US20130301389A1 - System And Method For Communicating Data Between Wellbore Instruments And Surface Devices - Google Patents
System And Method For Communicating Data Between Wellbore Instruments And Surface Devices Download PDFInfo
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- US20130301389A1 US20130301389A1 US13/884,155 US201113884155A US2013301389A1 US 20130301389 A1 US20130301389 A1 US 20130301389A1 US 201113884155 A US201113884155 A US 201113884155A US 2013301389 A1 US2013301389 A1 US 2013301389A1
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- 238000005553 drilling Methods 0.000 claims abstract description 27
- 238000013500 data storage Methods 0.000 claims abstract description 23
- 238000005259 measurement Methods 0.000 claims abstract description 18
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
- E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/24—Recording seismic data
- G01V1/26—Reference-signal-transmitting devices, e.g. indicating moment of firing of shot
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
Definitions
- aspects relate to communication between a seismic source and a seismic tool positioned within a wellbore. More specifically, non-limiting aspects relate to a system and method for communicating data between wellbore instruments and surface devices.
- Logging while drilling (“LWD”) while drilling operations may be performed using one or more remote signal sources and one or more signal receiver modules disposed on a drill string.
- sources/receivers include acoustic, and electro-magnetic sources/receivers, for example similar to those used in seismic while drilling, controlled sources electromagnetics (“CSEM”), and/or wellbore electro-magnetic imaging (deep resistivity imaging) as well as seismic while drilling (“SWD”) operations.
- a seismic while drilling tool (“SWD tool”) may be incorporated or positioned in a drill string and conveyed downhole into a wellbore.
- the SWD tool typically includes at least one acoustic sensor used to measure acoustic waves that have been generated by at least one remote seismic source (for example an air-gun located near the Ocean's surface), and that have travelled through the Ocean and/or Earth formations.
- at least one remote seismic source for example an air-gun located near the Ocean's surface
- the SWD tool may record the acoustic signals sensed during time intervals in the tool memory. During some recorded time intervals, no acoustic wave generated by the remote seismic source may possibly reach the acoustic sensor of the SWD tool. For example, this may occur because the remote seismic source may not have recently been actuated. As a result, the tool memory stores data for time intervals where a seismic source has not even generated an acoustic wave.
- a method for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by a seismic tool comprising determining at least one of a drilling pause and a seismic measurement, transmitting a trigger signal to a tool controller, actuating the seismic source, receiving the trigger signal; and recording seismic waves in a data storage medium.
- a configuration for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by the seismic tool comprising: a data storage medium; a seismic source configured to produce acoustic signals; and an acoustic receiver configured to receive the acoustic signals.
- the configuration may also provide a rig controller configured to receive measurements from rig operations and transmit a trigger signal and a tool controller configured to receive the trigger signals and initiate recording in the data storage medium.
- a method for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by a seismic tool comprising: determining at least one of a drilling pause, transmitting a trigger signal to the seismic source, recording seismic waves in a data storage medium, receiving the trigger signal; and actuating the seismic source.
- FIG. 1 shows an example of a well site having a seismic source and a seismic tool in an embodiment of the disclosure.
- FIG. 2 shows a schematic of communication between a seismic source and a seismic tool in an embodiment of the disclosure.
- FIG. 3 illustrates a flow chart related to a method of triggering a seismic source in an embodiment of the disclosure.
- FIG. 4 illustrate a flow chart related to another method of triggering a seismic source in an embodiment of the disclosure.
- the disclosure provides a system and a method that may eliminate or at least reduce the number of recorded time intervals during which no acoustic wave was generated by the seismic source or could possibly reach the acoustic sensor of the SWD tool.
- Such systems and methods cure the defects of systems not configured to efficiently record acoustic waves. These systems allow for increased capabilities as well as financial gains for operators. Aspects of the system and methods provided may ensure that the time intervals during which an acoustic wave has been generated by the remote seismic source has reached the acoustic sensor are recorded, thus reducing error in the entire system and recording of seismic wave.
- the system and method may reduce the duration of the recorded time intervals during which an acoustic wave generated by the remote seismic source has reached the acoustic sensor.
- FIG. 1 shows a schematic of one example of a well site 100 , which may be located onshore or offshore.
- the well site 100 illustrated in FIG. 1 is located offshore on a drilling vessel 10 .
- the drilling vessel 10 has a drill rig 20 on it that is used to drill a well 50 in Earth's formations with a drill string 30 .
- the drill string 30 may be assembled by threadedly coupling together end to end a number of segments (“joints”) 22 of drill pipe.
- the drill string 30 may include a drill bit 12 at its lower end.
- Casing 13 and/or a blow out preventer 8 may be positioned in the well 50 as shown in FIG. 1 .
- the drill string 30 may be composed of conventional drill pipe or may be wired drill pipe or coiled tubing, as necessary and as non-limiting embodiments.
