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    • 专利摘要:
    The described embodiments include a flow and data delivery system for gauges in a borehole. The power and data delivery system comprises a three-phase power supply coupled to a power cable for supplying power to a motor in a borehole positioned along a borehole. In addition, the power cable transmits power and data signals. The power and data delivery system also includes a meter in the borehole coupled to the engine in the borehole, and the meter in the borehole transmits data signals in the borehole along the power cable to a meter surface panel. Furthermore, the power and data delivery system comprises at least one meter positioned at a distance from the meter in the borehole and coupled to the power cable The at least one meter also transmits data signals in the borehole along the power cable to the meter surface panel.
    公开号:NL2019541A
    申请号:NL2019541
    申请日:2017-09-14
    公开日:2018-04-24
    发明作者:Darold Reed Stewart；Boyanapally Srilatha
    申请人:Halliburton Energy Services Inc；
    IPC主号:
    专利说明:

    Patent Center
    The Netherlands
    (21) Application number: 2019541 © Application submitted: 14/09/2017
    5 2019541
    A PATENT APPLICATION @ Int. CL:
    E21B 17/00 (2017.01) E21B 47/00 (2017.01)
    (30) Priority: (71) Applicant (s): 10/19/2016 US PCT / US2016 / 057756 Halliburton Energy Services, Ine. in Houston, Texas, United States of America, US. (41) Application registered: 24/04/2018 (72) Inventor (s): Stewart Darold Reed of Spring, Texas (US). (43) Application published: Srilatha Boyanapally of Stafford, Texas (US). 30/04/2018 (74) Authorized representative: J.M.H. Duyver lie. in Diegem.
    (54) COMMUNICATIONS OF MULTIPLE METERS OVER AN ESP POWER BUS (57) The described embodiments include a flow and data supply system for downhole gauges. The power and data delivery system includes a three-phase power supply coupled to a power cable for supplying power to a motor in a borehole positioned along a borehole. In addition, the power cable transmits power and data signals. The power and data delivery system also includes a downhole meter coupled to the downhole motor, and the downhole meter transmits downhole data signals along the power cable to a meter surface panel. Furthermore, the power and data delivery system includes at least one meter positioned remotely from the meter in the borehole and coupled to the power cable. The at least one meter also transmits downhole data signals along the power cable to the meter surface panel.
    NL A 2019541
    This publication corresponds to the documents originally submitted.
    COMMUNICATIONS OF MULTIPLE METERS ON A POWER SUPPLY BUS
    BACKGROUND The present invention relates generally to borehole power systems, and, in particular, to multi-meter communication along an electrical submersible pumping (ESP) power bus.
    Artificial lift systems, such as ESP systems, are often used in hydrocarbon-producing wells for pumping fluids from the wellbore to the surface. A conventional ESP system can include a centrifugal pump and electric motor driven by a three-phase voltage supply and a variable frequency drive (VFD), both of which are located on the surface. The three-phase voltage supply and the VFD supply three-phase current to the electric motor via a three-phase power cable. Data signals from a meter in a borehole can also be sent over the power cable to the surface. Such data signals may include various data related to the performance of downhole components and downhole tools.
    Although data signals are supplied to the surface through the downhole meter and the power cord, the downhole meter can only produce data from measurements of downhole conditions in the immediate vicinity of the downhole meter. In addition, in some cases, errors on a single phase of the three-phase power cable may render data transmission over the three-phase power cable unreliable. As a result, it can be difficult or unfeasible to obtain accurate data regarding conditions along a borehole within the bore or at a wellhead.
    BRIEF DESCRIPTION OF THE DRAWINGS Illustrative embodiments of the present description are described in detail below with reference to the accompanying figures, which are hereby incorporated by reference, and wherein:
    FIG. 1 is a schematic side view of a hydrocarbon producing environment comprising a plurality of meters coupled to a three-phase power cable supplying power to an electric submersible pump (ESP) motor;
    FIG. 2 is a circuit diagram of the hydrocarbon-producing environment of AFB. 1, including several meters coupled with the power cable;
    FIG. 3 is a data packet timing chart for a gauge in a borehole and a gauge in the borehole and / or wellhead for providing data transmission over the power cable without transmission overlapping; FIG. 4 is an example of a circuit diagram of a system that provides a DC current voltage level indication to a meter for starting data transmission;
    FIG. 5 is a flowchart of a process for transmitting power cable data from DC powered meters and implementing a meter reset when an overlap of the data packet is detected;
    FIG. 6 is a circuit diagram of the hydrocarbon-producing environment of AFB. 1, including multiple AC powered meters coupled to the power cable;
    FIG. 7 is a meter AC waveform without data signal;
    FIG. 8A is a current waveform of AFB. 7 with an applied frequency modulated data signal of one meter;
    FIG. 8B is a bit status diagram extracted from the meter data signal of AFB. 8A;
    FIG. 9A is a current waveform of AFB. 7 with applied two meter overlapping data signals both with different frequency modulations;
    FIG. 9B is a bit status diagram extracted from the data signals of the two meters of AFB. 9A;
    FIG. 10 is a flow chart of a process for transmitting data over the power cable with frequency modulated data signals; and FIG. 11 is a circuit diagram of the hydrocarbon-producing environment of AFB. 1, including multiple meters coupled with individual phases of the power cable.
    The illustrated images are purely examples and are not intended to establish or imply any limitation regarding the environment, architecture, design or process in which various embodiments may be implemented.
    DETAILED DESCRIPTION In the following detailed description of the illustrative embodiments, reference is made to the accompanying illustrations which form part thereof. These embodiments are described in sufficient detail to allow one skilled in the art to practice the invention, and it is obvious that other embodiments can be used and logical structural, mechanical, electrical and chemical changes can be made without departing of the spirit or scope of the invention. In order to avoid details which are not necessary for those skilled in the art to put the embodiments described herein into practice, certain information known to those skilled in the art may be omitted from the description. The following detailed description is therefore not to be understood in a limiting sense, and the scope of the illustrative embodiments is defined only by the appended claims.
    The present disclosure relates to providing multiple meters in and around a hydrocarbon producing environment, and methods and apparatus for providing communication of the multiple meters to the surface of the hydrocarbon producing environment. More particularly, the present disclosure relates to systems, devices and methods for transmitting data from the multiple meters over a power cable (i.e., a power bus) used to power an electric submersible pump (ESP) system. In addition, the gauges can be positioned at multiple locations along pipes within a borehole or on the surface near the wellhead. As defined herein, tubing can include any tubing, well casings as well as other types of wells that are either permanently installed along a well or can be taken out as a hydrocarbon production operation.
