U.S. patent application number 12/874917 was filed with the patent office on 2012-03-08 for systems and methods for monitoring a parameter of a subterranean formation using swellable materials.
This patent application is currently assigned to Halliburton Energy Services, Inc.. Invention is credited to Ron G. Dusterhoft, Stewart A. Levin, Jim Longbottom, James D. Vick, JR., Norman R. Warpinski.
Application Number | 20120055669 12/874917 |
Document ID | / |
Family ID | 44583183 |
Filed Date | 2012-03-08 |
United States Patent
Application |
20120055669 |
Kind Code |
A1 |
Levin; Stewart A. ; et
al. |
March 8, 2012 |
SYSTEMS AND METHODS FOR MONITORING A PARAMETER OF A SUBTERRANEAN
FORMATION USING SWELLABLE MATERIALS
Abstract
A system for monitoring a parameter of a subterranean formation
using swellable materials is disclosed. The system may include a
sensor device configured to detect a parameter of a subterranean
formation. The system may also include a swellable material
configured to position the sensor device toward a surface of the
subterranean formation by swelling of the swellable material. The
system may further include a telescoping section coupled to the
sensor device and emplaced in the swellable material. The
telescoping section may be configured to extend with the
positioning of the sensor device.
Inventors: |
Levin; Stewart A.;
(Centennial, CO) ; Dusterhoft; Ron G.; (Katy,
TX) ; Longbottom; Jim; (Magnolia, TX) ;
Warpinski; Norman R.; (Cypress, TX) ; Vick, JR.;
James D.; (Dallas, TX) |
Assignee: |
Halliburton Energy Services,
Inc.
|
Family ID: |
44583183 |
Appl. No.: |
12/874917 |
Filed: |
September 2, 2010 |
Current U.S.
Class: |
166/250.17 ;
166/196 |
Current CPC
Class: |
E21B 33/1208 20130101;
E21B 47/01 20130101; E21B 49/00 20130101 |
Class at
Publication: |
166/250.17 ;
166/196 |
International
Class: |
E21B 49/00 20060101
E21B049/00; E21B 33/12 20060101 E21B033/12 |
Claims
1. A system for monitoring a parameter of a subterranean formation
using swellable materials, the system comprising: a sensor device
configured to detect a parameter of a subterranean formation; a
swellable material configured to position the sensor device toward
a surface of the subterranean formation by swelling of the
swellable material; and a telescoping section coupled to the sensor
device and emplaced in the swellable material, wherein the
telescoping section is configured to extend with the positioning of
the sensor device.
2. The system of claim 1, wherein the sensor device is emplaced at
least partially in the swellable material.
3. The system of claim 1, wherein the swellable material is further
configured to position the sensor device against the surface of the
subterranean formation by swelling.
4. The system of claim 1, wherein the sensor device is operative to
communicate a signal related to the parameter of the subterranean
formation.
5. The system of claim 4, wherein the telescoping section is
configured to allow the positioning of the sensor device while the
sensor device is operative to communicate a signal related to the
parameter of the subterranean formation.
6. The system of claim 1, wherein the swellable material is on an
exterior surface of a tubular body and is configured to position
the sensor device away from the pipe by swelling.
7. The system of claim 6, wherein the swellable material is further
configured to reduce an effect on the sensor device of acoustic
noise traveling along the tubular body.
8. A system for monitoring a parameter of a subterranean formation
using swellable materials, the system comprising: a sensing tool
configured to detect a parameter of a subterranean formation,
wherein the sensing tool comprises a generally tubular body; and a
swellable material on an exterior surface of the generally tubular
body, wherein the swellable material is configured to anchor the
sensing tool in a position corresponding to a surface of the
subterranean formation by swelling of the swellable material.
9. The system of claim 8, wherein the swellable material is further
configured to substantially center the sensing tool between at
least two opposing points on the surface of the subterranean
formation.
10. The system of claim 9, wherein the swellable material comprises
a plurality of swellable members disposed along the generally
tubular body.
11. The system of claim 9, wherein the swellable material at least
substantially surrounds a length the generally tubular body.
12. The system of claim 8, wherein the swellable material is
configured to anchor the sensing tool against the surface of the
subterranean formation.
13. The system of claim 12, the swellable material comprises a
plurality of swellable members disposed along the generally tubular
body, wherein each swellable member partially surrounds a
corresponding length of the generally tubular body.
14. The system of claim 12, wherein the swellable material
longitudinally extends along a length of the generally tubular
body.
15. A method for monitoring a parameter of a subterranean
formation, the method comprising: introducing a sensing tool to a
wellbore, wherein the sensing tool comprises a generally tubular
body and is configured to detect a parameter of a subterranean
formation; positioning the sensing tool in a position corresponding
to a surface of the wellbore by swelling a swellable material,
wherein the swellable material is disposed on an exterior surface
of the generally tubular body; and detecting a parameter of a
subterranean formation with the sensing device.
16. The method of claim 15, wherein the positioning step comprises
substantially centering the sensing tool between at least two
opposing points on the surface of the wellbore.