- equipment e.g., top drive or rotary table
- the drill string 30 in the present example may be a so-called “wired” drill pipe that has associated with each pipe joint a cable, such as an electrical and/or optical conductor (not shown in FIG. 1 ) for communicating electrical power and signals from wellbore instruments 14 to the surface.
- the cable is typically communicatively coupled at each end of each joint 22 , such as by use of an inductive or flux coupler.
- wired, threadedly coupled drill pipe are described in U.S. Patent Application Publication No. 2006/0225926 filed by Madhavan et al., the underlying patent application for which is assigned to the assignee of the present invention.
- Another example of wired drill pipe is described in U.S. Pat. No. 6,641,434 issued to Boyle et al. and assigned to the assignee of the present invention.
- Such drill pipe structures are only provided as examples and are not intended to limit the scope of the present disclosure.
- the wellbore instruments 14 may be in communication with a logging unit 70 , which may be positioned at the Earth's surface, as a non-limiting embodiment.
- the logging unit 70 may transmit and may receive signals to and from the wellbore instruments 14 via a telemetry system, such as mud pulse telemetry, electromagnetic telemetry, acoustic telemetry, wireline telemetry and/or wired drill pipe telemetry (previously discussed).
- the logging unit may record data obtained from the wellbore instruments 14 .
- the wellbore instruments 14 may be any tool, sensor, or device capable of obtaining data related to the formation F, the well 50 and/or the drill string 30 .
- the wellbore instruments 14 may obtain a measurement or sample of the formation F or the well 50 .
- the wellbore instruments 14 may be logging while drilling (“LWD”) instruments or measurement while drill (“MWD”) instruments.
- the formation F is a geological formation or set of geological formations which is desired to be evaluated.
- the wellbore instruments 14 may be one or more devices that measure formation characteristics: a resistivity measuring device; a directional resistivity measuring device; a sonic measuring device; a nuclear measuring device; a nuclear magnetic resonance measuring device; a pressure measuring device; a seismic measuring device; an imaging device; a formation sampling device; a natural gamma ray device; a density and photoelectric index device; a neutron porosity device; and a borehole caliper device.
- the wellbore instruments 14 may be one or more devices for measuring characteristics of the drill string 30 and/or may include one or more of the following types of measuring devices: a weight-on-bit measuring device; a torque measuring device; a vibration measuring device; a shock measuring device; a stick slip measuring device; a direction measuring device; an inclination measuring device; a natural gamma ray device; a directional survey device; a tool face device; a borehole pressure device; and a temperature device.
- the wellbore instrument 14 may be a wireline configurable tool which may be a tool commonly conveyed by wireline cable as known to one having ordinary skill in the art.
- the wireline configurable tool may be a tool for obtaining a sample of the formation F, such as a coring tool, a sampling tool, a fluid analyzing tool, and/or a tool for measuring characteristics of the formation F, such as gamma radiation measurements, nuclear measurements, density measurements, and porosity measurements.
- power may be provided to the components through use of batteries or by use of a fluid turbine, as a non-limiting embodiment.
- the wellbore instruments 14 include at least one seismic tool 60 that may include a seismic receiver, a seismic source, and/or memory for storing information or data related to the generation or receipt of a seismic wave. It should also be noted that more than one seismic tool 60 may be positioned within the wellbore instruments 14 . In addition, one or more of the seismic tools 60 may be positioned along the drill string 30 , such as at distinct distance from the rig 20 and/or the Earth's surface. For example, a plurality of seismic tools 60 may be disposed along the drill string 30 and be communicatively coupled at any position along the wired drill pipe string.
- the drilling rig 20 may have or may be in communication with a seismic source 40 .
- the seismic source 40 may be provided in another vessel located remote from the drilling vessel 10 and/or located downhole within the well 50 .
- the seismic source 40 may be actuated to generate acoustic waves that travel through the formations F, for example through the ocean and through the Earth's formations. While a “surface” source is shown in FIG. 1 , the source may alternatively or additionally be a “downhole” source conveyed in the wellbore via the drill string, for example, a source of type similar to the source described in U.S. Pat. No. 6,782,970.
- the seismic tool 60 may sense, record, and process acoustic waves generated by the seismic source 40 .
- the seismic tool 60 may utilize a seismic/acoustic receiver to receive the acoustic wave, a processor to analyze the received acoustic wave, and a memory to store data related to the processed or unprocessed acoustic wave.
- the seismic tool 60 may transmit data indicative of the recorded acoustic wave, such as filtered/decimated recorded waves.
- the data indicative of the recorded acoustic waves may be used to control the trajectory of the well, and/or determine pore pressure, among other uses. It should be appreciated by those having ordinary skill in the art that while FIG. 1 shows one seismic tool 60 and one seismic source 40 , a plurality of the seismic tools 60 and/or a plurality of seismic sources 40 may also be used.
- FIG. 2 illustrates a schematic 120 of one example implementation of the invention.
- the seismic source is in communication with the seismic tool via a telemetry system 200 , which may comprise one or more of the above telemetry systems, such as wired drill pipe.
