Patent Document

BACKGROUND  
       [0001]     The present invention relates to the field of telemetry systems. In particular, the invention relates to a method and system for well telemetry.  
         [0002]     Coiled tubing is used in conventional well operations to convey downhole tools such as perforating guns, bridge plugs, and packers and to fish for objects downhole. Each of these uses can benefit from accurate measurements made by instruments located at the downhole end of the coiled tubing. For example, a measurement of the depth of a downhole device can be provided in real-time by a Coiled Tubing Collar Locator (CTCL). The CTCL includes an electromagnetic casing collar locator to detect the signal disturbance of the magnetic field as the tool passes a casing collar. This is useful information because the depths of the casing collars are known. In order to communicate that event to the uphole portion of the coiled tubing string, the CTCL changes the pressure of a circulation fluid, such as water, by opening and closing a side port by means of a solenoid valve. After a delay that can be calculated, the change in pressure is measurable uphole indicating the depth of the downhole device. Due to the physical characteristics of the circulation fluid, the maximum rate of data that can be communicated by pressure changes is low. It is difficult, therefore, to transmit more complex measurements, for example, formation measurements, uphole. In addition, some wells do not employ circulation fluid, which disables the CTCL-to-surface communication method.  
       SUMMARY  
       [0003]     In general, in one aspect, the invention features a system for borehole telemetry. The borehole telemetry system includes a coiled tubing string that is located in the borehole. A receiver is coupled to the coiled tubing string. In one possible implementation, the receiver is located inside the coiled tubing string. A transmitter is also coupled to the coiled tubing string. The transmitter generates signals guided for at least a portion of their path by the entire internal cross-section of the coiled tubing string to the receiver.  
         [0004]     In general, in another aspect, the invention features a system for borehole telemetry. The borehole telemetry system includes a coiled tubing string that is substantially rotatably fixed in the borehole. A receiver is coupled to the coiled tubing string. In one possible implementation, the receiver is located inside the coiled tubing string. A transmitter is also coupled to the coiled tubing string. The transmitter generates signals guided for at least a portion of their path by the coiled tubing string to the receiver.  
         [0005]     In general, in another aspect, the invention features a method for communicating in a borehole. Signals are generated at a transmitter that is coupled to a coiled tubing string in the borehole. The signals are transmitted for at least a portion of their path across in the entire internal cross-section of the coiled tubing string. The signals are received at a receiver coupled to the coiled tubing string. 
     
    
     BRIEF DESCRIPTION OF THE DRAWINGS  
       [0006]      FIG. 1  is a diagram of an uphole portion of one system according to the invention.  
         [0007]      FIG. 2  is a diagram of a downhole portion of one system according to the invention.  
         [0008]      FIG. 3  is a flowchart of a method for communicating in a borehole. 
     