    As described herein, the embodiments of the present disclosure provide a multi-meter data delivery system located in or around a hydrocarbon producing well. In a generalized embodiment, a three-phase power supply to a surface supplies three-phase power to an electric submersible pump (ESP) system in a wellbore via a three-conductor power cable. Several gauges may be positioned along the three-conductor power cable, and the gauges may be coupled to the cable using a new splicing site or an existing site, such as a vent box (i.e. a junction box) to a wellhead of the hydrocarbon producing well. The meters can communicate with a meter surface panel by transmitting data over the three-conductor cable, and the meter surface panel serves to collect data recorded by the meters.
    In further embodiments, one or more of the gauges positioned along the three-conductor cable may be coupled to a single conductor (e.g., phase) of the three-conductor cable. In such embodiments, individual meters can further communicate with the meter surface panel when grounding errors or other conductive problems are experienced on the conductors to which other meters are coupled. Additional descriptions of the foregoing system, device and method of electrical connection are described in the sections below and are illustrated in AFB. 1-11. We return to the images. FIG. 1 is a schematic side view of a hydrocarbon producing environment 100 where a well bore gauge 102, pipe gauges 104A and 104B, and wellhead gauge 106 are coupled to a three phase power cable 108 that supplies power to an electric submersible pump (ESP) motor 110. In the embodiment on FIG. 1, a bore 112 with a wellbore 114 extends from a surface 116 of the bore 112 to or through an underground formation 118. Production tubes 120 may be positioned within the bore 112 to provide a path for production fluids 121 to flow to the surface 116. to go. A wellhead 122 may provide a path for the production house 120 to exit bore 112, and the wellhead 122 may provide paths 124 and 126 for the production fluids 121 and gas to be collected from the bore 112, respectively. production house 120 also includes a pump 128 powered by the ESP motor 110. In addition, a protector 130 may be included along the production house 120 to protect the ESP motor 110 from the production fluids 121 contained in the ESP motor 110 end up. Furthermore, a gas separator 132 may be included along the production house 120 to prevent free gas from entering the pump 128.
    At the surface 116, a junction box 134 (ie, a ventilation box) may provide an access point to the power cable 108 for the wellhead gauge 106, and the junction box 134 may also provide a ventilation mechanism for venting any gas that may be present along the power cable 108. Furthermore, the junction box 134 provides a connection between a portion of the power cable 108 that penetrates the wellhead 122 and a portion of the power cable 108 that is coupled to a boost transformer 136. The boost transformer 136 can receive power from a variable frequency drive ( VFD, variable frequency drive) 138, and drive a voltage level of the current received from the VFD 138 to a voltage level sufficient to drive the ESP motor 110. Furthermore, the VFD 138 can control the motor speed of the ESP motor 110 by varying the current frequency and voltage applied to the ESP motor 110. The coupling of the boost transformer 136 to the VFD 138 is a sine wave filter (SWF, sine wave filter) 140.
    During production on bore 112, an operator may generally be available to monitor the VFD 138 and a meter surface panel 142 coupled to the VFD 138. Accordingly, data provided by meters 102, 104A, 104B and 106 are displayed on the VFD 138, or a display connected to the meter surface panel 142. Taking this into account, meters 102, 104A, 104B and 106 can provide data signals over the power cable 108 to the boost transformer 136. The boost transformer 136 may the data signals are transmitted by a meter choke 144, which is connected to the y-point of the three-phase system via power cable 108, with a communication / meter streamline 146. The communication / meter streamline 146 supplies the data signals to the meter surface panel 142 and also supplies the appropriate power supply to the meters. At the meter surface panel 142, the data signals can be filtered and processed for display on a display 148 of the VFD 138 or for local storage and / or conventional remote transmission processes (e.g., cellular or satellite modems).
    Gauges 102, 104A, 104B and 106 can measure different operating conditions of the ESP system in proximity to gauges 102, 104A, 104B and 106. For example, the gauge in borehole 102 may be coupled to the ESP motor 110 to a lower portion of the production house 120. The gauge in the borehole 102 can measure the temperature around the ESP motor 110, pressure from the bore 112 near the ESP. measure motor 110, vibration of the production house 120 near the ESP motor 110, or any other operating condition of the ESP system experienced near the ESP motor 110. Likewise, the tube meters 104A and 104B can measure similar operating conditions of the ESP system, but the tube meters 104A and 104B can measure the operating conditions at varying points along the production house 120. For example, the tube meter 104A can measure the operating conditions of the ESP system above the pump 128, but below a surface of the fluid 121 within the bore 112. Furthermore, the tube meter 104B can also measure the operating conditions of the ESP system above the pump 128, however, the meter tube 104B may also be positioned above the surface of the fluid 121 within the bore 112. The wellhead gauge 106 may additionally provide measurements for the tubing pressure and casing pressure to the wellhead 122. The wellhead gauge 106 may furthermore also measure the temperature of the production fluid at the wellhead. Measure the surface, the vibration and acoustics of the surface production tubes, the vibrations and acoustics of the surface tubes, and any other operating conditions of the ESP system at the wellhead 122 that may be valuable to be monitored by the wellhead meter 106 .
    The addition of data from the tube meters 104A and 104B can provide a view of the analysis before errors and automated interventions. For example, monitoring a differential pressure over a given length of the production house 120 can provide a basis for executing real-time algorithms that detect a build-up of paraffin in the production tube 120. Furthermore, monitoring the vibrations of the tube can help confirm or detect whether sand plugs are moving towards the surface 116 or detect a likelihood of sand slurries swirling in the production tube 120. In addition, monitoring of an annulus 150 can immediately measure the meter surface panel 142 or an operator on the Notifying a "gas kick" that occurs when a slug of fluid is pushed to the surface 116 through a tube from the bore 112. The knowledge of an actual distribution of temperature and pressure along the production tube 120 can provide accurate pressure, volume , temperature (PVT) fluid analysis and accurately determining a voltage drop in the power cable 108.