- the seismic tool 60 may include a data storage medium 23 and/or an acoustic receiver 25 .
- the data storage medium 23 may be any device or component capable of storing data, such as flash memory, a database, read only memory.
- the acoustic receiver 25 may include one or more hydrophones, geophones or other devices capable of receiving and/or deciphering an acoustic wave.
- the acoustic receiver and the data storage medium 23 may be incorporated into the seismic tool 60 , such as internal to the seismic tool 60 , or may be external to the seismic tool 60 and in communication.
- the seismic tool 60 may have an internal clock and/or may be in communication with a clock to have a precise and accurate time with respect to a surface clock.
- a tool controller 27 may be incorporated into and/or in communication with seismic tool 60 .
- the tool controller 27 may be in communication with the seismic source 40 via the telemetry system 200 and/or a rig controller 41 .
- the rig controller 41 may be communicatively coupled to the acoustic source 40 .
- the tool controller 27 acquires waveforms (a waveform may be an acoustic wave signal) from the acoustic receiver 25 .
- the seismic tool may store the acquired acoustic wave in the data storage medium 23 .
- the rig controller 41 may be incorporated in or in communication with the logging unit 70 .
- the rig controller 41 may be in communication with the acoustic source 40 to activate the seismic source 40 .
- the seismic source 40 may be any device capable of generating acoustic waves through the Earth, such as an air gun, an explosive, for example dynamite, a plasma sound source, or a seismic vibrator.
- the rig controller 41 may receive a command signal from the tool controller 27 to activate the seismic source 40 .
- the tool controller 27 may send a command signal to the rig controller 41 to activate the seismic source 40 .
- both uphole and downhole components are coupled with a fast telemetry system, for example a telemetry system with low latency and/large bandwidth, such as wired drill pipe telemetry.
- a fast telemetry system for example a telemetry system with low latency and/large bandwidth, such as wired drill pipe telemetry.
- Operations controlled by the rig controller 41 and operations controlled by the tool controller 27 may be synchronized.
- Geological conditions may vary along the paths traversed by the seismic waves allowing the operator to accurately record signals.
- FIG. 3 illustrates a flow chart 300 of a method of actuating the seismic source 40 with the seismic tool 60 .
- a flow chart 300 For example, synchronizing the actuation of acquisition and storage of the acoustic waves generated by the seismic source 40 and measured with the acoustic receiver (or sensor) 25 of the seismic tool 60 .
- a drilling and/or tripping pause is detected.
- the tool controller 27 may determine that drilling has momentarily paused and that a seismic measurement may be performed.
- U.S. Pat. No. 6,237,404 describes at least one example of how this may be accomplished.
- the drilling and/or tripping pause may be detected by the logging unit 70 and/or one of the wellbore instruments 14 , such as the seismic tool 60 .
- the drilling and/or tripping pause may also be manually detected, such as by an operator. In such an instance, a command may be input and/or transmitted to the logging unit 70 and/or the seismic tool 60 .
- a trigger signal may be transmitted.
- the tool controller 27 may transmit a trigger signal to the rig controller 41 , such as by use of the telemetry system.
- the rig controller 41 may transmit the trigger signal to the tool controller 27 .
- Recording of the acoustic wave may be initiated as shown at step 306 .
- the recording in the data storage medium 23 of the acoustic wave measured by the acoustic receiver 25 is initiated.
- it can be initiated shortly after step 304 is performed, or after a predetermined time or duration stored or transmitted to the seismic tool 60 as a configuration parameter.
- the rig controller 41 may receive the trigger signal transmitted by the tool controller 27 .
- the tool controller 27 may receive a signal that triggering of the seismic source 40 has or is about to occur, such as from the seismic source 40 , the logging unit 70 and/or the rig controller 41 .
- the rig controller 41 may actuate the seismic source 40 upon receiving the trigger signal as shown at step 310 .
- the rig controller 41 may have instructions to await a predetermined about of time after receiving the trigger signal to actuate the seismic source 40 .
- the trigger signal may request that the seismic source 40 be actuated at a predetermined time.
- the recording of the acoustic wave by the seismic tool 60 may be terminated at step 312 .
- the tool controller 27 may terminate the recording of the acoustic wave after a predetermined time after sending the trigger signal to the rig controller 41 .
- the tool controller 27 may terminate recording upon receipt of a signal from the rig controller 41 and/or the logging unit 70 .
- the seismic source 40 may be systematically fired each time the tool controller 27 initiates the recording a waveform.
- the initiation of recording and the firing can be synchronized.
- the telemetry system should provide sufficiently fast (or repeatable) communication of the trigger signal.
- the acoustic waveform obtained by the acoustic receiver 25 may be processed as shown at step 314 .
- the acoustic waveform may be processed downhole by the seismic tool 60 and/or processed at the surface at the logging unit 70 .
- a portion of the stored waveform having signals of interest may be determined.
- the processed waveform or a portion of the waveform may be transmitted to the logging unit 70 and/or the rig controller 41 , as shown at step 316 .
