US20120211278A1 - System and method for remote sensing - Google Patents

System and method for remote sensing Download PDF

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Publication number
US20120211278A1
US20120211278A1 US13/295,784 US201113295784A US2012211278A1 US 20120211278 A1 US20120211278 A1 US 20120211278A1 US 201113295784 A US201113295784 A US 201113295784A US 2012211278 A1 US2012211278 A1 US 2012211278A1
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United States
Prior art keywords
power
signal
conductive line
sensor
sensor signal
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Abandoned
Application number
US13/295,784
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English (en)
Inventor
Manuel E. Gonzalez
M. Clark Thompson
Robert L. Williford
David W. Beck
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Chevron USA Inc
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Chevron USA Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Chevron USA Inc filed Critical Chevron USA Inc
Priority to US13/295,784 priority Critical patent/US20120211278A1/en
Assigned to CHEVRON U.S.A. INC. reassignment CHEVRON U.S.A. INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: GONZALEZ, MANUEL E., BECK, DAVID W., THOMPSON, M. CLARK, WILLIFORD, ROBERT E.
Publication of US20120211278A1 publication Critical patent/US20120211278A1/en
Priority to US14/543,185 priority patent/US9103198B2/en
Abandoned legal-status Critical Current

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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/06—Measuring temperature or pressure
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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 OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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