    
     DETAILED DESCRIPTION  
       [0009]     The uphole portion  105  of a system for borehole telemetry is illustrated in  FIG. 1 . The uphole portion  105  functions together with the downhole portion  205  (shown in  FIG. 2 ) to enable communications from a downhole device such as a sensor to an uphole location. The uphole and downhole portions  105  and  205  are connected by a coiled tubing string  110 . In one embodiment, the coiled tubing string  110  is mounted in a rotatably fixed configuration relative to the borehole, as opposed to a rotational mounting, for example for drilling. The uphole portion  105  includes a receiver connector  115  coupled to the coiled tubing string  110 . The receiver connector  115  couples the coiled tubing string  110  to a receiver  130  via an antenna  120  and a communications cable  125 . The receiver  130  is coupled to a processor  135  that is coupled to electronic storage  140 . In one embodiment, the processor  135  is part of a computer in a rigsite network and the electronic storage  140  is a hard drive accessible to that network.  
         [0010]     In addition to the antenna  120 , the receiver  130  can include a low-noise amplifier and a frequency down-converter to prepare the received signal for demodulation. The processor  135  can demodulate the signal provided by the receiver  130 . The processor  135  can also filter and phase match the demodulated signal as required. The data represented by the signal can be stored in the electronic storage  140  and it can also be displayed, for example, on a monitor of the rigsite network. Instead or in addition to local display and storage, the data can be remotely transmitted by satellite or telecommunication methods.  
         [0011]     In one embodiment the interior of the coiled tubing  110  is filled with air. In another embodiment, a gas such as nitrogen gas  145  is introduced to the coiled tubing string  110  interior. The coiled tubing string  110  can be a welded pipe manufactured in a tube mill from bias welded flat strips of low-alloy, high-strength carbon steel. In one embodiment, a high degree of smoothness on the internal wall of the coiled tubing string  110  assists in the transmission of electromagnetic waves. A different coiled tubing string  110  is composed of a continuous helical metal conductor with a lossy housing made of composite material. The extent to which electromagnetic waves are transmitted in particular modes can be affected by the materials of the coiled tubing string  110 . For example, the composite material housing can reduce the portion of the electromagnetic wave energy transmitted in non-TE modes. The modes of transmission are discussed in more detail with respect to the transmitter of  FIG. 2 . In one embodiment, the coiled tubing string has an inner diameter of 2″. In another embodiment, the inner diameter is 3″.  
         [0012]      FIG. 2  illustrates the downhole portion  205  of a system for borehole telemetry. The downhole portion  205  is coupled to the coiled tubing string  110 . The downhole portion includes a tool  210  that houses a transmitter  225  that includes antenna  215 . A coaxial insulator  220  protects a communications cable that connects the antenna  215  to other components of the transmitter  225 . A sensor  235  takes measurements that are then represented by an electrical signal. The sensor  235  can be a CTCL or a device for measuring other parameters such as pressure and temperature. Coupled between the sensor  235  and transmitter  225  is a circuit board  230  that can also include a battery pack. The battery pack provides power to all the components. The circuit board  230  receives an electrical signal from the sensor  235  and converts that signal to a format that can be modulated on a microwave carrier. The newly formatted signal is communicated to the transmitter  225  that uses it to modulate a microwave carrier, e.g., a carrier in the 300 MHz to 300 GHz range. The transmitter  225  can include a frequency up-converter and a power amplifier as well as the antenna  215 . Conductor losses are low at carrier frequencies of 5 GHz and 30 GHz and a frequency within that range is used in one embodiment.  
         [0013]     In addition to the carrier frequency, the transmitter  225  also determines the balance of modes in which an electromagnetic wave is launched from the antenna  215 . A launched signal will include components from transverse electric (TE) and transverse magnetic (TM) modes. In one embodiment, the transmitter  225  is configured to launch the signal predominately in TE01 or TE11 mode. TE01 mode requires higher carrier frequencies than TE11, but has the advantage of transmitting microwave signals over long distances with low loss. TE11 is the dominant TE mode and can be used with lower transmission frequencies. In one embodiment, the transmitter  225  is configured to launch the signal predominately in TE11 mode initially and in TE01 mode after a particular depth has been reached. In another embodiment, the transmitter mode is determined based on well characteristics before the transmitter  225  is inserted into the borehole.  
         [0014]      FIG. 3  is a flowchart of a method for communicating in a borehole in one implementation of the invention. A sensor mounted on a coiled tubing string is lowered downhole. At  310 , the sensor detects the signal disturbance of the magnetic field as it passes a casing collar. As discussed above, in different embodiments sensors that measure other parameters, including but not limited to pressure and temperature, can be used with the method. At  320 , the detection of the casing collar is communicated by the sensor to a downhole transmitter that is also mounted on the coiled tubing string. At  330 , the transmitter modulates a microwave signal having a frequency of approximately 5-30 GHz with an amplified signal that represents the detection of the casing collar. At  340 , the transmitter antenna launches the modulated microwave into the entire cross-section of a nitrogen gas-filled coiled tubing string. As discussed above, the transmitter can be configured to launch the signal predominately in a particular mode, e.g., TE11 or TE01. At  350 , the antenna of a receiver located uphole from the transmitter detects the modulated microwave that has traversed the coiled tubing string waveguide. At  360 , the receiver converts the frequency of the detected microwave signal. At  370 , a processor demodulates the microwave signal to generate the signal representing the detection of the casing collar. At  380 , the signal corresponding to the detection of the casing collar is stored. In one embodiment, the signal is stored by calculating a depth based on the signal that is stored along with the time corresponding to that depth.  
         [0015]     The foregoing description of the embodiments of the invention has been presented for the purposes of illustration and description. It is not intended to be exhaustive or to limit the invention to the precise form disclosed. Many modifications and variations are possible in light of the above teaching. It is intended that the scope of the invention be limited not by this detailed description, but rather by the claims appended hereto.

Technology Category: 3