Patent Application
20140192621
Various techniques are used to measure formation properties, such as transient electromagnetic (EM) measurement techniques. Transient EM methods such as transient logging while drilling (LWD), especially using “look-ahead” capability, have been shown to have great use in geologic formation evaluation and measurement. Transient EM techniques involve disposing a tool including at least one transmitter and receiver, and transmitting transient pulses of current into a formation. The induced electromagnetic field and decay responses are measured. For proper operation of the transient EM tool, the transmitter and receiver must be well synchronized, i.e., the receiver data acquisition should start at the same instant of the transmit trigger, to within an error of, e.g., a few hundred nanoseconds.
It has been conventional to the industry to assemble a LWD or wireline tool string from individual modules (also referred to as subassemblies or “subs”) which perform various functions and carry out various measurements while the string has been lowered in the borehole. However, even though these subs are mechanically attached to each other and share common power, the string communication abilities remains limited. For instance, in operations such as LWD or production logging where a single conductor carries power and telemetry signals, the telemetry uses a unique master controller which respectively sends commands to a particular sub and/or accepts a reply. This type of data transfer in general denies the modules the ability to communicate directly with each other which in turn may severely limit some applications, e.g., multicomponent transient EM (TEM) and multicomponent induction applications.
A method of synchronization between downhole components includes: generating a dual tone synchronization signal by a signal generator in a first downhole component disposed in a borehole in an earth formation, the dual tone signal including a first constituent periodic signal having a first frequency f1 and a second constituent periodic signal having a second frequency f2 that is different from the first frequency; transmitting the synchronization signal to a second downhole component disposed in the borehole; receiving the synchronization signal by a signal processor in the second downhole component, calculating a phase difference between the first constituent signal and the second constituent signal, and calculating a transmission delay based on the phase difference; and synchronizing operation of the first and second downhole components based on the delay.
An apparatus for communicating between downhole components includes: an interface coupled to a first downhole component, the interface configured to communicatively couple the first downhole component to a transmission line and transmit signals to a second downhole component over the transmission line, the interface including a current loop transmitter configured to convert voltage signals from the first downhole component to current signals and transmit the current signals on a current loop formed by the transmission line.
The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, like elements are numbered alike:
Apparatuses and methods are provided for performing downhole operations such as electromagnetic (EM) measurement operations, including logging-while-drilling (LWD) and/or wireline operations. The apparatuses and methods also provide for direct communication between downhole components over a power and/or communication line extending along a borehole string. An exemplary method is provided for performing transient EM (TEM) logging operations, and for direct communication between downhole components. An exemplary apparatus and method provides for direct communication between subassemblies for, e.g., synchronization between a master subassembly (e.g., an EM transmitter) and another subassembly (e.g., an EM receiver). In one embodiment, synchronization is performed via a dual frequency one-way time delay measurement method. An embodiment of a communication apparatus or assembly includes interfaces for implementing a data channel in a bus or other transmission line for sending high-speed data from the master subassembly to affected subassemblies without interfering with other telemetry and power signals (e.g., between downhole components and surface units) already present on the transmission line.
Referring to
The BHA 22 and/or other portions of the borehole string 12 include sensor devices configured to measure various parameters of the formation and/or borehole. In one embodiment, the sensor devices include one or more transmitters and receivers configured to transmit and receive electromagnetic signals for measurement of formation properties such as composition, resistivity and permeability. An exemplary measurement technique is a transient EM (TEM) technique.
In one embodiment, the tool 24, BHA 22 and/or sensor devices include and/or are configured to communicate with a processor to receive, measure and/or estimate directional and other characteristics of the downhole components, borehole and/or the formation. For example, the tool 24 is equipped with transmission equipment including a power and/or data transmission line 30 to communicate with a processor such as a downhole processor 26 or a surface processing unit 28. Such transmission equipment may take any desired form, and different transmission media and connections may be used. Examples of connections include wired, fiber optic, acoustic, wireless connections and mud pulse telemetry.
