• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    method and apparatus for clock synchronization. the present invention relates to a system for synchronizing components of a downhole system, which includes a source set including a source clock, an electromagnetic source associated with the source set and configured to emit an electromagnetic signal for a grounding at a transmission time, a receiver set including a receiver clock, an electromagnetic receiver associated with the receiver clock and configured to detect the electromagnetic signal, and a processor configured to identify an electromagnetic signal reception time with based on the receiver clock and to adjust the receiver clock by comparing the transmission time with the reception time.
    公开号:BR112012025396B1
    申请号:R112012025396-4
    申请日:2011-04-07
    公开日:2020-03-17
    发明作者:Radu Coman；Michael Neubert
    申请人:Baker Hughes Incorporated；
    IPC主号:
    专利说明:

    Invention Patent Descriptive Report for "SYSTEM AND METHOD OF SYNCHRONIZING COMPONENTS OF A WELL BACKGROUND SYSTEM".
    CROSS REFERENCE TO RELATED REQUESTS
    This order claims the benefit of an earlier filing date of North American Interim Series Order No. 61 / 321,658, filed on April 7, 2010, the full description of which is hereby incorporated by reference. BACKGROUND
    Underground formations can be evaluated and / or monitored using information received from various measurement methods, such as methods for measuring seismic, acoustic, sonic, elastic and other properties at the bottom of the well. Such methods typically include the use of receivers positioned on the surface or arranged in a borehole. An example of a borehole measurement technique that uses seismic receivers includes the generation of a vertical seismic profile (VSP). VSP systems include seismic sources that generate seismic waves in an earth formation and seismic receivers positioned at wellhead locations selected to receive and measure seismic waves.
    Some measurement systems, such as a record system during drilling (LWD), a VSP system - during drilling (VSP-WD) and other systems that measure properties, such as seismic, acoustic, sonic and elastic properties at the bottom of well, use measurement tools that include sources or receivers arranged in the bottom of the well without a wired connection or other physical connection to the surface components. Such systems typically include clocks associated with downhole tools and surface components to record the times when measurement signals are transmitted and received, such that the travel time of the signals can be measured. Accurate time synchronization between a surface clock that controls and / or monitors a source and watches that control the acquisition of data from receivers is essential for these measurement methods. Common techniques for clock synchronization involve synchronizing the surface clock with downhole clocks before placing a tool or substitute in a borehole, and checking the time fluctuation (caused, for example, by changes in temperature in the downhole) of the downhole clocks after the downhole clocks are extracted from the borehole. These techniques generally do not include additional synchronization while the replacement or other tool is in the borehole. Downhole clocks required for such techniques therefore have to be maintained with a small error, requiring high energy and costly clocks. Such watches require continuous energization for an extended period (typically about 3 to 4 days) before being placed in the pit, have a relatively short life span, and require an uninterrupted power supply throughout the inspection. In addition, the energy consumption of such downhole clocks is relatively large, and therefore an external power source (such as a battery replacement) is generally required, which limits the placement of receptors in the downhole. . SUMMARY
    A system for synchronizing components of a downhole system includes a source set including a source clock, an electromagnetic source associated with the source set and configured to emit an electromagnetic signal for an earth formation at a transmission time, a receiver set including a receiver clock, an electromagnetic receiver associated with the receiver clock and configured to detect the electromagnetic signal, and a processor configured to identify an electromagnetic signal reception time based on the receiver clock and set the clock receiver with the comparison of transmission time with reception time.
    A method of synchronizing components of a downhole system includes the transmission of an electromagnetic signal through an electromagnetic source through an earth formation at a transmission time, the electromagnetic source associated with a source set including a clock. source, the detection of the electromagnetic signal by means of an electromagnetic receiver, the electromagnetic receiver associated with a receiver set including a receiver clock, the identification of a time of reception of the detected electromagnetic signal using the receiver clock, and the adjustment of the receiver clock with comparison of transmission time with reception time.
