WO2008076110A1 - Source multipolaire rotative - Google Patents

Source multipolaire rotative Download PDF

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Publication number
WO2008076110A1
WO2008076110A1 PCT/US2006/048310 US2006048310W WO2008076110A1 WO 2008076110 A1 WO2008076110 A1 WO 2008076110A1 US 2006048310 W US2006048310 W US 2006048310W WO 2008076110 A1 WO2008076110 A1 WO 2008076110A1
Authority
WO
WIPO (PCT)
Prior art keywords
acoustic
multipolar
acoustic source
source
receiver
Prior art date
Application number
PCT/US2006/048310
Other languages
English (en)
Inventor
Clovis Bonavides
Batakrishna Mandal
Georgios Varsamis
Arthur Cheng
Original Assignee
Halliburton Energy Services, Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Halliburton Energy Services, Inc. filed Critical Halliburton Energy Services, Inc.
Priority to PCT/US2006/048310 priority Critical patent/WO2008076110A1/fr
Publication of WO2008076110A1 publication Critical patent/WO2008076110A1/fr

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Classifications

    • 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
    • G01V1/44—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well

Definitions

  • the information disclosed herein relate to acoustic sources and receivers, including multipolar sources.
  • Wireline and logging while drilling tools may include multiple acoustic sources. Such sources may he used to determine various geological formation properties hy using the sources to launch acoustic signals into formations adjacent the borehole, so that signals reflected/modulated by the borehole and the surrounding formations may be received by one or more receivers. Received signals may include compressional waves (P-waves), shear waves (S-waves), and borehole guided waves (e.g. Stoneley, flexural, screw waves, etc). The signal arrival times and other characteristics of the received signals may be processed to determine various formation properties.
  • P-waves compressional waves
  • S-waves shear waves
  • borehole guided waves e.g. Stoneley, flexural, screw waves, etc.
  • a typical source arrangement may include a first bipolar source mounted orthogonally with respect to a second bipolar source. Both sources are typically mounted so as to operate at the same depth, and have a fixed orientation with respect to one or more receivers. As the bipolar sources travel along the length of a borehole, they are driven by an amplifier so as to emit powerful acoustic pulses for reception by the receivers.
  • FIGs. IA and IB are conceptual block diagrams and schematics of apparatus according to various embodiments of the invention.
  • FIGs. 2A and 2B illustrate apparatus and systems according to various embodiments of the invention.
  • FIG. 3 is a flow chart illustrating several methods according to various embodiments of the invention.
  • FIG.4 is a block diagram of an article according to various embodiments of the invention.
  • multipole transmitters may be used to excite borehole guided modes (e.g., Stoneley, flexural, screw, etc.).
  • a multipole transmitter of order N is implemented using 2N crystals (e.g., piezoelectric crystals) located on a circle having an inter-azimuthal spacing of about ⁇ r/N radians and alternating in sign (polarity), where N comprises a positive integer.
  • the crystals are mounted on a substantially flat plate, or some other substantially symmetrical object, such as a square beam, hexagonal beam, etc.
  • FIGs. IA and IB are conceptual block diagrams and schematics of apparatus 100 according to various embodiments of the invention. For example, turning to FIG.
  • an apparatus 100 may include an acoustic receiver 104 and a multipolar acoustic source 108 that is physically rotatable with respect to the acoustic receiver 104 about an azimuthal axis 112 passing through the multipolar acoustic source 108.
  • the azimuthal axis also passes through the acoustic receiver 104, which may at times comprise an array of acoustic sensors, as is known to those of ordinary skill in the art.
  • the multipolar acoustic source 108 may be made rotatable partially (e.g., via some variable-ratio mechanical linkage), or completely independent of the acoustic receiver 104.
  • Multipolar sources 108 may comprise bipolar 108', quadrupolar
  • the multipolar acoustic source 108 may comprise a bipolar acoustic source 108' having a substantially flat metal plate 116 disposed between two substantially planar crystals 120.
  • the substantially flat metal plate 116 may have a substantially rectangular shape, and the plate thickness may be relatively thin compared to the sum of the plate width and plate height, such as less than 1/10 of the sum of the plate width and the plate height.
  • the substantially planar crystals 120 may be substantially identical.
  • the multipolar acoustic source 108 may comprise a quadrapolar acoustic source 108".