- the processed waveform may be utilized for any reason known to those having ordinary skill in the art as shown at step 318 .
- the processed waveform may be used to adjust a time-depth conversion on a seismic map, to make a drilling decision, or to make a production decision.
- FIG. 4 illustrates a flow chart 400 of an alternate method of synchronizing the actuation of the seismic source 40 with the acquisition and storage of the acoustic wave by the seismic tool 60 .
- Determination of a drilling pause and/or that a seismic measurement is desired may occur at step 402 .
- the rig controller 41 a “master” controller disposed at the Earth's surface, such as the logging unit 70 , or the seismic tool 60 may identify the drilling pause or the desire for a seismic measurement.
- the rig controller 41 may receive measurement from draw-works, mud pumps, top drives, from an input interface (a keyboard) with a surface operator, or from another source as will be appreciated by those having ordinary skill in the art. These measurements or inputs may be used to determine the drilling pause and/or the desire for a seismic measurement.
- a trigger signal may be transmitted to the seismic source 40 as shown at step 404 .
- the rig controller 41 may transmit a trigger signal to the tool controller 27 .
- Another device at the surface or in communication with the seismic source 40 may transmit the trigger signal, such as via the logging unit 70 .
- the rig controller 41 may actuate the seismic source 40 as shown at step 406 .
- the rig controller 41 may actuate the seismic source a predetermined amount of time after transmitting the trigger signal.
- the tool controller 27 may receive the trigger signal as shown at step 408 .
- the tool controller 27 may initiate the recording seismic waves in the data storage medium 23 as shown at step 410 .
- the recording may be initiated immediately after receiving the trigger signal, after a predetermined amount of time, and/or at a certain time.
- the seismic tool 60 may terminate the recording of the seismic waves at a predetermined time, after a predetermined duration and/or upon receipt of a signal from the rig controller 41 or logging unit 70 .
- the seismic waves obtained may be processed, transmitted to the logging unit 70 and/or used for drilling, production or well service decisions as previously described.
- a method for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by a seismic tool may comprise determining at least one of a drilling pause and a seismic measurement; transmitting a trigger signal to a tool controller; actuating the seismic source; receiving the trigger signal; and recording seismic waves in a data storage medium.
- the method may be accomplished wherein the actuating the seismic source is accomplished through a rig controller.
- the method may be accomplished wherein the actuating the seismic source is accomplished by the rig controller that actuates the seismic source a predetermined amount of time after transmitting the trigger signal.
- the method may be accomplished wherein the actuating the seismic source is accomplished a predetermined amount of time after transmitting the trigger signal.
- the method may be accomplished wherein the receiving the trigger signal is by a tool controller.
- the method may be accomplished wherein the initiating the recording of the seismic waves is accomplished by the tool controller.
- the method may be accomplished wherein the recording the seismic waves in the data storage medium occurs one of immediately after receiving the trigger signal, after a predetermined amount of time, and at a specified time.
- a configuration for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by the seismic tool comprising: a data storage medium; a seismic source configured to produce acoustic signals; an acoustic receiver configured to receive the acoustic signals; a rig controller configured to receive measurements from rig operations and transmit a trigger signal; and a tool controller configured to receive the trigger signals and initiate recording in the data storage medium.
- a method for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by a seismic tool comprising: determining at least one of a drilling pause; transmitting a trigger signal to the seismic source; recording seismic waves in a data storage medium; receiving the trigger signal; and actuating the seismic source.
- the method may further comprise terminating the recoding of the seismic waves in the data storage medium.
Abstract
A method for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by a seismic tool having steps of determining at least one of a drilling pause and a seismic measurement, transmitting a trigger signal to a tool controller, actuating the seismic source; receiving the trigger signal and recording seismic waves in a data storage medium.
Description
- Aspects relate to communication between a seismic source and a seismic tool positioned within a wellbore. More specifically, non-limiting aspects relate to a system and method for communicating data between wellbore instruments and surface devices.
- Logging while drilling (“LWD”) while drilling operations may be performed using one or more remote signal sources and one or more signal receiver modules disposed on a drill string. Examples of sources/receivers include acoustic, and electro-magnetic sources/receivers, for example similar to those used in seismic while drilling, controlled sources electromagnetics (“CSEM”), and/or wellbore electro-magnetic imaging (deep resistivity imaging) as well as seismic while drilling (“SWD”) operations.
- Currently, conventional systems have significant difficulty in timing between transmitting seismic signals and receiving those seismic signals. Such difficulty results in excessive recording times, loss of power of critical components from inefficient use and excessive analysis time for evaluation.
- Aspects presented provide a capability to record seismic signals without the defects of conventional systems. A seismic while drilling tool (“SWD tool”) may be incorporated or positioned in a drill string and conveyed downhole into a wellbore. The SWD tool typically includes at least one acoustic sensor used to measure acoustic waves that have been generated by at least one remote seismic source (for example an air-gun located near the Ocean's surface), and that have travelled through the Ocean and/or Earth formations.
