shall be construed as encompassing both areas below
exposed earth and areas below earth covered by water such as ocean
or fresh water.
[0027] Unless otherwise specified, use of the term "wellbore fluid"
shall be construed as encompassing all fluids originating from
within the wellbore and all fluids introduced or intended to be
introduced into the wellbore. Accordingly, the term "wellbore
fluid" encompasses, but is not limited to, formation fluids,
production fluids, wellbore servicing fluids, the like, and any
combinations thereof.
[0028] Relatively large amounts of fluid (e.g., water) may be
needed for the preparation of wellbore servicing fluids, such as
drilling fluid, completion fluid, clean-out fluids, cementitious
slurries, stimulation fluids (for example, fracturing and/or
perforating fluids), acidizing fluids, gravel-packing fluids, or
the like. Common fluid sources used for preparing wellbore
servicing fluids include surface water, municipal water, and water
co-produced in the production of oil and gas, hereinafter referred
to as produced water. Water obtained from one or more of such
sources may contain concentrations of dissolved scale-forming ions.
The scale-forming ions may include, for example, barium ions,
calcium ions, magnesium ions, strontium ions, manganese ions
aluminum ions, sulfate ions, hydrogen carbonate ions, carbonate
ions, sodium ions, or any combination thereof. A fluid containing
concentrations of dissolved scale-forming ions may adversely affect
the intended function of a wellbore servicing fluid formed
therefrom and may contribute to the degradation and/or failure of
wellbore servicing equipment in contact with the fluid, such as
through corrosion and/or the formation of scale (e.g., in the form
of calcium, magnesium carbonates, and other scale-forming ions) on
flow surfaces of such wellbore servicing equipment. Further,
concentrations of such scale-forming ions may adversely affect the
intended function of a wellbore servicing fluid and/or render the
fluid unusable for use in wellbore servicing operations and/or for
use in the production of a wellbore servicing fluid.
[0029] Disclosed herein are embodiments of apparatuses, systems,
and methods of using the same, as may be useful for effectively
lowering the concentration of dissolved ions, such as scale-forming
ions, in wellbore fluids that may come in contact with one or more
surfaces of wellbore servicing equipment. Particularly, embodiments
of wellbore fluid treatment systems and wellbore servicing
apparatuses containing template-assisted crystallization beads,
methods of using the same, and a wellbore servicing equipment
de-scaling system comprising a surface wellbore fluid treatment
system and/or a wellbore servicing apparatus (e.g., downhole tool
or apparatus), will be disclosed herein.
[0030] In various embodiments disclosed herein, a plurality of TAC
beads are disposed within a confined space, but otherwise free to
move about and are mobile within the confined space. Such mobilized
TAC beads are in contrast to fixed beads such as adhered, coated or
otherwise affixed to a surface or structure. In some embodiments,
the mobilized TAC beads form a moving, percolating, or fluidized
bed within a confined space. Such mobilized TAC beads are effective
to induce turbulent fluid flow and perturbation there through which
aids in the effectiveness of the TAC beads in reducing scaling over
time.
[0031] FIG. 1 schematically illustrates an embodiment of an
environment in which a surface wellbore fluid treatment (SWFT)
system 110, a wellbore servicing apparatus 140 (e.g., a downhole
tool or apparatus), or a combination thereof may be deployed. In
the embodiment of FIG. 1, such an operating environment comprises a
wellsite 100 including a wellbore 115 penetrating a subterranean
formation 125 for the purpose of recovering hydrocarbons, storing
hydrocarbons, disposing of carbon dioxide, injecting wellbore
servicing fluids, or the like. In the embodiment of FIG. 1, a SWFT
system 110 for the treatment of a wellbore servicing fluid (WSF)
and/or a component thereof (e.g., water) is deployed at a wellsite
100 and is fluidly coupled to the wellbore 115 via a wellhead 160.
The wellbore 115 may be drilled into the subterranean formation 125
using any suitable drilling technique. In an embodiment, a drilling
or servicing rig 130 may generally comprise a derrick with a rig
floor through which a tubular string 135 (e.g., a drill string; a
work string, such as a segmented tubing, coiled tubing, jointed
pipe, or the like; a casing string; or combinations thereof) may be
lowered into the wellbore 115. A wellbore servicing apparatus 140
configured for one or more wellbore servicing operations (e.g., a
cementing or completion operation, a clean-out operation, a
perforating operation, a fracturing operation, production of
hydrocarbons, etc.) may be integrated within the tubular string 135
for the purpose of performing one or more wellbore servicing
operations. Additional downhole tools may be included with and/or
integrated within the wellbore servicing apparatus 140 and/or the
tubular string 135, for example, one or more isolation devices 145
(for example, a packer, such as a swellable or mechanical packer)
may be positioned within the wellbore 115 for the purpose of
isolating a portion of the wellbore 115.
[0032] The drilling or servicing rig may be conventional and may
comprise a motor driven winch and other associated equipment for
lowering the tubular string 135 and/or wellbore servicing apparatus
140 into the wellbore 115. Alternatively, a mobile workover rig, a
wellbore servicing unit (e.g., coiled tubing units), or the like
may be used to lower the tubular string 135 and/or wellbore
servicing apparatus 140 into the wellbore 115 for the purpose of
performing a wellbore servicing operation.
[0033] The wellbore 115 may extend substantially vertically away
from the earth's surface 150 over a vertical wellbore portion, or
may deviate at any angle from the earth's surface 150 over a
deviated or horizontal wellbore portion. Alternatively, portions or
substantially all of the wellbore 115 may be vertical, deviated,
horizontal, and/or curved. In some instances, a portion of the
tubular string 135 may be secured into position within the wellbore
115 in a conventional manner using cement 155; alternatively, the
tubular string 135 may be partially cemented in wellbore 115;
alternatively, the tubular string 135 may be uncemented in the
wellbore 115. In an embodiment, the tubular string 135 may comprise
two or more concentrically positioned strings of pipe (e.g., a
first pipe string such as jointed pipe or coiled tubing may be
positioned within a second pipe string such as casing cemented
within the wellbore). It is noted that although one or more of the
figures may exemplify a given operating environment, the principles
of the devices, systems, and methods disclosed may be similarly
applicable in other operational environments, such as offshore
and/or subsea wellbore applications.
[0034] In an embodiment, the SWFT system 110 may be coupled to the
wellhead 160 via a conduit 165, and the wellhead 160 may be
connected to (e.g., fluidly) the tubular string 135. In various
embodiments, the tubular string 135 may comprise a casing string, a
liner, a production tubing, coiled tubing, a drilling string, the
like, or combinations thereof. The tubular string 135 may extend
from the earth's surface 150 downward within the wellbore 115 to a
predetermined or desirable depth, for example, such that the
wellbore servicing apparatus 140 is positioned substantially
proximate to a portion of the subterranean formation 125 to be
serviced (e.g., into which a fracture 170 is to be introduced).
Flow arrows 180 and 175 indicate a route of fluid communication
from the SWFT system 110 to the wellhead 160 via conduit 165, from
the wellhead 160 to the wellbore servicing apparatus 140 via
tubular string 135, and from the wellbore servicing apparatus 140
into the wellbore 115 and/or into the subterranean formation 125
(e.g., into fractures 170). The wellbore servicing apparatus 140
may be configured to perform one or more servicing operations, for
example, fracturing the formation 125, hydrajetting and/or
perforating casing (when present) and/or the formation 125,
expanding or extending a fluid path through or into the
subterranean formation 125, producing hydrocarbons from the
formation 125, or other servicing operation. In an embodiment, the
wellbore servicing apparatus 140 may comprise one or more ports,
apertures, nozzles, jets, windows, or combinations thereof suitable
for the communication of fluid from a flowbore of the tubular
string 135 and/or a flowbore of the wellbore servicing apparatus
140 to the subterranean formation 125. In an embodiment, the
wellbore servicing apparatus 140 is actuatable (e.g., opened or
closed), for example, comprising a housing comprising a plurality
of housing ports and a sleeve being movable with respect to the
housing, the plurality of housing ports being selectively
obstructed or unobstructed by the sliding sleeve so as to provide a
fluid flowpath to and/or from the wellbore servicing apparatus 140
into the wellbore 115, the subterranean formation 125, or
combinations thereof. In an embodiment, the wellbore servicing
apparatus 140 may be configurable for the performance of multiple
wellbore servicing operations.
[0035] In an embodiment, the SWFT system 110 generally comprises a
flowpath in which a WSF and/or a component thereof is brought into
contact with a quantity of template assisted crystallization (TAC)
beads. In the embodiment of FIG. 2A, the SWFT system 110 generally
comprises a flowpath from (e.g., via fluidly connecting) a fluid
source 200 (e.g., a water source), a fluid treatment unit (FTU)
310, one or more storage vessels (such as storage vessels 205, 215,
220, and 230) a blender 240, a wellbore services manifold 250, and
one or more high pressure (HP) pumps 260. In additional or
alternative embodiments, a SWFT system may comprise any suitable
additional components, or any suitable combination of any of these
or any additional component. Persons of ordinary skill in the art
with the aid of this disclosure will appreciate that the flowpaths
described herein may include various configurations of piping,
tubing, etc. that are fluidly connected, for example, via flanges,
collars, welds, etc. These flowpaths may include various
configurations of pipe tees, elbows, and the like. These flowpaths
fluidly connect the various WSF process equipment described
herein.