  • the source 108" may include a substantially symmetrical metallic object 124 to separate a plurality of substantially planar crystals 120, and the plurality of substantially planar crystals 120 may again be substantially identical.
  • Other arrangements such as hexapolar and octapolar sources, known to those of ordinary skill in the art, may also be used.
  • Other components of the apparatus 100 may include a pressurized container 128 having walls of varying thickness to contain the multipolar acoustic source 108.
  • the apparatus may also include a resolver 132 to provide a signal proportional to the azimuthal location (about the azimuthal axis 112) of the multipolar acoustic source 108.
  • the apparatus 100 may include one or more motors 136 to rotate the multipolar acoustic source 108 about the azimuthal axis 112.
  • the apparatus 100 may also include logic 140, perhaps comprising a programmable drive, to actuate the motor 136 that rotates the multipolar acoustic source 108 about the azimuthal axis 112.
  • the logic 140 of the apparatus 100 may comprise many components, such as velocity anisotropy computation logic to receive electrical signals from the acoustic receiver 104 and to determine the anisotropy, and in some instances, the stress direction for a geological formation 148 proximate to the multipolar acoustic source 108.
  • the logic 140 may include drilling mechanics logic to direct a drill bit along a drilling path 150 in the geological formation 148 determined at least in part by the formation anisotropy.
  • the apparatus 100 may also include a data acquisition system 152 to couple to the acoustic receiver 104 and to receive signals generated by the multipolar acoustic source 108 via the receiver 104.
  • the data acquisition system 152, and any of its components, may be located downhole, perhaps in a tool housing, or at the surface 166, perhaps as part of a computer workstation 156 in a surface logging facility.
  • FIG. IB provides a schematic of circuitry 158 that may be used as part of the control electronics for one transducer in a pair of dipole source transducers, forming a part of the multipolar acoustic source 108.
  • the dipole source transducer drive circuit employs a linear driver configuration.
  • the acoustic signal generated by the driven transducer 120 may track the analog signal generated by a digital-to-analog converter (DAC) 160 in response to a digital waveform provided by a controller 164.
  • the waveform may be stored in a memory 168 or may be generated in accordance with software stored therein.
  • the waveform may be transmitted from computers or other logic located at the surface 166.
  • Two circuits 158 may be used to drive a dipole pair of crystals, and four such circuits 158 might be used to drive a set of four crystals, such as the quadrupole (multipolar) acoustic source 108 shown in FIG. IB [0019]
  • the driven transducer 120 may operate to convert an electrical signal into an acoustic signal through voltage-induced expansion and contraction.
  • the expansion and contraction of the transducer 120 may be respectively caused by positive and negative voltage differences across its terminals. Positive voltage differences may be induced in the secondary winding of a transformer 172 when the transistor 174 turns on and transistor 176 is off. Conversely, negative voltage differences may be induced when transistor 176 turns on and transistor 174 is off.
  • the control signals for transistors 174, 176 may be provided from a rectifier/splitter module via amplifiers 180, 182.
  • the rectifier/splitter module 178 splits an input signal into two output signals.
  • One of the output signals may follow the input signal when the input signal is positive, and be set to zero when the input signal is negative.
  • the other output signal may represent the negative of the input signal when the input signal is negative, and be set to zero when the input signal is positive.
  • both output signals may be presented as always positive or zero.
  • a summing amplifier 184 maybe used with a variety of resistance values to weight voltages on the outer terminals of the primary winding of the transformer 172 for tracking their respective portions of the analog signal as closely as possible.
  • two dipole sources forming a part of the multipolar acoustic source 108 may be excited in sequence, perhaps using resolver decoding circuitry 186 to determine the location of the multipole source 108 about the azimuthal axis 112.
  • an excitation sequence for the multipolar acoustic source 108 responsive to the azimuthal location of the source 108 may be programmed into the controller 164.
  • the timing between consecutive activations may also be programmable. That is, the transducers 120 may be fired individually or concurrently.
  • the programrnability of the disclosed acoustic tool makes possible a variety of improved logging methods.
  • multiple frequencies are used.
