U.S. patent application number 13/536478 was filed with the patent office on 2014-01-02 for wireline flow through remediation tool.
This patent application is currently assigned to BAKER HUGHES INCORPORATED. The applicant listed for this patent is Gary J. Cresswell, James William MacDonald. Invention is credited to Gary J. Cresswell, James William MacDonald.
Application Number | 20140000889 13/536478 |
Document ID | / |
Family ID | 49776944 |
Filed Date | 2014-01-02 |
United States Patent
Application |
20140000889 |
Kind Code |
A1 |
Cresswell; Gary J. ; et
al. |
January 2, 2014 |
WIRELINE FLOW THROUGH REMEDIATION TOOL
Abstract
A treatment tool treats downhole features with one additive
using sensors that acquire information relating to the downhole
feature. A conveyance device selectively positions the treatment
tool in a borehole. A related method includes acquiring information
relating to the downhole feature using a treatment tool positioned
in a borehole, estimating a condition relating to the downhole
feature based on the acquired information, and treating the
downhole feature using at least one additive applied by the
treatment tool. The method may also include estimating a change in
the condition of the downhole feature after the treatment of the
downhole feature.
Inventors: |
Cresswell; Gary J.; (Spring,
TX) ; MacDonald; James William; (The Woodlands,
TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Cresswell; Gary J.
MacDonald; James William |
Spring
The Woodlands |
TX
TX |
US
US |
|
|
Assignee: |
BAKER HUGHES INCORPORATED
HOUSTON
TX
|
Family ID: |
49776944 |
Appl. No.: |
13/536478 |
Filed: |
June 28, 2012 |
Current U.S.
Class: |
166/279 ;
166/75.12 |
Current CPC
Class: |
E21B 37/06 20130101;
E21B 49/00 20130101; E21B 43/25 20130101; E21B 47/00 20130101 |
Class at
Publication: |
166/279 ;
166/75.12 |
International
Class: |
E21B 21/06 20060101
E21B021/06; E21B 43/25 20060101 E21B043/25 |
Claims
1. A method for treating a downhole feature, comprising: acquiring
information relating to the downhole feature using a treatment tool
positioned in a borehole; estimating a condition relating to the
downhole feature based on the acquired information; treating the
downhole feature using at least one additive applied by the
treatment tool; and estimating a change in the condition of the
downhole feature after the treatment of the downhole feature.
2. The method of claim 1, wherein the downhole feature is a
naturally occurring feature selected from one of: (i) a subsurface
formation, and (ii) a fluid produced from the subsurface
formation.
3. The method of claim 1, wherein the downhole feature is a
human-made feature.
4. The method of claim 1, wherein the at least one additive is one
of: (i) an additive formulated to adjust a formation parameter;
(ii) an additive formulated to adjust a chemical property, (iii) an
additive formulated to adjust a fluid property, and (iv) a
corrosion inhibitor.
5. The method of claim 1, further comprising positioning the
treatment tool in the borehole, keeping the treatment tool in the
borehole while the condition is estimated, and conveying the
treatment tool out of the borehole after the treatment of the
downhole feature.
6. The method of claim 1, further comprising selectively isolating
a borehole location before treating the downhole feature.
7. The method of claim 1, further comprising moving the treatment
tool to a plurality of locations in the borehole.
8. The method of claim 1, further comprising flowing the at least
one additive through the treatment tool.
9. The method of claim 1, further comprising: drilling the borehole
using a drill string, wherein the treatment tool is positioned on
the drill string.
10. The method of claim 1, wherein the information relates to a
scale deposition indicator, the well condition relates to scale
formation, and the at least one additive includes a scale
inhibitor.
11. The method of claim 1, wherein the information relates to
asphaltene, the well condition relates to asphaltene deposition,
and the at least one additive includes an asphaltine inhibitor.
12. An apparatus for treating a downhole feature, comprising: a
treatment tool configured to treat the downhole feature with at
least one additive; at least one sensor associated with the
treatment tool, the at least one sensor being configured to acquire
information relating to the downhole feature; and a conveyance
device configured to selectively position the treatment tool in a
borehole.
13. The apparatus of claim 12, wherein the conveyance device is a
tubular configured to convey the at least one additive to the
treatment tool.