[0036] In an embodiment, a SWFT system such as SWFT system 110 may
be configured for any suitable wellbore servicing operation, such
as a drilling operation, a hydrajetting or perforating operation, a
remediation operation, a fluid loss control operation, a primary or
secondary cementing operation, or combinations thereof. For
example, in the embodiment of FIG. 1, the SWFT system is
illustrated as configured for a subterranean formation stimulation
operation (e.g., perforating and/or fracturing), for example, for
initiating, forming, or extending a fracture (such as fractures 170
of FIG. 1) within a hydrocarbon-bearing portion of a subterranean
formation (such as subterranean formation 125), or a portion
thereof. In such a stimulation operation (e.g., a hydraulic
fracturing operation), a WSF, such as a particle (e.g., proppant)
laden fluid (e.g., a fracturing fluid), may be introduced, at a
relatively high-pressure, into the wellbore 115. The particle laden
fluids may then be introduced into a portion of the subterranean
formation 125 at a rate and/or pressure sufficient to initiate,
create, or extend one or more fractures 170 within the subterranean
formation 125. Proppants (e.g., grains of sand, glass beads,
shells, ceramic particles, etc.,) may be mixed with the WSF, for
example, so as to keep the fractures open (e.g., to "prop" the
fractures) such that hydrocarbons may flow into the wellbore 115 so
as to be produced from the subterranean formation 125. Hydraulic
fracturing may create high-conductivity fluid communication between
the wellbore 115 and the subterranean formation 125, for example,
to enhance production of fluids (e.g., hydrocarbons) from the
formation.
[0037] In an embodiment, the fluid source 200 (e.g., a water
source) may comprise produced water, flowback water, surface water,
a water well, potable water, municipal water, or combinations
thereof. For example, in an embodiment the water obtained from the
fluid source 200 may comprise produced water that has been
extracted from the wellbore 115 while producing hydrocarbons from
the wellbore 115. As discussed above, produced water may comprise
dissolved scale-forming ions (e.g., calcium ions, magnesium ions,
iron ions, strontium ions, manganese ions aluminum ions, sulfate
ions, hydrogen carbonate ions, carbonate ions, sodium ions, etc.)
and/or other natural or synthetic constituents that are displaced
from a hydrocarbon formation during the production of the
hydrocarbons or from a wellbore servicing operation. In an
additional or alternative embodiment, water obtained from the fluid
source 200 may comprise flowback water, for example, water that has
previously been introduced into the wellbore 115 during a wellbore
servicing operation and subsequently flowed back or returned to the
surface. In addition, the flowback water may comprise hydrocarbons,
gelling agents, friction reducers, surfactants, and/or remnants of
WSFs previously introduced into the wellbore 115 during wellbore
servicing operations.
[0038] In another additional or alternative embodiment, water
obtained from the fluid source 200 may comprise local surface water
contained in natural and/or manmade water features (such as
ditches, ponds, rivers, lakes, oceans, etc.). Further, water
obtained from the fluid source 200 may comprise water obtained from
water wells or a municipal source. Water obtained from the fluid
source 200 may comprise water that originated from near the
wellbore 115 and/or may be water or another liquid (e.g., a
non-aqueous fluid) that has been transported to an area near the
wellbore 115 from any distance. Still further, water or another
fluid obtained from the fluid source 200 may comprise water stored
in local or remote containers. In some embodiments, water obtained
from the fluid source 200 may comprise any combination of produced
water, flowback water, local surface water, municipal water, and/or
container-stored water. As discussed earlier, local surface water,
municipal water, water from local or remote containers, etc., may
also include ions, such as scale-forming ions.
[0039] In an embodiment, the water from fluid source 200 of FIG. 2A
may be introduced via a conduit 202 into an untreated water storage
vessel 205 where it may be temporarily stored prior to being pumped
to FTU 310 via a conduit 302. Alternatively, the water may be
introduced directly from the fluid source 200 into the FTU 310.
[0040] In an embodiment, the FTU 310, as will be disclosed herein
with reference to FIG. 2B, may be configured to treat a fluid
(e.g., water) obtained from the fluid source 200 in order to render
the water suitable for use in preparing a WSF and/or for
utilization in a wellbore servicing operation. For example, as will
be disclosed herein, the FTU 310 may be configured to render inert
(e.g., by converting into crystals) scale-forming ions that may
negatively affect the performance of the wellbore servicing
equipment that the water contacts. In an embodiment, after
treatment via the FTU 310, the water may be introduced via a
conduit 312 into an intermediate storage vessel 215 for treated
water. Alternatively, the water may be routed to one or more other
components of the SWFT system 110 or may be used immediately (e.g.,
treated and used in real time) in forming a WSF.
[0041] In the embodiment of FIG. 2A, the water may be introduced
into a mixer or blender 240 from a storage vessel (e.g., the
intermediate storage vessel 215 in the embodiment of FIG. 2A) via a
conduit 217. Alternatively, the water may be introduced into the
blender 240 directly from the FTU 310. In an embodiment, the
blender 240 may be configured to mix solid and fluid components to
form a well-blended WSF. As depicted in the embodiment of FIG. 2A,
water from a storage vessel (e.g., storage vessel 215), a WSF
component from storage vessel 220, and one or more other components
such as additives from storage vessel 230 may be fed into the
blender 240 via conduits 217, 222 and 232, respectively. The
blender 240 may comprise any suitable type and/or configuration of
blender. The mixing conditions of the blender 240, including time
period, agitation method, pressure, and temperature of the blender
240, may be chosen by one of ordinary skill in the art with the aid
of this disclosure to produce a homogeneous blend having a
desirable composition, density, and viscosity. In alternative
embodiments, however, sand or proppant (e.g., WSF components),
water, and additives may be premixed and/or stored in a storage
tank before entering the blender 240. For example, in an embodiment
an Advanced Dry Polymer (ADP) blender may be utilized to dry blend
one or more dry components, which may then be dry fed into the
blender 240. In another embodiment, additives may be pre-blended
with water or other liquids, for example, using a GEL PRO blender,
which is a commercially available from Halliburton Energy Services,
Inc., to form a liquid gel concentrate that may be fed into the
blender 240. In the embodiment of FIG. 2A, the blender 240 is in
fluid communication with a wellbore services manifold 250 via a
conduit 242.
[0042] In the embodiments of FIG. 2A, the WSF may be introduced
into the wellbore services manifold 250 from the blender 240 via
conduit 242. As used herein, the term "wellbore services manifold"
may include a mobile vehicle, such as a truck and/or trailer,
comprising one or more manifolds for receiving, organizing, and/or
distributing WSFs during wellbore servicing operations. In the
embodiment illustrated by FIG. 2A, the wellbore services manifold
250 is coupled to eight HP pumps 260 via outlet conduits 252 and
inlet conduits 262. In alternative embodiments, however, there may
be more or fewer HP pumps 260 used in a wellbore servicing
operation. The HP pumps 260 may comprise any suitable type of high
pressure pump, a nonlimiting example of which is a positive
displacement pump. Outlet conduits 252 are outlet lines from the
wellbore services manifold 250 that supply fluid to the HP pumps
260. Inlet conduits 262 are inlet lines from the HP pumps 260 that
supply fluid to the wellbore services manifold 250. In an
embodiment, the HP pumps 260 may be configured to pressurize the
WSF to a pressure suitable for delivery into the wellhead 160. For
example, the HP pumps 260 may increase the pressure of the WSF to a
pressure of about 10,000 p.s.i., alternatively, about 15,000
p.s.i., alternatively, about 20,000 p.s.i. or higher.
[0043] From the HP pumps 260, the WSF may reenter the wellbore
services manifold 250 via inlet conduits 262 and be combined so
that the WSF may have a total fluid flow rate that exits from the
wellbore services manifold 250 through conduit 165 to the wellbore
115 of between about 1 BPM to about 200 BPM, alternatively from
between about 50 BPM to about 150 BPM, alternatively about 100
BPM.
[0044] In an embodiment, the WSF comprises a quantity of at least
one WSF additive, for example, depending on the wellbore servicing
operation. For example, in an embodiment where the wellbore
servicing operation comprises a hydraulic fracturing operation, the
at least one WSF component may comprise a quantity of proppant.
Nonlimiting examples of suitable proppants include resin coated or
uncoated sand, sintered bauxite, ceramic materials, glass beads,
ground shells, fruit pits, or hulls, resin coated ground shells,
fruit pits or hulls, plastics, or combinations thereof. In an
embodiment, the proppant may be present within the WSF (e.g., a
fracturing fluid) in a range from about 0.1 pounds of proppant per
gallon of fracturing fluid to about 25 pounds of proppant per
gallon of fracturing fluid, alternatively, from about 0.5
pounds/gallon to about 10 pounds/gallon, alternatively, from about
3 pounds/gallon to about 8 pounds/gallon. In an embodiment, the
proppant may be present within the WSF (e.g., a fracturing fluid)
in a range from about 1 pounds of proppant per gallon of fracturing
fluid to about 10 pounds of proppant per gallon of fracturing
fluid, alternatively, from about 3 pounds/gallon to about 8
pounds/gallon, alternatively, from about 5 pounds/gallon to about 6
pounds/gallon.
[0045] In an alternative embodiment, for example, in an embodiment
where the wellbore servicing operation comprises a gravel-packing
operation, the at least one WSF component may comprise a quantity
of gravel. The gravel particles are sized such that they are small
enough to ensure that sand from the formation cannot penetrate the
gravel pack formed by the WSF (e.g., a gravel-packing fluid). In an
embodiment, the gravel may be present in the WSF (e.g., a
gravel-packing fluid) in a range from about 0.1 pounds of gravel
per gallon of gravel packing fluid to about 15 pounds of gravel per
gallon of gravel-packing fluid, alternatively, from about 1
pound/gallon to about 12 pounds/gallon, alternatively, from about 5
pounds/gallon to about 8 pounds/gallon.
[0046] In other alternative embodiments, the WSF may comprise any
suitable additional type or formulation of fluid as may be suitable
for use in a wellbore servicing operation, such as a drilling
operation, a hydrajetting or perforating operation, a remediation
operation, a fluid loss control operation, a primary or secondary
cementing operation, or combinations thereof. For example, in an
embodiment, the WSF may comprise a drilling fluid, a hydrajetting
or perforating fluid, a fluid loss control fluid, a remedial fluid,
a sealant composition, a cementitious slurry, or combinations
thereof. One of skill in the art, upon viewing this disclosure,
will recognize one or more WSF components that may be included
within the WSF to yield a WSF (for example, of the types set forth
herein) so as to be suitable for use in the performance of a
wellbore servicing operation.
