U.S. patent application number 12/173546 was filed with the patent office on 2009-06-18 for system and method for detecting movement in well equipment.
This patent application is currently assigned to Schlumberger Technology Corporation. Invention is credited to John R. Lovell, Stuart MacKay.
Application Number | 20090151935 12/173546 |
Document ID | / |
Family ID | 40751698 |
Filed Date | 2009-06-18 |
United States Patent
Application |
20090151935 |
Kind Code |
A1 |
Lovell; John R. ; et
al. |
June 18, 2009 |
SYSTEM AND METHOD FOR DETECTING MOVEMENT IN WELL EQUIPMENT
Abstract
An apparatus for use in a well for indicating movement of a
reservoir. The apparatus may include first and second equipment
assemblies connected by a telescoping connection mechanism. A
sensor assembly may be provided and configured to detect relative
movement of at least a portion of the telescoping connection
mechanism. The relative movement of at least a portion of the
telescoping mechanism may interpreted so as to correlate to the
compaction or expansion of the reservoir.
Inventors: |
Lovell; John R.; (Houston,
TX) ; MacKay; Stuart; (Navi Mumbai, IN) |
Correspondence
Address: |
SCHLUMBERGER RESERVOIR COMPLETIONS
14910 AIRLINE ROAD
ROSHARON
TX
77583
US
|
Assignee: |
Schlumberger Technology
Corporation
Sugar Land
TX
|
Family ID: |
40751698 |
Appl. No.: |
12/173546 |
Filed: |
July 15, 2008 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
61013542 |
Dec 13, 2007 |
|
|
|
Current U.S.
Class: |
166/250.03 ;
166/66 |
Current CPC
Class: |
E21B 47/01 20130101;
E21B 17/07 20130101; E21B 47/007 20200501 |
Class at
Publication: |
166/250.03 ;
166/66 |
International
Class: |
E21B 47/04 20060101
E21B047/04 |
Claims
1. An apparatus for use in a well that extends to a reservoir,
comprising: a first equipment assembly; a second equipment
assembly; a telescoping connection mechanism between the first and
second equipment assemblies; and a sensor assembly to detect
movement in at least a portion of the telescoping connection
mechanism.
2. The apparatus of claim 1, further comprising a controller
configured to interpret measurement data from the sensor assembly
and to indicate compaction of the reservoir in response to the
measurement data.
3. The apparatus of claim 1, wherein the telescoping connection
mechanism has a first segment and a second segment arranged within
the first segment, wherein the first and second segments are
axially moveable with respect to each other.
4. The apparatus of claim 1, wherein the first equipment assembly
comprises a first casing segment to line the well, and the second
equipment assembly comprises a second casing segment to line the
well, wherein the first and second casing segments are
interconnected by the telescoping connection mechanism.
5. The apparatus of claim 1, wherein the sensor assembly comprises
a position sensor configured to provide substantially continuous
measurement of axial movement of the at least a portion of the
telescoping connection mechanism.
6. The apparatus of claim 1, wherein the sensor assembly comprises
a position sensor configured to provide discrete measurements
indicating axial movement of the at least a portion of the
telescoping connection mechanism.
7. The apparatus of claim 1, further comprising production
equipment to produce fluid from the reservoir.
8. The apparatus of claim 1, wherein the sensor assembly includes a
position sensor configured to detect relative movement between the
first and second equipment assemblies.
9. The apparatus of claim 8, wherein the position sensor includes a
probe member translatably engaged with a profile surface provided
in the telescoping connection mechanism, wherein the position
sensor detects movement in the at least a portion of the
telescoping connection mechanism based on the relative motion of
the probe member and the profile surface.
10. The apparatus of claim 9, wherein the probe member comprises a
radial protrusion, and wherein relative motion of the radial
protrusion and the profile surface is reported by the position
sensor as a radial displacement.
11. The apparatus of claim 8, wherein the position sensor includes
one of an optical, resistive, electrical, electrostatic, or
magnetic sensor
12. The apparatus of claim 1, wherein the sensor assembly is
configured to provide an indication that the first and second
completion assemblies have successfully landed with respect to each
other.
13. The apparatus of claim 1, wherein the sensor assembly is
configured to further provide an indication of one or more
properties associated with the well or reservoir.
14. The apparatus of claim 13, wherein the one or more properties
include pressure, temperature, or resistivity.