    In addition to the valuable data produced by the tube meters 104A and 104B, the tube meters 104A and 104B can also provide a mechanical improvement in the way the power cable 108 is placed. For example, each of the tube meters 104A and 104B includes a splice connection for the power cable 108 so that the meter 104A or 104B can be electrically coupled to the power cable 108. A power cable 108 is generally spliced on site using extensive practical processes for connecting two coils of the power cable 108. Splicing methods can be cumbersome in bad weather conditions and can involve inherent reliability problems. The tube gauges 104A and 104B can function as a mechanical splitting that is performed quickly. In addition, since the split is no longer done manually, the split may be subject to fewer man-made quality defects. The mechanical splitting of the tube meters 104A and 104B can also provide a rigid connection to the production house 120, replacing bands or clamps to couple the power cable 108 to the production house 120 in the vicinity of the tube meters 104A and 104B.
    FIG. 2 is a circuit diagram 200 of the hydrocarbon producing environment 100 of AFB. 1, including the DC powered meters 102, 104A, 104B and 106 coupled to the power cable 108. The hydrocarbon producing environment 100 of AFB. 1 can receive power from a utility 202, and the environment 100 can be disconnected from the utility by an interrupt switch 204. Meters 102, 104A, 104B, and 106 may be coupled to y points of the ESP motor 110, tube gauge chokes 206A, and 206B, and a wellhead gauge choke 208, coupled to power cable 108. Since gauges 102, 104A, 104B, and 106 are coupled to the y points, and a three-phase power bus of an ESP system is a floating system, a power supply voltage be applied to a y-point 210 on the meter choke 144 coupled to the boost transformer 136 and then to the power cable 108 to power meters 102, 104A, 104B and 106 without using an additional power bus running downhole.
    In addition, the y point 210 on the meter choke 144 can also facilitate the communication line 146 to communicate data from the meters 102, 104A, 104B and 106 over the power cable 108 and to the meter surface panel 142. Communication over the power cable 108 can be performed meters 102, 104A, 104B and 106 by modulating power consumption by meters 102, 104A, 104B and 106 using either an amplitude modulation scheme or a frequency modulation scheme. Modulated current can be detected by the meter surface panel 142 which also functions as a power source for the meters 102, 104A, 104B and 106. Therefore, a strategy for using the ESP power bus (ie the power cable 108) as a meter current and physical communication layer a cost effective and reliable borehole gauge that intrinsically covers long communication distances.
    ESP installations can be completed when the wellhead 122 is located a great distance away from the VFD 138. These distances can be as much as a hundred feet to a mile. Installing separate instrumentation and lead wires for monitoring parameters at wellhead 122, such as relocation and house pressures, can be very expensive and in some cases inconvenient. For example, a location 212 between the VFD 138 and the wellhead 122 may include a route for tank trucks to access battery tanks from a bore path. The power cable 108 at location 212 may be underground from the wellhead 122 to a position near the VFD 138. To avoid the insertion of instrumentation wires below location 212, which can be expensive and sensitive to an environment in which they the wellhead gauge 106 is positioned on the junction box 134. The junction box 134, which is in physical proximity to the wellhead 122, can provide a junction for the wellhead meter 106 to the power cable 108 so that the wellhead meter 106 can transmit data signals along the power cable 108 to the meter surface panel 142. Because the junction box 134 is located nearby the wellhead 122, the wellhead meter 106 coupled to the junction box 134 can use relatively short instrument cables from the wellhead 122 to the wellhead meter 106 relative to a length of the instrument cables with the wellhead meter 106 located on the VFD 138. Consequently, the wellhead meter 106 located at junction box 134 reduce the costs associated with long instrument cabling and improve the reliability and robustness of the wellhead gauge 106.
    We return to FIG. 3 illustrating a timing diagram 300 for the meter in the wellbore 102 and the wellhead meter 106 of AFB. 1 and 2 for providing data transmission over power cable 108 without transmission overlap. Although the timing diagram 300 illustrates data transmission from the meter in the borehole 102 and the wellhead meter 106, it will be understood that the data transmission could also take place from the tube meters 104A and 104B or any other meters coupled to the power cable 108 of FIG. 1 and 2. Furthermore, more than two meters coupled to the power cable 108 may be used in a similar manner to the timing diagram 300. A similar technique may be applied, for example, to a system comprising four or more meters coupled to the power cable 108.
    Meters 102 and 106 can communicate with meter surface panel 142 of AFB. 1 and 2 by modulating current consumed by meters 102 and 106. However, such meter signal modulation may not be functional if several meters attempt to communicate over power cable 108 at the same time. Therefore, timing diagram 300 provides an indication of how the meter in the borehole 102 and the wellhead gauge 106 can communicate over the power cable 108 without interfering with the transmission of data from the other gauge 102 or 106. As illustrated, at time t (0), a data packet 302 of the gauge is downhole. 102 sent over the power cable 108. Accordingly, a data packet 304 from the wellhead meter 106, at time t (X offset), is transmitted over the power cable 108. At time t (X), a data packet 306 of the meter in the wellbore 102 is sent over the power cable 108, and, at time t (X + offset), a data packet 306 from the wellhead meter 106 is sent over the power cable 108. In this way, the data packets 302, 304, 306 and 308 can be sent over the power cable 108 without interference from the other data packets. A buffer 310 may further be established between the transmissions of the data packets 302, 304, 306 and 308. The buffer 310 can provide temporal separation between transmission of data packets 302, 304, 306 and 308 to avoid overlapping of transmissions over the power cable 108.
    While gauges 102 and 106 can only communicate using one-way transmissions (ie, gauges 102 and 106 are communicating upwards only), timing diagram 300 can be established by programming gauges 102 and 106 to send repeatedly of data for a specified period of time after a time interval X has elapsed. That is, if the time interval X is one minute, the meter in the borehole 102 will transmit the data packet 302 upon startup of an ESP system. Then, the meter in the borehole 102 will transmit the data packet 306 after one minute has elapsed since the time of start-up. In addition, the wellhead gauge 106 will transmit the data packet 304 between the transmission of the data packets 302 and 306. For example, an offset value can be thirty seconds. Accordingly, the wellhead gauge 106 can transmit the data packet 304 thirty seconds after the start-up time, and the wellhead gauge 106 can also transmit the data packet 308 one minute and thirty seconds after the startup time. The data packets 302, 304, 306, and 308 can all be sent over the power cable 108 over a twenty second period, and the buffer 310 may be a ten second period. When meters 102 and 106 do not transmit data packets 302, 304, 306, and 308, meters 102 and 106 may go into a dormant bus state while meters 102 and 106 collect data, but do not transmit data on power cable 108.