[0047] In an embodiment, the WSF may further comprise one or more
additives. In an embodiment, the one or more additives may comprise
any suitable additive or combination of additives. Nonlimiting
examples of such additives include, but are not limited to,
polymers, crosslinkers, friction reducers, defoamers, foaming
surfactants, fluid loss agents, weighting materials, latex
emulsions, dispersants, vitrified shale and other fillers such as
silica flour, sand and slag, formation conditioning agents, hollow
glass or ceramic beads, elastomers, carbon fibers, glass fibers,
metal fibers, minerals fibers, of combinations thereof. One of
skill in the art will appreciate that one or more of such additives
may be added, alone or in combination, and in various suitable
amounts to yield a WSF of a desired character and/or
composition.
[0048] In an embodiment, the WSF is delivered into either a
subterranean formation (e.g., formation 125), a wellbore formed
within the subterranean formation (e.g., wellbore 115), or both. In
an embodiment, the step of delivering the WSF into the wellbore,
the subterranean formation, or both may comprise pressurizing the
WSF for example, via the operation one or more high-pressure pumps
(e.g., HP pump 260) and a wellbore manifold (e.g., wellbore
services manifold) to a pressure suitable for performing the
wellbore servicing operation.
[0049] For example, in an embodiment where the WSF is utilized in
the performance of a fracturing operation, the WSF may be delivered
at a pressure and rate sufficient to form or extend a fracture
(e.g., fracture 170) in a subterranean formation and to deposit a
proppant layer or bed (e.g., comprising TAC beads) therein. In
another embodiment where the WSF is utilized in the performance of
a gravel packing operation, the WSF may be delivered into the
wellbore at a pressure and rate suitable for forming a gravel pack
(e.g., gravel pack 182) comprising the WSF and TAC beads within the
wellbore.
[0050] In the embodiment of FIG. 2A, the SWFT system 110 comprises
a FTU, for example, a fluidized bed FTU (FBFTU) 310 such as shown
in FIG. 2B. In an embodiment, the FBFTU 310 may be configured to
contact a fluid (e.g., from fluid source 200, such as water) and a
quantity of TAC beads, for example, at a rate and/or ratio
sufficient to render inert at least a portion of one or more ionic
constituents (e.g., scale-forming ions) therefrom. For example, in
an embodiment, the FBFTU 310 is configured to lower the
concentration of dissolved ions, such as scale-forming ions, within
a fluid (e.g., from fluid source 200) introduced to the FBFTU 310.
The FBFTU 310 may be configured to lower the concentration of
dissolved ions, such as scale-forming ions, within a fluid without
injecting or dispersing any other fluid or chemical reactant (e.g.,
a water softener) into the fluid stream introduced to the FBFTU
310. Additionally, in an embodiment the FBFTU 310 may be configured
to retain the TAC beads within the FBFTU 310.
[0051] The FBFTU 310 may be configured to contact a fluid (e.g.,
from fluid source 200, such as water) and a quantity of
template-assisted crystallization beads 235, for example, at a rate
and/or ratio sufficient to form a fluidized bed between the fluid
and the template assisted crystallization beads 235 and sufficient
to render inert at least a portion of one or more ionic
constituents therefrom. In an embodiment, the one or more ionic
constituents comprise one or more species of scale-forming ions.
For example, in an embodiment, the FBFTU 310 is configured to lower
the concentration of scale-forming ions within a fluid (e.g., from
fluid source 200) introduced to the FBFTU 310. Scale-forming ions
suitable for treatment include, but are not limited to calcium
ions, magnesium ions, strontium ions, manganese ions aluminum ions,
sulfate ions, hydrogen carbonate ions, carbonate ions, sodium ions,
or any combination thereof. Particularly, in an embodiment as will
be disclosed herein, the FBFTU 310 may be configured to lower the
concentration of scale-forming ions within a fluid without
injecting or dispersing any other fluid or chemical reactant (e.g.,
a water softener) into the fluid stream introduced to the FBFTU
310. Additionally, in an embodiment the FBFTU 310 may be configured
to retain the template assisted crystallization beads 235 within
the FBFTU 310 while allowing wellbore fluids, additives,
particulate additives having sizes smaller than the template
assisted crystallization beads, or any combination thereof to enter
FBFTU 310, contact TAC beads 235, and then exit FBFTU 310.
[0052] Referring to FIG. 2B, an embodiment of the FBFTU 310 is
illustrated. In the embodiment of FIG. 2B, the FBFTU 310 generally
comprises at least one vessel 330 including a plurality of TAC
beads 235. For example, in the embodiment of FIG. 2B, the FBFTU 310
comprises two vessels 330; alternatively, a FBFTU may comprise any
suitable number of vessels (e.g., one, three, four, five, six,
seven, eight, nine, ten, or more vessels). In the embodiment of
FIG. 2B, the vessels 330 are arranged in parallel; alternatively, a
plurality of vessels may be configured in any suitable arrangement
(e.g., in series, or both in series and in parallel). In an
embodiment, vessels 330 may be oriented vertically, horizontally,
or a combination thereof with respect to the surface (e.g., the
earth's surface 150). In an embodiment, the vessels 330 may be
situated on a common structural support, alternatively multiple,
separate structural supports. Examples of a suitable structural
support or supports for these units may include a trailer, truck,
skid, barge or combinations thereof.
[0053] In the embodiment of FIG. 2B, an untreated fluid stream 211
may be introduced into the vessels 330 of FBFTU 310 via the conduit
302. In an embodiment, each of the one or more vessels 330
generally comprises a housing 233 having a cross-sectional area and
containing a quantity of TAC beads 235. The vessels may comprise
one or more inlets 232 and one or more outlets 234. In such an
embodiment, the vessels 330 are configured such that the TAC beads
235 may move freely within the confines of vessels 330 and come
into contact with the untreated fluid stream 211. Also, in such an
embodiment, each of the vessels 330 is configured to retain the
quantity of TAC beads 235 therein. For example, in the embodiment
of FIG. 2B, TAC beads 235 move freely within vessels 330 as they
contact untreated fluid stream 211 passing through vessels 330.
However, TAC beads 235 are also prevented and/or restricted from
leaving vessels 330 with the fluid stream 211 to prevent and/or
restrict the loss of any TAC beads, alternatively, the loss of a
substantial amount of the TAC beads, therefrom. For instance, the
vessels may comprise one or more screens, filters, meshes,
supports, trays, or combinations therein, which may be placed
within the vessels 330, at an inlet 232 and/or outlet 234 of the
vessel, upstream and/or downstream from the vessel 330, or
combinations thereof. In such an embodiment, the pore or opening
sizes of such a screen, filter, and/or mesh may be chosen based on
the sizing, type and/or volume of the TAC beads within the vessel
330. For instance, in an embodiment, the vessels 330 may contain
one or more of a screen, filter, filter or mesh which may have
pore/opening size ranging from about 60 mesh to about 10 mesh,
alternatively, about 48 mesh, about 40 mesh, about 35 mesh, about
32 mesh, about 30 mesh, about 28 mesh, about 24 mesh, about 22
mesh, about 20 mesh, about 18 mesh, about 16 mesh, about 14 mesh,
or about 12 mesh, or combinations thereof. As used herein, the term
"mesh" refers to the sizing of a material, according to the
standardized Tyler mesh size, that will pass through some specific
mesh (e.g., such that any particle of a larger size will not pass
through this mesh) but will be retained by some specific tighter
mesh (e.g., such that any particle of a smaller size will pass
through this mesh).
[0054] In an embodiment, the vessels 330 may be characterized as
being sized, for example, to accommodate a desired flow rate. For
example, the vessels may be configured to retain a suitable volume
of TAC beads. For example, each of the vessels may comprise TAC
beads ranging from about 25 lbs. to about 300 lbs., alternatively,
from about 75 lbs. to about 250 lbs., alternatively, from about 125
lbs. to about 200 lbs. In an embodiment, the vessels may be
configured to provide contact between a fluid stream being treated
and the quantity of TAC beads retained therein at a suitable rate
and/or for a suitable duration. For example, the vessels 330 may be
characterized as having a flow volume (in which the quantity of TAC
beads 235 is retained) having a suitable length, a suitable
cross-section area, and a suitable length to cross-sectional area
ratio. As will be appreciated by one of skill in the art upon
viewing this disclosure, and not intending to be bound by theory,
increases in the length of the flow volume of the vessel 330 may
generally increase the duration of the exposure (e.g., contact
time) of the fluid being treated to the TAC beads (e.g., at a given
flow-rate), and increases in the cross-sectional area of the vessel
may increase the flow-rate of fluid that may be exposed to the TAC
beads. For example, in an embodiment, the flow volume of the
vessels 330 may be in the range of from about 10 gal. to about 200
gal., alternatively, from about 50 gal. to about 160 gal.,
alternatively, from about 90 gal to about 120 gal. Also, in an
embodiment the cross-sectional area (e.g., the area of a
cross-section generally perpendicular to the direction of fluid
flow) of the vessels 330 may be in the range of from about 120
in.sup.2 to about 2,000 in.sup.2, alternatively, from about 250
in.sup.2 to about 1,800 in.sup.2, alternatively, from about 450
in.sup.2 to about 1,500 in.sup.2, alternatively, from about 600
in.sup.2 to about 1,000 in.sup.2. Also, in an embodiment the ratio
of length to cross-sectional area of the flow volume of the vessels
330 may be in the range of from about 2:1 to about 1:150,
alternatively, from about 1:4 to about 1:1, alternatively, from
about 1:3 to about 1:2. In an embodiment, the flow area of each of
the vessels 330 may comprise a suitable volume of TAC beads.