- The SWD tool may record the acoustic signals sensed during time intervals in the tool memory. During some recorded time intervals, no acoustic wave generated by the remote seismic source may possibly reach the acoustic sensor of the SWD tool. For example, this may occur because the remote seismic source may not have recently been actuated. As a result, the tool memory stores data for time intervals where a seismic source has not even generated an acoustic wave.
- In one example embodiment, a method for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by a seismic tool is presented, comprising determining at least one of a drilling pause and a seismic measurement, transmitting a trigger signal to a tool controller, actuating the seismic source, receiving the trigger signal; and recording seismic waves in a data storage medium.
- In another example embodiment, a configuration for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by the seismic tool, comprising: a data storage medium; a seismic source configured to produce acoustic signals; and an acoustic receiver configured to receive the acoustic signals. The configuration may also provide a rig controller configured to receive measurements from rig operations and transmit a trigger signal and a tool controller configured to receive the trigger signals and initiate recording in the data storage medium.
- In another example embodiment, a method for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by a seismic tool comprising: determining at least one of a drilling pause, transmitting a trigger signal to the seismic source, recording seismic waves in a data storage medium, receiving the trigger signal; and actuating the seismic source.
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FIG. 1 shows an example of a well site having a seismic source and a seismic tool in an embodiment of the disclosure. -
FIG. 2 shows a schematic of communication between a seismic source and a seismic tool in an embodiment of the disclosure. -
FIG. 3 illustrates a flow chart related to a method of triggering a seismic source in an embodiment of the disclosure. -
FIG. 4 illustrate a flow chart related to another method of triggering a seismic source in an embodiment of the disclosure. - The disclosure provides a system and a method that may eliminate or at least reduce the number of recorded time intervals during which no acoustic wave was generated by the seismic source or could possibly reach the acoustic sensor of the SWD tool. Such systems and methods cure the defects of systems not configured to efficiently record acoustic waves. These systems allow for increased capabilities as well as financial gains for operators. Aspects of the system and methods provided may ensure that the time intervals during which an acoustic wave has been generated by the remote seismic source has reached the acoustic sensor are recorded, thus reducing error in the entire system and recording of seismic wave. In addition, the system and method may reduce the duration of the recorded time intervals during which an acoustic wave generated by the remote seismic source has reached the acoustic sensor.
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FIG. 1 shows a schematic of one example of awell site 100, which may be located onshore or offshore. Thewell site 100 illustrated inFIG. 1 is located offshore on adrilling vessel 10. Thedrilling vessel 10 has adrill rig 20 on it that is used to drill a well 50 in Earth's formations with adrill string 30. Thedrill string 30 may be assembled by threadedly coupling together end to end a number of segments (“joints”) 22 of drill pipe. Thedrill string 30 may include adrill bit 12 at its lower end. Casing 13 and/or a blow out preventer 8 may be positioned in thewell 50 as shown inFIG. 1 . Thedrill string 30 may be composed of conventional drill pipe or may be wired drill pipe or coiled tubing, as necessary and as non-limiting embodiments. When thedrill bit 12 is axially urged into the formations F at the bottom of thewellbore 50 and when it is rotated by equipment (e.g., top drive or rotary table) on thedrilling rig 20, such urging and rotation causes thedrill bit 12 to axially extend thewell 50. Thedrill string 30 in the present example may be a so-called “wired” drill pipe that has associated with each pipe joint a cable, such as an electrical and/or optical conductor (not shown inFIG. 1 ) for communicating electrical power and signals fromwellbore instruments 14 to the surface. The cable is typically communicatively coupled at each end of eachjoint 22, such as by use of an inductive or flux coupler. Non-limiting examples of such wired, threadedly coupled drill pipe are described in U.S. Patent Application Publication No. 2006/0225926 filed by Madhavan et al., the underlying patent application for which is assigned to the assignee of the present invention. Another example of wired drill pipe is described in U.S. Pat. No. 6,641,434 issued to Boyle et al. and assigned to the assignee of the present invention. Such drill pipe structures are only provided as examples and are not intended to limit the scope of the present disclosure. - The
wellbore instruments 14 may be in communication with alogging unit 70, which may be positioned at the Earth's surface, as a non-limiting embodiment. Thelogging unit 70 may transmit and may receive signals to and from thewellbore instruments 14 via a telemetry system, such as mud pulse telemetry, electromagnetic telemetry, acoustic telemetry, wireline telemetry and/or wired drill pipe telemetry (previously discussed). The logging unit may record data obtained from thewellbore instruments 14. Thewellbore instruments 14 may be any tool, sensor, or device capable of obtaining data related to the formation F, the well 50 and/or thedrill string 30. Thewellbore instruments 14 may obtain a measurement or sample of the formation F or the well 50. In one non-limiting embodiment, thewellbore instruments 14 may be logging while drilling (“LWD”) instruments or measurement while drill (“MWD”) instruments. As defined, the formation F is a geological formation or set of geological formations which is desired to be evaluated. In embodiments, thewellbore instruments 14 may be one or more devices that measure formation characteristics: a resistivity measuring device; a directional resistivity measuring device; a sonic measuring device; a nuclear