    The meter surface panel 142 can determine which of the meters 102 and 106 the data packet is from. For example, the meter surface panel 142 may have a data packet counter or an odd-even data packet organizer to place data packets at the appropriate meter 102 or 106. In addition, meters 102 and 106 may add a pre-identification field to a transmitted data packet. It will be understood that the method described above with respect to timing diagram 300 may be used for either DC or AC powered meters 102, 104A, 104B and 106. It will also be appreciated that the timing sequences described herein, examples have been and can be adapted to ensure a desired data transmission rate and increased operability.
    In a case where the data packets 302, 304, 306, and 308 become unsynchronized and data bits begin to be superimposed, the meter surface panel 142 may detect an error and trigger a restore action. The errors can occur for several reasons. For example, the borehole meter 102 may experience temperature fluctuations in internal circles of the borehole meter 102 making timing oscillators or crystals less accurate. Errors can also be due to the aging of a timing circuit or a slight inconsistency in the quality control of the integrated circuit (IC) device. Over time, minor shifts and inaccuracies can develop and result in data packet degradation.
    Errors can be detected by the meter surface panel 142 using a standard control redundancy check (CRC) field included with each data packet. In addition, an error check mechanism can be performed by monitoring data transmission over the power cable 108 for an excessively high status or abnormal power modulation status. For example, if both meters 102 and 106 simultaneously produce a high bit on the power cable 108, the power consumption detected by the meter surface panel 142 may be abnormally high for either a high status for each of the meters 102 and 106. The abnormally high signal may result from a multi-meter topology with two meters 102 and 106 in a parallel circle. If both meters 102 and 106 attempt to consume a high current at the same time, the total power consumption determined by the meter surface panel will be
    142 are the sum of the power consumption of both meters 102 and 106.
    An additional technique for detecting an error by the meter surface panel 142 may be to design each of meters 102 and 106 with uniquely high states. That is, each of the meters 102 and 106 may be designed to consume power for data transmission at a level distinguishable by the meter surface panel 142. If, while receiving a data packet 302 or 306 of the meter in the borehole 102 , a high status unique to the wellhead meter 106 is detected, an error indication can be triggered. Once an error is detected by the meter surface panel 142 by any method, both meters 102 and 106 can be quickly re-synchronized by allowing the meter surface panel 142 to perform an automatic flow cycle on meters 102 and 106 to reset internal timers of meters 102 and 106. start.
    FIG. 4 is a circuit diagram of a system 400 that provides an indication to a meter for starting data transmission. A communication method for transmitting data packets over the power cable 108 may include shifting a power supply voltage applied to the y point 210 from the meter surface panel 142. Each power supply shift may be unique for triggering communications from a specific meter 102, 104A 104B or 106. Furthermore, any of meters 102, 104A, 104B and 106 can detect the shift and respond by transmitting a data packet over the power cable 108. Such a technique can be applied to both DC and AC powered meters.
    For example, the borehole gauge 102 may be designed to respond to a 150 VDC supply voltage while the wellhead gauge 106 may be designed to respond to a 100 VDC supply. The minimum supply voltage required to operate the meters could be 100 VDC or less so that both meters 102 and 106 continuously collect and convert data from their respective transducers regardless of whether meters 102 and 106 transmit data. Standard power supply circuits can counteract or distribute any excess voltage in normal operation.
    The system 400 can monitor a voltage supply 402. This can be done with commonly available voltage regulators or management ICs or base circuits using diode and / or other biasing methods, such as the circuit shown in system 400. It will be understood that many designs can achieve this functionality, but they are all within the range of the present description. For example, a simple DC circuit can be constructed using a Zener diode 404 and a transistor 406 to generate a high or low status supplied to an input / output (I / O) port 408 of meters 102 104A, 104B and 106. Based on the configuration of resistors 410, the Zener diode 404, the transistor 406 and the I / O port 408, a high shift between the voltage supply 402 and ground 412 would cause the Zener to diode 404 conducts and activates transistor 406. While the transistor 406 is energized, a high status can be generated on the I / O port 408. Alternatively, when the offset between the voltage supply 402 and the ground 412 is small, the Zener diode 404 is inactive and the transistor 406 is also inactive. The I / O port 408 can be pulled down through a configuration of the resistors 410. In addition, the resistors 410 can be used to limit current to both Zener diode 404, transistor 406 and L / O port 408 scale as voltages to usable ranges (e.g., to a usable high signal at the I / O port 408).
    Furthermore, resistors 410 can provide a mechanical to change an active voltage range for meters 102, 104A, 104B and 106. For example, if the meter in the borehole 102 sends data when the voltage supply 402 supplies 150 VDC to the system 400, the resistors 410 can be selected such that a voltage of approximately 150 VDC supplied from the voltage supply 402 to the Zener diode 404 will activate resulting in a high status applied to the I / O port 408. By receiving the high status at the I / O port 408, a logic signal can be supplied to the meter's firmware 102 , 104A, 104B or 106 to start sending a data packet. Once the meter surface panel 142 has received the full data packet, the meter surface panel 142 can automatically reset the voltage supply offset to signal meter 102, 104A, 104B or 106 to go into hibernation mode. As mentioned above, the hibernation mode may include that meters 102, 104A, 104B and 106 collect data, but do not transmit data on power cable 108.
    FIG. 5 is a flow chart of a process 500 for transmitting data on the power cable 108 of AFB. 1 of DC powered meters 102, 104A, 104B and 106. At block 502, the meter surface panel 142 can apply a DC supply voltage to the power cable 108 to supply power to meters 102, 104A, 104B, and 106 when meters 102, 104A, 104B, and 106 are DC powered meters. The application of the DC supply voltage to the power cable 108 can be performed regardless of a status of the three phase current supplied to the ESP motor 110.