15. A method comprising: positioning first and second well
equipment assemblies in a well; interconnecting the first and
second well equipment assemblies using a telescoping connection
mechanism; detecting relative movement between the first and second
well assemblies using a sensor assembly; and determining an
indication of reservoir compaction correlating to the relative
movement detected by the sensor assembly,
16. The method of claim 15, wherein positioning the first and
second well equipment assemblies comprises positioning first and
second casing segments that line the well.
17. The method of claim 15, wherein determining the indication of
reservoir compaction comprises: communicating to a controller the
relative movement detected by the sensor; communicating to the
controller other measurement data from the sensor assembly;
interpreting the relative movement and the other measurement data
communicated to the controller to provide the indication of
reservoir compaction.
18. The method of claim 17, wherein the other measurement data is
selected from pressure and temperature of the reservoir.
19. The method of claim 15, wherein detecting the relative movement
using the sensor assembly comprises using one of a mechanical
position sensor, an optical sensor, a resistive sensor, an
electrical sensor, an electrostatic sensor, or a magnetic
sensor.
20. The method of claim 15, further comprising communicating
relative movement from the sensor assembly to a surface controller
through a wireless mechanism.
21. The method of claim 20, wherein communicating the measurement
data from the sensor assembly to the surface controller through the
wireless mechanism comprises communicating through one of an
inductive coupler, an acoustic telemetry mechanism, or an
electromagnetic telemetry mechanism.
Description
RELATED APPLICATIONS
[0001] The following is based on and claims the benefit of priority
under 35 U.S.C. .sctn.119 to U.S. Provisional Patent Application
Ser. No. 61/013,542 entitled, "METHOD AND APPARATUS TO MEASURE
RESERVOIR COMPACTION," filed on Dec. 13, 2007.
TECHNICAL FIELD
[0002] The invention relates to measuring movement in well
equipment for measuring reservoir compaction.
BACKGROUND
[0003] One or more wellbores can be drilled through an earth
formation to a reservoir that may contain hydrocarbons or other
types of fluid (e.g. water). Completion equipment can then be
provided into the one or more wellbores. The completion equipment
can be used for extracting fluid from the reservoir and producing
the fluid to the earth surface.
[0004] As fluid is extracted from the reservoir, reservoir
compaction may occur. As fluid is extracted, the reservoir pressure
decreases in certain zones of the reservoir, in some cases causing
a loss of consolidation and overall compaction of the reservoir.
Reservoir compaction is particularly a problem in high permeability
reservoirs, or low porosity reservoirs, for example.
[0005] Compaction, or other movement of a reservoir can cause
deformation of well equipment, such as casing or tubing provided in
the wellbore(s), and can lead to failure of such well
equipment.
[0006] In some cases, well operators attempt to predict the amount
of movement that may occur as a result of production from the
reservoir. The operators then attempt to modify well equipment to
accommodate such movement. However, modifying well equipment
designed to accommodate predicted movement of the reservoir is
relatively expensive. Also, effective well equipment designed to
account for reservoir compaction, for example, requires an accurate
prediction of the potential degree of reservoir compaction, which
may not be economically feasible or possible.
SUMMARY
[0007] In general, according to an illustrative embodiment of the
present invention, an apparatus for use in a well that extends to a
reservoir includes first and second equipment assemblies, and a
telescoping connection mechanism between the first and second
equipment assemblies. A sensor detects movement in the telescoping
connection mechanism to enable measurement of reservoir
compaction.
[0008] Other or alternative features will become apparent from the
following description, from the drawings, and from the claims.
BRIEF DESCRIPTION OF THE DRAWINGS
[0009] FIG. 1 illustrates example well equipment disposed in a
wellbore having first and second equipment assemblies connected by
a telescoping connection mechanism and a sensor to detect movement
of the telescoping connection mechanism, according to an embodiment
of the present invention.
[0010] FIG. 2 illustrates a telescoping connection mechanism and an
associated sensor assembly, according to an embodiment of the
present invention.
[0011] FIG. 3 illustrates a schematic showing the use of an
inductive coupler with a system incorporated in an embodiment of
the present invention.
DETAILED DESCRIPTION
[0012] In the following description, numerous details are set forth
to provide an understanding of the present invention. However, it
will be understood by those skilled in the art that the present
invention may be practiced without these details and that numerous
variations or modifications from the described embodiments are
possible.