17. The method of claim 16, wherein the swellable material
comprises a plurality of swellable members disposed along the
generally tubular body.
18. The method of claim 16, wherein the swellable material at least
substantially surrounds a length the generally tubular body.
19. The method of claim 15, wherein the positioning step comprises
anchoring the sensing tool against the surface of the wellbore.
20. The method of claim 19, wherein the swellable material
longitudinally extends along a length of the generally tubular
body.
Description
BACKGROUND
[0001] The present invention relates to monitoring subterranean
formations and more particularly, systems and methods for
monitoring a parameter of a subterranean formation using swellable
materials.
[0002] Monitoring of reservoir behavior due to injection and
production processes is an important element in optimizing the
performance and economics of completion and production operations.
Examples of these processes may include hydraulic fracturing, water
flooding, steam flooding, miscible flooding, wellbore workover
operations, remedial treatments and many other hydrocarbon
production activities, as well as drill cutting injection, CO.sub.2
sequestration, produced water disposal, and various activities
associated with hazardous waste injection. Because the changes in
the reservoir may be difficult to resolve with surface monitoring
technology, it may be desirable to emplace sensor instruments
downhole at or near the reservoir depth in either special monitor
wells or within the injection and production wells.
[0003] Challenges with downhole measurements may include securely
coupling sensor packages to the rock mass, isolating the packages
as much as possible from noise in the wellbore, and providing
cabling paths (if necessary) for transmitting data to the surface.
Sensors may be deployed permanently or retrievably. Retrievable
sensors packages are often deployed on wirelines, but also on
coiled tubing or production tubing. Wireline deployed arrays may
use clamp arms, magnets, or bow springs for coupling to the
wellbore, whereas coiled tubing or tubing deployed arrays may have
decentralizers and may be locked into the wellbore through friction
and bending stresses. However, these types of deployment may be
susceptible to coupling problems if the clamp arms do not fully
extend, if magnets are placed over scale or other wellbore
irregularities, or if the coiled tubing is not wedged against the
casing wall.
[0004] Permanent sensors may be cemented in place, but this can be
a difficult and costly process for sizable sensor arrays.
Successful deployments of large sensor arrays may have inserted the
sensors coupled to tubing inside cemented casing with the tubing
then cemented inside the casing. Attempts to directly place sensor
arrays on the outside of casing have often been unsuccessful due to
damage to the array during emplacement. A successful deployment of
cemented sensors may remain susceptible to noise transferred either
up or down the tubulars because of the affixation to the tubing or
casing.
FIGURES
[0005] Some specific exemplary embodiments of the disclosure may be
understood by referring, in part, to the following description and
the accompanying drawings.
[0006] FIGS. 1A and 1B are partial schematic cross-sectional views
of a monitoring system using swellable materials in accordance with
an exemplary embodiment of the present invention.
[0007] FIG. 2 is schematic perspective view of a monitoring system
using swellable materials in accordance with an exemplary
embodiment of the present invention.
[0008] FIG. 3 is schematic perspective view of a monitoring system
using swellable materials in accordance with an exemplary
embodiment of the present invention.
[0009] FIGS. 4A, 4B, 4C and 4D are schematic cross-sectional views
of a monitoring system using swellable materials in accordance with
an exemplary embodiment of the present invention.
[0010] FIGS. 5A, 5B, 5C, 5D, 5E, 5F, 5G, 5H, 5I and 5J are
schematic partial cross-sectional views of a monitoring system
using swellable materials in accordance with an exemplary
embodiment of the present invention.
[0011] While embodiments of this disclosure have been depicted and
described and are defined by reference to exemplary embodiments of
the disclosure, such references do not imply a limitation on the
disclosure, and no such limitation is to be inferred. The subject
matter disclosed is capable of considerable modification,
alteration, and equivalents in form and function, as will occur to
those skilled in the pertinent art and having the benefit of this
disclosure. The depicted and described embodiments of this
disclosure are examples only, and not exhaustive of the scope of
the disclosure.
SUMMARY
[0012] The present invention relates monitoring subterranean
formations and more particularly, systems and methods for
monitoring a parameter of a subterranean formation using swellable
materials.
[0013] In one aspect, a system for monitoring a parameter of a
subterranean formation using swellable materials is disclosed. The
system may include a sensor device configured to detect a parameter
of a subterranean formation. The system may also include a
swellable material configured to position the sensor device toward
a surface of the subterranean formation by swelling of the
swellable material. The system may further include a telescoping
section coupled to the sensor device and emplaced in the swellable
material. The telescoping section may be configured to extend with
the positioning of the sensor device.
[0014] In another aspect, a system for monitoring a parameter of a
subterranean formation using swellable materials is disclosed. The
system may include a sensing tool configured to detect a parameter
of a subterranean formation. The sensing tool may include a
generally tubular body. The system may also include a swellable
material on an exterior surface of the generally tubular body. The
swellable material may be configured to anchor the sensing tool in
a position corresponding to a surface of the subterranean formation
by swelling of the swellable material.
