U.S. patent application number 15/025637 was filed with the patent office on 2016-07-28 for optically-controlled switching of power to downhole devices.
This patent application is currently assigned to Halliburton Energy Services, Inc.. The applicant listed for this patent is HALLIBURTON ENERGY SERVICES, INC.. Invention is credited to Burkay DONDERICI, Glenn A. WILSON.
Application Number | 20160215613 15/025637 |
Document ID | / |
Family ID | 54554433 |
Filed Date | 2016-07-28 |
United States Patent
Application |
20160215613 |
Kind Code |
A1 |
WILSON; Glenn A. ; et
al. |
July 28, 2016 |
OPTICALLY-CONTROLLED SWITCHING OF POWER TO DOWNHOLE DEVICES
Abstract
A well having optically controlled switching, the well including
a power cable run along a tubular string in a borehole, one or more
downhole devices attached to the tubular string, one or more
optically-controlled switches arranged downhole, where each switch
is coupled between the power cable and one of the one or more
downhole devices to enable or disable a flow of power to the
downhole device, and a switch controller coupled to the one or more
optically-controlled switches via an optical fiber, where each of
the one or more optically-controlled switches are independently
controllable.
Inventors: |
WILSON; Glenn A.; (Houston,
TX) ; DONDERICI; Burkay; (Houston, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
HALLIBURTON ENERGY SERVICES, INC. |
Houston |
TX |
US |
|
|
Assignee: |
Halliburton Energy Services,
Inc.
Houston
TX
|
Family ID: |
54554433 |
Appl. No.: |
15/025637 |
Filed: |
May 21, 2014 |
PCT Filed: |
May 21, 2014 |
PCT NO: |
PCT/US2014/039013 |
371 Date: |
March 29, 2016 |
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 47/125 20200501;
E21B 33/14 20130101; E21B 49/00 20130101; E21B 47/135 20200501;
E21B 47/00 20130101; G01V 3/30 20130101 |
International
Class: |
E21B 47/12 20060101
E21B047/12; E21B 33/14 20060101 E21B033/14; E21B 47/00 20060101
E21B047/00; E21B 49/00 20060101 E21B049/00 |
Claims
1. A well having optically-controlled switching, the well
comprising: a power cable run along a tubular string in a borehole;
one or more downhole devices attached to the tubular string; one or
more optically-controlled switches arranged downhole, wherein each
switch is coupled between the power cable and one of the one or
more downhole devices to enable or disable a flow of power to the
downhole device; and a switch controller coupled to the one or more
optically-controlled switches via an optical fiber, wherein each of
the one or more optically-controlled switches are independently
controllable.
2. The well of claim 1, wherein at least one of the downhole
devices includes a capacitive electrode.
3. The well of claim 1, wherein at least one of the downhole
devices includes a galvanic electrode.
4. The well of claim 1, wherein at least one of the downhole
devices includes a multi-turn loop antenna.
5. The well of claim 1, wherein at least one of the downhole
devices is an electric motor.
6. The well of claim 1, wherein the switch controller is arranged
at the surface.
7. The well of claim 1, further comprising an optical fiber current
sensor coupled to at least one of the optically-controlled switches
that measures a current of the corresponding downhole device.
8. The well of claim 1, further comprising optical fiber voltage
sensor coupled to at least one of the optically-controlled switch
that measures a voltage of the corresponding downhole device.
9. The well of claim 1, wherein the power cable is a
multi-conductor cable.
10. The well of claim 1, wherein the tubular string is electrically
insulated.
11. The well of claim 1, wherein the tubular string is a casing
string cemented within the borehole.
12. The well of claim 1, further comprising a processing unit which
determines a formation characteristic.