measuring device; a nuclear magnetic resonance measuring device; a pressure measuring device; a seismic measuring device; an imaging device; a formation sampling device; a natural gamma ray device; a density and photoelectric index device; a neutron porosity device; and a borehole caliper device. In embodiments, thewellbore instruments 14 may be one or more devices for measuring characteristics of thedrill string 30 and/or may include one or more of the following types of measuring devices: a weight-on-bit measuring device; a torque measuring device; a vibration measuring device; a shock measuring device; a stick slip measuring device; a direction measuring device; an inclination measuring device; a natural gamma ray device; a directional survey device; a tool face device; a borehole pressure device; and a temperature device. Thewellbore instrument 14 may be a wireline configurable tool which may be a tool commonly conveyed by wireline cable as known to one having ordinary skill in the art. For example, the wireline configurable tool may be a tool for obtaining a sample of the formation F, such as a coring tool, a sampling tool, a fluid analyzing tool, and/or a tool for measuring characteristics of the formation F, such as gamma radiation measurements, nuclear measurements, density measurements, and porosity measurements. For the drill string components disclosed, power may be provided to the components through use of batteries or by use of a fluid turbine, as a non-limiting embodiment. - In an embodiment, the
wellbore instruments 14 include at least oneseismic tool 60 that may include a seismic receiver, a seismic source, and/or memory for storing information or data related to the generation or receipt of a seismic wave. It should also be noted that more than oneseismic tool 60 may be positioned within thewellbore instruments 14. In addition, one or more of theseismic tools 60 may be positioned along thedrill string 30, such as at distinct distance from therig 20 and/or the Earth's surface. For example, a plurality ofseismic tools 60 may be disposed along thedrill string 30 and be communicatively coupled at any position along the wired drill pipe string. - The
drilling rig 20 may have or may be in communication with aseismic source 40. Theseismic source 40 may be provided in another vessel located remote from thedrilling vessel 10 and/or located downhole within thewell 50. Theseismic source 40 may be actuated to generate acoustic waves that travel through the formations F, for example through the ocean and through the Earth's formations. While a “surface” source is shown inFIG. 1 , the source may alternatively or additionally be a “downhole” source conveyed in the wellbore via the drill string, for example, a source of type similar to the source described in U.S. Pat. No. 6,782,970. - The
seismic tool 60 may sense, record, and process acoustic waves generated by theseismic source 40. For example, theseismic tool 60 may utilize a seismic/acoustic receiver to receive the acoustic wave, a processor to analyze the received acoustic wave, and a memory to store data related to the processed or unprocessed acoustic wave. Theseismic tool 60 may transmit data indicative of the recorded acoustic wave, such as filtered/decimated recorded waves. The data indicative of the recorded acoustic waves may be used to control the trajectory of the well, and/or determine pore pressure, among other uses. It should be appreciated by those having ordinary skill in the art that whileFIG. 1 shows oneseismic tool 60 and oneseismic source 40, a plurality of theseismic tools 60 and/or a plurality ofseismic sources 40 may also be used. -
FIG. 2 illustrates a schematic 120 of one example implementation of the invention. In the schematic 120, the seismic source is in communication with the seismic tool via atelemetry system 200, which may comprise one or more of the above telemetry systems, such as wired drill pipe. Theseismic tool 60 may include adata storage medium 23 and/or anacoustic receiver 25. Thedata storage medium 23 may be any device or component capable of storing data, such as flash memory, a database, read only memory. Theacoustic receiver 25 may include one or more hydrophones, geophones or other devices capable of receiving and/or deciphering an acoustic wave. It should be understood that the acoustic receiver and thedata storage medium 23 may be incorporated into theseismic tool 60, such as internal to theseismic tool 60, or may be external to theseismic tool 60 and in communication. Theseismic tool 60 may have an internal clock and/or may be in communication with a clock to have a precise and accurate time with respect to a surface clock. - A
tool controller 27 may be incorporated into and/or in communication withseismic tool 60. Thetool controller 27 may be in communication with theseismic source 40 via thetelemetry system 200 and/or arig controller 41. Therig controller 41 may be communicatively coupled to theacoustic source 40. When instructed to, thetool controller 27 acquires waveforms (a waveform may be an acoustic wave signal) from theacoustic receiver 25. The seismic tool may store the acquired acoustic wave in thedata storage medium 23. - The
rig controller 41 may be incorporated in or in communication with thelogging unit 70. Therig controller 41 may be in communication with theacoustic source 40 to activate theseismic source 40. Theseismic source 40 may be any device capable of generating acoustic waves through the Earth, such as an air gun, an explosive, for example dynamite, a plasma sound source, or a seismic vibrator. Therig controller 41 may receive a command signal from thetool controller 27 to activate theseismic source 40. Thetool controller 27 may send a command signal to therig controller 41 to activate theseismic source 40. - In an embodiment, both uphole and downhole components are coupled with a fast telemetry system, for example a telemetry system with low latency and/large bandwidth, such as wired drill pipe telemetry. Operations controlled by the
rig controller 41 and operations controlled by thetool controller 27 may be synchronized. - The arrangements disclosed may be used in conventional vertical wellbores, deviated wellbores and in extended reach systems as non-limiting embodiments. Geological conditions may vary along the paths traversed by the seismic waves allowing the operator to accurately record signals.