    A method of evaluating a property of an earth formation includes the disposition of a carrier in a borehole in the earth formation, the carrier including an electromagnetic receiver or an electromagnetic source, the electromagnetic receiver associated with a receiver clock and the source electromagnetic signal associated with a source clock, the transmission of an electromagnetic signal by grounding the electromagnetic source at a pre-selected transmission time, the transmission time being identified based on the source clock, the detection of the electromagnetic signal by means of the electromagnetic receiver, identifying a reception time of the detected electromagnetic signal using the receiver clock, adjusting the receiver clock by comparing the transmission time with the reception time to synchronize the receiver clock with the source clock, the emission of a seismic signal for the formation of earth in a fo seismic, the detection of the seismic signal by at least one seismic receiver, and the evaluation of at least one property of the formation based on the detected seismic signal.
    BRIEF DESCRIPTION OF THE DRAWINGS The subject that is considered to be the invention is particularly shown and distinctly claimed in the claims at the conclusion of the specification. The previous features and advantages of the invention, as well as others, will become evident from the following detailed description taken in conjunction with the accompanying drawings, in which: Figure 1 is a side cross-sectional view of a drilling system modality , assessment, exploration and / or underground well production; figure 2 represents an exemplary embodiment of a receiver used in conjunction with the systems and methods described here; and figure 3 is a flow chart that provides an exemplary method for synchronizing components of a downhole system. DETAILED DESCRIPTION
    Here, devices and methods for synchronizing at least two clocks are described, where at least one of the clocks is arranged in an underground location. In one embodiment, a downhole recording system includes at least one electromagnetic (EM) source associated with a source clock, and at least one EM receiver associated with a receiver clock and including an EM detector. The system is configured to transmit an EM signal from the EM source to the EM receiver and to synchronize the receiver clock with the source clock based on the EM signal.
    With reference to figure 1, an exemplary embodiment of a drilling, recording, evaluation, exploration and / or underground well production system 10 includes a borehole column 12 which is shown arranged in a borehole 14 which penetrates at least one earth formation 16 during an underground operation. As described here, the term "borehole" or "well" refers to a single hole that forms an entire or part of a drilled well, and the term "formations" refers to various characteristics and materials that can be found in a subsurface environment and surrounding the borehole. A conventional drilling tower 18 or other structure is configured to support and / or deploy the borehole column 12 and the various components.
    For example, the borehole column 12 is configured as a borehole column that includes one or more sections of pipe or spiral tubes that descend downwardly into the borehole 14 and that includes a downhole assembly (BHA) . In this example, the BHA includes a drill bit set 19. In other embodiments, the borehole column 12 includes a set of cables or other suitable carrier. A "bearer", as described here, indicates any device, device component, combination of devices, means and / or limb that can be used to conduct, house, support or otherwise facilitate the use of another device, device component , combination of devices, means and / or member. Exemplary non-limiting carriers include spiral drill tube, articulated tube drill columns and any combination or portion thereof. Other carrier examples include well casing tubes, cables, cable probes, profiling cable probes, drop shots, downhole substitutes, downhole assemblies, and drill columns.
    In one embodiment, one or more receiver sets 20 are positioned on or within the borehole column 12 or otherwise supported by the borehole column 12 and / or the borehole 14, and one or more sets of source 22 are arranged in one or more surface locations. In another embodiment, one or more source sets 22 are disposed in the bottom of the well with the borehole column 12 and / or inside the borehole 14, and one or more receiver sets 20 are arranged in one or more locations surface and / or downhole. The number and configuration of source sets 22 and receiver sets 20 are not limited.
    Receiver assemblies 20 and source assemblies 22 are configured to measure various downhole properties, such as seismic, acoustic, sonic, elastic and other properties. The source assemblies 22 can be positioned at a surface location and / or at the bottom of the shaft. For example, a source assembly 22 is disposed in the borehole at any selected location, such as disposed within a tool or downhole replacement. In one example, the source assembly 22 is a drill bit as part of a recording system during drilling.
    In one embodiment, one or more receiver sets 20 include seismic receivers configured to detect seismic waves emitted from formation 16 and / or a seismic source. One or more source sets 22 include seismic sources, such as mechanical vibrators. Seismic source assemblies 22 can be located at surface locations close to drillhole 14 or at any selected location, and seismic receiver assemblies 20 can be positioned at one or more locations along drillhole 14. The assemblies of receiver 20 and source sets 22 can be incorporated, for example, in a vertical seismic profile (VSP) and / or in a VSP system - during drilling (VSP-WD). Although receiver sets 20 are described in some embodiments as including seismic receivers, they are not limited to these. Receiver assemblies 20 can include any type of component featuring a clock configured to be synchronized with a remotely positioned clock.