In one embodiment, the downhole tool 24 includes separate subassemblies or “subs” that incorporate the transmitter and receiver(s). For example, a transmitter sub 32 houses an EM transmitter 34 (including, e.g., a transmitter antenna or coil) and associated electronics, which is configured to transmit EM pulses into the formation and is connected to the transmission line 30. The transmitter sub 32 is connected to a receiver sub 36 that houses one or more EM receivers 38 and 40 (e.g., receiver coils) and associated electronics, which is configured to receive EM signals from the formation and is also connected to the transmission line 30. The subs 32 and 36 are connected together via connection mechanism 42 (e.g. a pin-box connector). An electric source, which may be disposed downhole or at a surface location, is configured to apply electric current to the transmitter 34 through, e.g., the transmission line 30. Although the subs 32 and 36 are shown in direct connection, they are not so limited, as other subs, pipe sections or tools may be connected between them.
Although the tool 24, EM transmitter 34 and EM receivers 38 and 40 are described as being incorporated in downhole subs, they may be incorporated into any suitable downhole component, module or other carrier. A “carrier” as described herein means any device, device component, combination of devices, media and/or member that may be used to convey, house, support or otherwise facilitate the use of another device, device component, combination of devices, media and/or member. Exemplary non-limiting carriers include drill strings of the coiled tubing type, of the jointed pipe type and any combination or portion thereof. Other carrier examples include casing pipes, wirelines, wireline sondes, slickline sondes, drop shots, downhole subs, bottom-hole assemblies, and drill strings.
In one embodiment, the transmitter and the receivers are disposed axially relative to one another. An “axial” location refers to a location along the Z axis that extends along a length of the tool 24 and/or borehole 14. The receiver 40 is positioned at a selected axial distance L1 from the transmitter 34, and the receiver 38 is positioned at a shorter axial distance L2 from the transmitter.
Referring to
The EM transmitter sub 32 and the EM receiver sub 34 each include a communication assembly that connects the EM transmitter/receiver electronics to the transmission line 30. For example, the EM transmitter sub 32 includes a synchronization signal generation assembly 46 and the EM receiver sub 34 includes a synchronization signal processing assembly 48. An interface 50 is included in each communication assembly that adds a communication channel to the transmission line 30.
In one embodiment, each interface 50 is a relatively narrow-band high frequency interface (e.g., around 4 MHz) added between the sub electronics and the transmission line 30. In one embodiment, shown in
In one embodiment, one of the subassemblies (e.g., the EM transmitter sub 32) is configured as a master subassembly and has the capability to inject signals into the interface 50 to be broadcast to selected subassemblies or individual receivers (e.g., the EM receiver sub 36 or one of the EM receivers 38, 40) over the transmission line 30. The injected narrow-band (e.g., 4 MHz) signals can be either synchronization signals for time synchronization purposes or data transmission signals over the injected carrier.
For example, the transmitter communication assembly 46 includes a modem 54 for modulating data signals 56 from the transmitter, and a synchronization (sync) signal generator 58 for transmitting synchronization signals. The receiver sub 36 (or each receiver 38 and 40) includes a modem 54 for demodulating data signals and a sync processor 60 for receiving and processing synchronization signals.
In one embodiment, for time synchronization between transmitters and receivers, the sync generator 58 includes a dual tone signal generator capable of generating tones with fixed phase difference. The sync generator outputs a signal generated by two constituent signals having a fixed initial phase relationship. Each constituent signal has a different frequency or tone. In one embodiment, the constituent signals each have a frequency that falls within the frequency band of the channel added to the transmission line 30 by the interface 50.
In order to receive the dual tone signal, the sync processor 60 includes a phase sensitive receiver connected to the added channel of the transmission line 30. The sync processor 60 is configured to measure or calculate the difference in phase of the two tones transmitted by the master subassembly. In one example, the signal processing assembly 48 includes a digitizer followed by a Fourier transform processing routine that measures phase difference of the received tones.
It is noted that the subassemblies are not limited to the embodiments and configurations described herein. For example, the EM receiver sub 36, described as a synchronization signal receiver in
In the first stage, the borehole string 12, including downhole components such as the EM transmitter sub 32 and the EM receiver sub 36, is lowered in the borehole. The string 12 may be lowered, for example, during a drilling operation, LWD operation or via a wireline.