-
FIG. 3 illustrates aflow chart 300 of a method of actuating theseismic source 40 with theseismic tool 60. For example, synchronizing the actuation of acquisition and storage of the acoustic waves generated by theseismic source 40 and measured with the acoustic receiver (or sensor) 25 of theseismic tool 60. - As provided in
step 302, a drilling and/or tripping pause is detected. For example, thetool controller 27 may determine that drilling has momentarily paused and that a seismic measurement may be performed. U.S. Pat. No. 6,237,404 describes at least one example of how this may be accomplished. In another example, the drilling and/or tripping pause may be detected by thelogging unit 70 and/or one of thewellbore instruments 14, such as theseismic tool 60. The drilling and/or tripping pause may also be manually detected, such as by an operator. In such an instance, a command may be input and/or transmitted to thelogging unit 70 and/or theseismic tool 60. - As shown at
step 304, a trigger signal may be transmitted. For example, thetool controller 27 may transmit a trigger signal to therig controller 41, such as by use of the telemetry system. Instead or in addition to, therig controller 41 may transmit the trigger signal to thetool controller 27. - Recording of the acoustic wave may be initiated as shown at
step 306. In this step, the recording in thedata storage medium 23 of the acoustic wave measured by theacoustic receiver 25 is initiated. For example, it can be initiated shortly afterstep 304 is performed, or after a predetermined time or duration stored or transmitted to theseismic tool 60 as a configuration parameter. - At
step 308, as shown inFIG. 3 , therig controller 41 may receive the trigger signal transmitted by thetool controller 27. Of course, thetool controller 27 may receive a signal that triggering of theseismic source 40 has or is about to occur, such as from theseismic source 40, thelogging unit 70 and/or therig controller 41. - The
rig controller 41 may actuate theseismic source 40 upon receiving the trigger signal as shown atstep 310. Therig controller 41 may have instructions to await a predetermined about of time after receiving the trigger signal to actuate theseismic source 40. The trigger signal may request that theseismic source 40 be actuated at a predetermined time. - The recording of the acoustic wave by the
seismic tool 60 may be terminated atstep 312. For example, thetool controller 27 may terminate the recording of the acoustic wave after a predetermined time after sending the trigger signal to therig controller 41. Thetool controller 27 may terminate recording upon receipt of a signal from therig controller 41 and/or thelogging unit 70. - It is apparent, in at least an embodiment, that by applying this method, the
seismic source 40 may be systematically fired each time thetool controller 27 initiates the recording a waveform. In addition, the initiation of recording and the firing can be synchronized. Of course, to achieve this, the telemetry system should provide sufficiently fast (or repeatable) communication of the trigger signal. - The acoustic waveform obtained by the
acoustic receiver 25 may be processed as shown atstep 314. The acoustic waveform may be processed downhole by theseismic tool 60 and/or processed at the surface at thelogging unit 70. In addition, a portion of the stored waveform having signals of interest may be determined. The processed waveform or a portion of the waveform may be transmitted to thelogging unit 70 and/or therig controller 41, as shown atstep 316. - The processed waveform may be utilized for any reason known to those having ordinary skill in the art as shown at
step 318. For example, the processed waveform may be used to adjust a time-depth conversion on a seismic map, to make a drilling decision, or to make a production decision. -
FIG. 4 illustrates aflow chart 400 of an alternate method of synchronizing the actuation of theseismic source 40 with the acquisition and storage of the acoustic wave by theseismic tool 60. Determination of a drilling pause and/or that a seismic measurement is desired may occur atstep 402. For example, therig controller 41, a “master” controller disposed at the Earth's surface, such as thelogging unit 70, or theseismic tool 60 may identify the drilling pause or the desire for a seismic measurement. Therig controller 41 may receive measurement from draw-works, mud pumps, top drives, from an input interface (a keyboard) with a surface operator, or from another source as will be appreciated by those having ordinary skill in the art. These measurements or inputs may be used to determine the drilling pause and/or the desire for a seismic measurement. - A trigger signal may be transmitted to the
seismic source 40 as shown atstep 404. For example, therig controller 41 may transmit a trigger signal to thetool controller 27. Another device at the surface or in communication with theseismic source 40 may transmit the trigger signal, such as via thelogging unit 70. Therig controller 41 may actuate theseismic source 40 as shown atstep 406. As an example, therig controller 41 may actuate the seismic source a predetermined amount of time after transmitting the trigger signal. Thetool controller 27 may receive the trigger signal as shown atstep 408. - The
tool controller 27 may initiate the recording seismic waves in thedata storage medium 23 as shown atstep 410. The recording may be initiated immediately after receiving the trigger signal, after a predetermined amount of time, and/or at a certain time. Theseismic tool 60 may terminate the recording of the seismic waves at a predetermined time, after a predetermined duration and/or upon receipt of a signal from therig controller 41 orlogging unit 70. The seismic waves obtained may be processed, transmitted to thelogging unit 70 and/or used for drilling, production or well service decisions as previously described. - In one example embodiment, a method for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by a seismic tool is presented. The method may comprise determining at least one of a drilling pause and a seismic measurement; transmitting a trigger signal to a tool controller; actuating the seismic source; receiving the trigger signal; and recording seismic waves in a data storage medium.