    At block 504, a first data packet can be received at the meter surface panel 142 of a first meter 102, 104A, 104B or 106 during a first condition. At block 506, a second data packet can then be received at the meter surface panel 142 of a second meter 102, 104A, 104B or 106 during a second condition. Although it is described as the second data packet, the second data packet received at block 506 can also be defined as an initial data packet supplied by the second meter 102, 104A, 104B or 106. It will also be appreciated that additional meters can be included within the process 500. For example, data packets of four or more meters 102, 104A, 104B and 106 can be received individually and in a predetermined order at the meter surface panel 142. Furthermore, the first condition, the second condition and any additional condition resulting from the addition of more meters, a timing block in which the meters 102, 104A, 104B and 106A are programmed or designed to transmit the data packets over the power cable 108, as described in detail in the discussion of AFB. 3. In addition, the conditions can also be established by receiving different DC voltage values at meters 102, 104A, 104B and 106 when meters 102, 104A, 104B and 106 are programmed or designed to transmit the data packets at receiving a specific voltage value, as described in detail in the discussion of AFB. 4. The power cable 108 may, therefore, at any time include data packet transmissions from an individual meter 102, 104A, 104B or 106 or no data packet transmissions at all.
    Because the transmission timing of meters 102, 104A, 104B, and 106 may be compromised for various reasons (e.g., temperature fluctuations in internal circuits that cause the oscillators or crystals to be inaccurate), the meter surface panel 142 may interfere with data packet transmissions from the monitor and decode meters 102, 104A, 104B and 106 at block 508. By monitoring the data packet transmissions, the meter surface panel 142 can determine whether any of the data meter transmissions of one meter 102, 104A, 104B or 106 overlap with the data packet transmissions of another meter 102, 104A, 104B or 106. an error can be determined using a standard control redundancy check (CRC) field included with each data packet transmitted over the power cable 108. In addition, an error check mechanism can be performed by monitoring an excessively high status or abnormal power modulation status. For example, if multiple meters 102, 104A, 104B or 106 simultaneously produce a high bit, the power consumption detected by the meter surface panel 142 will be abnormally high for a high status of any of the individual meters 102, 104A, 104B or 106. Furthermore, each meter 102, 104A, 104B and 106 provide a unique high status on power cable 108. If, while receiving a data meter of one meter 102, 104A, 104B or 106, a high status unique to another meter 102, 104A, 104B or
    106 is detected, the meter surface panel 142 may indicate that an error has occurred.
    At decision block 510, it is determined whether any data packet transmissions overlap using the techniques described above. Once an error is detected, meters 102, 104A, 104B and 106 can be quickly re-synchronized when the meter surface panel 142 performs an automatic flow cycle, at block 512, to restart internal timers of meters 102, 104A, 104B and 106. When restarting meters 102, 104A, 104B and 106, process 500 may return to block 504 to receive a first data packet from a first meter 102, 104A, 104B or 106 again. If the meter surface panel 142 determines that the data packet transmissions do not overlap, at decision block 510, then the process 500 can be repeated from block 504 without commanding meters 102, 104A, 104B and 106 to re-synchronize.
    We return to FIG. 6 showing a circuit diagram 600 of the cage hydrogen producing environment 100 of AFB. 1, including multiple DC powered meters 602, 604A, 604B and 606 coupled to the power cable 108. The AC powered meters 602, 604A, 604B, and 606 may be coupled to the power cable 108 in a similar manner to the DC powered meters 102, 104A, 104B, and 106 except that the AC powered meters 602, 604A, 604B, and 606 include a capacitive coupling 608 that drives the meters 602, 604A, 604B, and 606 using a power meter. AC powered source can permit. For example, the meter surface panel 142 may apply an additional AC current signal to the power cable 108 instead of a DC current signal to turn on the meters 602, 604A, 604B, and 606. The AC powered meters 602, 604A, 604B, and 606 may be a provide greater efficiency in transmitting data packets over the power cable 108.
    It will be understood that although AFB. 6 shows the AC powered meters 602, 604A, 604B and 606, a frequency modulation scheme, as discussed below in the discussion of AFB. 7-9 can be applied to either an AC or DC powered meter system. For example, a frequency modulation system can also be applied to the DC powered meters 102, 104A, 104B and 106 described above in the discussion of AFB. 2. Frequency modulation can be defined as a non-stationary event type where a meter 602, 604A, 604B or 606 modulates current at a specific frequency over a defined period of time. The defined duration can correspond to one bit width.
    To help illustrate, AFB. 7 a current waveform 700 without a communication signal. The current waveform 700 includes a signal 702, an ordinate 704 representing a current of the signal 702, and an abscissa 706 representing time in seconds. In addition, the signal 702, as illustrated, is a 150 Hz AC signal. The 150 Hz AC signal is used to provide an easily interpretable graph. In operation, the signal 702 may generally be a signal in excess of 500 Hz. Furthermore, the 702 signal can consume 50 mA (RMS) current during operation.
    Meters 602, 604A, 604B and 606 can each have different frequency modulated signals when transmitting data over power cable 108. For example, meter 602 can use a 2 kHz frequency modulated signal and meter 606 can use a 7 kHz frequency modulated signal . In addition, meters 604A and 604B can each use different frequencies for their respective frequency modulated signals. The meter surface panel 142 may be able to recognize from which of the meters 602, 604A, 604B and 606 the data transmitted over the power cable 108 is based on the frequency of the frequency modulated signals.
    For example, when the meter 602 sends data over the power cable 108, it can apply a 2 kHz, 10 mA frequency modulated signal to the 150 Hz, 50 mA frequency modulated signal 702. Taking this into account, FIG. 8A is a current waveform 800 of a frequency modulated signal 802 comprising an applied data signal from the meter 602. Similar to FIG. 7 includes FIG. 8A the ordinate 704 representing current and the abscissa 706 representing time. By applying the 2 kHz, 10 mA signal to the 150 Hz signal 702, the resulting frequency modulated signal 802 includes durations 804 and 806 in which the meter 602 transmits the 2 kHz, 10 mA signal over the power cable 108. For example, if the meter 602 wants to transmit a high bit, the meter 602 can apply the frequency modulated signal to the power cable 108 for a bit length time (e.g., 0.05 seconds, giving a baud rate of 20). Periods 804 and 806 can represent correspondingly high bits transmitted by meter 602.