In the second stage, the master component (e.g., the EM transmitter sub 32), transmits a synchronization signal to another downhole component (e.g., the EM receiver sub 36). In one embodiment, the master component transmits a trigger signal to the downhole component in addition to the synchronization signal. The trigger signal is a signal indicating a time value associated with the master component. For example, the trigger signal indicates the time value at which the EM transmitter sub 32 commences transmission of transient EM signals into the formation.
An exemplary synchronization signal is shown in
In the third stage, the other downhole component (e.g., EM receiver sub 36) receives the trigger signal and the synchronization signal. The time of the trigger is noted, i.e., its position in the synchronization signal, and recording of TEM voltage signals from the formation by the EM receiver 38 or 40 is commenced. In one embodiment, the EM receiver sub 36 includes a circular buffer, and the trigger causes the EM receiver sub 36 to store data from the buffer at the trigger time and record subsequent data as needed. The EM receiver sub 36 also analyzes the synchronization to calculate the time delay τ that corresponds to the amount of time required to transmit the trigger to the EM receiver sub 36. This delay is used to adjust the trigger time for the receiver data so that the received TEM data is synchronized with the transmitter.
In one embodiment, the receiver calculates the delay τ based on the phase difference between the two tones or frequencies f1 and f2. For example, a fast Fourier transform (FFT) is used to calculate the phase difference φ(f2)−φ(f1). The delay may then be calculated based on:
In the fourth stage, a measurement operation is performed using the transmitter and receiver subassemblies. The measured voltage signals may be transformed, e.g., using a Fourier transform. The measured or transformed signals may be inverted or otherwise analyzed to estimate characteristics of the formation and/or borehole for the purpose of, e.g., formation evaluation and geosteering. For example, measured or transformed frequency domain TEM signals are inverted to provide estimations of formation properties, such as resistivities and distances to interfaces or boundaries in the formation.
In one embodiment, the EM transmitter sub 32 and the EM receiver sub 36 each include a current loop transmitter and/or current loop receiver that form part of a current loop communication system for direct communication between the EM transmitter sub 32 and the EM receiver sub 36 over the communication line. The current loop transmitter is configured to receive a voltage signal (e.g., data, commands or other communications) from the EM transmitter or receiver, convert the sensor signal to a current and inject the current into a current loop formed by the communication line. The current signal generated by the current loop transmitter is tuned to a frequency that is different than the communication line's pre-existing carrier frequency or frequencies.
An example of a current loop communication configuration is shown in the circuit diagram of
A first transceiver 90 (e.g., in the EM transmitter 34) converts voltage signals to current via the low impedance looking into the termination network of a second transceiver 90 through the transmission line 30 and transmits the current to the second transceiver 90 over the communication line 30. The second transceiver 90 (e.g., in the EM receiver 36) receives the current signal and converts the current signal to a voltage signal to be detected by the subassembly electronics. The communication line 30 in this configuration forms part of a current loop at the carrier frequency that includes, e.g., a power supply from the surface processing unit 28, the communication line 30 and return through the borehole string.
In one embodiment, each transceiver 90 includes circuitry for resonant decoupling of the transceiver from telemetry/power signals transmitted over the communication line 30. For example, resonant decoupling is achieved for the transceivers via a decoupling capacitor 92 (“C1” in the transmitter sub and “C2” in the receiver sub) and a transformer 94 (“X1” in the transmitter sub and “X2” in the receiver sub). The capacitors 92 allow for elimination of passing DC voltage acting on the bus 30 to the transformer primary winding which could cause excessive power losses and saturate the transformer's core.
In one embodiment, each transformer 94, together with an inductor 96 (“L1” or “L2”) and an additional capacitor 98 (“C3” or “C4”) forms a high quality band pass filter that can be tuned to the transceiver's operating frequency (e.g., 4 MHz). This also allows for effective suppression of low frequency telemetry signals that may be propagated to the transceiver inputs.
If the input impedance of a current loop receiver “R” were maintained high, a change of the communication line's impedance could de-tune the above mentioned band pass filter. This impedance change could occur if more downhole subs have been connected to the bus and/or their power/telemetry characteristics changed.