Definitions

  • the present invention relates generally to remote sensing and more particularly to sensing pressures and temperatures in a down hole environment.
  • An aspect of an embodiment of the present invention includes an apparatus for monitoring conditions in a borehole.
  • the well tubing and casing act as a conductive pair for delivering power to one or more downhole active sensors.
  • power and signal are isolated so that the same conductive pair may act to transmit the sensor signals to the surface.
  • An aspect of an embodiment of the present invention includes a system for measuring a condition in a downhole environment in a borehole beneath a surface, including a source, configured and arranged to transmit a power signal via a drillstring in the borehole a sensor module, in electrical communication with the source via the drillstring, the sensor module comprising an oscillator having a resonant frequency that varies with changes in the condition in the downhole environment, the sensor module being configured and arranged to receive power from the source and to produce a sensor signal in response to the condition in the downhole environment and to transmit the signal, via the drillstring, toward the surface, and a detector, in electrical communication with the sensor module via the drillstring and configured and arranged to receive the sensor signal.
  • An aspect of an embodiment of the present invention includes a system for monitoring conditions in a borehole.
  • the well tubing and casing act as a conductive pair for delivering power to one or more downhole active sensors.
  • power and sensor signals are isolated so that the same conductive pair may act to transmit the sensor signals to the surface.
  • Another aspect of an embodiment of the present invention includes a method of monitoring conditions in a borehole.
  • a power signal is transmitted via the drillstring to one or more downhole active sensors.
  • the sensor signal is transmitted via the drillstring to the surface. At each of the surface and the sensor, power and sensor signals are isolated.
  • aspects of embodiments of the present invention include tangible computer readable media encoded with computer executable instructions for performing any of the foregoing methods and/or for controlling any of the foregoing apparatuses or systems.
  • FIG. 1 is a schematic illustration of a system for interrogating a downhole environment in a borehole beneath a surface in accordance with an embodiment of the present invention
  • FIG. 2 is an electrical schematic diagram illustrating a circuit configured to provide DC power to a sensor in a down hole location and to accept input from the sensor for transmission to the surface;
  • FIG. 3 is a schematic diagram illustrating an alternating current embodiment of a transmission system for power and signal for a remote sensor
  • FIG. 4 is a schematic diagram illustrating a direct current embodiment of a transmission system for power and signal for a remote sensor
  • FIG. 5 is a block diagram of a transformer coupling system in accordance with an embodiment of the present invention.
  • FIG. 6 is a block diagram of a sensor module assembly in accordance with an embodiment of the present invention.
  • FIG. 7 is a block diagram of a sensor module interface in accordance with an embodiment of the present invention.
  • FIG. 8 is a block diagram of an insulated system in accordance with an embodiment of the present invention.
  • FIG. 1 illustrates an example of an apparatus 100 for monitoring a condition in a subsurface borehole.
  • the apparatus 100 includes an electromagnetically transmissive medium, such as a conductive line 102 , for conducting electromagnetic energy through the borehole.
  • a conductive line 102 may take different forms or embodiments, depending on the state of the borehole.
  • the conductive line 102 may comprise a production tubing string in a completed borehole or a drillstring in a borehole under construction.
  • a transformer 104 is provided to couple the conductive pipe to a source of electromagnetic energy. Alternate coupling methods to the transformer 104 may be employed.
  • the transmission line may directly couple to a coaxial cable or any other suitable cable.
  • the transformer 104 includes a stack of ferrite rings 106 , and a wire 108 wound around the rings.
  • the wire 108 includes leads 110 that may be coupled to a signal generator 112 which may be configured to produce a pulsed or a continuous wave signal, as necessary or desirable.
  • the wire 108 may further be coupled to a receiver 114 .
  • the receiver 114 may be embodied as a computer that includes a bus for receiving signals from the apparatus 100 for storage, processing and/or display.
  • the computer 114 may be provided with a display 118 which may include, for example, a graphical user interface.
  • the computer 114 may be programmed to process the received sensor signals to provide a measure of the sensed characteristic.
  • the computer 114 may perform any desired processing of the detected signal including, but not limited to, a statistical (e.g., Fourier) analysis of the signal, a deconvolution of the signal, a correlation with another signal or the like.
  • a statistical (e.g., Fourier) analysis of the signal e.g., a deconvolution of the signal, a correlation with another signal or the like.
  • Commercial products are readily available and known to those skilled in the art that can be used to perform any suitable frequency detection.
  • the computer may be provided with a look-up table in memory or in accessible storage, that correlates received modulated signals to sensed conditions in the borehole.
  • the borehole will be lined with a borehole casing 120 which is used to provide structural support to the borehole.
  • This casing 120 is frequently made from a conductive material such as steel, in which case it will cooperate with the line 102 in order to form a coaxial transmission line, and it is not necessary to provide any additional conductive medium.
  • a conductive sleeve (not shown) may be provided within the casing in order to form the coaxial structure.
  • the apparatus 100 may include dielectric rings 122 disposed periodically along the conductive line 102 .
  • the spacers can, for example, be configured as insulated centralizers which can be disks formed from any suitable material including, but not limited to, nylon or polytetrafluoroethylene (PTFE).
  • PTFE polytetrafluoroethylene
