WO2015178906A1 - Optically-controlled switching of power to downhole devices - Google Patents
Optically-controlled switching of power to downhole devices Download PDFInfo
- Publication number
- WO2015178906A1 WO2015178906A1 PCT/US2014/039013 US2014039013W WO2015178906A1 WO 2015178906 A1 WO2015178906 A1 WO 2015178906A1 US 2014039013 W US2014039013 W US 2014039013W WO 2015178906 A1 WO2015178906 A1 WO 2015178906A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- optically
- downhole
- well
- downhole devices
- controlled switches
- Prior art date
Links
- 239000013307 optical fiber Substances 0.000 claims abstract description 21
- 238000000034 method Methods 0.000 claims description 26
- 238000012544 monitoring process Methods 0.000 claims description 21
- 230000015572 biosynthetic process Effects 0.000 claims description 11
- 238000012545 processing Methods 0.000 claims description 10
- 239000004020 conductor Substances 0.000 claims description 4
- 238000005259 measurement Methods 0.000 description 11
- 238000004519 manufacturing process Methods 0.000 description 8
- 238000002347 injection Methods 0.000 description 5
- 239000007924 injection Substances 0.000 description 5
- 230000003287 optical effect Effects 0.000 description 5
- 238000012986 modification Methods 0.000 description 3
- 230000004048 modification Effects 0.000 description 3
- 238000012806 monitoring device Methods 0.000 description 3
- 238000011084 recovery Methods 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 238000005553 drilling Methods 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 239000004568 cement Substances 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 230000008878 coupling Effects 0.000 description 1
- 238000010168 coupling process Methods 0.000 description 1
- 238000005859 coupling reaction Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000000835 fiber Substances 0.000 description 1
- 238000010304 firing Methods 0.000 description 1
- 230000002028 premature Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
- E21B47/125—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using earth as an electrical conductor
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices, or the like
- E21B33/14—Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
- E21B47/13—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency
- E21B47/135—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency using light waves, e.g. infrared or ultraviolet waves
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
- G01V3/18—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
- G01V3/18—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging
- G01V3/30—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging operating with electromagnetic waves
Definitions
- 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.
- 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.
- 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.
- This method also inherently increases cost due to the additional wire required to run each power source.
- 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).
- FIG. 1 shows an illustrative permanent EM monitoring system for a reservoir.
- FIG. 2 is an enlarged schematic view of an illustrative optically controlled well monitoring system.
- FIG. 3 is a flow diagram of an illustrative method for controlling a permanent EM monitoring system.
- 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.
- a switch controller is optically coupled to the switches via an optical fiber and independently controls each of the switches.
- 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.
- the tubular string may be a casing string, wherein the tubular string, power cable, and downhole devices are cemented within the borehole.
- FIG. 1 shows an illustrative permanent EM monitoring system 100 (hereinafter "system 100").
- 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.
- the casing string 106 may be a general tubular string.
- the tubular string may be electrically insulated.
- a production tubing string 1 10 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 1 12 and 1 14 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.
- the well 102 includes downhole devices 1 16a-c (illustrated as a first, second, and third downhole device 1 16a, 1 16b, and 1 16c, 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 1 16a-c receive power from a power source 1 18 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.
- 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 1 16a-c.
- the switches 122a-c are independently controllable via an optical fiber 124 coupled to a switch controller 126.
- 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 1 16a-c.
- 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 1 16a-c to obtain one or more parameters or formation characteristics. For example, if one of the downhole devices 1 16a-c is a dielectric measurement tool, those parameters may include a resistivity distribution and an estimated water saturation.
- 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 1 16a-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.
- FIG. 2 illustrates an enlarged schematic view of an optically controlled well monitoring system 200 (hereinafter "system 200").
- 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.
- the system 200 includes three downhole devices 1 16a-c attached to the casing string 106.
- the downhole devices 1 16a-c receive power from the power source 1 18 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 1 16a-c and the power cables 120a-b, thereby enabling or disabling a flow of power to the associated downhole device 1 16a-c.
- 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.
- 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.
- the downhole devices 1 16a-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 1 16 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 1 16b.
- the third switch 122c has one contact associated with the return power cable 120b closed, thereby enabling a return path for the current.
- 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.
- the sensor 206 is coupled to the second switch 122b for measurements of the corresponding downhole device 1 16a-c.
- sensors 206 may include a current or voltage sensor that measures the current or voltage of the downhole device 1 16b.
- the sensor 206 may take temperature or vibration measurements in proximity to the downhole device 1 16a-c.
- such a configuration may enable more precise measurements due to measuring individual downhole devices 1 16a-c, as compared to taking a single measurement near the power source 1 18 and only obtaining overall system information.
- 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.
- 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.
- 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.
- the operator may individually control each of the switches with a switch controller coupled thereto via an optical cable.
- the method 300 may further monitor characteristics of the downhole devices.
- the method 300 may employ a current sensor coupled to the device to monitor the current generated or received by the device.
- voltage of the downhole device may be measured using voltage sensors.
- 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.
- Embodiments disclosed herein include:
- a well having optically controlled switching 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.
- 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
- 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 1 1 A processing unit which determines a formation characteristic.
- 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.
