U.S. patent application number 10/116235 was filed with the patent office on 2003-10-09 for system and method for sensing and monitoring the status/performance of a downhole tool.
Invention is credited to Schultz, Roger L., Streich, Steven G..
Application Number | 20030188862 10/116235 |
Document ID | / |
Family ID | 28673923 |
Filed Date | 2003-10-09 |
United States Patent
Application |
20030188862 |
Kind Code |
A1 |
Streich, Steven G. ; et
al. |
October 9, 2003 |
System and method for sensing and monitoring the status/performance
of a downhole tool
Abstract
A system and method for sensing and monitoring the
status/performance of components of a downhole tool to enable any
problems to be corrected.
Inventors: |
Streich, Steven G.; (Duncan,
OK) ; Schultz, Roger L.; (Aubrey, TX) |
Correspondence
Address: |
JOHN W. WUSTENBERG
P.O. BOX 1431
2600 SOUTH 2ND STREET
DUNCAN
OK
73536
US
|
Family ID: |
28673923 |
Appl. No.: |
10/116235 |
Filed: |
April 3, 2002 |
Current U.S.
Class: |
166/250.01 ;
166/118; 166/138; 166/166; 166/179 |
Current CPC
Class: |
E21B 47/002 20200501;
E21B 33/129 20130101 |
Class at
Publication: |
166/250.01 ;
166/179; 166/118; 166/166; 166/138 |
International
Class: |
E21B 023/01; E21B
047/00 |
Claims
What is claimed is:
1. A downhole tool comprising: a body member; at least one slip
member; at least one packer member; at least one drag member; and a
sensor mounted on or near at least one of the members for sensing
information relating to the performance of the member.
2. The tool of claim 1 further comprising a central processor
disposed on the body member for receiving data from the sensor,
processing the data, and generating a signal corresponding to the
processed data to send to another location.
3. The tool of claim 2 wherein the signal is transmitted to the
surface to enable personnel on the surface to change parameters to
improve the performance of the tool.
4. The tool of claim 2 wherein the signal is transmitted to another
down hole device to adjust the parameters needed to maintain proper
operation of the tool.
5. The tool of claim 1 wherein the sensor senses load on the
member.
6. The tool of claim 1 wherein the sensor senses the differential
pressure across the member.
7. The tool of claim 1 wherein the sensor senses whether fluid is
flowing in a certain area of the tool by sensing the pressure drop
between adjacent members.
8. The tool of claim 1 wherein the sensor senses stresses within
the member.
9. The tool of claim 1 wherein the sensor senses the weight set
down on the tool.
10. The tool of claim 1 wherein the sensor senses movement of the
member.
11. The tool of claim 1 wherein the sensor senses the effects that
fluids may have on the member.
12. The tool of claim 1 wherein the sensor senses fluid flow
through the body member.
13. The tool of claim 1 wherein the sensor senses leakage of fluids
or gases past the member.
14. The tool of claim 1 wherein the body member is disposed in a
casing and wherein the sensor senses acoustics related to the
casing.
15. The tool of claim 1 wherein the sensor is in the form of an
accelerometer to sense vibrational forces on the member.
16. A downhole tool comprising: a body member; at least one slip
member; at least one packer member; at least one drag member; and a
camera mounted on or near at least one of the members to provide
video data relating to the condition of the member to enable the
member to be monitored.
17. The tool of claim 16 further comprising a central processor
disposed on the body member for receiving the video data from the
camera, processing the video data, and generating a signal
corresponding to the processed video data to send to another
location.
18. The tool of claim 16 wherein the video data is transmitted to
another downhole device to adjust the parameters needed to maintain
proper operation of the tool.
19. The tool of claim 17 wherein the signal enables an operator on
the surface to observe the condition of the member and change
parameters to improve the performance of the tool.
20. The tool of claim 16 wherein the camera is a CMOS camera.
21. A method for sensing the performance of a downhole tool having
a body member, at least one slip member, at least one packer
member, and at least one drag member; the method comprising the
steps of: disposing a sensor at or near at least one of the
members; sensing information relating to the performance of the
member; and transmitting the information to the surface to enable
personnel on the surface to change parameters to improve the
performance of the tool.
22. The method of claim 21 further comprising the step of providing
a central processor on the body member for receiving the
information from the sensor, processing the information, and
generating a signal corresponding to the processed information to
send to another location.
23. The method of claim 21 further comprising the step of
transmitting the information to another downhole device to adjust
the parameters needed to maintain proper operation of the tool.
24. The method of claim 21 wherein the step of sensing comprises
sensing the load on the member.
25. The method of claim 21 wherein the step of sensing comprises
sensing the differential pressure across the member.
26. The method of claim 21 wherein the step of sensing comprises
sensing whether fluid is flowing in a certain area of the tool by
sensing the pressure drop between adjacent members.
27. The method of claim 21 wherein the step of sensing comprises
sensing stresses within the member.
28. The method of claim 21 wherein the step of sensing comprises
sensing the weight set down on the tool.