    Using analog or digital filtering schemes, the frequency modulated signal 802 can be filtered in the two separate frequencies (e.g. 150 Hz and 2 kHz), and a bit status extracted from the 2 kHz signal sent by the meter 602 over the power cable 108. Using the filtered signals, AFB. 8B, a bit status diagram 810 extracted from the 2 kHz signal sent by the meter 602. In the bit status diagram 810, the abscissa 706 continues to represent time, while an ordinate 812 represents a bit status of the signal supplied by the meter 602. The periods For example, 804 and 806 are represented as high signals while a remainder of the bit status diagram 810 is represented as low signals 814. Since bit width is relatively large (e.g., 0.05 seconds), start and end points of the signal supplied by the meter 602 can also be located by a moderately fast brute force sampling method and / or a comparative method. In addition, locating the start and end points of the signal provided by the meter 602 can also be done with a deliberately designed rectifier circuit that can transform an analog signal into a near square wave similar to the bit status diagram 810 of AFB. 8B. In this way, data from the meter 602 is sent over the power cable 108 to the meter surface panel 142 using a frequency modulation scheme.
    FIG. 9A is a current waveform 900 of the frequency modulated signal 702 of AFB. 7 with applied data signals of two meters 602 and 606 simultaneously. The data signals applied to the 150 Hz signal 702 produce a frequency modulated signal 902. It will be appreciated that although the frequency modulated signal 902 includes data signals of two meters 602 and 606, any number of meters 602, 604A, 604B and 606 can be simultaneously applied to the 150 Hz signal 702 for producing the frequency modulated signal 902. As in the current waveforms 700 and 800 described above, the current waveform 900 includes the ordinate 704 representing current and the abscissa 706 representing time. In addition, the frequency modulated signal 902 includes signals from the meter 602 transmitting at a 2 kHz frequency and the meter 606 transmitting at a 7 kHz frequency, both of which are applied to the 150 Hz frequency modulated signal 702.
    FIG. 9B provides a bit status diagram 910 extracted from the 2 kHz signal sent by the meter 602 and the 7 kHz signal sent by the meter 606. The bit status diagram 910 includes the abscissa 706 representing time and an ordinate 912 representing a bit status of data signals 914 and 916 represent meters 602 and 606, respectively. An analog or digital signal filtering process (eg, a bandpass filter) can be used to separate the frequency modulated signal 902 into three separate waveforms (eg, 150 Hz, 2 kHz, and 7 kHz) for isolating each of the different frequencies. Furthermore, the 2 kHz and 7 kHz frequency signals can be transformed into the bit states shown on AFB. 9B. Accordingly, it will be understood that two or more data signals from two or more of the meters 602, 604A, 604B and 606 can be simultaneously transmitted over the power cable 108 using the frequency modulation scheme without interfering with each other. Furthermore, a more sophisticated approach using a robust and accurate solution can be achieved using advanced digital signal processing (DSP) methods for locating non-stationary communication bits in both the frequency and time domain, such as a discrete wavelet transformation (DWT). The DWT can decompose a raw signal (e.g., the frequency modulated signal 902) into three-dimensional transform which can then be filtered to extract a desired frequency component while maintaining a time domain position of the desired frequency component. The filtered transformation can then be reconstructed to the time domain, accurately displaying bit positions. The DWT can provide sharper resolution and ability to filter out high-energy random noise when compared to other DSP transformations. Other DSP strategies (eg, sliding fast Fourier transform (FFT), short time FFT, multispectral analysis, etc.) can be built to target the same frequency and time localization information pertinent to the non-stationary signals.
    FIG. 10 is a flow chart of a process 1000 for transmitting data over the power cable 108 with a frequency modulated data signal. At block 1002, either AC or DC current is applied to the three-phase y point 210 through the meter surface panel 142 to drive meters 602, 604A, 604B, and 606. In addition, meters 602, 604A, 604B, and 606 can be driven by the AC or DC current applied to the y point 210 regardless of a current status of the ESP motor 110. Furthermore, an AC power supply may include a frequency greater than 500 Hz.
    At block 1004, a data packet may be received at the meter surface panel 142 of one or more of the meters 602, 604A, 604B or 606. It will be appreciated that additional meters may be included within the data transmission process 1000 over the power cable 108. For example, data packets of four or more meters 602, 604A, 604B, and 606 may be received at the meter surface panel 142. Furthermore, the first frequency, the second frequency, and any additional frequencies resulting from the addition of more meters may all be differentiated so that the meter surface panel 142 can easily filter the data signals and assign the resulting data to the appropriate meters 602, 604A, 604B and 606.
    At block 1006, the data transmissions of the meters can be correspondingly filtered by the meter surface panel 142 in such a way that the meter surface panel 142 can assign the transmitted data to the appropriate meters 602, 604A, 604B, and 606. By assigning the data the appropriate gauge allows a user to observe an environment in the borehole and wellhead at various different positions along the bore 112. Since gauges 602, 604A, 604B, and 606 can simultaneously transmit data on the power cord 108, the gauge surface panel 142 can additionally provide information about the conditions of the bore 112 at a greater frequency than with the sequential technique described above. For example, conditions within bore 112 can be updated every minute or every thirty seconds by any meter without having to wait for data transmissions from the rest of the meters to complete.
    We return to FIG. 11 showing a circuit diagram 1100 of the hydrocarbon producing environment 100 of AFB. 1, including tube meters 1104A and 1104B coupled to individual phases 1108A and 1108B of power cable 108. It will be understood that although only tube meters 1104A and 1104B are shown as coupled to individual phases 1108A and 1108B, more meters may be positioned along the power cable 108 and may also be coupled to the individual phases 1108A and 1108B. In addition, meters may also be coupled to an individual phase 1108C, which constitutes a third phase of the three-phase power cable 108. Since gauges 1104A and 1104B are coupled to individual phases 1108A and 1108B, gauges 1104A and 1104B are not coupled to y points of power cable 108. Furthermore, other gauges, such as the borehole gauge 102 and wellhead gauge 106 may also be coupled with the power cable 108, but the borehole meter 102 and the wellhead gauge 106 may be coupled to the power cable at the y points provided by the ESP motor 110, the junction box 134, or any other y point by the addition from another meter along the power cable 108.
    When a problem occurs in one of the phases 1108A, 1108B or 1108C of the power cable 108, such as a ground fault, transmission of data from a meter 102 or 106 coupled to the three phases of the power cable 108 can be inhibited . For example, in the illustrated example, if a phase problem occurs on the phase 1108C, the borehole meter 102 and the wellhead meter 106 can no longer communicate with the meter surface panel 142 over the power cable 108. However, the tube meters 1104A and 1104B can continue to communicate with the meter surface panel 142 over the individual phases 1108A and 1108B, respectively. Therefore, while a full view of the ESP system may not be available from all meters 102, 1104A, 1104B and 106, an operator can still access data provided by meters 1104A and 1104B as long as phases 1108A and 1108B remain functional.