14. The apparatus of claim 13, wherein the treatment tool includes
a port and a flow path for conveying the at least one additive from
the tubular to the port.
15. The apparatus of claim 14, wherein the at least one sensor is
positioned proximate to the port.
16. The apparatus of claim 14, wherein the at least one sensor
includes a plurality of sensors arrayed at the port.
17. The apparatus of claim 12, further comprising at least one
sealing device for selectively isolating a selected borehole
location.
18. The apparatus of claim 17, wherein the selected borehole
location is one of: (i) an area on a surface adjacent to the
treatment tool, and (ii) an annular space between the treatment
tool and an adjacent surface.
19. The apparatus of claim 12, further comprising a signal
conducting media configured to convey the information acquired by
the at least one sensor to a surface location.
20. The apparatus of claim 19, further comprising an information
processing device in signal communication with the signal
conducting media and configured to control the treatment tool in
response to the information acquired by the at least one
sensor.
21. The apparatus of claim 19, further comprising an information
processing device in signal communication with the signal
conducting media, the information processing device being
configured to at least one of: (i) estimate a condition relating to
the downhole feature based on the information acquired by the at
least one sensor; and (ii) estimate a change in the condition of
the downhole feature after the treatment of the downhole feature.
Description
BACKGROUND OF THE DISCLOSURE
[0001] 1. Field of the Disclosure
[0002] The disclosure relates generally to systems and methods for
treating subsurface features.
[0003] 2. Description of the Related Art
[0004] Hydrocarbons such as oil and gas are recovered from a
subterranean formation using a borehole drilled into the formation.
At times during or after the drilling of the borehole, it may be
desirable to alter a condition of a downhole feature. One example
of downhole feature having an undesirable condition is a formation
having poor fluid mobility. Another example is a borehole section
that may be structurally unstable. Still another example includes
downhole equipment (e.g., production tubing, pipelines, valves,
etc.) that may be exposed to substances that corrode, degrade or
otherwise reduce their efficiency or service life. Each of these
conditions may be improved by treating the downhole feature in
question with a suitable additive.
[0005] This disclosure provides, in part, enhanced additive
treatment systems and methods suitable for such uses.
SUMMARY OF THE DISCLOSURE
[0006] Aspects of the present disclosure may be used to diagnose,
treat, and evaluate a downhole feature in a single trip. The
downhole feature may be associated with a hydrocarbon producing
well, a geothermal well, a groundwater well, or any other borehole
formed in a subsurface formation.
[0007] In one aspect, a well treatment method according to the
present disclosure may include acquiring information relating to
the downhole feature using a treatment tool positioned in a
borehole; estimating a condition relating to the downhole feature
based on the acquired information; treating the downhole feature
using at least one additive applied by the treatment tool; and
estimating a change in the condition of the downhole feature after
the treatment of the downhole feature.
[0008] In another aspect, a well treatment apparatus according to
the present disclosure may include a treatment tool configured to
treat the downhole feature with at least one additive; at least one
sensor associated with the treatment tool, the at least one sensor
being configured to acquire information relating to the downhole
feature; and a conveyance device configured to selectively position
the treatment tool in a borehole.
[0009] It should be understood that examples of certain features of
the disclosure have been summarized rather broadly in order that
detailed description thereof that follows may be better understood,
and in order that the contributions to the art may be appreciated.
There are, of course, additional features of the disclosure that
will be described hereinafter and which will form the subject of
the claims appended hereto.
BRIEF DESCRIPTION OF THE DRAWINGS
[0010] The advantages and further aspects of the disclosure will be
readily appreciated by those of ordinary skill in the art as the
same becomes better understood by reference to the following
detailed description when considered in conjunction with the
accompanying drawings in which like reference characters designate
like or similar elements throughout the several figures of the
drawing and wherein:
[0011] FIG. 1 is a schematic elevation view of a treatment tool in
accordance with one embodiment of the present disclosure;
[0012] FIG. 2 is a schematic elevation view of a treatment tool
having sealing elements in accordance with one embodiment of the
present disclosure;
[0013] FIG. 3 is a schematic elevation view of a treatment tool
adapted for closed loop operation in accordance with one embodiment
of the present disclosure;
[0014] FIG. 4 is a schematic elevation view of a treatment tool
used in conjunction with a drilling system in accordance with one
embodiment of the present disclosure; and
[0015] FIG. 5 is a flow chart illustrating a treatment method in
accordance with one embodiment of the present disclosure.