Abstract
Description
Claims
Priority Applications (8)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
BR112016024531A BR112016024531A2 (en) | 2014-05-21 | 2014-05-21 | ? well having optically controlled switching, and method for permanent electromagnetic monitoring? |
MYPI2016703834A MY180277A (en) | 2014-05-21 | 2014-05-21 | Optically-controlled switching of power to downhole devices |
US15/025,637 US20160215613A1 (en) | 2014-05-21 | 2014-05-21 | Optically-controlled switching of power to downhole devices |
CA2946379A CA2946379A1 (en) | 2014-05-21 | 2014-05-21 | Optically-controlled switching of power to downhole devices |
AU2014395165A AU2014395165B2 (en) | 2014-05-21 | 2014-05-21 | Optically-controlled switching of power to downhole devices |
PCT/US2014/039013 WO2015178906A1 (en) | 2014-05-21 | 2014-05-21 | Optically-controlled switching of power to downhole devices |
GB1617641.4A GB2540078A (en) | 2014-05-21 | 2014-05-21 | Optically-controlled switching of power to downhole devices |
NO20161663A NO20161663A1 (en) | 2014-05-21 | 2016-10-19 | Optically-controlled switching of power to downhole devices |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US2014/039013 WO2015178906A1 (en) | 2014-05-21 | 2014-05-21 | Optically-controlled switching of power to downhole devices |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2015178906A1 true WO2015178906A1 (en) | 2015-11-26 |
Family
ID=54554433
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2014/039013 WO2015178906A1 (en) | 2014-05-21 | 2014-05-21 | Optically-controlled switching of power to downhole devices |
Country Status (7)
Country | Link |
---|---|
US (1) | US20160215613A1 (en) |
AU (1) | AU2014395165B2 (en) |
BR (1) | BR112016024531A2 (en) |
CA (1) | CA2946379A1 (en) |
GB (1) | GB2540078A (en) |
NO (1) | NO20161663A1 (en) |
WO (1) | WO2015178906A1 (en) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10260335B2 (en) | 2014-10-30 | 2019-04-16 | Halliburton Energy Services, Inc. | Opto-electrical networks for controlling downhole electronic devices |
US11487041B2 (en) * | 2015-02-13 | 2022-11-01 | Halliburton Energy Services, Inc. | Downhole fluid characterization methods and systems employing a casing with a multi-electrode configuration |
Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20040108114A1 (en) * | 2002-11-22 | 2004-06-10 | Lerche Nolan C. | Providing electrical isolation for a downhole device |
US20100288501A1 (en) * | 2009-05-18 | 2010-11-18 | Fielder Lance I | Electric submersible pumping system for dewatering gas wells |
US20110035153A1 (en) * | 2007-11-29 | 2011-02-10 | Baker Hughes Incorporated | Wellbore logging performance verification method and apparatus |
US20130043048A1 (en) * | 2011-08-17 | 2013-02-21 | Joseph C. Joseph | Systems and Methods for Selective Electrical Isolation of Downhole Tools |
WO2014044334A2 (en) * | 2012-09-18 | 2014-03-27 | Statoil Petroleum As | Improved pump for lifting fluid from a wellbore |
-
2014
- 2014-05-21 US US15/025,637 patent/US20160215613A1/en not_active Abandoned
- 2014-05-21 GB GB1617641.4A patent/GB2540078A/en not_active Withdrawn
- 2014-05-21 WO PCT/US2014/039013 patent/WO2015178906A1/en active Application Filing
- 2014-05-21 BR BR112016024531A patent/BR112016024531A2/en not_active IP Right Cessation
- 2014-05-21 AU AU2014395165A patent/AU2014395165B2/en not_active Ceased
- 2014-05-21 CA CA2946379A patent/CA2946379A1/en not_active Abandoned
-
2016
- 2016-10-19 NO NO20161663A patent/NO20161663A1/en not_active Application Discontinuation
Patent Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20040108114A1 (en) * | 2002-11-22 | 2004-06-10 | Lerche Nolan C. | Providing electrical isolation for a downhole device |
US20110035153A1 (en) * | 2007-11-29 | 2011-02-10 | Baker Hughes Incorporated | Wellbore logging performance verification method and apparatus |
US20100288501A1 (en) * | 2009-05-18 | 2010-11-18 | Fielder Lance I | Electric submersible pumping system for dewatering gas wells |
US20130043048A1 (en) * | 2011-08-17 | 2013-02-21 | Joseph C. Joseph | Systems and Methods for Selective Electrical Isolation of Downhole Tools |
WO2014044334A2 (en) * | 2012-09-18 | 2014-03-27 | Statoil Petroleum As | Improved pump for lifting fluid from a wellbore |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10260335B2 (en) | 2014-10-30 | 2019-04-16 | Halliburton Energy Services, Inc. | Opto-electrical networks for controlling downhole electronic devices |
US11487041B2 (en) * | 2015-02-13 | 2022-11-01 | Halliburton Energy Services, Inc. | Downhole fluid characterization methods and systems employing a casing with a multi-electrode configuration |
Also Published As
Publication number | Publication date |
---|---|
AU2014395165B2 (en) | 2017-05-11 |
GB2540078A (en) | 2017-01-04 |
AU2014395165A1 (en) | 2016-11-03 |
US20160215613A1 (en) | 2016-07-28 |
NO20161663A1 (en) | 2016-10-19 |
CA2946379A1 (en) | 2015-11-26 |
GB201617641D0 (en) | 2016-11-30 |
BR112016024531A2 (en) | 2017-08-15 |
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