[0055] In an embodiment, the FBFTU 310 may be configured such that
TAC beads 235 form a fluidized bed with untreated fluid stream 211
as untreated fluid stream 211 passes through vessels 330. Vessel
sizes, vessel geometries, TAC bead loadings, values of other
process parameters relevant to fluidization bed fluidization, or
any combination thereof suitable for achieving fluidization between
the TAC beads and an untreated fluid stream at a given fluid flow
rate may be determined by one of ordinary skill in the art with the
aid of this disclosure. For example, an untreated fluid stream may
be flowed via a feed conduit into the bottom of a vertical
cylindrical vessel containing TAC beads. By selecting a vessel
having an inner diameter of about 6 inches and a height of about 48
inches, a feed conduit having an inner diameter of about 1 inch,
and a quantity of the TAC beads in a range of from about 30% to
about 75%, a fluidized bed may be achieved at untreated fluid feed
rates of about 50 gallons/minute (gal/min). In an embodiment, each
of vessels 330 may be loaded with a suitable volume of loose TAC
beads to provide optimal fluidization for an anticipated fluid flow
rate through vessels 330. For example, the vessels may each
comprise a volume of TAC beads of from about 200 in.sup.3 to about
18,000 in.sup.3, alternatively, from about 720 in.sup.3 to about
9,000 in.sup.3, alternatively, from about 2,000 in.sup.3 to about
6,000 in.sup.3. Thus, the FBFTU 310 may be sized to treat a
suitable volume of fluid (e.g., untreated water), for example, the
FBFTU 310 may be configured for the treatment of from about 100
gal/min to 2,000 gal/min, alternatively, from about 150 gal/min to
about 1,000 gal/min. Not wishing to be bound by theory, it is
believed that mechanical action of the induced turbulence of the
wellbore fluid, alone or further enhanced by fluidized bed
conditions, maintains an increased proportion of the crystalline
solids in an agitated state. As a result, the crystalline solids
remained in solution to a greater extent than, for example, laminar
flow regimes, thereby further reducing the formation of scale on
pipes and other wellbore servicing equipment that the wellbore
fluid comes into contact with.
[0056] In an embodiment, each vessel 330 may further include an
inlet valve 236 and an outlet valve 237. Inlet valves 236 and
outlet valves 237 may allow for the flow rate through each of the
vessels 330 to be controlled independently and/or for an individual
vessel 330 to be isolated (e.g., allowing for the total flow rate
via the FBFTU 310 to be scaled-up or scaled-down and/or allowing
for maintenance such as TAC bead change-outs during ongoing fluid
treatment operations).
[0057] In an embodiment, the FBFTU 310 may further comprise one or
more filtration devices, for example, located upstream from the one
or more vessels 330. In such an embodiment, the filtration device
may be configured to remove particulate material, sediment, or
various other contaminants from a fluid stream, for example, prior
to introduction of the fluid stream into the vessels 330.
[0058] In an embodiment, the pH of the one or more streams may be
monitored. For example, in an embodiment, the pH of the untreated
fluid stream 211 may be monitored prior to being introduced into
the vessels 330. In addition, if the pH of the fluid stream is not
within a suitable pH range, the pH of the water may be adjusted.
Such a suitable pH may be from about 6.0 to about 9.0,
alternatively, from about 6.5 to about 8.5, alternatively, from
about 7.0 to about 8.0. In such an embodiment, the pH may be
adjusted via the introduction of an additive, such as one or more
of various basic and/or acidic compositions, as may be appreciated
by one of skill in the art with the aid of this disclosure, for
example, to bring the pH of the water stream within the desired pH
range.
[0059] Referring to FIGS. 2A and 2B, while in the embodiment of
FIG. 2A a single FBFTU 310 is shown upstream of the blender 240, in
alternative embodiments a plurality of FBFTUs may be employed
and/or one or more FBFTUs may be located in alternative positions
within the SWFT system 110. For example, one or more FBFTUs may be
located upstream of the blender (e.g., as shown in FIG. 2A), one or
more FBFTUs may be located downstream of the bender, or both. In an
embodiment, one or more FBFTUs are used to form treated water, and
the treated water may be used in a variety of additional
operations, for example as a component in preparing one or more
wellbore servicing fluids (e.g., prepared in blender 240).
Additionally or alternative, upon preparation of a WSF or component
there (e.g., a treated and/or untreated fluid such as water
combined with one or more additional WSF components such as gels,
proppants, etc.), such prepared WSF or component thereof may be
further treated via a FBFTU of the type described herein. For
instance, in an embodiment the FBFTU 310 may be located downstream
from a first blender like blender 240 and, optionally, upstream
from a second blender. In such an embodiment, a fluid stream
comprising one or more pre-blended WSF components may be introduced
into the FBFTU 310 for treatment. Also, in such an embodiment, the
FBFTU 310 is configured to reduce the concentration of dissolved
ions, such as scale-forming ions, within the fluid. Accordingly,
FBFTUs of the type described herein may be used to treat a
component of a WSF (e.g., water), to treat a WSF (e.g., a
fracturing fluid, for example an aqueous gel system prior to
addition of proppant), or combinations thereof.
[0060] While in the embodiment of FIG. 2B, the FBFTU 310 comprises
a vessel 330, in an alternative embodiment the FBFTU 310 may
comprise other wellbore servicing equipment configured to provide
contact between a fluidized, percolating, or otherwise
mobile/moving quantity of TAC beads and a fluid stream (e.g.,
untreated fluid stream 211). For example, the FBFTU 310 may
comprise other types of wellbore servicing equipment that may be
configured to contact a fluid stream with a fluidized, percolating,
or otherwise mobile/moving quantity of TAC beads, such as a
pressure vessel, a water storage tank, or combinations thereof.
[0061] In an embodiment, the TAC beads may be effective to reduce
the concentration of dissolved ions, such as scale-forming ions
(e.g., calcium ions, magnesium ions, iron ions, strontium ions,
manganese ions aluminum ions, sulfate ions, hydrogen carbonate
ions, carbonate ions, sodium ions, etc.), present within a solution
or composition. In an embodiment, the TAC beads may be
characterized as having a size (e.g., a diameter) of ranging from
about 0.500 millimeters (mm) to about 0.900 mm, alternatively, from
about 0.550 mm to about 0.850 mm, alternatively, from about 0.600
mm to about 0.800 mm. In an embodiment, the quantity of beads may
be characterized as having a mesh size ranging from about 20/40
mesh to about 16/30 mesh. As used herein, the term "mesh" refers to
the sizing of a material, according to the standardized Tyler mesh
size, will pass through some specific mesh (e.g., such that any
particle of a larger size will not pass through this mesh) but will
be retained by some specific tighter mesh (e.g., such that any
particle of a smaller size will pass through this mesh.
[0062] In an embodiment, the TAC beads generally comprise a
generally spheroidal body having an outer surface. The generally
spheroidal body may comprise a polymeric material. For example, in
an embodiment, the generally spheroidal body of the TAC beads
comprises a modified acrylic copolymer, a modified styrenic
copolymer, or combinations thereof. Examples of a suitable modified
styrenic or acrylic copolymer include, but are not limited to,
poly(styrene-co-styrene sulfonate), poly(methyl acrylate),
polymethyl methacrylate (PMMA), poly(butyl acrylate), polyvinyl
acetate, and combination thereof. Not intending to be bound by
theory, in an embodiment, at least a portion (for example, at least
50%, alternatively, at least 60%, 70%, 80%, 90%, or 95%) of the TAC
beads may be crosslinked with diacrylates, for example, so as to
increase the geometric integrity of the TAC beads. In an
embodiment, the outer, generally spheroidal surface of a given TAC
bead may comprise a plurality of templates (e.g., dimples) disposed
on and/or at least partially within the outer surface of the
generally spheroidal body (e.g., similar in appearance to a golf
ball). In an embodiment, the templates may comprise a curved,
concave surface geometry. The templates may be distributed about
the surface of the spheroidal body in various configurations. For
example, the templates may be distributed about the surface of the
spheroidal body uniformly, evenly, randomly, or any combination
thereof. Not intending to be bound by theory, the surface
morphology of the TAC beads, which may comprise a great number of
nucleation sites, may contribute to the formation of crystals over
the surface of the TAC beads. In an embodiment, the nucleation site
may comprise one or more suitable functional moieties, for example,
as may contribute to the crystallization of scale-forming ions.
Example of suitable functional moieties may include, but are not
limited to, carboxylic acid functional moieties, sulfonate
functional moieties, or combinations thereof.
[0063] Not seeking to be bound by theory, the TAC beads may be
configured to convert dissolved scale-forming ions into inert
crystalline solids. For example, not intending to be bound by
theory, the templates may act as a site for heterogeneous
nucleation. For example, the surface geometry of the templates is
configured to provide a lower energy path for the formation of a
crystalline solid from a plurality of ions through the process of
nucleation. During nucleation at or within a template disposed on a
TAC bead, a nucleus of solute molecules (e.g., scale-forming ions)
is formed and reaches a critical size so as to stabilize within the
solvent. Not intending to be bound by theory, once a nucleus has
reached the critical size, where the crystalline structure has
begun to form, crystal growth of the nucleus may continue until the
size of the forming crystal reaches a point where it breaks free
from the template of the TAC bead. Once the crystal (e.g., an inert
crystalline solid) has broken free from the template, it may
continue absorbing other dissolved ions within the solvent, acting
as a site for homogenous nucleation. Not intending to be bound by
theory, crystals formed from TAC beads may be kept in the fluid
stream, and with their presence, may further accelerate the
conversion of dissolves ions into crystals within the fluid stream.
As such, the quantity of TAC beads may aid in converting dissolved
scale-forming ions into inert crystalline solids. An example of
suitable TAC beads is commercially available from Next.TM.
Filtration Technologies, Inc. of Lake Worth, Fla. as ScaleStop.TM..
The TAC beads may be provided in a dry form, alternatively, as
solution or slurry.
[0064] For example, not intending to be bound by theory, the
reaction by which an ion is converted into a crystal (e.g., an
inert crystalline solid) at a nucleation site of a TAC bead may
react according to the formula:
Ca.sup.2++2HCO.sub.3.fwdarw.CaCO.sub.3+H.sub.2O+CO.sub.2 Formula
I.
[0065] Thus, in the nonlimiting example set forth in Formula I, a
cation (e.g., Ca.sup.+2) is transformed into a crystal (e.g.,
CaCO.sub.3). In addition, the one or more of the products of the
reaction set forth in Formula I may react according to the
formula:
CO.sub.2+H.sub.2O.sub.3.fwdarw.H.sub.2CO.sub.3 Formula II.