  • the dipole waveform frequency may be set to a low frequency (e.g. 0.5 kHz), and in the next firing sequence, the dipole waveform frequency may be set to a high frequency (e.g. 3 kHz).
  • the controller 164 may be programmed to alternate between two frequencies or cycle through multiple frequencies. In this manner, acoustic logs at multiple frequencies may be acquired in a single run. Multiple waveforms, including chirped dipole waveforms, may be transmitted.
  • the controller 164 may also be programmed to adjust the duration of the transmitted waveform to compensate for extraneous noise. Increasing the waveform duration increases the transmitted energy, thereby improving the measurement signal-to-noise ratio (SNR). Alternatively, the duration may be altered to tailor the bandwidth of the waveform. [0024] In some embodiments, the controller 164 is programmed to excite or fire the transducers 120 in an order and at a rate that depends on the desired resolution of measurements based on a given waveform. For example, a low frequency dipole log may require fewer measurements than a high-frequency dipole log. Accordingly, the controller 164 may be programmed to fire the transducers 120 with a low-frequency waveform less often than firing them with a high-frequency waveform (e.g. half as often). This may permit faster logging or reduce the telemetry bandwidth of the telemetry transmitter 188 used to transmit acquired data to the surface.
  • SNR measurement signal-to-noise ratio
  • the adjusted parameters may be controlled from the surface 166, either automatically or by manual control. They may also be controlled within the apparatus 100 itself (e.g. using adaptive control mechanisms or algorithms in the logic 140, or stored in a memory to be executed by the processor of the data acquisition system 152). Further information regarding possible excitation sequences and programmable parameters may be gained by studying U.S. Patent No. 6,661,737, assigned to the Halliburton Company and incorporated herein by reference in its entirety.
  • FIGs. 2A and 2B illustrate apparatus 200 and systems 264 according to various embodiments of the invention, which may comprise portions of a tool body 270 as part of a wireline logging operation, or of a downhole tool 224 as part of a downhole drilling operation.
  • FIG. 2 A shows a well during wireline logging operations.
  • a drilling platform 286 is equipped with a derrick 288 that supports a hoist 290.
  • Drilling of oil and gas wells is commonly carried out using a string of drill pipes connected together so as to form a drilling string that is lowered through a rotary table 210 into a wellbore or borehole 212.
  • the drilling string has been temporarily removed from the borehole 212 to allow a wireline logging tool body 270, such as a probe or sonde, to be lowered by wireline or logging cable 274 into the borehole 212.
  • the tool body 270 is lowered to the bottom of the region of interest and subsequently pulled upward at a substantially constant speed.
  • instruments e.g., logic 140 shown in FIG.
  • a system 264 may also form a portion of a drilling rig 202 located at a surface 204 of a well 206.
  • the drilling rig 202 may provide support for a drill string 208.
  • the drill string 208 may operate to penetrate a rotary table 210 for drilling a borehole 212 through subsurface formations 214.
  • the drill string 208 may include a Kelly 216, drill pipe 218, and a bottom hole assembly 220, perhaps located at the lower portion of the drill pipe 218.
  • the bottom hole assembly 220 may include drill collars 222, a downhole tool 224, and a drill bit 226.
  • the drill bit 226 may operate to create a borehole 212 by penetrating the surface 204 and subsurface formations 214.
  • the downhole tool 224 may comprise any of a number of different types of tools including MWD (measurement while drilling) tools, LWD (logging while drilling) tools, and others.
  • Kelly 216, the drill pipe 218, and the bottom hole assembly 220 may be rotated by the rotary table 210.
  • the bottom hole assembly 220 may also be rotated by a motor (e.g., a mud motor) that is located downhole.
  • the drill collars 222 may be used to add weight to the drill bit 226.
  • the drill collars 222 also may stiffen the bottom hole assembly 220 to allow the bottom hole assembly 220 to transfer the added weight to the drill bit 226, and in turn, assist the drill bit 226 in penetrating the surface 204 and subsurface formations 214.
  • a mud pump 232 may pump drilling fluid
  • drilling mud (sometimes known by those of skill in the art as "drilling mud") from a mud pit 234 through a hose 236 into the drill pipe 218 and down to the drill bit 226.
  • the drilling fluid can flow out from the drill bit 226 and be returned to the surface 204 through an annular area 240 between the drill pipe 218 and the sides of the borehole 212.