DETAILED DESCRIPTION OF THE DISCLOSURE
[0016] The present disclosure relates to devices and methods for
treating downhole features, such as a hydrocarbon bearing formation
or well equipment, with one or more additives. The treatment may be
performed during any stage of well construction or production
(e.g., drilling, logging, workover, remediation, etc.). An
exemplary treatment system may be deployed to diagnose a particular
condition and introduce one or more additives selected to adjust
the condition. The additives may be any agent or substance that
interacts with the downhole feature in a predetermined manner. The
treatment system may also monitor the treatment to evaluate the
treatment effectiveness. Further, the systems may be self-contained
and mobile. That is, in a single trip, a condition of a selected
downhole feature may be evaluated, treated, and re-evaluated.
Moreover, the treatment system may be used to treat multiple zones
or locations along the borehole during a single trip. Illustrative
non-limiting embodiments of systems and related methods for
treating a downhole feature with an additive are discussed below.
While the present disclosure is discussed in the context of a
hydrocarbon producing well, it should be understood that the
present disclosure may be used in any borehole environment (e.g., a
geothermal well).
[0017] Referring now to FIG. 1, there is shown one embodiment of a
treatment system 10 for treating one or more downhole features of
interest. The treatment tool 10 may be conveyed along a borehole 12
via a conveyance device 14. In one embodiment, the treatment tool
10 may include a sub 16, a port 18 for dispensing additives, and
one or more sensors 20 for estimating one or more parameters of
interest. The conveyance device 14 may be a tubular such as coiled
tubing having a flow bore that conveys additives to the treatment
tool 10. A flow line 24 in the sub 16 directs the additive from the
conveyance device 14 to the port 18. The flow line 24 may be a
fluid pathway or passage in the sub 16.
[0018] The downhole features that may be treated by the treatment
tool 10 may be naturally occurring and/or human made. Illustrative
naturally occurring features include, but are not limited to, rock,
earth, soil, liquid hydrocarbons, gaseous hydrocarbons, brine,
water, and other substances, which may be homogeneous fluids or
mixtures of fluids, that make up a subsurface formation or are
produced from a subsurface formation. Illustrative human made
features include, but are not limited to: mechanical devices such
as wellbore tubulars (e.g., casing, liners, production tubing),
production devices, intelligent well completions, anchors, sand
screens, valves, packers; functional materials and chemicals such
as gravel, cement, proppants, surface injected fluids (e.g., water
or steam), and relative permeability modifiers; and other devices
that may be disposed in a borehole to perform one or more
functions. The human made feature(s) may be conveyed from the
surface into the borehole or constructed in situ. It should be
understood that the feature(s) to be treated may be inside a well
tubular, in an annulus between the well tubular and a borehole
wall, in a cement sheath between a well tubular and a formation, or
in the formation.
[0019] During drilling of the borehole or any time thereafter,
these downhole features may have or develop an undesirable
condition. As used herein, the term "condition" refers to a state,
property, phase, characteristic of the downhole feature.
Illustrative conditions include a material property (e.g.,
permeability, porosity, mobility, etc.), a mechanical property
(e.g., hardness, ductility, Young's Modulus, etc.), a chemical
property (e.g., acidity, pH), a fluid property (e.g., phase,
viscosity, salinity, water content, etc.), erosion, corrosion,
plugging, structural instability, etc. A condition may be
considered "undesirable" because it may impair hydrocarbon
production rates, damage a subsurface formation, reduce the service
life of well equipment, render a borehole unstable, or otherwise
reduce the efficiency or commercial value of a hydrocarbon
reservoir.
[0020] To identify and quantify such conditions, the sensors 20 may
be configured to acquire information relating to the downhole
feature(s) of interest. The sensors 20 may be in signal
communication with a controller (not shown) via a suitable
communication line 26. It should be understood that the type of
sensors 20 used on the treatment tool 10 depends on the downhole
feature to be treated. Illustrative, but not exhaustive, sensors
are discussed below.