[0066] Further, in the nonlimiting example set forth in Formula II,
byproducts of the reaction set forth in Formula II (e.g., H.sub.2O
and CO.sub.2) may react to yield carbonic acid (e.g.,
H.sub.2CO.sub.3), thereby lowering the pH of the fluid stream. In
an embodiment, a reduction of the fluid stream pH may lead to
dissolution of existing scale. For example, a reduction in the pH
of a fluid stream treated with a quantity of TAC beads may dissolve
existing scale from at least one surface in fluid communication
with a flowpath of the treated fluid. Surfaces that may be in fluid
communication with a flowpath of the treated fluid may include, but
are not limited to, surfaces of a wellbore, a subterranean
formation, a component of wellbore servicing equipment, or any
combination thereof.
[0067] In an embodiment, the SWFT system may be employed to reduce
the rate of accumulation of scale on surfaces of wellbore servicing
equipment over time, to reduce the presence of accumulated scale on
surfaces of wellbore servicing equipment, or a combination thereof.
The SWFT system may also be effective in reducing the rate of scale
accumulation, reducing the presence of previously accumulated
scale, or a combination thereof, on other surfaces in fluid
communication with a fluid treated by the SWFT system including,
but not limited to, wellbore surfaces, surfaces of a subterranean
formation, or a combination thereof. In an embodiment, the SWFT
system may reduce the rate of accumulation of scale on surfaces of
wellbore servicing equipment over time, reduce the presence of
accumulated scale on surfaces of wellbore servicing equipment, or a
combination thereof, without generating a separate waste stream.
Although not wishing to be bound by theory, it is believed that the
mechanisms utilized by the TAC beads do not require the use of
additional harmful chemicals to convert the scale-forming ions into
inert crystalline solids or to dissolve pre-existing scale. In
contrast, scale reduction and/or prevention treatments utilizing
conventional chemical scale inhibitors result in a waste stream.
Such waste streams may require additional treatment before being
released into the environment, long-term storage, or a combination
thereof.
[0068] One or more embodiments of a SWFT system 110 having been
disclosed, one or more embodiments of the method of servicing a
wellbore utilizing the SWFT system 110 are also disclosed herein.
Referring to FIG. 3, a method of servicing a wellbore in accordance
with an embodiment of the disclosure is generally described. In an
embodiment shown in FIG. 3, the wellbore servicing method 400
begins at step 401, wherein a wellbore servicing system, such as
the wellbore servicing system 110 of FIG. 1, is provided, prepared,
or otherwise procured at a wellsite. In an embodiment, the step of
providing a wellbore servicing system at a wellsite may comprise
providing and/or obtaining access to a wellsite such as wellsite
100 of FIG. 1, for example, having a wellbore 115 penetrating a
subterranean formation 125 or a portion thereof. In an embodiment,
a wellbore 115 may comprise a tubing string like tubing string 135
positioned within the wellbore 115 and a wellhead like wellhead 160
providing access to the tubing string 135. Alternatively, a tubing
string may be absent from the wellbore and may later be positioned
therein (e.g., via a mobile, coiled-tubing rig or the like), for
example, for the purpose of communicating a wellbore fluid, such as
a WSF, into the wellbore and/or the formation. In another
embodiment, the step of providing a wellbore servicing system at a
wellsite may comprise transporting one or more components of the
wellbore servicing system to the wellsite. For example, one or more
components of wellbore servicing equipment, such as the storage
vessels 205, 215, 220, and/or 230, the FBFTU 310, blender 240, the
wellbore services manifold 250, the HP pumps 260, various other
servicing equipment, or combinations thereof may be transported to
or otherwise provided at the wellsite. In such an embodiment, one
or more of any such components may be configured for transport, for
example one or more of such components may be positioned on a
truck, a trailer, a skid, a barge, a boat, or other support thereby
rendering the servicing equipment mobile. In yet another
embodiment, the step of providing a wellbore servicing system at a
wellsite may comprise accessing a fluid source, such as the fluid
source 200 illustrated in FIGS. 2A and 2B. In such an embodiment
and as noted above, the water from the fluid source 200 may
comprise produced water, flowback water from the formation,
municipal water, surface water, other sources of water, or
combinations thereof. In an alternative embodiment, for example,
wherein the fluid further comprises a non-aqueous fluid (e.g., an
oleaginous fluid, for example to form an emulsion), the fluid
source may comprise a fluid vessel containing a stored fluid. In
still another embodiment, the step of providing a wellbore
servicing system at a wellsite may comprise fluidly coupling
components of the wellbore servicing system (e.g., the storage
vessels 205, 215, 220, and/or 230, the FBFTU 310, blender 240, the
wellbore services manifold 250, the HP pumps 260, or combinations
thereof) to each other, to the fluid source, and/or to the wellbore
115 (e.g., via the wellhead 160), for example, as illustrated in
FIGS. 1, 2A, and 2B.
[0069] The method 400 may progress to step 403 wherein a fluid
(e.g., water) containing scale-forming ions is provided. The fluid
may comprise any wellbore servicing fluid and/or component thereof
containing scale-forming ions. In an embodiment, the fluid may be a
mixture of fluids drawn from two or more fluid sources, wherein at
least one of the fluids comprises scale-forming ions. In various
embodiments, the fluid may include, but is not limited to, one or
more of the fluids described above in connection with fluid source
200. In various embodiments, the fluid may comprise produced water,
flowback water, formation fluid, municipal water, surface water or
any combination thereof. In an embodiment, at least a portion of
the fluid containing scale-forming ions may be provided by
producing a fluid from a subterranean formation.
[0070] The method 400 may progress to step 405, wherein the fluid
is contacted with the TAC beads and a fluidized bed comprising the
TAC beads and the fluid is formed. As the fluid passes through the
bed of TAC beads, contact of the fluid with the TAC beads results
in fluidization, percolation, and/or movement of the beads, thus
forming a fluidized bed as the term is understood to those skilled
in the art.
[0071] The method 400 may progress to step 407, wherein the fluid
is separated from the TAC beads and recovered as a treated fluid.
For example, the TAC beads may be retained within the contacting
vessel, for example via a screen. In an alternative embodiment, any
suitable solid-fluid separation device may be employed, for
example, a gravity separator or a centrifuge. In an embodiment, TAC
beads may exit the top of the vessel along with the treated fluid,
and the TAC beads may be separated from the fluid (for example, via
gravity) and returned to the vessel and fluidized bed.
[0072] The method 400 may progress to step 409, wherein a WSF is
formed from the treated fluid. For example, the treated fluid may
be combined with a variety of additives and components of the type
described herein to produce a WSF suitable for use in a wellbore
and/or surrounding formation. The method 400 may progress to step
417, wherein the wellbore servicing fluid is delivered and placed
into a wellbore penetrating a subterranean formation, the
subterranean formation, or both.
[0073] Embodiments of a SWFT system and methods of employing such
wellbore fluid treatment systems have been disclosed herein. Also
disclosed herein, are embodiments of a wellbore servicing apparatus
(e.g., a downhole tool or apparatus) capable of treating wellbore
fluids with template-assisted crystallization beads retained
therein. Referring to FIGS. 4A-4B, a simplified schematic view of a
wellbore servicing apparatus 500 in accordance with an embodiment
of the disclosure is shown. The wellbore servicing apparatus 500
may be situated within a wellbore 505 and generally comprises a
housing 550 and a mandrel 555 within the housing. The wellbore
servicing apparatus 500 may also comprise an annular space 560,
which is located between an outer circumferential surface 556 of
mandrel 555 and an inner circumferential surface 551 of housing
550. Template-assisted crystallization beads 545 may be retained
within annular space 560 such that the TAC beads 545 can move
around freely within the confines of the annular space 560.
Additionally, in an embodiment the wellbore servicing apparatus 500
may be configured to retain the template assisted crystallization
beads within the annular space 560 while allowing produced fluids,
wellbore servicing fluids, additives, particulate additives having
sizes smaller than the template assisted crystallization beads, or
any combination thereof to enter the annular space 560, contact TAC
beads 545, and then exit the annular space 560.
[0074] Still referring to FIGS. 4A-4B, a flowpath 585 between an
interior 520 and an exterior 515 (allowing fluid flow from interior
to exterior and/or vice-versa) of the wellbore servicing apparatus
500 may be in fluid communication with the annular space 560 such
that fluid may flow through the annular space 560 and contact the
TAC beads 545. In various embodiments, the interior 520 of the
wellbore servicing apparatus 500 may comprise an inner flowbore
510, which is bounded by an inner circumferential surface 552 of
the mandrel 555. In various embodiments, the flow of fluid between
the exterior 515 of the wellbore servicing apparatus 500 and the
annular space 560 may be facilitated by openings 561, which may
extend through housing 550. In various embodiments, the flow of
fluid between the inner flowbore 510 and the annular space 560 may
be facilitated by openings 562, which may extend through mandrel
555.
[0075] In an embodiment, the housing 550, the mandrel 555, or both
may be porous, perforated, or otherwise constructed such that fluid
may readily flow there through. For example, the housing 550, the
mandrel 555 or both may be constructed of or comprise perforated
pipe, closely spaced tubing/rod rings or a helix of tubing or solid
rod (having a structure similar to a compressed coil spring with
fluid flow space between closely spaced adjacent coils, referred to
herein as helical coiled tubing), a screen, or combinations
thereof. Referring to FIG. 4C, the housing 550 may comprise helical
coiled tubing 557, and may further comprise a screen on the
interior surface 551 and/or outer surface 549. In such an
embodiment, interstitial spaces 559 extending between adjacent
coils of helical coiled tubing 557 may function as the openings 561
through which fluid may pass. Likewise, mandrel 555 may comprise
helical coiled tubing 553, and may further comprise a screen on the
interior surface 552 and/or exterior surface 556. In such an
embodiment, interstitial spaces 558 existing between and extending
through adjacent coils of helical coiled tubing 553 and may
function as the openings 562 through which fluid may pass. Suitable
screening materials may comprise, for example, 30X.09 stainless
steel wire, and may comprise sieve openings in a range from about
0.15 mm to about 0.5 mm. In some embodiments, the screening
material may have pore/opening sizes ranging from about 60 mesh to
about 10 mesh, alternatively, about 48 mesh, about 40 mesh, about
35 mesh, about 32 mesh, about 30 mesh, about 28 mesh, about 24
mesh, about 22 mesh, about 20 mesh, about 18 mesh, about 16 mesh,
about 14 mesh, or about 12 mesh, or combinations thereof. Suitable
helical coiled tubing may comprise, for example, stainless steel
rod having a diameter of about 0.25 mm arranged in a tightly wound,
closely spaced helix.