13. A permanent electromagnetic (EM) monitoring method, comprising:
positioning a tubular string having a power cable and one or more
downhole devices attached thereto in a borehole; controlling the
flow of power to each of the downhole devices via one or more
optically-controlled switches arranged downhole, wherein each
switch is coupled between one of the one or more downhole devices
and the power cable; and controlling the one or more
optically-controlled switches with a switch controller, the switch
controller being coupled to the one or more optically-controlled
switches via an optical fiber, and wherein each of the one or more
optically-controlled switches are independently controllable.
14. The method of claim 13, further comprising cementing the
tubular string and downhole devices in the borehole.
15. The method of claim 13, further comprising monitoring
characteristics of the downhole devices.
16. The method of claim 15, wherein the characteristic includes one
of the group of an electrical current, an electrical voltage, a
temperature, or a vibration.
17. The method of claim 16, wherein the monitoring the electrical
current is performed by an optical fiber current sensor coupled to
one of the optically-controlled switches.
18. The method of claim 16, wherein the monitoring the electrical
voltage is performed by an optical fiber voltage sensor coupled to
one of the optically-controlled switches.
19. The method of claim 13, further comprising controlling one of a
voltage, current, or waveform of the downhole devices with the
corresponding optically-controlled switch.
20. The method of claim 13, wherein one of the downhole devices
includes a multi-turn loop antenna, the method further comprising
measuring an electromagnetic signal with the multi-turn loop
antenna.
21. The method of claim 13, wherein one of the downhole devices
includes an electric motor, the method further comprising
controlling the electric motor.
22. The method of claim 13, further comprising determining a
formation characteristic with a processing unit.
Description
BACKGROUND
[0001] Oilfield operators are faced with the challenge of
maximizing hydrocarbon recovery within a given budget and
timeframe. While they perform as much logging and surveying as
feasible before and during the drilling and completion of
production wells and, in some cases, injection wells, the
information gathering process does not end there. It is desirable
for the operators to track the movement of fluids in and around the
reservoirs, as this information enables them to adjust the
distribution and rates of production among the producing and/or
injection wells to avoid premature water breakthroughs and other
obstacles to efficient and profitable operation. Moreover, such
information gathering further enables the operators to better
evaluate treatment and secondary recovery strategies for enhanced
hydrocarbon recoveries.
[0002] To obtain such information, a permanent electromagnetic (EM)
monitoring system may be attached to the casing string as it is run
into the borehole. Example monitoring devices may include
electrodes and electromagnetic antennas. Power to the monitoring
devices may be independently controlled to enable maximum power
delivery and easier monitoring of individual device power
consumption or, for example, to determine independent device
current leakage. If not properly determined, such leakage may be
incorrectly interpreted as formation resistivity, thus resulting in
inaccurate measurement determinations.
[0003] The independent power control may be accomplished by having
a single power source and a switching unit at the Earth's surface
and running independent power lines downhole to each of the
monitoring devices. However, this consumes a great amount of
limited space within the borehole, thus limiting the number of
independent lines that may be run. This method also inherently
increases cost due to the additional wire required to run each
power source. Moreover, the increased hardware represents
additional points of failure within the system, may introduce
additional unwanted currents and/or voltage noise, and adds
additional hardware that must be accounted for so as not to be
damaged when performing further downhole operations (e.g.,
perforating, hydraulic fracturing, or stimulation activities).
BRIEF DESCRIPTION OF THE DRAWINGS
[0004] Accordingly, there are disclosed herein systems and methods
for controlling power to downhole devices via optical switching. In
the drawings:
[0005] FIG. 1 shows an illustrative permanent EM monitoring system
for a reservoir.
[0006] FIG. 2 is an enlarged schematic view of an illustrative
optically controlled well monitoring system.
[0007] FIG. 3 is a flow diagram of an illustrative method for
controlling a permanent EM monitoring system.
[0008] It should be understood, however, that the specific
embodiments given in the drawings and detailed description thereto
do not limit the disclosure. On the contrary, they provide the
foundation for one of ordinary skill to discern the alternative
forms, equivalents, and modifications that are encompassed together
with one or more of the given embodiments in the scope of the
appended claims.