    The above-described embodiments have been presented by way of illustration and allow one skilled in the art to practice the description, however, the description is not intended to be complete or limitative of the described forms. Many slight changes and variations will be apparent to those skilled in the art without departing from the scope and spirit of the description. For example, although the flowcharts show a serial process, some of the steps / processes can be performed in parallel or out of sequence, or combined in a single step / single process. The scope of the claims is intended to broadly cover the described embodiments and any such modification. Furthermore, the following clauses represent additional embodiments of the description and are to be considered within the scope of the description: Clause 1, a flow and data system for sensors in a borehole of a bore, comprising a three phase power supply which is coupled with a power cable for supplying power to a downhole motor positioned along a bore; wherein the power cable is configured to send power and send data signals; a downhole meter coupled to the downhole motor, the downhole meter configured to transmit downhole data signals along the power cable to a meter surface panel; and at least one meter spaced from the meter in the borehole and coupled to the power cable, the at least one meter being configured to transmit data signals along the power cable to the meter surface panel.
    Clause 2, flow and data delivery system of clause 1, wherein the at least one meter comprises a wellhead gauge positioned near a wellhead of the bore.
    Clause 3, power and data delivery system according to clause 2, wherein the wellhead gauge is coupled to the power cable at a y point generated by a choke coupled to a ventilation box, a Jbox, or any three-phase junction on a surface of the bore.
    Clause 4, flow and data delivery system according to at least one of clauses 1 to 3, wherein the at least one meter comprises at least one tube meter positioned along a production house within the borehole.
    Clause 5, power and data delivery system according to clause 4, wherein the at least one tube meter is coupled to the power cable at a y point generated by a choke.
    Clause 6, flow and data delivery system according to at least one of clauses 1 to 5, wherein the at least one meter comprises a first tube meter positioned along the tube of the bore above a fluid level of the bore, a second tube meter which is positioned along the tube of the bore below the fluid level of the bore and above the motor in the borehole, and a third tube gauge positioned along the tube of the bore below the motor in the borehole.
    Clause 7, flow and data delivery system according to at least one of clauses 1 to 6, wherein the downhole motor is an electric submersible pump (ESP) motor, and the downhole motor is configured to measure a temperature of the ESP motor.
    Clause 8, power and data delivery system according to at least one of clauses 1 to 7, wherein the downhole meter and the at least one meter comprise AC powered meters, and the AC powered meters are configured to transmit the downhole data signals and the meter data signals simultaneously over the power cable.
    Clause 9, flow and data delivery system according to at least one of clauses 1 to 7, wherein the downhole meter and the at least one meter comprise DC powered meters, and the DC powered meters are configured to alternate between transmitting the downhole data signals and the meter data signals over the power cable.
    Clause 10, method for receiving data from several meters of a bore, the method comprising supplying three phase power to an electric submersible pump (ESP) motor positioned within a borehole via a power cable comprising a first second and third conductor; receiving a first data packet from a first meter of the bore via the power cable when a first environment is reached; and receiving a second data pack of a second meter from the bore via the power cable when a second environment is reached.
    Clause 11, method according to clause 10, wherein the first meter comprises a borehole meter coupled to the ESP motor, and the second meter comprises a wellhead meter coupled to a ventilation box, a J box, or some three-phase split the bore.
    Clause 12, method according to clause 11, further comprising receiving a third data packet of a third meter of the bore via the power cable when a third environment is reached, the third meter comprising a tube meter coupled to the power cable along pipes within a borehole of the bore.
    Clause 13, method according to at least one of clauses 10 to 12, wherein the first meter and the second meter are DC or AC powered meters, and the first environment includes a first time after the first meter starts operating, the second environment includes a second time after the second meter starts operating, and the first time and the second time do not overlap so that the first data packet and the second data packet are received at different times.
    Clause 14, method according to at least one of clauses 10 to 12, wherein the first meter and the second meter are DC or AC driven meters, and the first environment and the second environment overlap in such a way that the first data packet and the second data packet is received simultaneously.
    Clause 15, method according to at least one of clauses 10 to 14, wherein the first environment comprises a first voltage supplied on the power cable, and the second environment comprises a second voltage supplied on the power cable, the first voltage is different from the second voltage.
    Clause 16, method according to clause 15, wherein the first meter is configured to detect when the first voltage is supplied on the power cable and send the first data packet only when the first voltage is supplied on the power cable, and the second meter is configured to detect when the second voltage is supplied to the power cable and to send the second data packet only when the second voltage is supplied to the power cable.
    Clause 17, a flow and data supply system for downhole sensors of a borehole, comprising a three-phase power supply coupled to a power cable for supplying power to a motor in a borehole positioned within a borehole, wherein the power cable includes a first, second and third conductor over which power and data signals are transmitted; a first meter coupled to the first conductor of the power cable, the first meter in the borehole configured to transmit a first packet of data signals on the first conductor, a second meter coupled to the second conductor of the power cable the second downhole meter being configured to transmit a second packet of the data signals on the second conductor; and a third meter coupled to the third conductor of the power cable, wherein the third downhole meter is configured to transmit a third packet of data signals on the third conductor.
    Clause 18, flow and data delivery system according to clause 17, wherein the first meter is coupled to the downhole motor, the second meter is positioned along tubulars within the wellbore, and the third meter is communicatively coupled to a wellhead of the wellbore. bore.
    Clause 19, flow and data delivery system according to clause 17 or 18, wherein the first meter, the second meter and the third meter are each positioned along pipes within the borehole.
    Clause 20, flow and data delivery system according to any one of clauses 16 to 19, wherein the first meter, the second meter and the third meter are each configured to further transmit the data signals on the respective first, second and third conductors in the case that one or more of the other conductors coupled to the one or more other respective meters experience a problem that precludes transmission on the one or more other conductors.
    Clause 21, power and data delivery system according to at least one of clauses 16 to 20, wherein the first, second and third meters are configured to be coupled to an existing connection with the power cable or to a connection created by the meter with the power cord.