[0013] As used here, the terms "above" and "below"; "up" and
"down"; "upper" and "lower"; "upwardly" and "downwardly"; and other
like terms indicating relative positions above or below a given
point or element are used in this description to more clearly
describe some embodiments of the invention. However, when applied
to equipment and methods for use in wells that are deviated or
horizontal, such terms may refer to a left to right, right to left,
or diagonal relationship as appropriate.
[0014] In accordance with some exemplary embodiments of the present
invention, a system for use in a well that extends to a reservoir
may include well equipment having multiple assemblies connected by
a telescoping connection mechanism. A telescoping connection
mechanism may be configured to allow for relative axial movement of
the first and second equipment assemblies (e.g., along the axial
direction of the equipment assemblies and the wellbore). Also, a
sensor assembly may be associated with the telescoping connection
mechanism in order to detect movement in the telescoping connection
mechanism in order to estimate or measure reservoir compaction.
Reservoir compaction refers to one or more zones of the reservoir
collapsing due to fluid loss and the associated loss of pressure,
for example, resulting in an overall reduction of the length of the
wellbore extending through the collapsed zones.
[0015] The sensor assembly can include one or more sensors, where
one sensor is used for detecting movement in the well equipment,
while other sensors can measure other properties associated with
the wellbore and/or reservoir. As discussed further below,
measurements made by such other sensors can also be used as an
independent indication or verification of reservoir compaction.
[0016] FIG. 1 illustrates an exemplary arrangement that includes
well equipment installed in a wellbore 100 and having a first
assembly 102 and a second assembly 104 interconnected by a
telescoping connection mechanism 106. In one example, the well
equipment assembly 102 may comprise a first casing segment, and the
well equipment assembly 104 may comprise a second casing segment. A
"casing" is a structure, normally formed of metal, which may line
the walls of the wellbore. The telescoping connection mechanism 106
allows for relative axial movement of the first and second casing
segments 102 and 104. In other examples, other forms of tubular
structures (e.g., pipes, tubing, etc.) can be connected to the
telescoping connection mechanism 106. Generally, a "telescoping
connection mechanism" refers to any mechanism that interconnects
two members while allowing relative axial movement of the two
members. For example, the telescoping connection mechanism can be a
contracting joint or an expansion joint.
[0017] The wellbore 100 depicted in FIG. 1 extends to a reservoir
108 that may contain a desirable fluid such as hydrocarbon, fresh
water, and so forth. Production equipment 103 can be provided
inside the wellbore to extract the fluid from the reservoir 108 as
part of a production operation.
[0018] The first and second casing segments 102, 104 may be
connected or coupled to the formation adjacent to the wellbore. If
reservoir compaction occurs, one or both of the casing segments
102, 104 may shift as a result of the compaction. This shifting can
cause the casing segments 102, 104 to move axially relative to each
other at the telescoping connection mechanism 106. Although
reservoir compaction is typically described as casing segment 102
moving closer to casing segment 104, embodiments of the current
invention may also encompass relative axial movement in which the
casing segments 102, 104 move away from each other, as will be
readily appreciated by those of skill in the art.
[0019] In accordance with some embodiments of the present
invention, a sensor assembly 110 may be associated with the
telescoping connection mechanism 106. The sensor assembly 110 may
be connected to a communications link 112 that extends to well
surface equipment 116. The communications link 112 can include an
electrical cable, a fiber optic cable, or some other type of link
(e.g., wireless link, such as an acoustic link, pressure pulse
link, electromagnetic link, etc.). The communications link 112 may
pass through the wellhead 114 in order to connect to a controller
118 provided at the well surface.
[0020] The controller 118 (which can be implemented with a
computer, for example) may be configured to receive measurement
data from the sensor assembly 110, and to process the measurement
data to provide an indication regarding one or more properties of
the wellbore 100 and reservoir 108. The one or more properties can
include indications of whether the reservoir 108 has experienced
compaction, and the extent of such compaction, for example. Other
well or reservoir properties that can be indicated by the
controller 118 may include pressure, temperature, and reservoir
resistivity, among others.
[0021] In the example of FIG. 1, the controller 118 may include
processing software 120 executable on one or more central
processing units CPU(s) 122, which is (are) connected to storage
124. The storage 124 can be used to store measurement data as well
as instructions contained in the form of software 120.