29. The method of claim 21 wherein the step of sensing comprises
sensing movement of the member.
30. The method of claim 21 wherein the step of sensing comprises
sensing the effects that fluids may have on the member.
31. The method of claim 21 wherein the step of sensing comprises
sensing fluid flow through the body member.
32. The method of claim 21 wherein the step of sensing comprises
sensing leakage of fluids or gases past the member.
33. The method of claim 21 wherein the body member is disposed in a
casing and wherein the step of sensing comprises sensing acoustics
related to the casing.
34. The method of claim 21 wherein the step of sensing comprises
sensing vibrational forces on the member.
35. A method for monitoring the performance of a downhole tool
having a body member, at least one slip member, at least one packer
member, and at least one drag member; the method comprising the
steps of: mounting a camera on or near at least one of the members
to provide video data relating to the condition of the member; and
monitoring the condition of the member from the surface.
36. The method of claim 35 further comprising the steps of:
providing a central processor on the body member for receiving the
video data from the camera; processing the video data; generating a
signal corresponding to the processed video data; and transmitting
the signal to the surface.
37. The method of claim 35 further comprising the step of changing
parameters relating to the member in response to the video data to
improve the performance of the tool.
Description
BACKGROUND
[0001] In order to produce oil and gas from a subterranean well,
oil field tubulars, commonly called a "work string," are inserted
in the well bore, or in a casing located in the well bore. Packers
and downhole tools are connected to the work string with the
packers functioning to isolate formations, and the tools assisting
in displacing various fluids into the formations or for retrieving
hydrocarbons from the formations.
[0002] Some packers are mechanically set at a desired depth in the
casing, or well bore, by picking up on the work string at the
surface, turning the work string and then lowering the work string
until mechanical slips associated with the packer have extended
outwardly to engage, or grip, the casing, or well bore. As
additional work string weight is set down on the engaged slips, a
series of elastomeric packer elements are deformed to seal off
against the casing, or well bore. Fluid is then pumped down the
work string so that its pressure is exerted against another set of
slips located above the packer. This fluid pressure hydraulically
extends the latter slips outwardly until they engage, or grip the
casing, or well bore. Thus, various fluids can be pumped down the
work string and through internal passages of the packer before they
exit below the packer, while the packer slips are kept sealed
against the casing, or well bore, by the weight of the work
string.
[0003] In other techniques, the packers are set by utilizing the
workstring to create hydraulic pressure to expand slips of a
setting mechanism into engagement with the casing, or well
bore.
[0004] It can be appreciated that these types of packers and
downhole tools encompass a number of subsystems and/or components
that function together in an integral manner thus allowing the
device to be manipulated so that it will perform its intended task.
However, there is no method to monitor, evaluate, report, or
improve the condition, or function, of these devices or their
surroundings during the downhole operation. Therefore, if a problem
occurs during the operation, the devices would have to be removed
from the well for inspection and repair and then reinserted into
the well--a procedure that is time-consuming and costly.
[0005] Therefore, what is needed is a system and method for sensing
and monitoring the status/performance of components of a packer,
and/or downhole tool to enable any problems to be corrected.
BRIEF DESCRIPTION OF THE DRAWING
[0006] The drawing is a schematic view of a system according to an
embodiment of the invention.
DETAILED DESCRIPTION
[0007] Referring to the drawing, a packer is referred to in general
by the reference numeral 10 and is in the form of an elongated
tubular body member 12 adapted to be inserted into a casing, or
well bore, on a work string, or the like (not shown). Since the
packer 10, per se, does not form any part of the present invention,
it is shown, and will be described, only generally.
[0008] The packer includes upper slips 14 and 16 mounted on the
body member 12 which operate in a conventional manner so that they
can be set in response to fluid being pumped down the work string
to exert pressure against the slips. This pressure causes the upper
slips 14 and 16 to extend outwardly to engage, or grip, the casing
or well bore, in a conventional manner.
[0009] Lower slips 18 are also provided on the body member 12 which
are mechanically set in a conventional manner by picking up on the
work string at the surface, turning the work string for a
predetermined angular amount, and then lowering the work string
until the lower slips 18 have extended outwardly to engage (grip)
the casing, or well bore.
[0010] Packer elements 20 and 22 are provided on the body member 12
and extend between the upper slips 16 and the lower slips 18. The
packer elements 20 and 22 deform, usually by compressing or
extending, as additional work string weight is set down in the
casing, or wellbore, to seal off against the casing, or well bore.
A series of drag blocks 24 are angularly spaced around the body
member 12 below the packer element 22.
[0011] Since the slips 14, 16, 18; the packer elements 20 and 22;
and the drag blocks 24 are all, per se, conventional, they will not
be shown or described in any greater detail.
[0012] As a result of the foregoing, various fluids can be pumped
down the work string, and pass through internal passages, or bores,
of the body member 12 before they exit below the packer 10, while
the slips 14,16 and 18 are kept sealed against the casing, or well
bore, by the weight of the work string.