[0015] In yet another aspect, a method for monitoring a parameter
of a subterranean formation is disclosed. The method may include
introducing a sensing tool to a wellbore. The sensing tool may
include a generally tubular body and is configured to detect a
parameter of a subterranean formation. The method may also include
positioning the sensing tool in a position corresponding to a
surface of the wellbore by swelling a swellable material. The
swellable material may be disposed on an exterior surface of the
generally tubular body. The method may also include detecting a
parameter of a subterranean formation with the sensing device.
[0016] Certain embodiments of the present disclosed provide for a
retractable sensor device and/or tool that may reenter a retracted
state. Certain embodiments provide for swell controls that may be
adapted for swelling and/or de-swelling swellable materials.
[0017] The features and advantages of the present invention will be
apparent to those skilled in the art. While numerous changes may be
made by those skilled in the art, such changes are within the
spirit of the invention.
DETAILED DESCRIPTION
[0018] The present invention relates monitoring subterranean
formations and more particularly, systems and methods for
monitoring a parameter of a subterranean formation using swellable
materials.
[0019] The systems, apparatuses and methods of the present
disclosure may allow for the deployment of sensors in permanent,
semi-permanent, and/or retrievable applications with minimal effect
on the wellbore, superior coupling to the rock mass, minimal
vibrational degrees of freedom, and significant isolation from the
wellbore noise for those cases where monitoring of the reservoir is
desirable. In certain embodiments, sensors may be at least
partially emplaced within swell packers for direct coupling to
tubulars with maximum isolation from the rock mass for cases where
it is desirable to monitor the tubing deformation and/or flow
noise/activity within the tubing. Such swell packers may be
constructed of elastomers that swell when exposed to either
hydrocarbons or water, depending upon the application, in order to
seal off and isolate zones within the wellbore. The swell packers
may provide coupling by swelling and forcing a sensor package
against either a formation, a wellbore, or any rigid contact point.
In certain embodiments, swellable materials may be implemented to
centralize or decentralize sensors and/or sensor tools within a
wellbore, depending on the desirability of placing the sensors
and/or sensor tools in a central or decentralized position.
[0020] Illustrative embodiments of the present invention are
described in detail herein. In the interest of clarity, not all
features of an actual implementation may be described in this
specification. It will of course be appreciated that in the
development of any such actual embodiment, numerous
implementation-specific decisions must be made to achieve the
specific implementation goals, which will vary from one
implementation to another. Moreover, it will be appreciated that
such a development effort might be complex and time-consuming, but
would nevertheless be a routine undertaking for those of ordinary
skill in the art having the benefit of the present disclosure.
[0021] To facilitate a better understanding of the present
invention, the following examples of certain embodiments are given.
In no way should the following examples be read to limit, or
define, the scope of the invention. Embodiments of the present
disclosure may be applicable to horizontal, vertical, deviated, or
otherwise nonlinear wellbores in any type of subterranean
formation. Embodiments may be applicable to injection wells as well
as production wells, including hydrocarbon wells. In addition well
bore and well casing implementations, embodiments may be applicable
for securely planting surface instruments in soft, crumbly
ground.
[0022] FIG. 1A illustrates a system 100 where a tubular body 105
having an axis 105A is shown disposed in a wellbore 140 and
adjacent to the wall 120. As depicted, the tubular body 105 may be
disposed in an uncased section of wellbore 140, but the tubular
body 105 may be disposed in a cased section or in near-surface
ground in other embodiments. The tubular body 105 may provide a
conduit for formation fluids to travel therethrough. The system 100
may include a sensor package 110 fully or partially encased in a
swellable element 115. The sensor package 110 may be disposed at or
near an outer boundary of the swellable element 115.
[0023] It should be clearly understood that the principles of this
disclosure are not limited to use with a particular sensor, sensor
package, sensing device or tool. Instead, the principles of this
disclosure are applicable to wide variety of devices, tools and
methods. Two common sensors for reservoir monitoring are seismic
and deformation sensors. The sensor package 110 may include, for
example, a sonde, a geophone, an accelerometer, a hydrophone, or
another device that detects ground motion due to either source
shots (e.g., vertical seismic profiling or crosswell surveys) or
passive behavior such as microseismicity and/or noise in both the
wellbore and the reservoir. Also, for example, the sensor package
110 may include a sensor for measuring deformation in the downhole
environment, such as a tiltmeter that measures the gradient of
displacement, or any instrument that measures differential
displacement in the reservoir.
[0024] A line 135 may be coupled to the sensor package 110. The
line 135 may be any one, or a combination, of a multi-conductor
cable, a single conductor cable, a fiber optic cable, a fiber optic
bundle, and a conduit or umbilical that contains cables, fiber
optics and control lines to provide a hydraulic connection down
hole. In certain embodiments, the line 135 may be a wireline. In
certain embodiments, the line 135 may be a means of placing the
sensor package 110 in the wellbore 140. In the alternative, the
sensor package 110 and the swellable material may be coupled to the
tubular body 105 and introduced into the wellbore 140 together. The
line 135 may also be a means of communicating electrical signals,
such as indications of a parameter associated with the subterranean
formation, between the sensor package 110 and a data collection
system and/or control system at remote location, such as the
earth's surface or a subsea location. In certain embodiments, the
line 135 may be a means of communicating with another well tool at
another location in the wellbore 140 or another wellbore. As
depicted, a portion of the line 135 may be encased in the swellable
element 115. In alternative embodiments, the sensor package 110 may
communicate via any type of telemetry, such as acoustic, pressure
pulse, electromagnetic telemetry or any wireless means.