    In one embodiment, system 10 can include any of several sensor sets configured to evaluate the properties of borehole 14 and / or formation 16. Examples of such sensor sets include nuclear magnetic resonance (NMR) sensors, resistivities, porosity sensors, gamma ray sensors and others.
    In one embodiment, the receiver sets 20 and / or source sets 22 are each equipped with transmission equipment to finally be communicated to a surface processing unit 24. Such transmission equipment can take any desired shape, and different means and methods of transmission can be used. Examples of connections include wired, fiber optic, wireless and memory-based systems.
    Each of the source sets 22 is associated with one or more source blocks 26 to record time values related to signals generated by a respective source set 22, each of the receiver sets 20 includes or is otherwise associated with a clock. receiver 28 to record time values related to signals detected by a respective set of receiver 20. Clocks 26, 28 can be any suitable type of clock, for example, a clock having a resolution of at least 1 ppm (an error of 1 ms in 10s). Examples of suitable clocks include crystal oscillators, atomic clocks, such as rubidium-based atomic clocks, optical clocks and clocks controlled by the global positioning system (GPS). For example, the source clock 26 may be a temperature-controlled crystal oscillator. The source clock 26 can be an external clock in communication with the source set 22, or it can be incorporated as a component within the source set 22. The source clock 26, in one embodiment, is a remote unit in communication with one or more source sets 22 via a wired connection or a wireless connection, such as a radio frequency communicator. The source clock 26, in one embodiment, is connected to the source set 22 or is otherwise in communication with the source set 22 to command or otherwise control the source set 22 and / or monitor the source set 22. In one embodiment, the source clock 26 is connected to a sensor to detect the activation of the source set 22 to determine the activation time or transmission time (that is, the emission of a seismic signal or other signal) . For example, in the example where source set 22 includes a seismic source, source clock 26 is connected to a seismic sensor that is incorporated into source set 22 or that is part of an acoustic / seismic receiver (or another type of receiver) disposed near source set 22. In another example, in the example where source set 22 includes a drill bit as a seismic source, source clock 26 does not command or control the seismic source, but can be used to monitor the seismic / acoustic output of the seismic source by means of appropriate sensors. System 10 includes at least one EM signal source or electromagnetic wave 30 and at least one EM 32 signal detector. The EM 30 signal source is configured to be arranged at a surface or downhole location and is configured to emit an EM signal through formation 16 to one or more EM 32 signal detectors. In one embodiment, each EM 30 signal source and / or EM signal detector is included in a respective source set 22 or receiver set 20, it is in communication with it, or is otherwise associated with it, although it does not need to be configured that way. The EM signal detector (s) (32) can (s) be included in one or more sets of source 22 or one or more sets of receiver 20 or communicatively connected thereto.
    In one embodiment, the EM 30 signal source is configured to emit EM waves with a frequency less than or equal to about 100 Hz. Such low frequency waves can propagate through training materials with minimal attenuation, thus allowing communication between source sets 22 and receiver sets 20. In one embodiment, the EM 30 signal source is configured to emit EM waves at a frequency less than or equal to about 10 Hz. Examples of EM 30 sources and EM detectors 32 include coil antennas and associated electronics capable of transmitting and receiving extremely low frequency (ELF) or super low frequency (SLF) waves, respectively.
    In one embodiment, each of the source sets 22 includes or is otherwise associated with the EM 30 signal source, and each of the receiver sets includes or is otherwise associated with one or more EM 32 signal detectors. In this embodiment, the EM 30 signal source is configured as a component of the source set 22, but can also be configured as a separate set. For example, in the example where the source set 22 is arranged at a surface location, the EM 30 signal source is arranged at the source set location or at a remote surface location and configured to communicate with the set of sources. source 22 via a wired or wireless connection.