DETAILED DESCRIPTION
[0009] Certain disclosed system and method embodiments provide an
optically controlled switching system for downhole devices. The
system may include a tubular string having a power cable and one or
more downhole devices attached thereto and arranged within a
borehole. One or more optically-controlled switches are arranged
downhole, each of which is coupled between one of the downhole
devices and the power cable to enable or disable a flow of power to
the downhole device. Additionally, a switch controller is optically
coupled to the switches via an optical fiber and independently
controls each of the switches.
[0010] In some embodiments, exemplary downhole devices may include
capacitive electrodes, galvanic electrodes, multi-loop antennas,
and electric motors (e.g., gauges, valves, and the like). The
system may further include additional sensors, such as current and
voltage sensors coupled to the switches and capable of measuring a
current or voltage of the corresponding downhole device. In further
embodiments, the tubular string may be a casing string, wherein the
tubular string, power cable, and downhole devices are cemented
within the borehole.
[0011] To provide some context for the disclosure, FIG. 1 shows an
illustrative permanent EM monitoring system 100 (hereinafter
"system 100"). As depicted, the system 100 includes a well 102
having a casing string 106 set within a borehole 104 of a formation
101 and secured in place by a cement sheath 108. In alternative
embodiments, the casing string 106 may be a general tubular string.
Moreover, the tubular string may be electrically insulated.
[0012] Inside the casing string 106, a production tubing string 110
defines an annular flow path (between the walls of the casing
string and the production tubing string) and an inner flow path
(along the bore of the production tubing string). Wellhead valves
112 and 114 provide fluid communication with the bottom-hole region
via the annular and inner flow paths, respectively. Well 102 may
function as a production well, an injection well, or simply as a
formation monitoring well.
[0013] The well 102 includes downhole devices 116a-c (illustrated
as a first, second, and third downhole device 116a, 116b, and 116c,
respectively) attached to the casing string 106 and cemented within
the borehole 104. Example downhole devices may include, but are not
limited to, capacitive electrodes, galvanic electrodes, multi-loop
antennas, and electric motors (e.g., gauges, valves, and the like).
The downhole devices 116a-c receive power from a power source 118
via a power cable 120 strapped to the outside of the casing string
106. The power cable 120 may include a mono-conductor or
multi-conductor core.
[0014] Interposed between the power cable 120 and each downhole
device 116a-c is an optically-controlled switch 122a-c (depicted as
a first, second, and third switch, 122a, 122b, and 122c,
accordingly) which enables or disables the flow of power to the
corresponding downhole device 116a-c.
[0015] The switches 122a-c are independently controllable via an
optical fiber 124 coupled to a switch controller 126.
Advantageously, only a single power cable 120 and a single optical
fiber 124 are required, thus substantially saving space within the
borehole and reducing or eliminating the problems of the prior art
which may use individual power cables for each downhole device
116a-c.
[0016] The switch controller 126 is coupled to and controlled by a
processing unit 128 which may be, for example, a computer in
tablet, notebook, laptop, or portable form, a desktop computer, a
server or virtual computer on a network, a mobile phone, or some
combination of like elements that couple software-configured
processing capacity to a user interface 130. The processing unit
128 may perform processing including compiling a time series of
measurements to enable monitoring of the time evolution, and may
further include the use of a geometrical model of the reservoir
that takes into account the relative positions and configurations
of the downhole devices 116a-c to obtain one or more parameters or
formation characteristics. For example, if one of the downhole
devices 116a-c is a dielectric measurement tool, those parameters
may include a resistivity distribution and an estimated water
saturation.
[0017] The processing unit 128 may further enable the user to
adjust the configuration of the system, for example, modifying such
parameters as acquisition or generation rate of the downhole
devices 116a-c, firing sequence, transmit amplitudes, transmit
waveforms, transmit frequencies, receive filters, and demodulation
techniques. In some contemplated system embodiments, the processing
unit 128 further enables the user to adjust injection and/or
production rates to optimize production from the reservoir.