[0025] Referring next to FIG. 1B, therein is depicted the system
100 of FIG. 1A with the swellable element 115 in an expanded
configuration. When the swellable element 115 comes in contact with
an activating agent, the swellable element 115 expands radially
outwardly. As illustrated in FIG. 1B, the swellable element 115 may
come in contact with the wellbore wall 120 due to swelling. The
sensor package 110 may include a telescoping section 130 configured
to extend outwardly toward the wall 120 along with the expansion of
the swellable element 115 such that the swellable element 115 in
effect pulls the sensor package 110 toward the wall 120. In certain
embodiments, the swellable element 115 may force the sensor package
110 to come into contact with the wall 120 and/or to partially or
completely protrude into the wall 120. The telescoping section 130
may include any means by which the sensor package 110 may be
displaced while maintaining connection with the portion of the line
135 encased in the swellable element 115. For example, the
telescoping member 130 may include an extensible arm or an
expandable cavity within the swellable element 115 that houses a
length of the line 135 with sufficient slack corresponding to the
displacement of the sensor package 110.
[0026] Certain embodiments may employ a single swellable element
115 as depicted in FIGS. 1A and 1B. Other embodiments may employ
multiple swellable elements. Though not shown in FIGS. 1A and 1B,
one or more additional swellable elements may be placed about the
tubing 105.
[0027] It is recognized that the swellable element 115 may be made
of different materials, shapes, and sizes. For example, the
swellable element 115 may be deployed on tubing with a symmetrical
ring configuration. The swellable element 115 may take an annular
form surrounding or partially surrounding the tubing 105, and may
be any elastomeric sleeve, ring, or band suitable for expanding
within a space between tubing 105 and an outer tubing, casing, or
wellbore.
[0028] The term "swell" and similar terms (such as "swellable") are
used herein to indicate an increase in volume of a material.
Typically, this increase in volume is due to incorporation of
molecular components of a fluid into the swellable material itself,
but other swelling mechanisms or techniques may be used, if
desired. The swellable element 115 may include one or more
swellable materials that swell when contacted by an activating
agent, such as an inorganic or organic fluid. In one embodiment, a
swellable material may be a material that swells upon contact with
and/or absorption of a hydrocarbon, such as oil. In another
embodiment, a swellable material may be a material that swells upon
contact with and/or absorption of an aqueous fluid. The hydrocarbon
is absorbed into the swellable material such that the volume of the
swellable material increases creating a radial expansion of the
swellable material when positioned around a base pipe which creates
a radially outward directed force that may operate to radially
extend telescoping members as described above. The swellable
material may expand until its outer surface contacts the formation
face in an open hole completion or the casing wall in a cased
wellbore. The swellable material accordingly may provide the force
to extend the telescoping member 130 of the sensor package 110 to
the surface of the formation such as wellbore wall 120.
[0029] Suitable swellable elements include, but are not limited, to
the swellable packers disclosed in U.S. Pat. Nos. 3,385,367;
7,059,415; and 7,143,832; the entire disclosures of which are
incorporated by reference. In certain embodiments, the swellable
element 115 may be individually designed for the conditions
anticipated for a particular case, taking into account the expected
temperatures and pressures for example. Some exemplary swellable
materials may include elastic polymers, such as EPDM rubber,
styrene butadiene, natural rubber, ethylene propylene monomer
rubber, ethylene-propylene-copolymer rubber, ethylene propylene
diene monomer rubber, ethylene-propylene-diene terpolymer rubber,
ethylene vinyl acetate rubber, hydrogenized acrylonitrile butadiene
rubber, acrylonitrile butadiene rubber, isoprene rubber, butyl
rubber, halogenated butyl rubber, brominated butyl rubber,
chlorinated butyl rubber, chlorinated polyethylene, chloroprene
rubber and polynorborene.
[0030] As discussed above, these and other swellable materials may
swell in contact with and by absorption of hydrocarbons so that the
swellable material expands. In one embodiment, the rubber of the
swellable materials may also have other materials dissolved in or
in mechanical mixture therewith, such as fibers of cellulose.
Additional options may be rubber in mechanical mixture with
polyvinyl chloride, methyl methacrylate, acrylonitrile,
ethylacetate or other polymers that expand in contact with oil.
Other swellable materials that behave in a similar fashion with
respect to hydrocarbon fluids or aqueous fluids also may be
suitable. Those of ordinary skill in the art, with the benefit of
this disclosure, will be able to select an appropriate swellable
material for use in the present invention based on a variety of
factors, including the desired swelling characteristics of the
swellable material and the environmental conditions in which it is
to be deployed.