    In one embodiment, the EM 30 signal source or the EM 32 signal detector is arranged in a surface or downhole location with or without a connection to a source or receiver assembly. For example, the EM 30 signal source is configured to emit an EM signal from a surface location at a transmission time that is recorded by a surface clock (for example, the source clock 26 or the receiver clock 28) , and one or more EM 32 signal detectors are configured to detect the downhole EM signal and are arranged at a downhole location or depth corresponding to a source or receiver set location or depth. In this example, the EM 30 signal source does not need to be connected or associated with a surface source or receiver set. In another example, the EM 30 signal source is configured to emit an EM signal from a bottom location (which may correspond to a location or depth of a source or receiver set), one or more EM 32 signal detectors they are arranged in one or more surface locations and / or downhole (which may correspond to a depth or location of a source or receiver set) to detect the EM signal.
    In one embodiment, source sets 22 and / or EM 30 signal source include control and / or processing electronics 34 including one or more processors, memory and / or other devices configured to perform functions, such as EM 30 signal source, EM signal reception, EM-related data generation and signal measurement and / or data storage. Receiver sets 20 and / or EM signal detector 32 include control and / or processing electronics 36 configured to control EM signal detector 32, control receiver clock 28, receive EM signals, generate data related to EM signals , process data and / or store data.
    Referring to figure 2, in one embodiment, an exemplary receiver set 20 is configured as a downhole seismic receiver set 40. Seismic receiver set 40 includes a seismic receiver 42, such as a geophone, a clock receiver 28, and an EM signal detector 32. A housing 44 is configured to have the seismic receiver 42, the receiver clock 28 and / or the EM signal detector 32 therein. Although the receiver clock is shown in figure 2 as being arranged in the receiver assembly 40, the receiver clock may be configured as a separate component and arranged with the seismic receiver assembly or arranged with the borehole column 12 and / or another component in the borehole column 12 In addition, the EM signal detector can be configured as a separate component with respect to receiver set 40. Housing 44 can be formed from any suitable material, such as steel, capable of supporting bear downhole conditions, such as high temperatures and / or pressures. Housing 44 may have any shape suitable to be lowered or otherwise arranged in the bore 14. Examples of housing 44 include a downhole assembly (BHA), a pipe segment, a downhole replacement , a probe, a drill collar, a cable tool and an LWD tool. In one embodiment, housing 44 is configured to be connected to the borehole wall or the borehole casing.
    In one embodiment, the seismic receiver set 40 includes control and / or processing electronics 36 in operable communication with the seismic receiver 42, receiver clock 28 and / or the EM 32 signal detector. Electronics 36 includes a or more processors configured to generate data, such as signal sines, determine downhole clock time changes and adjust downhole clocks as needed. Electronics 36 may also include memory devices for storing EM signal and clock data, seismic data and the like. The receiver set 40 can be connected to one or more power sources, such as a battery 46 arranged in housing 40, a battery replacement connected to housing 40, power generated by a downhole power module, or power sources energy on the surface through a cable connection.
    The locations of the EM 30 signal sources and the EM 32 signal detectors are not limited to those described here. In addition, the locations of the signal sources 30 and the EM 32 signal detectors need not correspond directly to the locations of the receiver sets 20 and the source sets 22, but can be remotely positioned with respect to them. In one embodiment, at least one EM 30 signal source is located at a surface location (located in receiver sets 20 or source sets 22 on the surface or at a selected distance from one or more of such sets) and one or more signal detectors 32 are located in a downhole position at a depth that corresponds to a depth of one or more downhole receiver sets 20 or source sets 22. In another embodiment, one or more EM 32 signals are located at surface locations (located in receiver sets 20 or source sets 22 on the surface or at a selected distance from one or more of such sets) and at least one EM 30 signal source is located in one position downhole at a depth that corresponds to a depth of one or more receiver sets 20 or downhole source sets 22. Figure 3 illustrates a method 50 for synchronizing components of a downhole system. Method 50 includes one or more stages 51-55. Method 50 is described here in conjunction with system 10, one or more sets of receiver 20, one or more sets of source 22, and / or one or more sets of seismic receiver 40, although method 50 may be performed in conjunction with any number and configuration of clocks, sources, receivers or other measurement tools. In one embodiment, method 50 includes performing all stages 51-55 in the order described. However, certain stages can be omitted, stages can be added, or the order of stages can be changed. In addition, method 50 can be performed in conjunction with cable measurement processes, VSP processes, LWD or MWD processes, VSP processes - during drilling (VSP-WD) and any other appropriate seismic measurement or recording processes.