[0021] For evaluating parameters of subsurface formations, the
sensors 20 may include formation evaluation sensors such as
resistivity tools, nuclear magnetic resonance (NMR) tools, gamma
ray detectors, acoustic tools, and other well logging tools that
provide information relating to a geological parameter, a
geophysical parameter, a petrophysical parameter, and/or a
lithological parameter. Thus, the sensors 20 may include sensors
for estimating formation resistivity, dielectric constant, the
presence or absence of hydrocarbons, acoustic porosity, bed
boundary, formation density, nuclear porosity and certain rock
characteristics, permeability, capillary pressure, and relative
permeability. It should be understood that this list is
illustrative and not exhaustive.
[0022] For estimating properties of downhole fluids (naturally
occurring or engineered), the treatment tool may include sensors 20
for estimating aromatic content; asphaltene content; bacterial
content; bubble point; chemical composition (this overlaps the
parameters with the word "content"); color; density; specific
gravity; hydrate (gas hydrate) content; naphthenic content;
nitrogen content; odor; oxygen content; radioactivity; salt
content; solids content; sulfur content; paraffinic content; pH
(acidity/alkalinity); phase (defined as gas or liquid); pressure;
temperature; viscosity. Illustrative devices include, but are not
limited to, spectrometers, dielectric sensors, optical analyzers,
detectors using gas chromatography, ion selective sensors,
resonators, refractometers, etc.
[0023] One or more of the sensors 20 may also be configured to
acquire information relating to the treatment tool 10. For example,
a sensor 21 may be positioned along the flow line 24 to monitor one
or more parameters relating to the additive(s) being dispensed by
the port 18. Illustrative parameters may include flow rate,
pressure, phase, etc.
[0024] To perform the treatments during a single trip, the
treatment tool 10 may use a "high bandwidth" transmission to
transmit the information acquired by the sensors 20 to the surface
for analysis. For instance, the communication line 26 for
transmitting the sensor information may be an optical fiber, a
metal conductor, or any other suitable signal conducting medium.
One non-limiting communication line is a TELECOIL coiled tubing
system available from BJ Services, Inc that uses coiled tubing with
a small diameter signal conductor line. It should be appreciated
that the use of a "high bandwidth" communication line may allow
surface personnel to monitor and control the treatment activity in
"real time." Also, the sensors 20 may be arrayed axially and/or
circumferentially along the sub 16 and the port 18 may be nested
within a cluster of sensors 20. Strategically distributing the
sensors 20 at and around the region where an additive is being
applied may increase the accuracy and resolution of the information
acquired by the sensors 20.
[0025] The port 18 may be configured to engage and seal against an
adjacent surface. As shown in FIG. 1, the surface may be a wall of
a casing 30 (which may be perforated). The port 18 may include a
packer element 19 that forms a circumferential seal around an
opening (not shown) of the port 18. The tool 10 may include arms or
stand-offs (not shown) positioned opposite of the port 18. These
arms or similar devices may be extended radially outward to thrust
the tool 10 and the port 18 against the desired surface.
Alternatively or additionally, the port 18 may include a radially
extendable probe that may be driven outward using a mechanical,
electro-mechanical, or hydraulic actuator (not shown).
[0026] In one exemplary mode of use, the treatment tool 10 is
conveyed into a selected location in the well 12 by the conveyance
device 14, which may be coiled tubing. Once appropriately
positioned, the sensors 20 may be used to acquire information
relating to one or more conditions in the well. Of course, the
sensors 20 may be operated to acquire information prior to
positioning as well. In either case, the sensors 20 generate
signals indicative of one or more parameters relating to the
downhole feature or features. These signals may be conveyed via the
signal conductor 26 to the surface. Personnel at the surface
process the sensor signals to estimate one or more downhole
conditions of interest. If personnel conclude that it is desirable
to adjust the condition(s), one or more additives are pumped down
the conveyance device 14 to the treatment tool 10. The port 18
expels the additive into the selected location. The sensors 20 may
continue to furnish information relating to the condition(s) during
treatment to thereby allow personnel at the surface to monitor the
treatment activity (e.g., evaluate a change in the downhole
condition).
[0027] Additionally, after the treatment is complete, the sensors
20 may be used to evaluate the effectiveness of the treatment. That
is, the sensors 20 may estimate one or more parameters relating to
the treated downhole feature to determine whether a particular
downhole condition has been adequately adjusted or whether further
treatment is desired. After the treatment is complete, the
treatment tool 10 may be retrieved to the surface. Alternatively,
the treatment tool 10 may be moved to one or more additional
locations in the borehole.