[0031] In some embodiments, the swellable materials may be
permeable to certain fluids but prevent particulate movement
therethrough due to the porosity within the swellable materials.
For example, the swellable material may have a pore size that is
sufficiently small to prevent the passage of the sand therethrough
but sufficiently large to allow hydrocarbon fluid production
therethrough. For example, the swellable material may have a pore
size of less than 1 mm.
[0032] As discussed above, the activating fluid/agent may comprise
a hydrocarbon fluid or an aqueous fluid. In addition, an activating
fluid may comprise additional additives such as weighting agents,
acids, acid-generating compounds, and the like, or any other
additive that does not adversely affect the activating fluid or
swellable material with which it may come into contact. For
instance, it may be desirable to include an acid and/or an
acid-generating compound to at least partially degrade any filter
cake that may be present within a wellbore. One of ordinary skill
in the art, with the benefit of this disclosure, will recognize
that the compatibility of any given additive should be tested to
ensure that it does not adversely affect the performance of the
activating fluid or the swellable material.
[0033] The activation agent may be introduced to the swellable
material in a variety of ways. The activation agent may be injected
into the wellbore or casing from a source at the surface. In other
embodiments, the activation agent may be placed in the wellbore or
casing and released on demand. In yet other embodiments, swelling
of the swellable material may be delayed, if desired. For example,
a membrane or coating may be on any or all surfaces of the material
to thereby delay swelling of the material. The membrane or coating
could have a slower rate of swelling, or a slower rate of diffusion
of fluid through the membrane or coating, in order to delay
swelling of the material. The membrane or coating could have
reduced permeability or could break down in response to exposure to
certain amounts of time and/or certain temperatures. Suitable
techniques and arrangements for delaying swelling of a swellable
material are described in U.S. Pat. Nos. 7,143,832 and 7,562,704,
the entire disclosures of which are incorporated herein by
reference.
[0034] The swellable materials of certain embodiments may be
shrinkable or may be distintegratable. A deactivating fluid/agent,
for example, may comprise a salt compound that would cause the
swelled materials to contract by way of osmosis. A disintegrating
fluid/agent, for example, may comprise any chemical adapted to
chemically destroy the swellable material. In either case, the
shrinking or disintegrating of the swellable material allows for
the unanchoring of the sensor device or tool.
[0035] In alternative embodiments, the system 100 may comprise a
sampling package (not shown) in lieu of or in addition to the
sensor package 110. The sampling package may comprise an extendable
straw or functional equivalent. When the swellable element 115
comes in contact with an activating agent, the swellable element
115 expands radially outwardly and may seal about an area of the
wellbore wall 120. The sampling package, coming into contact with
the formation, may facilitate fluid flowing from the formation such
that the fluid may be monitored by the sensors. Alternatively or
additionally, the fluid from the formation at that spot may be used
as a fluid power source. Alternatively or additionally, the
sampling package, coming into contact with the formation, may
obtain a sample from the location. Then, by way of the de-swelling
processes disclosed herein, the system 100 may be retracted from
the wellbore 120 and the sample may be recovered from the sampling
package.
[0036] FIG. 2 illustrates a system 200 where a swellable element
215 provides for symmetric instrument tool clamping within a
borehole or casing. A tool 205 may be or include a sensor device, a
microseismic array tool, or any other tool for which vibrations
degrade its fidelity. As depicted, the tool 205 may comprise a
tubular body and may be disposed in an uncased section of the
wellbore 240. Alternatively, the tool 205 may be disposed in a
cased wellbore. Certain embodiments may include umbilical lines,
wirelines, or tubes to the surface that could be incorporated to
provide for positioning and/or monitoring the tool 205 and downhole
sensors, for electrically activated controls of subsurface
equipment, for injecting chemicals, or any combination thereof. In
alternative embodiments, communication with the tool 205 may be
achieved via any type of telemetry, such as acoustic, pressure
pulse or electromagnetic telemetry.
[0037] One or more swellable elements 215 may be coupled to the
tool 205 and may be configured to expand to anchor symmetrically,
or substantially symmetrically, the tool 205 against a wall 220 of
the wellbore or casing. For example, the swellable elements 215 may
be configured to swell, due to contact with an activation agent, to
a position 210. As illustrated by the position 210, the swellable
elements 215 may come in contact with the wall 220 upon
expansion.
[0038] The swellable elements 215 may be any elastomeric sleeve,
band, ring, or other annular form surrounding or partially
surrounding the tubing 205 and suitable for expanding between the
tool 205 and wall 220, as long as the swellable elements 215 anchor
the tool 205 in a symmetrical or substantially symmetrical manner.
For example, when a configuration of the swellable elements 215
fully ring the tool 205, the tool 205 may become well-centered in
the wellbore or casing so that microseismic energy may reach the
tool 205 substantially equally well from all sides. In certain
embodiments, a symmetric, or substantially symmetric, system
similar to system 200 may surround a geophone planted in a shallow
surface borehole to suppress decoupled oscillations of the
instrument.