[0018] FIG. 2 illustrates an enlarged schematic view of an
optically controlled well monitoring system 200 (hereinafter
"system 200"). The system 200 may be similar to the system 100 of
FIG. 1 and therefore may be best understood with reference thereto,
where like numerals represent like elements that will not be
described again in detail. In particular, as depicted, the system
200 includes three downhole devices 116a-c attached to the casing
string 106. The downhole devices 116a-c receive power from the
power source 118 via the power cables 120a-b (wherein power cable
120a is a source cable and power cable 120b is a return cable). The
three switches 122a-c are interposed between each of the downhole
devices 116a-c and the power cables 120a-b, thereby enabling or
disabling a flow of power to the associated downhole device
116a-c.
[0019] The switches 122a-c are controlled by the switch controller
126 and coupled thereto via the optical fiber 124. One exemplary
protocol that may be implemented over the optical fiber 124
enabling the switch controller 126 to independently control each
switch 122a-c is radio-over-fiber. When implementing such a
protocol, the system 200 may further include an optical modulator
202 for modulating the signal sent via the optical cable to the
switches 122a-c. The modulated signal may be received by a
demodulator 204a-c coupled to or integrated with the switches
122a-c for demodulating the optical signal and operating only the
desired switch 122a-c, thus enabling independent control of each
switch 122a-c.
[0020] As depicted, the downhole devices 116a-c are electrodes
which inject and receive current flowing through the formation 101.
The first switch 122a has both contacts open, therefore the first
electrode 116 neither injects nor receives current. The second
switch 122b has the contact associated with the source power cable
120a closed, thereby enabling injection of current from the second
electrode 116b. The third switch 122c has one contact associated
with the return power cable 120b closed, thereby enabling a return
path for the current.
[0021] Advantageously, only a single power cable 120 is required
(even though a source and return power cable 120a and 120b are
depicted). This is a significant reduction in cables, and thus
space, required downhole. Moreover, the system requires less power
than prior systems due to the switches being optically operated
rather than electrically operated.
[0022] In some embodiments, the optical fiber 124 may further serve
to transmit data from one or more sensors 206 (one shown) coupled
to or integrated with the switches 122a-c to help monitor the
system 200. As depicted, the sensor 206 is coupled to the second
switch 122b for measurements of the corresponding downhole device
116a-c. For example, such sensors 206 may include a current or
voltage sensor that measures the current or voltage of the downhole
device 116b. Alternatively, the sensor 206 may take temperature or
vibration measurements in proximity to the downhole device 116a-c.
Advantageously, such a configuration may enable more precise
measurements due to measuring individual downhole devices 116a-c,
as compared to taking a single measurement near the power source
118 and only obtaining overall system information.
[0023] FIG. 3 is a flow diagram of an illustrative permanent EM
monitoring method 300. The method begins at block 302 with a crew
coupling one or more EM monitoring downhole devices and a power
cable to a tubular string. The power cable is coupled to a power
source at or near the Earth's surface. Downhole devices may be, for
example, electrodes or a multi-turn loop antenna. The crew further
couples an optically-controlled switch between each of the downhole
devices and the power cable. Of course, those skilled in the art
will appreciate that the optically-controlled switch may
alternatively be embedded with or part of the downhole device
circuitry and need not be a physically separate attachment or
hardware. The tubular string and equipment attached thereto may
then be run into a borehole and cemented therein for permanent
monitoring.
[0024] At block 304, a well operator may control the flow of power
to each of the downhole devices via the switches coupled between
the downhole devices and the power cable. Moreover, as at block
306, the operator may individually control each of the switches
with a switch controller coupled thereto via an optical cable.
Advantageously, only a single power cable and a single optical
fiber are required, thus substantially saving space within the
borehole and reducing or eliminating the problems of the prior art
which may use individual power cables for each downhole device
116a-c.