[0013] A sensor 30 is disposed inside the bore of the body member
12, three sensors 30 are placed on, in, and/or around the slips 14,
16, and 18, respectively; two sensors 30 are placed on, in, or
around the packer elements 20 and 22, respectively; and a sensor 30
is placed on, in, or around the drag blocks 24.
[0014] The sensors 30 are conventional, and, as such, sense and
provide information that will be described that is transmitted to
the surface to enable personnel on the surface to change parameters
that would improve the performance of the packer 10.
[0015] The sensors 30 can include, but are not limited to, sensors
that sense pressure, load, movement, fluid identification, fluid
flow, acoustic properties and/or acceleration. For example, they
could provide information about differential pressure across
various components of the packer 10 including the slips 14, 16, and
18, and the packer elements 20 and 22, thus providing information
about stresses in these components due to pressure loading. Also,
the sensors 30 could be utilized to determine if fluid is flowing
in areas by measuring the pressure drop between components in these
areas. They could also sense, and provide analysis of, stresses
within components thus warning of premature failure of a component.
Further, the sensors 30 could determine if the initial weight set
down on the packer 10 is within proper operating parameters, and,
if not, they could send a signal to the surface so that the
operator could make adjustments from the surface or to other
downhole devices (passive or active) that could be called upon to
adjust the force needed to maintain the proper operation of the
tool. Still further, the sensors 30 could also sense relative
movement between components of the packer 10 including the slips
14, 16, and 18, as well as the packer elements 20 and 22 and the
drag blocks 24, to evaluate the position of the components relative
to one another and thus help determine if the component may become
unstable.
[0016] The sensors 30 could also be used to determine the effects
that fluids may have on various components. For example, these
effects could include chemical degradation of elastomers or metals
to the point they will no longer function within their design
limits. Further, the sensors 30 could be used to determine fluid
flow through the packer 10, the casing, or the well bore to assist
in determining leakage, erosion or imminent removal of components
such as the washing off of the packer elements before they are set.
Moreover, the sensors 30 could be utilized to determine leakage of
fluids or gases past components of the packer 10, such as the
packer elements 20 and 22, and/or they could be in the form of
acoustic sensors to determine factors involving acoustics, such as
the condition of cement behind the casing, or thickness of the
casing or components. This would, in turn, provide information as
to the condition of the casing prior to setting the packer 10 or
the condition of a component that may be experiencing erosion
during the job. The sensors 30 could also be in the form of
accelerometers which could be utilized to help determine if
vibrational forces are exceeding design limits or if fatigue in any
of the components of the packer 10 is excessive.
[0017] A series of relatively small video cameras 34 are placed
inside the inner diameter of the body member 12; in or around the
slips 14, 16, and 18; on each side of the packer elements 20 and
22; and/or in or around the drag blocks 24. The video cameras 34
could be provided in place of, or in addition to, the sensors 30,
and function to provide operators with a visual picture of the
condition of these components, as well as the packer 10 in general,
and its surroundings. This would enable an operator on the surface
to observe these components and, if they are not functioning in a
normal manner, to make adjustments from the surface.
[0018] The video cameras 34 are conventional and, as a non-limiting
example, could be solid state CMOS cameras. Electronic circuits
associated with the video cameras 34 could be fabricated using bulk
CMOS processes.
[0019] A central processor 36 is disposed on the body member 12 to
receive data from the sensors 30 and/or video data from the video
cameras 34, process the data, and generate a signal or signals
corresponding to the processed data to send to another location
such as directly to the surface or to any intervening downhole
device. In this context, various methods for transferring this data
could be utilized including mud pulse, acoustic transfer through
the fluid or tubulars, electromagnetic, fiber optics or hard wire,
all of which are known in the art.
[0020] The above enables the packer 10, in general, as well as its
various components, to be continuously monitored and evaluated so
that any problems detected can be corrected.
[0021] It is understood that several variations may be made in the
foregoing without departing from the scope of the invention. For
example, the invention is not limited to use with a packer, but is
equally applicable to any downhole device. Also, the
above-mentioned electronic circuits could be replaced with an
optical system. Also, additional sensors can also be placed on
other sub-systems, or components, of the packer 10 including, but
not limited to, seals (such as o-rings), j-slots, springs, internal
tubes, adapters, subs, fasteners, and the like. Further, the
sensors 30 and/or the video cameras 34 could be replaced with
artificially intelligent devices. It is also understood that
spatial references, such as "upper", "lower", "inner", and "outer"
"below" "in between", etc., are for the purpose of illustration
only and do not limit the specific orientation or location of the
layers described above.
[0022] The foregoing descriptions of specific embodiments of the
present invention have been presented for purposes of illustration
and description. They are not intended to be exhaustive or to limit
the invention to the precise forms disclosed, and obviously many
modifications and variations are possible in light of the above
teaching. The embodiments were chosen and described in order to
best explain the principles of the invention and its practical
application, to thereby enable others skilled in the art to best
utilize the invention and various embodiments with various
modifications as are suited to the particular use contemplated. It
is intended that the scope of the invention be defined by the
claims appended hereto and their equivalents.
* * * * *