[0028] Referring to FIG. 2, there is shown another embodiment of a
treatment tool 10 in accordance with the present disclosure. The
FIG. 2 treatment tool 10 may include a sub 16, a port 18, and one
or more sensors 20. In this embodiment, the conveyance device 14
may be a wireline, e-line, or other non-rigid carrier that does not
have a bore suited to convey additives. Thus, a separate umbilical
31 may be used to convey additives to the treatment tool 10. For
example, the umbilical 31 may flow the additive(s) to a flow line
24 in the sub 16 that channels the additive(s) to the port 18.
[0029] The embodiment of FIG. 2 also includes sealing elements 40
that may be activated to form an isolated annular zone 42. The
sealing elements 40 may be packers or other suitable sealing
devices that engage and form an annular seal with an adjacent
surface (e.g., open hole surface, liner, casing, etc.). In the FIG.
2 embodiment, the additive may be dispensed into the annular zone
42. As in the FIG. 1 embodiment, the sensors 20 may be arrayed such
that the area in which the additive is dispensed may be
monitored.
[0030] Referring to FIG. 3, there is shown still another embodiment
of a treatment tool 10 in accordance with the present disclosure.
The treatment tool 10 may include a sub 16, a port 18, and one or
more sensors 20. However, a downhole reservoir 50 supplies the
additive(s) for the treatment tool 10. A pump (not shown) or other
suitable fluid mover may be used to flow the additive(s) through a
flow line 24 formed in the sub 16 that directs the additive(s) to
the port 18. Further, a downhole controller 52 may be programmed to
control one or more aspects of the operation of the treatment tool
10. The embodiment of FIG. 3 may also include a sealing element 40
that may be activated to hydraulically isolate a lower well section
56 from an upper well section 58. The sealing elements 40 may be
packers or other suitable sealing devices that engage and form an
annular seal with an adjacent surface (e.g., open hole surface,
liner, casing, etc.). As in the FIG. 1 embodiment, the sensors 20
may arrayed such that the area in which the additive is dispensed
may be monitored.
[0031] The controller 52 may be programmed to autonomously control
the treatment operation. For instance, the controller 52 may
include an information processing device (not shown) in signal
communication with the sensors 20. The controller 52 may be
programmed with algorithms, programs, mathematical models, or
instructions to estimate a condition relating to the downhole
feature based on the acquired information and/or estimate a change
in the condition of the downhole feature after the treatment of the
downhole feature. The controller 52 may also operate in a
semi-autonomous mode by cooperating with a surface controller (not
shown).
[0032] In an exemplary mode of use, the FIG. 3 treatment tool 10
may be positioned in the borehole 12 at a desired location. Either
by a surface signal or by using pre-programmed logic, the
controller 52 may initiate a treatment program by first evaluating
one or more downhole conditions using the sensors 20. Using the
information provided by the sensors 20 and pre-programmed
instructions, the controller 52 may select one or more additives
for adjusting or modifying a condition of a downhole feature. The
controller 52 may continue to monitor the downhole condition as the
additive is being applied. Afterward, the controller 52 may perform
further evaluation of the downhole condition using the sensors 20
to determine the effectiveness of the treatment.
[0033] It should be appreciated that in this mode of use, only a
single "trip" is needed to identify conditions that may require
remediation, treat the condition, and evaluate the effectiveness of
the treatment. That is, all of these activities are performed by
one treatment tool during a single deployment in the well. Thus,
the need for a first trip to evaluate a condition and a separate
second trip to treat the condition may be eliminated. Also
eliminated may be additional trips into the well to evaluate the
treatment.
[0034] It should be appreciated that the above-described
embodiments may be adapted for use after the borehole 12 (FIG. 1)
has been drilled. For example, the treatment tool 10 may be used
after a borehole section has been drilled or after an open hole
section has been cased and cemented. Also, the treatment tool 10
may be used in producing wells.