  • the drilling fluid may then be returned to the mud pit 234, where such fluid is filtered.
  • the drilling fluid can be used to cool the drill bit 226, as well as to provide lubrication for the drill bit 226 during drilling operations. Additionally, the drilling fluid may be used to remove subsurface formation 214 cuttings created by operating the drill bit 226.
  • the system 264 may include a drill collar 222, a downhole tool 224, and/or a wireline logging tool body 270 to house one or more apparatus 200, similar to or identical to the apparatus 100 described above and illustrated in FIGs. IA and IB.
  • the term "housing” may include any one or more of a drill collar 222, a downhole tool 224, and a wireline logging tool body 270 (all having an outer wall to enclose a rotatable multipolar acoustic source).
  • the downhole tool 224 may comprise an LWD tool or MWD tool.
  • the tool body 270 may comprise a wireline logging tool, including a probe or sonde, for example, coupled to a logging cable 274. Many embodiments may be realized.
  • a system 264 may include a display 296 to present formation anisotropy information in graphic form based on processed signals received by the acoustic receiver and originated by the multipolar acoustic source.
  • a system 264 may also include velocity anisotropy computation logic, perhaps as part of a surface logging facility 292, or a computer workstation 254, to receive electrical signals from the acoustic receiver and to determine formation anisotropy for a geological formation 214 proximate to the multipolar acoustic source.
  • the system 264 may include drilling mechanics logic to direct a drill bit 226 along a drilling path in the geological formation 214 determined at least in part by the formation anisotropy.
  • the system 264 may also include a data acquisition system to couple to the acoustic receiver and to receive signals generated by the multipolar acoustic source. Either or both of the drilling mechanics logic and the data acquisition system may be included as part of a surface logging facility 292, or a computer workstation 254.
  • Such modules may include hardware circuitry, and/or a processor and/or memory circuits, software program modules and objects, and/or firmware, and combinations thereof, as desired by the architect of the apparatus 100, 200 and systems 264, and as appropriate for particular implementations of various embodiments.
  • such modules may be included in an apparatus and/or system operation simulation package, such as a software electrical signal simulation package, a power usage and distribution simulation package, a capacitance-inductance simulation package, a power/heat dissipation simulation package, and/or a combination of software and hardware used to simulate the operation of various potential embodiments.
  • apparatus and systems of various embodiments can be used in applications other than for logging operations, and thus, various embodiments are not to be so limited.
  • the illustrations of apparatus 100, 200 and systems 264 are intended to provide a general understanding of the structure of various embodiments, and they are not intended to serve as a complete description of all the elements and features of apparatus and systems that might make use of the structures described herein.
  • FIG. 3 is a flow chart illustrating several methods according to various embodiments of the invention.
  • the method 311 may begin with exciting a multipolar acoustic source to generate an acoustic signal at a selected azimuthal location while rotating the multipolar acoustic source with respect to an acoustic receiver at block 321. Rotation may occur about an azimuthal axis passing through the multipolar acoustic source (and perhaps the acoustic receiver).
  • the method may include receiving the acoustic signal as a received acoustic signal by the acoustic receiver at block 325.
  • the method 311 may include storing data associated with the received acoustic signal and the selected azimuthal location in a memory at block 329, and/or telemetering data associated with the received acoustic signal to a remote collection station (e.g., a surface logging facility or computer) at block 333.
  • a remote collection station e.g., a surface logging facility or computer
  • the method 311 may continue at block 337 with processing data associated with the received acoustic signal, perhaps to determine geologic formation anisotropy, to detect an increasing sonic propagation velocity in the geologic formation, or to determine geometry (e.g., location and orientation) of a fracture or natural/tectonic stress direction in the geological formation, each of these methods being known to those of ordinary skill in the art.
  • Using a rotatable multipolar source may permit the generation of data which, when processed, allows anisotropy to be determined or resolved to less than ⁇ r/6 radians along the azimuthal axis.