    In the first stage 51, one or more source sets 22 or receiver sets 20 are lowered to a location in a downhole portion of the borehole 14 or otherwise arranged therein. The tool can be lowered during or after drilling the borehole 14. One or more source sets 22 or receiver sets 20 are disposed in the downhole by any of several methods, such as being dropped into the borehole 14 in a probe, inserted in the borehole column 12, and pumped to a bottom position by means of drilling mud or other fluid at the bottom of the well. In one embodiment, one or more source sets 22 and / or receiver sets 20 are lowered into the borehole 12 by a cable, inserted during a MWD or LWD process, or inserted into the downhole by any other suitable processes. In one embodiment, when seismic measurements are performed and the seismic source is the drill bit set 19, one or more receiver sets 20 will be arranged at a surface location, at a bottom location in the same borehole. that the drill bit assembly 19, and / or at a remote drill column location and one or more source assemblies 22 are lowered into the downhole as the bore hole is drilled.
    In the second stage 52, an EM signal is generated at a selected location, such as a surface location or at the bottom of the shaft, through the EM 30 signal source and transmitted through formation 16. In one embodiment, the EM signal is a pulsed EM signal or an EM sine or cosine signal showing a defined frequency over a selected period of time. In one mode, the defined frequency is less than or equal to about 100 Hz. In one mode, the defined frequency is less than or equal to about 10 Hz.
    Although the example described here with reference to method 50 includes a surface EM source in conjunction with one or more EM receptors, the systems and methods described here are not limited. For example, the EM signal can be generated at the bottom of the well and detected by one or more EM receivers positioned at surface locations and / or at the bottom of the well.
    Suitable electronics associated with the EM 30 signal source, such as source electronics 34, record the time, referred to here as the transmission time, at which the EM signal is initiated, or another time selected during the EM pulse. In one embodiment, the transmission time is a preselected time known to a receiver processor associated with the EM 32 signal detector and / or receiver set 20, 40, and known to a source processor associated with one or more more EM 30 signal sources and / or source set 22, before arranging source set 22 or receiver set 20, 40 on the downhole. In one embodiment, the source processor generates a sine or cosine signal. The maximum / minimum amplitude or the crossing point or any other predefined point on the sine or cosine curve can be correlated to the transmission time.
    In the third stage 53, the EM signal detector 32 detects the EM signal that has been transmitted through the formation and records the time received based on the receiver clock 28 (i.e., the "measured reception time"). In one embodiment, the receiver processor generates a sine or cosine signal from the EM detector and determines the measured reception time based on the sine signal. For example, the measured reception time is identified as the time that corresponds to a maximum amplitude of the EM signal. The receiver processor uses the known transmission time, and calculates a "correct reception time", that is, a reception time that would be measured by the source clock 26 or by a clock perfectly synchronized with the source clock 26 based on a transit time of the EM signal. "Transit time" refers to the amount of time required for the EM signal to travel between formation 16 between source set 22 and receiver set 20. In one embodiment, transit time is previously known and / or is calculated based on the distance between the source set 22 and the receiver set 20, the EM signal wave frequency and the measured properties of the formation 16.
    For example, the receiver processor adds the transit time to the known transmission time to calculate the correct reception time. In one embodiment, the receiver processor defines a synchronized time grid based on the reception time or the corrected reception time of the EM signal. For example, a frequency of 10 Hz leads to a 100 ms time grid distance.
    In the fourth stage 54, the receiver processor compares the measured reception time to the correct reception time. If there is a difference between the measured reception time and the correct reception time, the receiver processor will adjust the frequency of the source clock 26 and the receiver clock 28 and / or otherwise adjust the receiver clock 28 to synchronize the receiver clock 28 with source clock 26.
    For example, if the correct reception time is 10 ms longer than the measured reception time, the difference will be justified by adding 10 ms to the downhole data or by adjusting the receiver clock 28 as an addition. 10 ms to the rock bottom clock.