[0039] The areal contact of the swellable elements 215 with the
tool 205 provides stiffening and allows shifting of modal
vibrations to higher frequencies above the range of the microseisms
or other sources that are being monitored. Because they expand into
available space, the swelling elements themselves are very well
suited for use in irregular boreholes as tool contact is
necessarily hit-or-miss along the length of the tool in such
settings. Similar swelling elements applied to surface-based
acquisition sensors (e.g., shallow borehole geophones or
tiltmeters) allow firm emplacement that, in contrast to permanent
cementation, allows subsequent retrieval and reuse. In certain
embodiments, the swellable elements 215 may form seals in the
wellbore 240 by swelling. The swellable elements 215 accordingly
may prevent fluid from flowing outside of an interval along the
body of the tool 205. In certain embodiments, the swellable
elements 215 may be configured to effectively isolate the entire,
or nearly the entire, body of the tool 205, as desired.
[0040] FIG. 3 illustrates a system 300 where a swellable element
315 provides for asymmetric instrument tool clamping within a
wellbore 340. One or more swellable elements 315 may be coupled to
the tool 305 in an asymmetric manner so that the swellable elements
315 anchor the tool 305 in an asymmetrical manner. In such a
configuration, the tool 305 may be pushed up against a side 320 of
the wellbore or casing, where the tool 305 may receive microseismic
energy via direct contact. The swellable elements 315 may push the
tool against the borehole wall more uniformly and firmly along its
length, as compared to conventional approaches.
[0041] It should be understood, in light of this disclosure, that a
number of combinations of tubing and/or wireline run with encased,
ring, or partial ring deployment may have advantages that can be
exploited for a given monitoring situation, as for example to
shield against noise, temperature, or wellbore chemistry and to
appropriately couple for what is actually being monitored.
[0042] FIGS. 4A-4D illustrate a system 400 run on wireline using an
eccentric swell packer for clamping a tool 405. A swellable element
415 may run along a length of the tool 405 to provide for
asymmetric instrument tool clamping within a wellbore or casing.
The swellable element 415 may fit along a holder 410. FIGS. 4A and
4B depict the swellable element 415 prior to activation. FIGS. 4C
and 4D depict the swellable element 415 in an expanded position
after contact with an activation agent. The expansion may cause the
swellable element 415 and the tool 405 to contact the wall 420 of
the wellbore or casing.
[0043] FIGS. 5A-5H illustrate a system 500 where a tubular body 505
is shown disposed in a wellbore or casing 540 and adjacent to the
wall 575. FIGS. 5A and 5B respectively illustrate partial side and
perspectives views of the system 500 in a retracted state. FIGS. 5C
and 5D respectively illustrate partial side and perspectives views
of the system 500 in an expanded state. The tubular body 505 may be
encircled by an inner arrangement 510 and an outer arrangement 515.
The tubular body 505 may be provided with ribbing 555 or other
means configured to prevent rotation of the inner arrangement 510
about the tubular body 505. The tubular body 505 may be provided
with one or more flanges 545 proximate to the inner arrangement 510
and configured to anchor the inner arrangement 510 so as to prevent
axial movement with respect to the tubular body 505.
[0044] The inner arrangement 510 and the outer arrangement 515 may
respectively include components 510A and 515A, disposed in a
generally circular, annular and/or cylindrical arrangement. For
example, as depicted in the cross-sectional representations in
FIGS. 5B and 5D, one or more components 510A, 515A generally form
partial sectors or arcs. The components 510A, 515A may be solid or
hollow pieces and may be made of metal, composite or another type
of suitable material.
[0045] One or more sensor packages 550 may be coupled to the outer
arrangement 515. Each sensor package 550 may have at least a
portion extending into a component 515A. In certain embodiments,
one or more sensor packages may be coupled to the inner arrangement
505. In certain embodiments, one or more sensor packages may be
coupled to both the inner arrangement 505 and the outer arrangement
515. In the latter embodiment, the sensor packages may be
configured for noise-canceling in order to attenuate tubular-borne
noise.
[0046] As depicted, the inner arrangement 510 and the outer
arrangement 515 may be coupled by way of one or more struts 520.
The struts 520 may be configured to have a degree of freedom and,
for example, may be swivably attached to one or both of the inner
arrangement 510 and the outer arrangement 515. It may be preferable
that a swivel attachment be associated with either one or the other
of the inner arrangement 510 and the outer arrangement 515, so that
both may maintain a stable configuration during insertion into or
retrieval from the borehole. In one exemplary embodiment, the
swivel attachment may be of a hinge type and may have a vertical
length around an axis of rotation. In certain embodiments, the
swivel attachment may include paths for electrical signal
lines.
[0047] Adjacent components 510A, 515A may be coupled to each other.
For example without limitation, each component 510A, 515A may be
coupled to an adjacent component 510A, 515A via a mandrel and/or an
expansion sleeve. As depicted, adjacent components 510A of the
inner arrangement 510 are coupled via expansion sleeves 525.