In one embodiment, to mitigate this issue, the current loop receiver module includes a very low impedance front-end amplifier, i.e., operating as a current amplifier, or in transimpedance mode. In this embodiment, the input impedance of the current loop receiver at the transceiver frequency is negligible while remain sufficiently high for telemetry signals. The transceivers' information is delivered from the current loop transmitter to the current loop receiver by current owing from the current loop transmitter output to the current loop receiver input, and the amount of current diverted to connected extra subs will be in reverse proportion to the ratio of their input impedances to the impedance of the current loop receiver. In this way, additional subs or components added to the communication line 30 do not result in an appreciable change in performance of the current loop.
The current loop communication system can be configured as a one-way system, where a first component includes only a current loop transmitter and is configured to transmit current signals to a second component that includes only a current loop receiver. In other embodiments, the communication system is configures as a half-duplex or a full-duplex system.
The apparatuses and methods described herein provide various advantages over prior art techniques, including providing a method for effective synchronization between downhole components over existing communication/power lines.
The dual tone synchronization method overcomes disadvantages inherent in prior art methods. For example, for transient EM tools, synchronization of the receiver using the rising edge of voltage signals induced in receiver coils (due to current in the formation induced by the EM transmitter) is possible, however the conductivity of the formation between the transmitter and receiver tends to distort and lengthen the rise time of the rising edge, making synchronization variable, inaccurate and unreliable. Furthermore, this synchronization method can be badly affected by random noise. Algorithms for distinguishing the axis and polarity of dipole reversals by the receiver will likely be complicated and may be unreliable, thus reducing the reliability of a synchronization method using the receiver voltage signals.
The dual tone synchronization methods overcome these deficiencies and provide an accurate method for time synchronization of transmitters and receivers, e.g., that are placed on separate subassemblies. In addition, the method may be a one-way syncing method that doesn't require two-way communication and handshaking among the affected subassemblies.
The communication systems and interfaces described herein provide for direct communication between subassemblies by implementing a data channel in a bus or other transmission line that allows for sending high-speed data between subassemblies without interfering with other telemetry and power signals (e.g., between downhole components and surface units) already present on the transmission line. The systems thus are compatible with current tools without requiring engineering modifications to unaffected tools on the string, and allow for transmission of digital communication so that receiver information can be transmitted to the affected subassemblies. In the case of the transient EM tool, the transmit subassembly needs to send the transmit axis and transmit polarity associated with each dipole reversal.
For example, in the transient EM tool the transmitter and receiver are located on separate subassemblies that have very limited communication capabilities between them. Typically, separate subassemblies on the drill string are powered by a single common wire or other communication line. It is possible for subassemblies to communicate over this bus over a narrow band data channel around 250 kHz. This channel is not suitable for passing sync signals from transmitter to receiver, since the data channel is dedicated to tool control and data acquisition, and cannot be preempted to pass sync signals. The communication systems and interfaces described herein address these deficiencies by providing for direct communication between subassemblies over the communication line via one or more separate data channels that do not interfere with power and/or telemetry channels.
Generally, some of the teachings herein are reduced to an algorithm that is stored on machine-readable media. The algorithm is implemented by a computer and provides operators with desired output.
The systems described herein may be incorporated in a computer coupled to various downhole components, subassemblies and/or surface processing units. Exemplary components include, without limitation, at least one processor, storage, memory, input devices, output devices and the like. As these components are known to those skilled in the art, these are not depicted in any detail herein. The computer may be disposed in at least one of a surface processing unit and a downhole component.
In support of the teachings herein, various analyses and/or analytical components may 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 for operation and analyses of the apparatus and methods disclosed herein in any of several manners well-appreciated in the art. It is considered that these teachings may be, but need not be, implemented in conjunction with a set of computer executable instructions stored on 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 may provide for equipment operation, control, data collection and analysis and other functions deemed relevant by a system designer, owner, user or other such personnel, in addition to the functions described in this disclosure.
While the invention has been described with reference to exemplary embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications will be appreciated by those skilled in the art to adapt a particular instrument, situation or material to the teachings of the invention without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the appended claims.