    In the fifth stage 55, the measurement of a property of formation 16 and / or borehole 12 can be performed with the receipt of data from receiver set 20. In one embodiment, a set of seismic source 22 is activated to emit waves seismic in formation 16. A source clock 26 is associated with seismic source set 22 and records a time in which seismic waves are emitted. In one embodiment, the source clock 26 is used to trigger the seismic shot, for example, by sending a trigger signal to the seismic source set 22 at a selected time. One or more seismic receiver sets 40 detect and record seismic signals, which can be timed using receiver clock 28, and processed at the bottom of the well or later read, when one or more receiver sets 20 are retrieved from the borehole. sounding 14. Alternatively, one or more receiver sets 20 may be in communication with a surface component, such as the surface processing unit 24, and transmit the recorded seismic data to it. In another embodiment, such as in an LWD or MWD application, seismic data is recorded by one or more receiver sets 20 that operate on the surface or remotely on the drill string. Appropriate downhole processing, such as stacking and detecting first arrival events, is performed, and the resulting data is stored in electronics 36 and / or transmitted to source assembly 22 and / or the processing unit surface area 24.
    The systems and methods described here provide several advantages over existing processing methods and devices. The systems and methods described here allow for effective downhole synchronization, reduce energy consumption, eliminate the need to energize downhole clocks before registration, and eliminate the need for uninterrupted power supplies. In addition, the need for highly accurate and costly time measuring devices is reduced or eliminated. For example, the methods described above can be used successively using relatively low-cost crystal oscillators for surface and downhole clocks, which typically have an error of about 10 ppm (ie, 1 ms in 100 s), and both would be sufficient in contrast to prior art methods that require the use of much more precise controlled oscillators. In addition, because the downhole clock energy requirements are lower, an external battery power substitute may not be required, which may allow the placement of VSP substitutes closer to a drill bit and improve "advance drill" measurements.
    In support of the teachings contained herein, various analyzes and / or analytical components can be used, including digital and / or analog systems. The system may have components, such as a processor, storage media, memory, input, output, communications link (wired, wireless, pulsed mud, optical or other), user interfaces, software programs, signal processors (digital or analog) and other such components (such as resistors, capacitors, inductors and others) to provide operation and analysis of the apparatus and methods described here in any of the various ways well appreciated in the art. It is considered that these teachings can be implemented, although they do not need to, in conjunction with a set of computer executable instructions stored in a computer readable medium, including memory (ROMs, RAMs), optical (CD-ROMs), or magnetic (disks) , hard drives), or any other type that, when executed, causes a computer to implement the method of the present invention. These instructions can provide equipment operation, control, data collection and analysis and other functions considered relevant by a system designer, owner, user or other personnel, in addition to the functions described in this description.
    One skilled in the art will recognize that various components or technologies can provide certain necessary or beneficial functionality or features. Consequently, these functions and features, insofar as they may be necessary in support of the appended claims and variations thereof, are recognized as being inherently included as part of the teachings contained herein and a part of the described invention.
    While the invention has been described with reference to the exemplary modalities, it will be understood by those skilled in the art that various changes can be made and that equivalents can be replaced by elements of the same without departing from the scope of the invention. In addition, many modifications will be appreciated by those skilled in the art to adapt a specific instrument, situation or material to the teachings of the invention without departing from its essential scope. Therefore, it is intended that the invention is not limited to the specific modality described as the best method contemplated for carrying out this invention, but that the invention includes all modalities that are within the scope of the appended claims.
    权利要求:
    Claims (15)
    [1]
    1. System for synchronizing components of a downhole system, characterized by comprising: a source set (22) including a source clock (26) and an electromagnetic source (30) configured to emit an electromagnetic signal in a formation of earth (16) in a transmission time; a receiver assembly (20) including a receiver clock (28) and an electromagnetic receiver configured to detect the electromagnetic signal; and a processor (24) configured to identify an electromagnetic signal reception time and adjust the receiver clock (28) based on transmission time, reception time and transit time, the transit time being an amount time required for the electromagnetic signal to travel between the electromagnetic source (30) and the electromagnetic detector (32).