[0022] An example of the telescoping connection mechanism 106 is
depicted in FIG. 2. The telescoping connection mechanism 106 may
include a first connection segment 202 (which is connected to the
first casing segment 102), and a second connection segment 204
(which is connected to the second casing segment 104). Note that in
some implementations, the second casing segment 104 along with the
second connection segment 204 (e.g., as part of a lower completion
assembly) can be deployed into the wellbore first, followed later
by deployment of the first casing segment 102 along with the first
connection segment 202 (e.g., as part of an upper completion
assembly). In such multi-part deployment, the later deployed first
connection segment 202 may be landed with the previously installed
second connection segment 204.
[0023] Alternatively, the first casing segment 102, second casing
segment 104, and the telescoping connection mechanism 106 can be
deployed into the wellbore together.
[0024] The second connection segment 204 has a portion 205 of
reduced diameter relative to the first connection segment 202. As a
result, the reduced diameter portion 205 can move axially inside of
the first connection segment 202. Each of the first and second
connection segments 202 and 204 may be configured to be generally
tubular in shape, so that the reduced diameter portion 205 may be
substantially concentrically arranged inside (and moveable with
respect to) the first connection segment 202.
[0025] In some implementations, it may be desirable to run a cable
or control line (arranged outside the casing segments 102 and 104)
through the telescoping connection mechanism 106. To do so, such a
cable or control line can be wound around the outside of the
connection segments 202 and 204. In other cases, the communications
link may be run along an interior bore or within portions of the
casing segments 102, 104 (e.g., such as along the exterior of
production tubing, among other methods).
[0026] As further depicted in FIG. 2, a motion or position detector
206, which is part of the sensor assembly 110 of FIG. 1, may be
provided as a part of the telescoping connection mechanism 106. The
motion detector 206 may be configured with a radial protrusion 208
(e.g., a mechanical probe member) that engages with a slanted
surface 210 provided by a profile feature 212 (e.g., a conical
shape, cam surface, or some other shape) inside the first
connection segment 202.
[0027] A biasing element 214, such as a spring, may be provided to
push the first connection segment 202 away from the second
connection segment 204. However, due to compaction of the
surrounding reservoir, the first and second connection members 202
and 204 may overcome the biasing force and be pushed towards each
other, or in some cases be pushed further away from each other.
Assuming for the purpose of description that the second connection
segment 204 (and the second casing segment 104) is fixed in
position, then relative movement of the first and second connection
segments 202 and 204 will cause relative axial movement of the
first connection segment 202, for example. Accordingly, the radial
protrusion 208 of the motion detector 206 will move along or across
the slanted surface 210 of the profile feature 212. Movement along
the slanted surface 210 by the radial protrusion 208 results in
radial movement (i.e., displacement) of the radial protrusion 208.
The angle of the slanted surface 210 may function to correlate a
large axial movement to a relatively limited radial movement.
[0028] As depicted in FIG. 2, if the radial protrusion 208 were to
move downwardly relative to the first connection segment 202 (e.g.,
when the first connection segment 202 is moving away from the
second connection segment 204), then the radial protrusion 208 will
be pushed radially inwardly by the slanted surface 210. On the
other hand, if the radial protrusion 208 were to move upwardly
relative to the first connection segment 202 (e.g., when the first
connection segment 202 is moving toward the second connection
segment 204), then the radial protrusion 208 will move radially
outwardly.
[0029] The motion detector 206 may be configured to detect
differences in the radial position of the radial protrusion 208,
and to communicate the extent of such radial movement over the
communications link 112 (FIG. 1) to the earth surface controller
118 for processing.
[0030] In another embodiment, the profile feature 112 may be
present on the second connection segment 204 and the radial
protrusion 208 and motion detector 206 can be provided on the first
connection segment 202. In still other embodiments, a motion
detector similar to motion detector 206 may directly engage with
the first connection segment 202 so that relative movement between
the first and second connection segments 202, 204 can be
detected.
[0031] The motion detector 206 can provide continuous measurement
of movement, corresponding to continuous movement of the radial
protrusion 208 relative to the slanted surface 210. Such detected
continuous movement can be reported continuously to the earth
surface controller 118. Alternatively, instead of continuous
measurement data, the motion detector 206 can report discrete
movement measurements to the controller 118. Even further
alternatively, the motion detector 206 may be interrogated either
periodically or continuously to report the current position of the
radial protrusion 208 or change in position of the radial
protrusion 208.