[0076] Referring again to FIGS. 4A-4B, fluid may flow from the
formation/wellbore into the inner flowbore 510 (e.g., a produced
fluid such as hydrocarbons and/or water), from the inner flowbore
510 out into the exterior 515 of the wellbore servicing apparatus
500 (e.g., a WSF pumped downhole), or a combination thereof by
passing through annular space 560 and openings 561, 562. In an
embodiment and as illustrated by flowpath arrow 580a, a wellbore
servicing fluid containing scale-forming ions (for example, a
fracturing fluid) may flow from inner flowbore 510, through annular
space 560 and openings 561, 562, and to the exterior 515 of
wellbore servicing apparatus 500. The wellbore servicing fluid may
further flow from exterior 515 into one or more fractures 540, and
possibly even into the unconsolidated portions of the subterranean
formation 535 surrounding the one or more fractures 540. In various
embodiments, the wellbore fluid flowing into exterior 515 comprises
a WSF. Various WSFs suitable for use with various embodiments of
the wellbore servicing apparatus, such as the wellbore servicing
apparatus 500, are described in more detail herein. In another
embodiment and as illustrated by flowpath 580b of FIGS. 4A-4B, a
formation fluid (e.g., hydrocarbons and/or water) may flow from
unconsolidated portions of subterranean formation 535 to exterior
515 of the wellbore servicing apparatus 500 by way of one or more
fractures 540. The formation fluid may continue on from exterior
515, through annular space 560 and openings 561, 562, and into
inner flowbore 510. Formation fluids, such as a formation fluid
following the flowpath illustrated by 580b, may present, for
example, during a production phase of a wellbore such as wellbore
505.
[0077] Still referring to FIGS. 4A-4B, a fluid may contact one or
more of TAC beads 545 as the fluid containing scale-forming ions
(for example, water produced from a hydrocarbon production well or
water from a geothermal well) flows through annular space 560. In
various embodiments, the TAC beads 545 induce a turbulent flow 530
of the fluid as the fluid passes through the annular space 560. In
various embodiments, the TAC beads 545 contact the fluid passing
through the annular space 560 such that a fluidized bed is formed
between the TAC beads 545 and the fluid. Annular space sizes,
annular space geometries, TAC bead loadings, values of other
process parameters relevant to bed fluidization, or any combination
thereof suitable for achieving fluidization between the TAC beads
and a wellbore fluid stream at a given wellbore fluid flow rate may
be determined by one of ordinary skill in the art with the aid of
this disclosure. In an embodiment, annular space 560 may be loaded
with a suitable volume of loose TAC beads to provide optimal
fluidization for an anticipated fluid flow rate through wellbore
servicing apparatus 500. As discussed above, the
template-crystallization beads may convert at least a portion of
the scale-forming ions into inert crystalline solids dispersed
freely within the fluid. Not wishing to be bound by theory, it is
believed that mechanical action of the fluidized bed allows for
breaking off of micro and nano scale mineral particles form the TAC
beads, and perturbation of the fluidized bed maintains the
crystalline solids in solution to a greater extent than would be
possible under, for example, laminar flow conditions. Thus, it is
believed that the rendering of the scale-forming ions into inert
crystalline solids and the maintaining of those crystalline solids
in solution reduces the rate of growth of scale on tubing and on
surfaces of other wellbore servicing equipment over time.
[0078] In various embodiments, a method of servicing a wellbore is
provided that comprises placing a wellbore servicing apparatus
containing TAC beads into a wellbore, and contacting a fluid
containing scale-forming ions (e.g., a produced fluid such as
water, a wellbore servicing fluid or component thereof, or both)
with at least a portion of the TAC beads. In an embodiment, TAC
beads move freely within a chamber of the wellbore servicing
apparatus. In another embodiment, the fluid circulates from a
subterranean formation and then through a chamber of the wellbore
servicing apparatus containing the TAC beads. In yet another
embodiment, the TAC beads induce a turbulent flow of the fluid,
form a fluidized bed with the fluid, or a combination thereof. In
still another embodiment, a concentration of scale-forming ions in
the fluid prior to contacting the TAC beads is greater than about
50 parts per million (ppm). In still another embodiment, a
concentration of scale-forming ions in the fluid prior to
contacting the TAC beads is reduced by at least 10, 20, 30, 40, 50,
60, 70, 80, or 90% via contact with the TAC beads.
[0079] In an embodiment, the wellbore servicing apparatus comprises
a packer containing template-assisted crystallization beads within
a lining (e.g., an annular space such as annular space 560
described herein) of the packer. In an embodiment, a portion of the
packer (e.g., a sub-assembly) of the packer is similar to that
shown in FIGS. 4A-C, with additional components such as a plurality
of sealing elements and a slip-wedge system for gripping the
wellbore and setting the packer. The production packer may be
inserted into a wellbore during the course of or in anticipation of
a production phase of the wellbore. The production packer may be
designed, placed, configured, or any combination thereof such that
at least a portion of production fluids emerging from production
zones of the subterranean formation of the wellbore pass through
the lining (e.g., annular space 560), contact the TAC beads, and
form a fluidized bed comprising the production fluids and the TAC
beads before flowing to the surface through a production string
flowbore. The production packer may be designed, placed,
configured, or any combination thereof such that at least a portion
of one or more wellbore servicing fluids introduced into the
wellbore, the production zone, the subterranean formation, or any
combination thereof via the production packer passes through the
lining (e.g., annular space 560), contacts the TAC beads, and forms
a fluidized bed with the TAC beads. In an exemplary embodiment, the
wellbore servicing apparatus 400 is placed within a production zone
of a well-bore as a production packer.
[0080] Wellbore servicing apparatuses designed, configured, and
placed in a wellbore according to various embodiments of the
disclosure may present a longer-term solution for reducing,
preventing, or reducing and preventing the accumulation of scale on
surfaces of wellbore servicing equipment over time in comparison to
conventional scale prevention measures, such as the administration
of scale inhibitors. Although not wishing to be bound by theory, it
is believed that self-regenerating properties of the TAC beads in
combination with the scale reducing and/or preventing mechanisms
described above (e.g., conversion of the ions to an inert
crystalline solid freely suspended within the wellbore fluid)
enables various embodiments of the wellbore servicing apparatus
disclosed herein to continue over several months. In contrast,
conventional chemical scale inhibitors, typically administered as a
squeeze treatment in a single administration, provide more limited
options for long-term scale-inhibition. Furthermore, scale
inhibitors are often chemically incompatible with fracturing fluids
introduced into the wellbore as they compete with the zirconium and
aluminum based cross-linkers included in the fracturing fluid to
facilitate rapid viscosification once the fracturing fluid has been
introduced into a wellbore. Thus, wellbore servicing apparatuses
according to embodiments of the disclosure present additional
advantages over conventional scale inhibition in that neither the
TAC beads nor the inert crystalline solids produced therefrom
chemically interfere with other aspects of the wellbore
operations.
[0081] Embodiments of SWFT systems 110 and wellbore servicing
apparatuses 500 capable of treating wellbore fluids have been
disclosed herein. Also disclosed herein are embodiments wherein at
least one embodiment of the SWFT systems and at least one
embodiment of the wellbore servicing apparatuses are integrated
into a single wellbore servicing system. As used herein, the term
"integrated wellbore fluid treatment system" (IWFT system) refers
to wellbore servicing systems utilizing at least one SWFT system
and at least one wellbore servicing apparatus of the disclosure to
treat one or more wellbore fluids comprising scale-forming
ions.
[0082] Referring now to FIG. 5A, an IWFT system 600 in accordance
with an embodiment of the disclosure is shown situated in a
wellbore environment similar to the wellbore environment described
with respect to FIG. 1. IWFT system 600 generally comprises a SWFT
system 610 (for example, similar to SWFT 110 described herein), a
first flowpath 605, a wellbore servicing apparatus 640 (for
example, similar to wellbore servicing apparatus 500 described
herein), and a second flowpath 615. A vessel 620 of the SWFT system
610 and the wellbore servicing apparatus 640 may comprise chambers
625,630, respectively. In an embodiment, the wellbore servicing
apparatus 640 comprises a production packer 680 and the chamber 630
is defined by an annular space within the production packer
assembly. TAC beads 635 may be contained by but freely disposed
within the chamber 625 of the vessel 620, the chamber 630 of the
wellbore servicing apparatus 640, or a combination thereof. The
first flowpath 605 (e.g., a flowpath for placement of fluid into
the wellbore and/or surrounding formation) may establish fluid
communication between a fluid source 636 and chamber 625 via a
first conduit 675, and between the chamber 625 and the wellbore 650
via a second conduit 680. The second flowpath 615 (e.g., a flowpath
for recovery of a fluid from the wellbore and/or the surrounding
formation to the surface) may establish fluid communication between
a space 655 within the wellbore 650 that is exterior to wellbore
servicing apparatus 640 and chamber 630, and between chamber 630
and a flowbore 645 of the wellbore servicing apparatus 640. The
second flowpath 615 may further establish fluid communication
between space 655 and a space exterior to the wellbore. For
example, in an embodiment the second flowpath 615 may establish
fluid communication with one or more fractures 665 of subterranean
formation 670. The second flowpath 615 may also establish fluid
communication between flowbore 645 and a space 660 exterior to the
wellbore. Space 660 may be, for example, an open space (e.g., a
storage pit, tank, etc.), a space inside wellbore servicing
equipment located outside the well, or a combination thereof. In an
embodiment, the second flowpath 615 may establish fluid
communication between flowbore 645 and a space 660 inside a holding
tank 695 via a conduit 690. In an embodiment, the first flowpath
605 may be in fluid communication with the second flowpath 615, for
example such that a wellbore servicing fluid (e.g., fracturing
fluid) may be formed from water treated via contact with a mobile
or fluidized bed of TAC beads, placed downhole, and recovered (and
treated via further contact with a mobile or fluidized bed of TAC
beads) while being flowed back to the surface from downhole.