[0025] The method 300 may further monitor characteristics of the
downhole devices. For example, the method 300 may employ a current
sensor coupled to the device to monitor the current generated or
received by the device. Alternatively, voltage of the downhole
device may be measured using voltage sensors. Advantageously,
taking such measurements at each device individually may provide
the operator with more accurate and detailed data as compared to
merely monitoring the overall system near the power source.
Additional measurements that may be taken are, for example and
without limitation, downhole temperature and vibrations. Such
measurements may be conveyed to the surface via the optical fiber.
The method 300 may utilize such measurements to determine a
formation characteristic with a processor, such as formation
resistivity.
[0026] Numerous other modifications, equivalents, and alternatives,
will become apparent to those skilled in the art once the above
disclosure is fully appreciated. For example, similar application
can be applied to wireline resistivity logging,
logging-while-drilling (LWD), electromagnetic ranging, and
telemetry applications without departing from the scope of the
present disclosure. It is intended that the following claims be
interpreted to embrace all such modifications, equivalents, and
alternatives where applicable.
[0027] Embodiments disclosed herein include:
[0028] A: A well having optically controlled switching, the well
including a power cable run along a tubular string in a borehole,
one or more downhole devices attached to the tubular string, one or
more optically-controlled switches arranged downhole, where each
switch is coupled between the power cable and one of the one or
more downhole devices to enable or disable a flow of power to the
downhole device, and a switch controller coupled to the one or more
optically-controlled switches via an optical fiber, where each of
the one or more optically-controlled switches are independently
controllable.
[0029] B: A permanent electromagnetic (EM) monitoring method that
includes positioning a tubular string having a power cable and one
or more downhole devices attached thereto in a borehole,
controlling the flow of power to each of the downhole devices via
one or more optically-controlled switches arranged downhole,
wherein each switch is coupled between one of the one or more
downhole devices and the power cable, and controlling the one or
more optically-controlled switches with a switch controller, the
switch controller being coupled to the one or more
optically-controlled switches via an optical fiber, and wherein
each of the one or more optically-controlled switches are
independently controllable
[0030] Each of embodiments A and B may have one or more of the
following additional elements in any combination:
[0031] Element 1: At least one of the downhole devices includes a
capacitive electrode. Element 2: At least one of the downhole
devices includes a galvanic electrode. Element 3: At least one of
the downhole devices includes a multi-turn loop antenna. Element 4:
At least one of the downhole devices is an electric motor. Element
5: The switch controller is arranged at the surface. Element 6: An
optical fiber current sensor coupled to at least one of the
optically-controlled switches that measures a current of the
corresponding downhole device. Element 7: An optical fiber voltage
sensor coupled to at least one of the optically-controlled switch
that measures a voltage of the corresponding downhole device.
Element 8: Where the power cable is a multi-conductor cable.
Element 9: Wherein the tubular string is electrically insulated.
Element 10: Where the tubular string is a casing string cemented
within the borehole. Element 11: A processing unit which determines
a formation characteristic.
[0032] Element 12: Cementing the tubular string and downhole
devices in the borehole. Element 13: Monitoring characteristics of
the downhole devices. Element 14: Where the characteristic includes
one of the group of an electrical current, an electrical voltage, a
temperature, or a vibration. Element 15: Where the monitoring the
electrical current is performed by an optical fiber current sensor
coupled to one of the optically-controlled switches. Element 16:
Where the monitoring the electrical voltage is performed by an
optical fiber voltage sensor coupled to one of the
optically-controlled switches. Element 17: Controlling one of a
voltage, current, or waveform of the downhole devices with the
corresponding optically-controlled switch. Element 18: Where one of
the downhole devices is a multi-turn loop antenna, the method
further comprising measuring an electromagnetic signal with the
multi-turn loop antenna. Element 19: Where one of the downhole
devices includes an electric motor, the method further comprising
controlling the electric motor. Element 20: Further comprising
determining a formation characteristic with a processing unit.
* * * * *