Adjacent components 515A of the outer arrangement 515 are coupled
via expansion sleeves 530. The expansion sleeves 525 and 530 may
partially encase, surround or otherwise wrap around portions of
adjacent circular components 510A and 515A, thereby aiding the
generally circular alignment of the components 510A and 515A. The
expansion sleeves 525 and 530 may be made of metal, composite or
another type of suitable material.
[0048] FIGS. 5E-5J illustrate one example of an expansion sleeve
530 about adjacent circular components 515A. FIG. 5E illustrates an
unexpanded state, while FIG. 5F illustrates an expanded state. The
adjacent components 510A may be configured to allow a region 535
between them when not flush. Swellable elements may be disposed in
the region 535. In one example, elastomer 530A may be disposed in
the region 535 with swell controls 560. Though not depicted, an
expansion sleeve 525 and adjacent circular components 510A may be
similarly configured. The swellable elements may be configured to
expand generally tangentially to the inner arrangement 510 so that
the inner arrangement 510 expands generally tangentially, as
opposed to radially. Thus, the swellable elements, in conjunction
with other elements of system 500, provide a mechanism for the
system 500 to detach from the tubular body.
[0049] As depicted in FIG. 5G, the swell controls 560 may include
fluid and/or electrical lines 565 that may be configured to convey
activation agent and/or activate valves 570. The valve 570 may
include one or more reservoirs and may be operable to disperse the
activation agent to the swellable materials 515A. By this or
similar means, the swell controls 560 may be adapted for swelling
the swellable materials 515A so that the system 500 may detach from
the tubular body.
[0050] In addition to detachment, the swellable elements may
similarly provide a mechanism for reattachment. For example, it may
be preferable for the swellable elements to be water-swellable. A
deswelling agent may include salt to extract water from a
water-swellable material by osmosis. The electrical lines may later
be used to expose the swellable elements to a deswelling agent in
order to shrink the swellable material, thereby transitioning the
tool to a retracted state that would allow for tool retrieval.
Thus, the swell controls 560 may be adapted for de-swelling the
swellable materials 515A.
[0051] FIGS. 5H and 5I show diagrams of one exemplary embodiment of
a valve 570. By way of example without limitation, the valve 570
may include a deswelling agent reservoir 572 and/or a swelling
agent reservoir 574. A slide 576 may include ports that may be
selectively aligned with a deswelling agent reservoir 572 and/or a
swelling agent reservoir 574. For example, FIG. 5I depicts a view
of the slide where ports 578A are shown in an open state and in
aligned with a reservoir port. Ports 578B are shown in a closed
state and not aligned with a reservoir port. The valve 570 may be
configured with the slide 576 to allow for the controlled feed of
an agent to the swellable material. The slide 576 may be activated
by hydraulics or an electrical device such as an electromagnet on
either end. In alternative embodiments, one or both of the valve
570 and the slide 576 may be adapted so the ports of the slide may
be selectively aligned with the ports of a reservoir by rotation,
rather than lateral motion of the slide 576 indicated in FIG. 5H.
For example, the slide 576 may have a disk form with ports that may
be rotated about a center.
[0052] FIG. 5J illustrates a mandrel 525A that may be used in the
alternative or in addition to expansion sleeves to couple two or
more adjacent circular components 510A and 515A. The mandrel 525A
may be used as a one- or two-ended piston to prevent or minimize
lateral expansion such that expansion is directed along an axis of
the mandrel. In certain embodiments, secondary mandrels in the
outer arrangement 515 may be preferred in order to shift the
centerpoint of the inner arrangement 510 as the tubular body 505
may not always be well-centered in the borehole 540.
[0053] Swellable elements may be included with the mandrels 525A.
As depicted in FIG. 5J, a mandrel 525A may include an outer body
525B that at least partially surrounds an elastomer material 525C.
The elastomer material 525C is shown in an at least partially
expanded state. The outer body 525B may comprise metal, a
composite, or any other suitable material. Although the mandrel
525A is depicted as having a particular shape, it should be
understood that the shape and implementation of the mandrel 525A
may be subject to considerable modification, as would be understood
by one of ordinary skill in the art having the benefit of this
disclosure.
[0054] Thus, in the expanded state, the system 500 allows sensor
packages to be deployed in a state that has no direct physical
contact or intermediate structural contact with the tubular body.
Having the tool placed against the side of the borehole with no
direct solid-to-solid contact with the tubular body, the sensor
packages are afforded a degree of acoustic isolation from acoustics
that may otherwise be transferred via the tubular body. Further,
the system 500 provides a safety margin such that the tool may be
spared from sharp, high-force, or uncontrolled movements that could
endanger tubing, wiring, the borehole wall, or the tool. The
generally circular outer arrangement 515 provides a perimeter that
may allow for positioning while maintaining tolerance for
irregularities that may be encountered in the surface of the
borehole. Although system 500 is depicted with four circular
components and four sensor packages in the outer arrangement 515,
and four circular components in the inner arrangement 510, it
should be understood that other embodiments may include a different
number and combination of circular components and sensor
packages.