    As used herein, the singular forms "a", "the" and "it" are intended to include the plural forms, unless otherwise clearly indicated by the context. Furthermore, it will be understood that the terms "include" and / or "comprising" when used in this specification and / or the claims specify the presence of the features, steps, operations, elements and / or components mentioned, but not exclude the presence or addition of one or more other features, steps, operations, elements, components and / or groups thereof.
    In addition, the steps and components described in the above embodiments and illustrations are illustrative only and do not imply that any particular step or component is a requirement of a described embodiment.
    权利要求:
    Claims (15)
    [1]
    CONCLUSIONS
    1. Flow and data delivery system for meters in a borehole of a borehole, comprising:
    a three-phase power supply coupled to a power cable for supplying power to a motor in a borehole positioned along a borehole;
    the power cord configured to transmit power and transmit data signals;
    a downhole meter coupled to the downhole motor, the downhole meter being configured to transmit downhole data signals along the power cable to a meter surface panel; and at least one meter spaced from the meter in the borehole and coupled to the power cable, the at least one meter being configured to transmit data signals along the power cable to the meter surface panel.
    [2]
    The power and data delivery system of claim 1, wherein the at least one meter comprises a wellhead gauge positioned near a wellhead of the bore, and wherein the wellhead gauge is coupled to the power cable at a y point generated by a choke coupled with a ventilation box, a J box, or any three-phase split on a surface of the bore.
    [3]
    The flow and data delivery system of claim 1, wherein the at least one meter comprises at least one tube meter positioned along a production house within the borehole.
    [4]
    The power and data delivery system of claim 4, wherein the at least one tube gauge is coupled to the power cable at a y point generated by a choke.
    [5]
    The flow and data delivery system of claim 1, wherein the at least one meter comprises a first tube meter positioned along the tube of the bore above a fluid level of the bore, a second tube meter positioned along the tube of the bore below the bore tube. fluid level of the bore and above the motor in the borehole, and a third tube gauge positioned along the tube of the bore below the motor in the borehole.
    [6]
    The power and data delivery system of claim 1, wherein the downhole motor is an electric submersible pump (ESP) motor, and the downhole motor is configured to measure a temperature of the ESP motor.
    [7]
    The power and data delivery system of claim 1, wherein the downhole meter and the at least one meter comprise AC powered meters, and the AC powered meters are configured to transmit the downhole data signals and the meter data signals simultaneously at the same time. the power cord.
    [8]
    The power and data delivery system of claim 1, wherein the downhole meter and the at least one meter comprise DC powered meters, and the DC powered meters are configured to alternate between transmitting the downhole data signals and the meter data signals over the power cable.
    [9]
    A method for receiving data from several meters of a bore, the method comprising:
    providing three phase power to a downhole electric submersible pump (ESP) motor positioned within a borehole via a power cable comprising a first, second and third conductor;
    receiving a first data packet from a first meter of the bore via the power cable when a first environment is reached; and receiving a second data pack of a second meter from the bore via the power cable when a second environment is reached.
    [10]
    The method of claim 9, wherein the first meter comprises a borehole meter coupled to the ESP motor, and the second meter comprises a wellhead meter coupled to a ventilation box, a J-box, or any three-phase split of the bore.
    [11]
    The method of claim 10, further comprising receiving a third data packet of a third meter of the bore via the power cable when a third environment is reached, the third meter comprising a tube meter coupled to the power cable along tubes within a borehole of the bore.
    [12]
    The method of claim 9, wherein the first meter and the second meter are DC or AC driven meters, and the first environment includes a first time after the first meter starts operating, the second environment includes a second time after the second meter starts to operate, and the first time and the second time do not overlap so that the first data packet and the second data packet are received at different times.
    [13]
    The method of claim 9, wherein the first meter and the second meter are DC or AC driven meters, and the first environment and the second environment overlap in such a way that the first data packet and the second data packet are received simultaneously.
    5
    [14]
    The method of claim 9, wherein the first environment comprises a first voltage supplied to the power cable, and the second environment comprises a second voltage supplied to the power cable, wherein the first voltage is different from the second voltage.
    [15]
    The method of claim 14, wherein the first meter is configured to detect when the first voltage is supplied on the power cable and transmit the first data packet only when the first voltage is supplied on
    15 the power cable, and the second meter is configured to detect when the second voltage is supplied to the power cable and transmit the second data packet only when the second voltage is supplied to the power cable.
    grounding return
    Y / P »0 DC supply to meters across three-phase y-circuit first data packet of first meter received during first condition second data packet of second meter received during second condition transmissions of meters
    5Ö8- Z decode / ëv e rl a pp and the x - v n a transmissions
    Command 510 meters to activate cycle «f · '*: · Λ *'
    512
    I
    O time (sec) time (sec) bit status
    810 bit status extracted from signal with 2 time (sec) time (sec)
    10 bit status extracted from signal with 2 kHz and 7 kHz bit status
    Summary
    The described embodiments include a current and
    5 data delivery system for gauges in a borehole. The power and data delivery system includes a three-phase power supply coupled to a power cable for supplying power to a motor in a borehole positioned along a borehole. In addition, the power cable transmits power and data signals. The power and
    The data delivery system also includes a downhole meter coupled to the downhole motor, and the downhole meter transmits downhole data signals along the power cable to a meter surface panel. Furthermore, the power and data delivery system includes at least one meter that is remote
    15 positioned from the gauge in the borehole and coupled to the power cord. The at least one meter also transmits downhole data signals along the power cable to the meter surface panel.
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    同族专利:
    公开号 | 公开日
    GB2567775A|2019-04-24|
    NO20190268A1|2019-03-26|
    WO2018075037A1|2018-04-26|
    NL2019541B1|2018-08-07|
    CA3035352A1|2018-04-26|
    US20190186246A1|2019-06-20|
    AR109675A1|2019-01-09|
    GB201902577D0|2019-04-10|
    US11105190B2|2021-08-31|
    FR3057607A1|2018-04-20|
    CA3035352C|2021-03-09|
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    法律状态:
    2021-05-12| MM| Lapsed because of non-payment of the annual fee|Effective date: 20201001 |
    优先权:
    申请号 | 申请日 | 专利标题
    PCT/US2016/057756|WO2018075037A1|2016-10-19|2016-10-19|Multi-gauge communications over an esp power bus|
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