- In another example embodiment, the method may be accomplished wherein the actuating the seismic source is accomplished through a rig controller.
- In another example embodiment, the method may be accomplished wherein the actuating the seismic source is accomplished by the rig controller that actuates the seismic source a predetermined amount of time after transmitting the trigger signal.
- In another example embodiment, the method may be accomplished wherein the actuating the seismic source is accomplished a predetermined amount of time after transmitting the trigger signal.
- In another example embodiment, the method may be accomplished wherein the receiving the trigger signal is by a tool controller.
- In another example embodiment, the method may be accomplished wherein the initiating the recording of the seismic waves is accomplished by the tool controller.
- In another example embodiment, the method may be accomplished wherein the recording the seismic waves in the data storage medium occurs one of immediately after receiving the trigger signal, after a predetermined amount of time, and at a specified time.
- In another example embodiment, a configuration for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by the seismic tool is presented comprising: a data storage medium; a seismic source configured to produce acoustic signals; an acoustic receiver configured to receive the acoustic signals; a rig controller configured to receive measurements from rig operations and transmit a trigger signal; and a tool controller configured to receive the trigger signals and initiate recording in the data storage medium.
- In another example embodiment, a method for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by a seismic tool comprising: determining at least one of a drilling pause; transmitting a trigger signal to the seismic source; recording seismic waves in a data storage medium; receiving the trigger signal; and actuating the seismic source.
- In another example, the method may further comprise terminating the recoding of the seismic waves in the data storage medium.
- While the invention has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope of the invention as disclosed herein. Accordingly, the scope of the invention should be limited only by the attached claims.
Claims (10)
1. A method for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by a seismic tool comprising:
determining at least one of a drilling pause and a seismic measurement;
transmitting a trigger signal to a tool controller;
actuating the seismic source;
receiving the trigger signal; and
recording seismic waves in a data storage medium.
2. The method according to claim 1 , wherein the actuating the seismic source is accomplished through a rig controller.
3. The method according to claim 2 , wherein the actuating the seismic source is accomplished by the rig controller that actuates the seismic source a predetermined amount of time after transmitting the trigger signal.
4. The method according to claim 1 , wherein the actuating the seismic source is accomplished a predetermined amount of time after transmitting the trigger signal.
5. The method according to claim 1 , wherein the receiving the trigger signal is by a tool controller.
6. The method according to claim 1 , wherein the initiating the recording of the seismic waves is accomplished by the tool controller.
7. The method according to claim 1 , wherein the recording the seismic waves in the data storage medium occurs one of immediately after receiving the trigger signal, after a predetermined amount of time, and at a specified time.
8. A configuration for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by a seismic tool, comprising:
a data storage medium;
a seismic source configured to produce acoustic signals;
an acoustic receiver configured to receive the acoustic signals;
a rig controller configured to receive measurements from rig operations and transmit a trigger signal; and
a tool controller configured to receive the trigger signals and initiate recording in the data storage medium.
9. A method for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by a seismic tool comprising:
determining at least one of a drilling pause;
transmitting a trigger signal to the seismic source;
recording seismic waves in a data storage medium;
receiving the trigger signal; and
actuating the seismic source.
10. The method according to claim 9 , further comprising:
terminating the recoding of the seismic waves in the data storage medium.
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PCT/US2011/059388 WO2012064610A2 (en) | 2010-11-08 | 2011-11-04 | System and method for communicating data between wellbore instruments and surface devices |
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US10190377B2 (en) * | 2013-06-17 | 2019-01-29 | Guy Wheater | Mud sensing hole finder |
US11015429B2 (en) | 2015-09-10 | 2021-05-25 | Halliburton Energy Services, Inc. | Passive ranging using acoustic energy originating from a target wellbore |
US10458233B2 (en) * | 2016-12-29 | 2019-10-29 | Halliburton Energy Services, Inc. | Sensors for in-situ formation fluid analysis |
Also Published As
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BR112013011342A2 (en) | 2017-10-31 |
WO2012064610A2 (en) | 2012-05-18 |
JP2013545980A (en) | 2013-12-26 |
WO2012064610A3 (en) | 2012-08-16 |
MX2013005175A (en) | 2013-07-29 |
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