[0035] Additionally, embodiments of the present disclosure may be
used during drilling of a borehole 12. Referring now to FIG. 4
there is schematically illustrated a drilling system that may
include one or more treatment tools 10 according to aspects of the
present disclosure. A treatment tool 10 may be used to treat one or
more downhole features during drilling of the borehole 12. While a
land system is shown, the teachings of the present disclosure may
also be utilized in offshore or subsea applications. A drilling
system 100 may have a bottom hole assembly (BHA) or drilling
assembly 102 is conveyed via a tubing 104 into the borehole 12. The
tubing 104 may include a rigid carrier, such as jointed drill pipe
or coiled tubing, and may include embedded conductors for power
and/or data for providing signal and/or power communication between
the surface and downhole equipment. The BHA 102 may include a
drilling motor 106 for rotating a drill bit 108.
[0036] At the surface, an additive supply system 110 may be used to
supply one or more additives to the treatment tool(s) 10. In one
embodiment, the system 110 may include an additive supply unit 112,
an injector unit 114, and a controller 116. The system 110 may
direct the additive(s) into an umbilical 118 disposed inside or
outside of the tubing 104. The additive supply unit 112 may include
multiple tanks for storing different additives and one or more
pumps for pumping the additives. The injector unit 114 selectively
injects these additives into the umbilical 118. Additionally, or
alternatively, the additives may be pumped into the tubing 104. The
injector unit 114 may be a pump such as a positive displacement
pump, a centrifugal pump, a piston-type pump, or other suitable
device for pumping fluid. The controller 116 may control operations
by utilizing an information processing device having suitable
software programs.
[0037] During use, the treatment tool 10 may estimate one or more
parameters of interest relating to a selected downhole feature of
interest as the drilling system 150 drills the borehole. The
sensors 20 may generate information that may be transmitted to the
surface via a suitable communication link. Various options are
available for the subsequent treatment operation.
[0038] In one treatment mode, drilling is interrupted and sealing
elements 40 may be activated to provide an isolated treatment zone.
Next, one or more additives may be pumped into the borehole 12 via
the umbilical 118 and/or the tubing 104. The sensors 20 may
continue to provide information during and after the additive
treatment to evaluate effectiveness. In another treatment mode, an
additive may be dispensed as the borehole 12 is being drilled;
i.e., without interrupting drilling. In still another treatment
mode, the treatment may be performed while the drilling system 150
is being pulled out of the borehole 12. It should be understood
that such treatment modes are only illustrative and other modes of
use are encompassed in the present disclosure.
[0039] Referring now to FIG. 5, there is shown an illustrative well
treatment method 140 for minimizing scale deposition (i.e., a
"scale squeeze"). At step 142, the treatment tool may be conveyed
into a borehole that intersects one or more production zones that
produces some amount of water. At step 144, the on-board sensors of
the treatment tool may used to obtain information relating scale
formation (i.e., a well condition) at a first production zone. This
information may be the presence of a scale deposition indicator(s),
e.g., such as concentration or amount of a scale inhibitors and/or
ionic material in the fluid produced from the first zone. At step
146, this information is conveyed to the surface where personnel
determine whether the sensor information indicates a risk of
unacceptable scale formation.
[0040] If the results are acceptable, then the treatment tool may
be moved to a second production zone at step 148, or retrieved to
the surface at step 150. If the results are unacceptable, then at
step 152 the treatment device injects a scale inhibitor (e.g.,
phosphonated carboxylic acids) into the first production zone.
After the treatment is complete, at step 154, the sensors of the
treatment tool are again used to obtain information relating to
scale formation to evaluate the effectiveness of the treatment. If
the results are acceptable, then the treatment tool may be moved to
a second production zone (step 148) or retrieved to the surface
(step 150). If the results are unacceptable, then further treatment
may be applied by repeating step 152.
[0041] In a similar fashion, embodiments of the present disclosure
may be used to control asphaltene deposition. In one illustrative
method, the on-board sensors of the treatment tool are configured
to obtain information relating to the presence or concentration of
asphaltenes in the produced fluid at a production zone. If the
concentration of asphaltenes is out of an expected or desired
range, personnel may use the treatment tool to treat the production
zone with an asphaltine inhibitor. The effectiveness of the
treatment may be thereafter evaluated using the sensors of the
treatment tool. The treatment tool may be configured to treat one
condition or may include suitable on-board sensors to treat a
variety of well conditions.