  • the illustrated embodiment makes use of a coaxial transmission line, it is contemplated that alternate embodiments of a transmission line may be employed, such as a single conductive line, paired conductive lines, or a waveguide.
  • the casing alone may act as a waveguide for certain frequencies of electromagnetic waves.
  • lengths of coaxial cable may be used in all or part of the line. Such coaxial cable may be particularly useful when dielectric fluid cannot be used within the casing 120 (e.g., when saline water or other conductive fluid is present in the casing 120 ).
  • a probe portion 124 is located near the distal end of the apparatus 100 .
  • the probe portion may be located at any point along the length of the transmission line. Indeed, multiple such probe portions may be placed at intervals along the length.
  • wavelength multiplexing on the coaxial line could be used to allow for multiple probes to use a single communication line without interfering with each other.
  • the probe portion may include a port 126 that is configured to communicate ambient pressures and/or temperatures from fluid present in the borehole into the probe where it may be sensed by the sensor (not shown in FIG. 1 ). Below the probe is illustrated a packer 128 and packer teeth 130 .
  • FIG. 2 is an electrical schematic illustrating a down hole portion of an embodiment of the system in accordance with the invention.
  • An RC terminator 200 is intended to reduce or eliminate reflections at the line end. From the line end, the path of the power signal depends on whether it is a DC or an AC signal. Applied DC will take the upper path 202 through the high inductance inductor 204 (which may be, for example, about 1 mH) and pass through diode 206 , arriving at the DC power out 208 at the right of the Figure. On the other hand, applied AC will pass through the relatively lower inductance inductor 212 (which may be, for example, about 17 ⁇ H).
  • a passive power switching method and apparatus allows selective application of power to down hole circuits and loads.
  • an isolator may be nothing more than a dielectric break in an otherwise solid piece of tubing.
  • such an isolator needs to fit within well casings with sufficient clearance, exhibit low end-to-end capacitance, be able to standoff many hundreds of volts of applied potential, and perhaps most importantly, be received by wellsite managers with confidence that it will not fail.
  • Built-in failsafe design features may also be useful, or required for acceptance by users.
  • a technique for DC isolation includes a ceramic or other non-conductive insulator inserted in series with well tubing. This may be, for example, built-in to a 4 foot section of tubing, commonly referred to as a “sub”.
  • the ceramic and tubing parts may be clamped together and should be connected without electrically shorting the tubing parts together.
  • An insulating coating may be applied to the internal and external surfaces of the assembly as electrical breakdown protection across the gap.
  • the RF (sensor signal) and DC (power) connection is made to the tubing thru a common connection, with signal separation handled electronically outside the well.
  • FIG. 3 An example of a set-up in accordance with an embodiment of the invention is schematically illustrated in FIG. 3 .
  • the power signal generated at the surface is an AC signal delivered to input 300 .
  • the AC signal is coupled into the conductor pair via power cores 302 which may be of the ferrite transformer type described above in relation to FIG. 1 .
  • FIG. 4 illustrates an alternate approach in which the power signal is a DC signal.
  • a primary difference is the use of a transformer which may be, for example, a toroidal transformer made with tape wound cores on the wellstring tubing just below the wellhead and above a set of RF ferrite cores 304 .
  • a transformer which may be, for example, a toroidal transformer made with tape wound cores on the wellstring tubing just below the wellhead and above a set of RF ferrite cores 304 .
  • a small number of turns make up the primary of the transformer, with the well tubing making up the secondary winding of the transformer.
  • it may be a single turn secondary winding.
  • the sensor module 310 and bowspring centralizer 312 used in the DC isolator approach remains unchanged in such an AC application.
  • the power signals generated by power supply 318 are provided to the sensor module 310 from the lower transformer 304 .
  • the sensor module 310 generates communication signals that are transmitted to the lower transformer 304 .
  • the communication signals are conducted up the tubing string to the upper transformer 302 and then transmitted to the receiver 320 of the surface system 500 (as illustrated in FIG. 5 ).
  • the electrical path is completed by grounding the tubing string on unused sides of the upper and lower transformers and by grounding the surface system and sensor module 310 .
  • the casing is generally grounded.
  • the tubing string above the upper transformer may be grounded by coupling the tubing string to the casing through the wellhead.
  • the tubing string below the lower transformer 304 may be grounded by connecting the tubing string to the casing via the bowspring centralizer 312 , for example.
  • the transformers are formed by formed by using the tubing string as one of the windings of each transformer.
  • the power signal from the surface system is transmitted to the primary winding of a toroidal transformer positioned around the tubing string.
  • the tubing string itself is the single turn secondary winding of the transformer for the power circuit.
  • the lower transformer is another toroidal transformer surrounding the tubing string and includes, for the power circuit, a primary winding that is the tubing string itself and a secondary winding that is connected to the sensor module 310 .
  • signals are transmitted using the same transformers, though (as compared to the power circuit) the roles of the primary and secondary windings in each transformer are reversed.
  • the technique for AC isolation includes an isolator built-up on a short section of steel tubing, incorporating AC and RF magnetics. Separate AC and RF electrical connections ( 300 , 314 respectively) may be made through a wellhead hanger 316 .
  • a suitable impedance for the RF signal may be established by selection of the RF magnetic material.
  • a suitable impedance for the AC source may be established by selection of the AC transformer characteristics.