[0083] Also disclosed herein are embodiments of an IWFT method. As
used herein, the term "integrated wellbore fluid treatment method"
refers to an embodiment of a wellbore fluid treatment method
wherein the number of untreated wellbore fluid flowpaths in a
wellbore environment is reduced by treating wellbore fluids at two
or more locations. For example, a method utilizing the IWFT system
600 of FIG. 5A is an integrated WFT method in accordance with an
embodiment of the disclosure because all flowpaths in fluid
communication with flowbore 645 pass through a fluidized bed of TAC
beads before entering flowbore 645. Fluids originating from
fractures 665 and flowing up through flowbore 645 along the second
flowpath 615 are treated by the wellbore servicing apparatus 640
before entering flowbore 645. Likewise, fluid entering flowbore 645
from the surface along flowpath 605 are treated by SWFT system 610
before entering flowbore 645. Without the presence of both SWFT
system 610 and wellbore servicing apparatus 640, the inner surfaces
685 of flowbore 645 would be exposed to untreated wellbore fluids
passing through flowbore 645 via an untreated wellbore fluid
flowpath, which could lead to the formation of scale therein.
[0084] Referring to FIG. 5B, an IWFT method 700 in accordance with
an embodiment of the disclosure is generally described. The IWFT
method 700 may begin at block 710, wherein an integrated wellbore
servicing system (e.g., SWFT system 610 and wellbore servicing
apparatus 640) is provided at a wellsite. The wellbore servicing
system generally comprises at least one SWFT system and at least
one wellbore servicing apparatus, each containing TAC beads and
made in accordance with an embodiment of the disclosure. In an
embodiment, a SWFT comprising an FBFTU made in accordance with an
embodiment of the disclosure is provided at a surface location of
the wellbore environment and TAC beads are contained by but freely
disposed within a chamber of the FBFTU. In an embodiment, TAC beads
are contained by but freely disposed within a liner (e.g., annular
space or other chamber) of a wellbore servicing apparatus provided
at a downhole location inside a wellbore.
[0085] The IWFT method 700 may progress to block 720, wherein fluid
is treated by passing the fluid through a fluidized bed comprising
the fluid and the TAC beads. In an embodiment, two or more fluids
may be treated simultaneously, at different times, or a combination
thereof. In an embodiment, the FBFTU of the SWFT and the wellbore
servicing apparatus may treat fluids simultaneously, at different
times, or a combination thereof. In an embodiment, a WSF or
component thereof (e.g., water) is treated at the surface, pumped
downhole and into the wellbore and/or surrounding formation, and is
recovered and treated downhole prior to being flowed back to the
surface.
[0086] THE IWFT method 700 may progress to block 730, wherein fluid
treated according to block 720 is transported along a wellbore
fluid flowpath such that the fluid traverses an outer boundary of
the wellbore. Examples of an outer boundary of the wellbore include
the wellhead (which is an outer boundary of fluid flow from the
wellbore) and/or a production zone and/or surrounding formation
(which is an outer boundary of fluid flow into the formation via
the wellbore). In other words, a fluid is first treated at the
surface and/or downhole prior to flowing through a flowpath defined
by the wellbore such that scaling within the wellbore (e.g.,
production tubing and related equipment) is reduced. In an
embodiment, a wellbore fluid forms a fluidized bed with TAC beads
when passing through a chamber of the FBFTU of the SWFT before
traversing an outer boundary of a wellbore. In an embodiment, a
wellbore fluid forms a fluidized bed with TAC beads when passing
through a chamber (e.g., an annular space) of a wellbore servicing
apparatus before passing through the outer boundary of the
wellbore.
[0087] Advantageously, various embodiments of IWFT systems and
methods may be employed to reduce the rate of accumulation of scale
on surfaces of wellbore servicing equipment disposed within a
wellbore environment over time. Various embodiments of IWFT systems
and methods of the disclosure may also advantageously reduce the
presence of accumulated scale on surfaces of wellbore servicing
equipment by, for example, the mechanism described above in
connection with formula I.
[0088] In various embodiments of the disclosure, apparatuses,
systems, and methods of using the same may utilize mobilized TAC
beads (e.g., fluidized beds of TAC beads) to reduce the rate of
accumulation of scale, reduce the presence of previously
accumulated scale, or a combination thereof, on surfaces wellbore
servicing equipment over time. Various apparatuses, systems, and
methods disclose herein may utilize mobilized TAC beads (e.g.,
fluidized beds of TAC beads) to treat wellbore fluids containing
quantities of scale-forming ions at concentrations of greater than
about 50 ppm. In an embodiment, a method of servicing a wellbore
utilizing a FBFTU containing TAC beads, a wellbore servicing
apparatus containing TAC beads in a chamber (e.g., a production
packer comprising a liner containing TAC beads freely disposed
therein) may be utilized to treat wellbore fluids comprising one or
more species of scale-forming ions, wherein an initial
concentration of the scale-forming ions is greater than about 50
parts per million. In an embodiment, a wellbore fluid containing
calcium ions, magnesium ions, or a combination thereof present in
concentrations of greater than about 50 ppm may be treated with one
or more embodiments of the apparatuses, systems, and methods
disclosed herein such that the concentrations may be substantially
reduced by converting the ions into inert crystalline solids freely
dispersed within the wellbore fluid.
[0089] As noted above, a fluid (e.g., water) that contains various
contaminants, such as those mentioned above, may adversely affect
the intended function of a WSF formed therefrom and/or adversely
affect wellbore servicing equipment in contact with such a fluid
(e.g., water) and/or such a WSF, such as through the formation of
scale on the inner flow surfaces of the wellbore servicing
equipment. As disclosed herein, a concentration of scale-forming
ions (e.g., calcium ions, magnesium ions, iron ions, strontium
ions, manganese ions aluminum ions, sulfate ions, hydrogen
carbonate ions, carbonate ions, sodium ions, etc.) may be
substantially reduced within a fluid stream, for example, via the
systems, apparatuses, and/or methods disclosed herein. For example,
as disclosed herein, a concentration of scale-forming ions (e.g.,
calcium ions, magnesium ions, iron ions, strontium ions, manganese
ions aluminum ions, sulfate ions, hydrogen carbonate ions,
carbonate ions, sodium ions, etc.) may be substantially reduced
within formation fluids produced from a formation, such as
formation fluids produced from the subterranean formation 125.
Conventional means of reducing the concentration of scale-forming
ions, for example, various chemicals, such as water softening
chemicals, may also not be effective when included within a WSF
and/or may undesirably alter the character or composition of the
WSF, and the present disclosure provides a suitable alternative.
Further, the addition of such chemicals to a WSF may adversely
affect the performance of such a fluid and/or be harmful to the
environment. As such, the instantly-disclosed compositions and
methods allow for a reduction of scale-forming ions in WSFs (or
component fluids thereof) and produced (e.g., formation) fluids,
thereby decreasing the incidence of scaling of various servicing
equipment, within the wellbore, and/or within the formation. As
such, the instantly-disclosed compositions and methods allow for
improved productivity of formation fluids and decreased downtime
resulting from scaling, corrosion, or other damage due to the
presence of scale-forming ions.
Additional Disclosure
[0090] The following are nonlimiting, specific embodiments in
accordance with the present disclosure:
[0091] A first embodiment, which is a method of servicing a
wellbore, comprising:
[0092] placing a wellbore servicing apparatus into a wellbore,
wherein the wellbore servicing apparatus contains a plurality of
mobilized template-assisted crystallization beads; and
[0093] contacting a fluid comprising scale-forming ions with at
least a portion of the template-assisted crystallization beads.
[0094] A second embodiment, which is the method of the first
embodiment, wherein the wellbore servicing apparatus comprises a
packer and the template-assisted crystallization beads are
contained within a chamber of the packer.
[0095] A third embodiment, which is the method of one of the first
through the second embodiments, wherein the fluid flows from a
subterranean formation and then through a chamber of the wellbore
servicing apparatus containing the template-assisted
crystallization beads.
[0096] A fourth embodiment, which is the method of one of the first
through the third embodiments, wherein the template-assisted
crystallization beads induce turbulent flow of the fluid.
[0097] A fifth embodiment, which is the method of one of the first
through the fourth embodiments, wherein the mobilized
template-assisted crystallization beads form a fluidized bed upon
flow of the fluid there through.
[0098] A sixth embodiment, which is the method of one of the first
through the fifth embodiments, wherein the scale-forming ions
comprise calcium, magnesium, strontium, aluminum, hydroxide,
sulfate, hydrogen carbonate, carbonate, sodium, or any combination
thereof.
[0099] A seventh embodiment, which is the method of one of the
first through the sixth embodiments, wherein a concentration of the
scale-forming ions in the fluid prior to contacting the template
assisted crystallization beads is greater than about 50 ppm.
[0100] An eighth embodiment, which is the method of one of the
first through the seventh embodiments, further comprising
converting the scale-forming ions into crystalline solids freely
dispersed within the fluid.
[0101] A ninth embodiment, which is the method of the eighth
embodiment, wherein the crystalline solids are inert.
[0102] A tenth embodiment, which is the method of one of the first
through the ninth embodiments, wherein the method of servicing a
wellbore reduces the rate of accumulation of scale on at least one
surface of the wellbore, a subterranean formation, a component of
wellbore servicing equipment, or any combination thereof.
[0103] An eleventh embodiment, which is the method of one of the
first through one of the tenth embodiments, wherein the method of
servicing a wellbore reduces accumulated scale on at least one
surface of the wellbore, a subterranean formation, a component of
wellbore servicing equipment, or any combination thereof.