[0055] In another embodiment, the inner arrangement 510 may be
coupled to spring- powered extensions released to point inwards to
the tubular body 505 in order to "measure" the radial distance
between the inner arrangement 510 and the tubular body 505 at three
or more points. As the spring-powered extensions increasingly
extend, they may restrict the flow of swelling agent into their
respective components 510A, thereby allowing those swellable
sections nearest the tubular to be expanded outwards more rapidly
than those farther away, and thereby centering the inner
arrangement 510 at a uniform distance from the tubular body 505.
Once deployed, the extensions may be refracted into the inner
arrangement 510.
[0056] Certain embodiments of the present disclosure may provide a
simpler, cheaper, and easier means of coupling sensors to a
formation or tubing/casing that are likely to provide much surer
coupling. Most previous sensor deployments have used cement
coupling (generally for permanent deployments), mechanical coupling
such as clamp arms and bow springs (for both permanent and
retrievable applications), magnetic coupling (retrievable
applications), or even uncoupled deployments (e.g., sensors
attached to tubing run inside of casing) that rely on friction and
bending stresses. Methods and systems of the present disclosure may
eliminate the need for mechanical clamp arms (which may have leak
issues with seals and high temperature), bow springs (which may
have poor high frequency response and resonances), magnets (which
may have limited coupling and resonances), or cementing. Methods
and systems of the present disclosure may also improve
omnidirectional array fidelity, even for retrievable operations and
settings where the swelling elements may be subsequently
de-swelled, detached or torn off to facilitate tool retrieval or
repositioning.
[0057] Certain embodiments of the present disclosure may allow for
long-term emplacement in difficult open-hole environments without
permanently cementing an instrument in place. This may simplify
operations and may allow for retrievable sensor devices if
difficulties occur during emplacement. This may avoid the situation
in open-hole environments where mechanical arms or bowsprings can
sink into soft materials in the hole and cause poor tool coupling.
Such a situation can occur in shales and many shallow boreholes
where sensors would otherwise have to be cemented in permanently to
obtain good coupling.
[0058] Certain embodiments may allow for improved signal fidelity
for microseismic monitoring of hydraulic fractures by ensuring
better coupling compared to clamp arms, bow spring, magnets, or
other emplacement methods, thus attenuating or eliminating
longitudinal tool vibrations that degrade the recording fidelity of
elastic body wave motion parallel to a tool axis. In certain
embodiments, swelling elements may effectively dampen acoustic
noise generated by flow in production tubulars as well as noise
received via the tubulars. The swelling elements may even yield
sensor isolation from the tubulars even though swellable elements
are in contact with both. Additionally, certain embodiments may
allow for securely planting surface instruments in soft, crumbly
ground.
[0059] Certain embodiments may remove directional bias of recorded
signals by emplacing sensors in the center of a borehole with equal
response from all directions, as opposed to a likely higher
fidelity on the side of the borehole on which it is deployed when
clamped or cemented. Certain embodiments may eliminate the need for
a nearby vertical observation well by allowing for installation of
tools in the injection/production well with good coupling and a
degree of noise suppression from tubing activities.
[0060] Certain embodiments may be used for time-lapse seismic
monitoring and/or time-lapse deformation monitoring throughout the
life of the reservoir for more permanent installations. The
time-lapse seismic application requires a source on either the
surface or in a nearby well; time-lapse deformation only requires
continuous measurements of tilt or other deformation parameters.
For emplacement of tiltmeters, geophones, or other sensors in
shallow boreholes, certain embodiments provide a fast, easy method
to deploy sensors, potentially allowing them to stabilize much
faster--which translates to a shorter lead time for monitoring.
[0061] Even though the figures depict embodiments of the present
disclosure in a horizontal section of a wellbore, it should be
understood by those skilled in the art that embodiments of the
present disclosure are well suited for use in deviated or vertical
wellbores or casings. Accordingly, it should be understood by those
skilled in the art that the use of directional terms such as above,
below, upper, lower, upward, downward and the like are used in
relation to the illustrative embodiments as they are depicted in
the figures, the upward direction being toward the top of the
corresponding figure and the downward direction being toward the
bottom of the corresponding figure. Additionally, as discussed
above, embodiments of the present disclosure may be implemented in
cased or uncased wellbores, even though only uncased wellbores are
depicted in the figures.
[0062] Therefore, the present invention is well adapted to attain
the ends and advantages mentioned as well as those that are
inherent therein. The particular embodiments disclosed above are
illustrative only, as the present invention may be modified and
practiced in different but equivalent manners apparent to those
skilled in the art having the benefit of the teachings herein.
Furthermore, no limitations are intended to the details of
construction or design herein shown, other than as described in the
claims below. It is therefore evident that the particular
illustrative embodiments disclosed above may be altered or modified
and all such variations are considered within the scope and spirit
of the present invention. Also, the terms in the claims have their
plain, ordinary meaning unless otherwise explicitly and clearly
defined by the patentee. The indefinite articles "a" or "an," as
used in the claims, are defined herein to mean one or more than one
of the element that it introduces.
* * * * *