    [2]
    2. System according to claim 1, characterized by the fact that the processor (24) is configured to combine the transmission time with the transit time of the electromagnetic signal to calculate a correct reception time.
    [3]
    3. System according to claim 2, characterized by the fact that the processor (24) is configured to compare the correct reception time with the measured reception time to calculate a relative oscillation between the source clock (26) and the receiver clock (28).
    [4]
    4. System according to claim 3, characterized by the fact that the processor (24) is configured to adjust the receiver clock (28) based on the relative oscillation to synchronize the receiver clock (28) with the clock. source (26).
    [5]
    5. System according to claim 1, characterized by the fact that the source clock (26) and the receiver clock (28) are selected from at least one of a crystal oscillator, a clock supported by the system global positioning (GPS), an optical clock and an atomic clock.
    [6]
    6. System according to claim 1, characterized by the fact that the receiver assembly (20) is configured to be arranged in a borehole in a ground formation (16), and the receiver assembly (20) it is configured to be arranged in a surface location.
    [7]
    System according to claim 6, characterized by the fact that the receiver set (20) is a plurality of receiver sets arranged in multiple locations in the borehole.
    [8]
    8. System according to claim 1, characterized in that the source set (22) includes a seismic source, and the receiver set (20) includes a seismic receiver (42).
    [9]
    9. System according to claim 8, characterized by the fact that the receiver assembly (20) is configured to be arranged in a borehole in a ground formation (16), and the source assembly (22) it is configured to be arranged in a surface location.
    [10]
    10. System according to claim 8, characterized by the fact that the seismic source is a drill bit and the seismic receiver (42) is configured to be arranged in at least one of a surface location and a remote location at the bottom of well.
    [11]
    11. System according to claim 1, characterized by the fact that the electromagnetic signal includes an electromagnetic wave signal having a frequency less than or equal to about 10 Hz.
    [12]
    12. Method of synchronizing components of a downhole system, characterized by comprising: the transmission of an electromagnetic signal through a source set (22) through an earth formation (16) in a transmission time, the set of source (22) including a source clock (26) and an electromagnetic source (30); detecting the electromagnetic signal by means of a receiver assembly (20), the receiver assembly (20) including a receiver clock (28) and an electromagnetic receiver; the identification of a time of reception of the electromagnetic signal detected using the receiver clock (28); and setting the receiver clock (28) based on transmission time, reception time and transit time, transit time being an amount of time required for the electromagnetic signal to travel between the electromagnetic source (30 ) and the electromagnetic detector (32).
    [13]
    13. Method according to claim 12, characterized by the fact that the comparison includes combining the transmission time with the transit time of the electromagnetic signal to calculate a correct reception time, and the comparison of the correct reception time with the time measured reception rate to calculate a relative oscillation between the source clock (26) and the receiver clock (28).
    [14]
    14. Method according to claim 12, characterized by the fact that the electromagnetic signal includes an electromagnetic wave signal having a frequency less than or equal to about 10 Hz.
    [15]
    15. Method according to claim 12, characterized in that the source set (22) includes a seismic source and the receiver set (20) includes a seismic receiver (42).
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    同族专利:
    公开号 | 公开日
    GB2491757A|2012-12-12|
    US8805632B2|2014-08-12|
    WO2011127280A3|2012-01-19|
    WO2011127280A2|2011-10-13|
    BR112012025396A2|2016-06-28|
    GB2491757B|2015-12-16|
    US20110251813A1|2011-10-13|
    GB201216849D0|2012-11-07|
    NO20121043A1|2012-11-07|
    引用文献:
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    法律状态:
    2016-09-20| B08F| Application fees: application dismissed [chapter 8.6 patent gazette]|Free format text: REFERENTE A 3A ANUIDADE. |
    2017-01-03| B08G| Application fees: restoration [chapter 8.7 patent gazette]|
    2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2019-10-01| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|
    2020-01-14| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2020-03-17| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 07/04/2011, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US32165810P| true| 2010-04-07|2010-04-07|
    US61/321,658|2010-04-07|
    PCT/US2011/031575|WO2011127280A2|2010-04-07|2011-04-07|Method and apparatus for clock synchronization|
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