[0104] A twelfth embodiment, which is the method of one of the
tenth through the eleventh embodiments, wherein the wellbore
servicing equipment comprises piping.
[0105] A thirteenth embodiment, which is the method of one of the
first through the twelfth embodiments, wherein the template
assisted crystallization beads comprise a styrenic polymer, an
acrylic polymer, or combinations thereof.
[0106] A fourteenth embodiment, which is the method of one of the
first through the thirteenth embodiment, wherein the template
assisted crystallization beads are configured to provide a
plurality of nucleation sites for the crystallization of the
scale-forming ions.
[0107] A fifteenth embodiment, which is the method of one of the
first through fourteenth embodiments, wherein the plurality of
nucleation sites comprise carboxylic acid functional moieties,
sulfonate functional moieties, or combinations thereof.
[0108] A sixteenth embodiment, which is the method of one of the
first through the fifteenth embodiments, wherein the template
assisted crystallization beads are at least partially
self-regenerating
[0109] A seventeenth embodiment, which is a method of servicing a
wellbore, comprising:
[0110] contacting a fluid comprising scale-forming ions with a
quantity of template-assisted crystallization beads in a vessel to
form a treated fluid, wherein the template-assisted crystallization
beds are mobile within the vessel; and
[0111] placing the treated fluid into a wellbore, a subterranean
formation, or a combination thereof.
[0112] An eighteenth embodiment, which is the method of the
seventeenth embodiment,
[0113] wherein the template-assisted crystallization beads induce
turbulent flow of the fluid.
[0114] A nineteenth embodiment, which is the method of one of the
seventeenth through the eighteenth embodiments, wherein the
mobilized template-assisted crystallization beads form a fluidized
bed within the vessel.
[0115] A twentieth embodiment, which is the method of one of the
seventeenth through the nineteenth embodiments, further comprising
producing a fluid from the subterranean formation.
[0116] A twenty-first embodiment, which is the method of one of the
seventeenth through the twentieth embodiments, wherein the fluid
comprises at least a portion of the produced fluid from the
subterranean formation.
[0117] A twenty-second embodiment, which is the method of one of
the twentieth through the twenty-first embodiments, further
comprising returning the fluid to the subterranean formation.
[0118] A twenty-third embodiment, which is the method of one of the
seventeenth through the twenty-second embodiments, wherein the
fluid comprises a produced water, flowback water, a formation
fluid, or a combination thereof.
[0119] A twenty-fourth embodiment, which is the method of one of
the seventeenth through the twenty-third embodiments, wherein the
treated fluid further comprises one or more additional components
to form a wellbore servicing fluid.
[0120] A twenty-fifth embodiment, which is the method of the
twenty-fourth embodiment, wherein wellbore servicing fluid
comprises a substantially aqueous fluid, a brine, an emulsion, an
invert emulsion, an oleaginous fluid, or combinations thereof.
[0121] A twenty-sixth embodiment, which is the method of one of the
twenty-fourth through the twenty-fifth embodiments, wherein the
wellbore servicing fluid comprises a proppant.
[0122] A twenty-seventh embodiment, which is the method of one of
the twenty-fourth through the twenty-sixth embodiments, wherein the
wellbore servicing fluid comprises a fracturing fluid, a
gravel-packing fluid, or combinations thereof.
[0123] A twenty-eighth embodiment, which is the method of one of
the seventeenth through the twenty-seventh embodiments, wherein the
template-assisted crystallization beads reduce the rate of
accumulation of scale on one or more surfaces of wellbore servicing
equipment over time, reduce the presence of accumulated scale on
one or more surfaces of wellbore servicing equipment, or a
combination thereof, without generating a separate waste
stream.
[0124] A twenty-ninth embodiment, which is a wellbore servicing
apparatus, comprising:
[0125] a housing;
[0126] a mandrel within the housing;
[0127] an annular space between an outer circumferential surface of
the mandrel and an inner circumferential surface of the
housing;
[0128] a plurality of mobilized template-assisted crystallization
beads within the annular space;
[0129] a flowpath between an interior and an exterior of the
wellbore servicing apparatus that is in fluid communication with
the annular space such that a fluid may flow through the annular
space and contact the template-assisted crystallization beads.
[0130] A thirtieth embodiment, which is the apparatus of the
twenty-ninth embodiment, wherein the template-assisted
crystallization beads are configured to induce a turbulent flow of
a wellbore fluid as the wellbore fluid passes through the annular
space.
[0131] A thirty-first embodiment, which is the apparatus of one of
the twenty-ninth through the thirtieth embodiments, wherein the
housing comprises helical coiled tubing, a screen, or both.
[0132] A thirty-second embodiment, which is the apparatus of one of
the twenty-ninth through the thirtieth embodiments, wherein the
mandrel comprises helical coiled tubing, a screen, or both.
[0133] A thirty-third embodiment, which is a fluid treatment system
comprising:
[0134] a fluid source;
[0135] a vessel in fluid communication with the fluid source and
receiving fluid therefrom, wherein the vessel contains a plurality
of mobilized template-assisted crystallization beads; and
[0136] a wellhead in fluid communication with the vessel and
receiving a treated fluid therefrom.
[0137] A thirty-fourth embodiment, which is the fluid treatment
system of the thirty-third embodiment, wherein the
template-assisted crystallization beads are configured to induce a
turbulent flow of the fluid as the fluid passes through the
vessel.
[0138] A thirty-fifth embodiment, which is the fluid treatment
system of one of the thirty-third through the thirty-fourth
embodiments, wherein the mobilized template-assisted
crystallization beads form a fluidized bed upon flow of the fluid
there through.
[0139] A thirty-sixth embodiment, which is a wellbore servicing
system, comprising:
[0140] a first flowpath, comprising: [0141] a first conduit from a
fluid source to a vessel; [0142] a chamber of the vessel; and
[0143] a second conduit from the chamber within the vessel to a
wellbore,
[0144] a second flowpath, comprising: [0145] a space within the
wellbore and exterior to a wellbore servicing apparatus; [0146] a
chamber of the wellbore servicing apparatus; and [0147] a flowbore
of the wellbore servicing apparatus, and
[0148] a plurality of mobilized template-assisted crystallization
beads within the chamber of the vessel, within the chamber of the
wellbore servicing apparatus, or a combination thereof.
[0149] A thirty-seventh embodiment, which is the system of the
thirty-sixth embodiment, wherein the first flowpath is in fluid
communication with the second flowpath.
[0150] A thirty-eighth embodiment, which is a wellbore fluid
treatment method comprising treating a wellbore fluid traversing an
outer boundary of a wellbore by passing the wellbore fluid through
a plurality of mobilized template-assisted crystallization
beads.
[0151] A thirty-ninth embodiment, which is the method of the
thirty-eighth embodiment, wherein the template-assisted
crystallization beads are contained by but freely disposed within a
chamber of a surface fluid treatment vessel.
[0152] A fortieth embodiment, which is the method of one of the
thirty-eighth through the thirty-ninth embodiments, wherein the
wellbore fluid forms a fluidized bed with the template-assisted
crystallization beads when passing through the chamber and before
traversing the outer boundary of the wellbore.
[0153] A forty-first embodiment, which is the method of one of the
thirty-eighth through the fortieth embodiments, wherein the
template-assisted crystallization beads are contained by but freely
disposed within a chamber of a wellbore servicing apparatus inside
the wellbore.
[0154] A forty-second embodiment, which is the method of the
forty-first embodiment, wherein the wellbore fluid forms a
fluidized bed with the template-assisted crystallization beads when
passing through the liner of the wellbore servicing apparatus and
before traversing the outer boundary of the wellbore.
[0155] A forty-third embodiment, which is a wellbore fluid
treatment method comprising contacting a wellbore servicing fluid
or component thereof with a plurality of mobilized
template-assisted crystallization beads such that turbulent fluid
flow is induced.
[0156] While embodiments of the invention have been shown and
described, modifications thereof can be made by one skilled in the
art without departing from the spirit and teachings of the
invention. The embodiments described herein are exemplary only, and
are not intended to be limiting. Many variations and modifications
of the invention disclosed herein are possible and are within the
scope of the invention. Where numerical ranges or limitations are
expressly stated, such express ranges or limitations should be
understood to include iterative ranges or limitations of like
magnitude falling within the expressly stated ranges or limitations
(e.g., from about 1 to about 10 includes, 2, 3, 4, etc.; greater
than 0.10 includes 0.11, 0.12, 0.13, etc.). For example, whenever a
numerical range with a lower limit, R.sub.l and an upper limit,
R.sub.u, is disclosed, any number falling within the range is
specifically disclosed. In particular, the following numbers within
the range are specifically disclosed:
R=R.sub.l+k*(R.sub.u-R.sub.l), wherein k is a variable ranging from
1 percent to 100 percent with a 1 percent increment, i.e., k is 1
percent, 2 percent, 3 percent, 4 percent, 5 percent, 50 percent, 51
percent, 52 percent, 95 percent, 96 percent, 97 percent, 98
percent, 99 percent, or 100 percent. Moreover, any numerical range
defined by two R numbers as defined in the above is also
specifically disclosed. Use of the term "optionally" with respect
to any element of a claim is intended to mean that the subject
element is required, or alternatively, is not required. Both
alternatives are intended to be within the scope of the claim. Use
of broader terms such as comprises, includes, having, etc. should
be understood to provide support for narrower terms such as
consisting of, consisting essentially of, comprised substantially
of, etc.
[0157] Accordingly, the scope of protection is not limited by the
description set out above but is only limited by the claims which
follow, that scope including all equivalents of the subject matter
of the claims. Each and every claim is incorporated into the
specification as an embodiment of the present invention. Thus, the
claims are a further description and are an addition to the
embodiments of the present invention. The discussion of a reference
in the Detailed Description of the Embodiments is not an admission
that it is prior art to the present invention, especially any
reference that may have a publication date after the priority date
of this application. The disclosures of all patents, patent
applications, and publications cited herein are hereby incorporated
by reference, to the extent that they provide exemplary, procedural
or other details supplementary to those set forth herein.
* * * * *