[0042] It should be appreciated that embodiments of the treatment
tool can evaluate well conditions at discrete intervals in the well
and to treat only those specific intervals that have an out-of-norm
condition. Many wells may have several zones from which formation
fluids are produced. These formation fluids commingle in the
borehole or production tubing and flow to the surface. Thus,
analyzing the fluid at the surface may identify a particular
undesirable condition. However, such an analysis, by itself, may
not furnish information as to which zone or zones have the
undesirable condition. Advantageously, the treatment tools
according to the present disclosure may be used to cost-efficiently
isolate and treat specific zones in a single trip.
[0043] Controlling scale and asphaltine deposition are merely
examples of the variety of downhole conditions that may be treated
with the treatment tool 10. Discussed below are non-limiting
applications for the treatment tools according to the present
disclosure. The treatment tool 10 may be used for borehole acid
treatment to remove scale or similar deposits from perforations and
well-completion components. Acidization may also be used to
control, among other things, corrosion, paraffin, emulsion,
hydrates, hydrogen sulfide, inorganics and other harmful
substances. Other uses include damage removal, completion and
stimulation of horizontal wells, matrix acidizing, fracture
acidizing and gel breaking. Additives for such uses include, but
are not limited to, hydrochloric acid and viscoelastic surfactant
(VES) based fluids.
[0044] The treatment tool 10 may be used to treat a downhole
feature using nanoparticles. Suitable nanoparticles include
alkaline earth metal oxides, alkaline earth metal hydroxides,
alkali metal oxides, alkali metal hydroxides, transition metal
oxides, transition metal hydroxides, post-transition metal oxides.
Illustrative applications include recharging beds or packs of
substrate particles with nanoparticles, zone isolation and flow
control in water shutoff, stabilizing clays, such as clays in a
subterranean formation,
[0045] The treatment tool 10 may be used for borehole acid
treatment to blocking gels, cement, microcement, silicates, and
other materials to strengthen a borehole. VES-gelled fluids have
been widely used as gravel-packing, frac-packing and fracturing
fluids. The treatment tool 10 may be used to treat subterranean
hydrocarbon formations, such as in hydraulic fracturing, completion
fluids, gravel packing fluids and fluid loss pills.
[0046] While the present teachings have been discussed in the
context of hydrocarbon producing wells, it should be understood
that the present teachings may be applied to geothermal wells,
groundwater wells, subsea analysis, etc.
[0047] As used herein, the term "additive" generally refers to an
engineered material that is formulated to perform a desired task.
For example, an "additive" may be any material(s), agent(s) or
substance(s) that interact with the downhole feature in a
predetermined manner. An additive may be a gas, liquid, a gel,
plasma, or a solid entrained in a fluid carrier. An additive may be
chemically active (e.g., an acid), thermally active,
electromagnetically responsive (e.g., magnetorheological fluids),
mechanical (e.g., a proppant, gravel, cement, resin, etc.) or have
specialized material properties (e.g., relative permeability
modifiers). Also, merely for brevity, this disclosure refers to an
"additive" in the singular. It should be understood that such
references are inclusive of the plural "additives."
[0048] The term "conveyance device" as used above means any device,
device component, combination of devices, media and/or member that
may be used to convey, house, support or otherwise facilitate the
use of another device, device component, combination of devices,
media and/or member. Exemplary non-limiting conveyance devices
include drill strings of the coiled tube type, of the jointed pipe
type and any combination or portion thereof. Other conveyance
device examples include casing pipes, wirelines, wire line sondes,
slickline sondes, drop shots, downhole subs, BHA's, drill string
inserts, modules, internal housings and substrate portions thereof,
self-propelled tractors.
[0049] As used above, the term "sub" refers to any structure that
is configured to partially enclose, completely enclose, house, or
support a device. The term "information" as used above includes any
form of information (Analog, digital, EM, printed, etc.). The term
"information processing device" herein includes, but is not limited
to, any device that transmits, receives, manipulates, converts,
calculates, modulates, transposes, carries, stores or otherwise
utilizes information. An information processing device may include
a microprocessor, resident memory, and peripherals for executing
programmed instructions.
[0050] The present disclosure is susceptible to embodiments of
different forms. There are shown in the drawings, and herein will
be described in detail, specific embodiments of the present
disclosure with the understanding that the present disclosure is to
be considered an exemplification of the principles of the
disclosure and is not intended to limit the disclosure to that
illustrated and described herein.
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