  • the RF impedance, established by the RF magnetics is also affected by the presence of the AC magnetics, which represent a very high impedance to the RF. As such, it may be necessary to provide an electrical path around the AC magnetics to the wellhead for the RF currents travelling up the wellstring from the sensor package 310 . In that case, two different electrical connections to the wellhead would be required.
  • the power frequencies may be between 5 kHz and 200 kHz, for example.
  • the RF frequencies for data may be between 3 MHz and 8 MHz.
  • power is supplied in a range between 1 and 10 kHz and data is transmitted using a frequency-shift keying modulation scheme at frequencies in the range between 15 and 30 kHz.
  • Power frequencies above the RF range are, in theory, usable.
  • Sensor data frequencies may also be selected outside the foregoing ranges. Because the transmission frequencies of the power and sensor signals are different, it is possible to separate them using filtering at either the surface system 500 and/or at the sensor module 310 .
  • FIG. 6 is a block diagram of a sensor module 600 assembly in accordance with an embodiment of the present invention. As will be appreciated the sensor module 600 is similar to the arrangement illustrated in FIG. 2 and represents an alternate approach to illustrating similar concepts.
  • the sensor module 600 connects to the lower transformer by way of a bus 602 that carries both the power signal and the sensor data signal.
  • a low pass filter 604 passes the low frequency power signal to the sensor module power circuitry which is made up of a transformer 606 , a rectifier 608 , and a voltage regulator 610 .
  • Power is supplied to a microprocessor 612 and to one or more digital gauges 614 , each of which may be, for example, a Quartzdyne® gauge, available from Quartzdyne, Inc. of Salt Lake City, Utah.
  • Such gauges constitute a quartz resonator and are often packaged along with an accompanying oscillator circuit and processor (e.g., frequency counter), and may include reference and temperature crystals along with their respective oscillator circuitry.
  • a portion of the surface system 500 that acts as a gauge interface module is shown in block diagram form in greater detail in FIG. 7 .
  • a bus 702 communicates with the upper transformer 302 .
  • a serial input 704 obtains power from a power supply, not shown.
  • An MPU 706 manages the input power and outputs the power by way of a low pass filter 708 , digital attenuator 710 , and power amplifier 712 .
  • a power monitor 714 senses the output power and returns data on the sensed power to the MPU 706 .
  • a second low pass filter 716 which in the illustrated embodiment is an inductor, passes the power signal to the bus 702 and excludes the higher frequency data signals that are being returned from the sensor module. The data signals instead pass through a high pass filter 718 to a demodulator 720 and thence to the MPU 706 .
  • Output from the MPU may be passed via an Ethernet connection 722 , or other type of connection.
  • FIG. 8 is a block diagram illustrating an arrangement similar to that illustrated in FIG. 4 and represents an alternate approach to illustrating similar concepts. As described above, this approach makes use of ceramic insulated tubing subs in order to isolate a portion of the tubing. One insulating sub forms the upper isolator 319 while another forms the lower isolator 321 . An intermediate tubing portion 802 becomes the transmission line for signals and power in the system. Similarly to the transformer embodiment, the tubing string conducts power signals from a connection point located just below the upper ceramic insulated tubing sub (upper insulator 319 ) to a connection point located just above the lower ceramic insulated tubing sub (lower insulator 321 ).
  • the power signals are provided to a sensor module/gauge assembly 310 from the connection point located just above the lower insulator 321 .
  • the sensor module 310 generates communication signals that are transmitted to the connection point located just above the lower insulator 321 .
  • the communication signals are conducted up the tubing string to the connection point located just below the upper insulator 319 and then transmitted to the surface system 500 .
  • the electrical path is completed by grounding the tubing string above the upper ceramic insulated tubing sub and below the lower ceramic insulated tubing sub and by grounding the surface system and sensor module.
  • the casing is generally grounded.
  • the tubing string above the upper ceramic insulated tubing sub may be grounded by coupling the tubing string to the casing through the wellhead.
  • the tubing string below the lower ceramic insulated tubing sub may be grounded by connecting the tubing string to the casing via a bowspring shorting centralizer, for example.
  • the inventors arranged up to 17,000′ of coaxial cable that matched the losses of a field test (i.e., simulated the depth of a typical deep well).
  • a remote full-wave AC power rectifier/filter was provided at the end of the cable to provide DC power to amplify the sensor signal.
  • a low frequency 60 hertz AC voltage was transmitted down the cable. It provided about 10 volts DC (out of the rectifier/filter) at the cable terminus.
  • An amplified sensor signal (frequency peak) was received at the surface using an HF radio detector. This setup allowed receipt of over 120 readings per second at the surface.
  • This technique uses the well tubing and casing as a conductive pair (CP) to carry the power down to the remote, powered sensor set or associated devices.
  • CP conductive pair
  • the tubing is maintained on center of the well-casing with annular insulator spacers (“centralizers”) such that the conductive pair (tubing and casing) do not electrically short to each other.
  • centralizers annular insulator spacers
  • a second use of the CP arrangement of the well hardware described herein is to power an electrical submersible pump (ESP) system for artificial lifting of fluids in the producing zones.
  • Electrical power sent to the ESP, via the tubing string, can be used to power attached sensor systems with the signals from those sensors using the same CP as the RF path back to surface instruments.
  • methods for commanding various functions down-hole might be accomplished by selecting a specific power frequency that would perform various separate remote operations (i.e. multiple zone valve control, etc.) by using resonant, frequency selective networks at the remote valve location.