  • the method 311 may include displaying a graphic representation of the formation anisotropy on a human-readable display at block 341.
  • the method 311 may include, at block 349, guiding a drill bit along a drilling path in a geological formation according to the geometry of the determined formation anisotropy (e.g., either parallel to or perpendicular to the formation anisotropy).
  • the method 311 may also include, at block 349, guiding a drill bit along a path substantially orthogonal to the longitudinal axis of a fracture direction, or a maximum (either natural or tectonic) stress direction, as determined by processing the data at block 337.
  • the methods described herein do not have to be executed in the order described, or in any particular order.
  • various activities described with respect to the methods identified herein can be executed in iterative, serial, or parallel fashion.
  • Information, including parameters, commands, operands, and other data, can be sent and received in the form of one or more carrier waves.
  • a software program can be launched from a computer-readable medium in a computer-based system to execute the functions defined in the software program.
  • One of ordinary skill in the art will further understand the various programming languages that may be employed to create one or more software programs designed to implement and perform the methods disclosed herein.
  • the programs may be structured in an object-orientated format using an object-oriented language such as Java or C++.
  • the programs can be structured in a procedure-orientated format using a procedural language, such as assembly or C.
  • the software components may communicate using any of a number of mechanisms well known to those skilled in the art, such as application program interfaces or interprocess communication techniques, including remote procedure calls.
  • FIG. 4 is a block diagram of an article 485 of manufacture according to various embodiments, such as a computer, a memory system, a magnetic or optical disk, or some other storage device.
  • the article 485 may include a processor 487 coupled to a machine-accessible medium such as a memory 489 (e.g., removable storage media, as well as any memory including an electrical, optical, or electromagnetic conductor) having associated information 491 (e.g., computer program instructions and/or data), which when accessed, results in a machine (e.g., the processor 487) performing such actions as exciting a multipolar acoustic source to generate an acoustic signal at a selected azimuthal location while rotating the multipolar acoustic source with respect to an acoustic receiver about an azimuthal axis passing through the multipolar acoustic source.
  • a machine-accessible medium such as a memory 489 (e.g., removable storage media, as well as any memory including an electrical, optical, or electromagnetic conductor) having associated information 491 (e.g., computer program instructions and/or data), which when accessed, results in a machine (e.g., the processor 487) performing such actions as exciting a multi
  • Additional actions may include receiving the acoustic signal to provide a received acoustic signal by the acoustic receiver, and storing data associated with the received acoustic signal and the selected azimuthal location in a memory (perhaps the same memory 489). Further actions may include processing the data to determine formation anisotropy of a formation proximate to the multipolar acoustic source with a resolution of less than ⁇ /6 radians, determining the geometry of a fracture or natural/tectonic stress direction in a geological formation based on processing the data, and guiding a drill bit along a path substantially orthogonal to the longitudinal axis of the fracture direction or stress direction.
  • Using the apparatus, systems, and methods disclosed herein may reduce discrepancies that arise when unmatched sources are used in borehole logging operations.
  • a rotatable multipolar acoustic source may also enable the use of greater power and larger transducer elements for a given tool body housing volume.
  • inventive subject matter may be referred to herein, individually and/or collectively, by the term "invention" merely for convenience and without intending to voluntarily limit the scope of this application to any single invention or inventive concept if more than one is in fact disclosed.
  • inventive subject matter may be referred to herein, individually and/or collectively, by the term "invention" merely for convenience and without intending to voluntarily limit the scope of this application to any single invention or inventive concept if more than one is in fact disclosed.
  • inventive subject matter merely for convenience and without intending to voluntarily limit the scope of this application to any single invention or inventive concept if more than one is in fact disclosed.