[0032] Note that the sensor assembly 110 can include one or more
other sensors, such as 216, 218, 220, and so forth. Some of these
sensors may be provided as part of the telescoping connection
mechanism 106, while other sensors may be provided apart from the
connection mechanism 106. The sensors can include pressure sensors,
temperature sensors, and resistivity sensors, among others.
[0033] The motion detector 206 of FIG. 2 functions effectively as a
position sensor that is used to detect changes in the position of a
mechanical component, in this case the first connection segment
202. Through the use of a profile feature 212 comprising a slanted
surface 210, for example, a relatively small change in radial
position may be correlated to a relatively large change in axial
position.
[0034] In a different implementation, a position sensor can be
implemented using an optical, resistive, electrical, electrostatic,
or magnetic mechanism. For example, a position sensor can include
an optical detector that uses the Faraday effect, a photo-activated
ratio detector, a resistive contacting sensor, an inductively
coupled ratio detector, a variable reluctance device, a
capacitively coupled ratio detector, a radio wave directional
comparator, or an electrostatic ratio detector, among others.
[0035] An optical detector can use a position sensing detector to
determine the position of an optical probe light that is incident
upon a surface of the moveable device. The probe light can be
directed to an optically reflective surface that is attached to the
moveable member. The laser beam is reflected from the optically
reflective surface. The optical detector may be constructed using
photodetectors, such as photo-diodes or PIN-diodes, to detect the
reflected laser beam.
[0036] A capacitance-based position sensor uses a variable
capacitor having a value that varies with relative position of a
pair of objects. In such systems, the relative position of the
objects can be determined by measuring the capacitance.
[0037] A magnetic sensor to detect motion typically relies upon
permanent magnets to detect the presence or absence of a
magnetically permeable object within a certain predefined detection
zone relative to the sensor. As one example, the magnetic sensor
can be a Hall effect sensor. A Hall effect occurs when a
current-carrying conductor is placed into a magnetic field, where a
voltage is generated that is perpendicular to both the current and
the field. Alternatively, the magnetic sensor can include a
magnetoresistive sensor, which uses a magnetoresistive effect to
detect a magnetic field. Relative movement of members can be
detected based on measured magnetic fields.
[0038] The other sensors used to measure other properties can
provide additional information to allow for more accurate detection
of whether reservoir compaction has occurred. For example,
temperature measurement can be used to provide an indication of
compaction, since as pressure within a zone of the reservoir
lowers, the granular components within the reservoir are forced
into closer contact and may ultimately be fused together. Such
action lowers the permeability of the zone and may result in a
decrease of flow from that zone. Reduced flow will cause a
reduction in temperature, which is an indication of possible
reservoir compaction. This data in combination with the position
sensor used to detect relative movement of different segments of
well equipment can be used to confirm that reservoir compaction has
occurred.
[0039] Note that another possible application of the sensor that is
associated with the telescoping connection mechanism 106 is that
the sensor assembly 110 can provide an indication that the two
different segments of the well equipment have successfully landed
into the correct position.
[0040] In implementations where the first equipment segment and the
second equipment segment are deployed at different times, it may be
difficult to provide a wired connection from a sensor of the sensor
assembly 110 to the earth surface. In such implementations, as
depicted in FIG. 3, an inductive coupler mechanism 302 can be
provided. A sensor 300, which can be part of the sensor assembly
110 of FIG. 1, may be connected to a first inductive coupler
portion 304, which is positioned proximate a second inductive
coupler portion 306 when the upper well equipment segment is landed
with the lower well equipment segment. In one embodiment, the
second inductive coupler portion 306 can be a female inductive
coupler portion, while the first inductive coupler portion 304 may
be a male inductive coupler portion. When positioned proximate to
each other, the inductive coupler portions 304 and 306 may be
configured to communicate both power and data such that the sensor
300 can be powered using power provided over the link 112. Further,
measurement data of the sensor 300 can be communicated through the
inductive coupler 302 to the link 112 for communication to the
surface.
[0041] Alternatively, instead of using an inductive coupler,
acoustic telemetry or electromagnetic (EM) telemetry can be
used.
[0042] While the invention has been disclosed with respect to a
limited number of embodiments, those skilled in the art, having the
benefit of this disclosure, will appreciate numerous modifications
and variations there from. It is intended that the appended claims
cover such modifications and variations as fall within the true
spirit and scope of the invention.
* * * * *