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  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Remote Sensing (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Geophysics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Electromagnetism (AREA)
  • Arrangements For Transmission Of Measured Signals (AREA)
  • Investigating Or Analyzing Materials By The Use Of Electric Means (AREA)
  • Geophysics And Detection Of Objects (AREA)
US13/295,784 2010-11-12 2011-11-14 System and method for remote sensing Abandoned US20120211278A1 (en)

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US13/295,784 US20120211278A1 (en) 2010-11-12 2011-11-14 System and method for remote sensing
US14/543,185 US9103198B2 (en) 2010-11-12 2014-11-17 System and method for remote sensing

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US41317910P 2010-11-12 2010-11-12
US13/295,784 US20120211278A1 (en) 2010-11-12 2011-11-14 System and method for remote sensing

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EP (1) EP2638244B1 (zh)
CN (1) CN103221635A (zh)
AU (1) AU2011325931B2 (zh)
BR (1) BR112013011709B1 (zh)
CA (1) CA2817593C (zh)
EA (1) EA025452B1 (zh)
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US20140311235A1 (en) * 2013-03-14 2014-10-23 Sercel-Grc Corporation Downhole Quartz Gauge with Minimal Electronics
US20150070186A1 (en) * 2010-11-12 2015-03-12 Chevron U.S.A. Inc. System and Method For Remote Sensing
US20160102545A1 (en) * 2014-10-09 2016-04-14 Baker Hughes Incorporated Wireless passive pressure sensor for downhole annulus monitoring
US9708905B2 (en) * 2015-06-05 2017-07-18 Sensor Developments As Wellbore wireless thermal conductivity quartz transducer with waste-heat management system
US9846087B2 (en) 2014-12-03 2017-12-19 Heidelberger Druckmaschinen Ag Device for measuring the temperature in a plug connector by using a superimposed test frequency
US20190211670A1 (en) * 2013-03-15 2019-07-11 Merlin Technology, Inc. Inground device with advanced transmit power control and associated methods
US20220195806A1 (en) * 2020-12-23 2022-06-23 Halliburton Energy Services, Inc. Power conditioning system for pulse power drilling
US11867057B2 (en) 2013-03-15 2024-01-09 Merlin Technology, Inc. Advanced inground device power control and associated methods
US11994023B2 (en) 2021-06-22 2024-05-28 Merlin Technology, Inc. Sonde with advanced battery power conservation and associated methods

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EA037631B1 (ru) * 2020-07-14 2021-04-23 ОБЩЕСТВО С ОГРАНИЧЕННОЙ ОТВЕТСТВЕННОСТЬЮ "Тота Системс" Способ определения физических величин в скважине на основе пьезорезонансных датчиков без электроники и устройство для его осуществления

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US20150070186A1 (en) * 2010-11-12 2015-03-12 Chevron U.S.A. Inc. System and Method For Remote Sensing
US9103198B2 (en) * 2010-11-12 2015-08-11 Chevron U.S.A. Inc. System and method for remote sensing
US20140311235A1 (en) * 2013-03-14 2014-10-23 Sercel-Grc Corporation Downhole Quartz Gauge with Minimal Electronics
US9506340B2 (en) * 2013-03-14 2016-11-29 Sercel-Grc Corporation Downhole quartz gauge with minimal electronics
US20190211670A1 (en) * 2013-03-15 2019-07-11 Merlin Technology, Inc. Inground device with advanced transmit power control and associated methods
US11867057B2 (en) 2013-03-15 2024-01-09 Merlin Technology, Inc. Advanced inground device power control and associated methods
US10648326B2 (en) * 2013-03-15 2020-05-12 Merlin Technology, Inc. Inground device with advanced transmit power control and associated methods
US20160102545A1 (en) * 2014-10-09 2016-04-14 Baker Hughes Incorporated Wireless passive pressure sensor for downhole annulus monitoring
US9828848B2 (en) * 2014-10-09 2017-11-28 Baker Hughes, A Ge Company, Llc Wireless passive pressure sensor for downhole annulus monitoring
US9846087B2 (en) 2014-12-03 2017-12-19 Heidelberger Druckmaschinen Ag Device for measuring the temperature in a plug connector by using a superimposed test frequency
US9708905B2 (en) * 2015-06-05 2017-07-18 Sensor Developments As Wellbore wireless thermal conductivity quartz transducer with waste-heat management system
US20220195806A1 (en) * 2020-12-23 2022-06-23 Halliburton Energy Services, Inc. Power conditioning system for pulse power drilling
US11680447B2 (en) * 2020-12-23 2023-06-20 Halliburton Energy Services, Inc. Power conditioning system for pulse power drilling
US11994023B2 (en) 2021-06-22 2024-05-28 Merlin Technology, Inc. Sonde with advanced battery power conservation and associated methods

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CN103221635A (zh) 2013-07-24
EA025452B1 (ru) 2016-12-30
EP2638244A2 (en) 2013-09-18
AU2011325931B2 (en) 2015-12-10
WO2012065118A3 (en) 2013-03-07
AU2011325931A1 (en) 2013-05-02
CA2817593C (en) 2018-09-18
BR112013011709B1 (pt) 2020-10-06
MX2013005021A (es) 2013-06-03
EP2638244B1 (en) 2020-03-25
WO2012065118A2 (en) 2012-05-18
CA2817593A1 (en) 2012-05-18
EA201390692A1 (ru) 2014-03-31
BR112013011709A2 (pt) 2017-07-25

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