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  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Acoustics & Sound (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geology (AREA)
  • Remote Sensing (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • General Physics & Mathematics (AREA)
  • Geophysics (AREA)
  • Geophysics And Detection Of Objects (AREA)

Abstract

Dans certains modes de réalisation de l'invention, un appareil et un système ainsi qu'un procédé et un article, peuvent fonctionner pour exciter une source acoustique multipolaire afin de générer un signal acoustique au niveau d'un emplacement azimutal sélectionné tout en faisant tourner la source acoustique multipolaire par rapport à un récepteur acoustique autour d'un axe azimutal traversant la source acoustique multipolaire. Les opérations peuvent comprendre, entre autre, la réception du signal acoustique en tant que signal acoustique reçu par le récepteur acoustique, et le stockage des données associées au signal acoustique reçu dans une mémoire.
PCT/US2006/048310 2006-12-19 2006-12-19 Source multipolaire rotative WO2008076110A1 (fr)

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Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2831631A4 (fr) * 2012-04-09 2015-05-06 Halliburton Energy Services Inc Appareil de source acoustique, systèmes et procédés associés
CN108979628A (zh) * 2018-08-01 2018-12-11 中国科学院地质与地球物理研究所 一种随钻声波多极子组合测井模式及信号收发同步方法
US20220003111A1 (en) * 2020-07-02 2022-01-06 Saudi Arabian Oil Company Methods and apparatus for downhole geometry reconstruction and feature detection and classification

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0264323A2 (fr) * 1986-10-15 1988-04-20 Schlumberger Limited Procédé et dispositif pour la mesure acoustique multipole dans un puits
US4832148A (en) * 1987-09-08 1989-05-23 Exxon Production Research Company Method and system for measuring azimuthal anisotropy effects using acoustic multipole transducers
WO2000017672A1 (fr) * 1998-09-22 2000-03-30 Dresser Industries, Inc. Procede et appareil d'enregistrement acoustique
US6661737B2 (en) * 2002-01-02 2003-12-09 Halliburton Energy Services, Inc. Acoustic logging tool having programmable source waveforms

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0264323A2 (fr) * 1986-10-15 1988-04-20 Schlumberger Limited Procédé et dispositif pour la mesure acoustique multipole dans un puits
US4832148A (en) * 1987-09-08 1989-05-23 Exxon Production Research Company Method and system for measuring azimuthal anisotropy effects using acoustic multipole transducers
WO2000017672A1 (fr) * 1998-09-22 2000-03-30 Dresser Industries, Inc. Procede et appareil d'enregistrement acoustique
US6661737B2 (en) * 2002-01-02 2003-12-09 Halliburton Energy Services, Inc. Acoustic logging tool having programmable source waveforms

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2831631A4 (fr) * 2012-04-09 2015-05-06 Halliburton Energy Services Inc Appareil de source acoustique, systèmes et procédés associés
AU2012376843B2 (en) * 2012-04-09 2015-09-03 Halliburton Energy Services, Inc. Acoustic source apparatus, systems, and methods
US9158014B2 (en) 2012-04-09 2015-10-13 Halliburton Energy Services, Inc. Acoustic source apparatus, systems, and methods
CN108979628A (zh) * 2018-08-01 2018-12-11 中国科学院地质与地球物理研究所 一种随钻声波多极子组合测井模式及信号收发同步方法
US20220003111A1 (en) * 2020-07-02 2022-01-06 Saudi Arabian Oil Company Methods and apparatus for downhole geometry reconstruction and feature detection and classification

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