EP1999342A2 - Ensemble trépan équipé d'un dispositif de diagraphie - Google Patents

Ensemble trépan équipé d'un dispositif de diagraphie

Info

Publication number
EP1999342A2
EP1999342A2 EP07759037A EP07759037A EP1999342A2 EP 1999342 A2 EP1999342 A2 EP 1999342A2 EP 07759037 A EP07759037 A EP 07759037A EP 07759037 A EP07759037 A EP 07759037A EP 1999342 A2 EP1999342 A2 EP 1999342A2
Authority
EP
European Patent Office
Prior art keywords
drill bit
bit assembly
shaft
downhole
logging device
Prior art date
Legal status (The legal status 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 status listed.)
Ceased
Application number
EP07759037A
Other languages
German (de)
English (en)
Other versions
EP1999342A4 (fr
Inventor
Francis Leany
Christopher Durrand
Paula Turner
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Services Petroliers Schlumberger SA
Prad Research and Development Ltd
Schlumberger Technology BV
Schlumberger Holdings Ltd
Original Assignee
Individual
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
Priority claimed from US11/277,380 external-priority patent/US7337858B2/en
Application filed by Individual filed Critical Individual
Publication of EP1999342A2 publication Critical patent/EP1999342A2/fr
Publication of EP1999342A4 publication Critical patent/EP1999342A4/fr
Ceased legal-status Critical Current

Links

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/01—Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
    • E21B47/013—Devices specially adapted for supporting measuring instruments on drill bits
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B10/00—Drill bits
    • E21B10/60—Drill bits characterised by conduits or nozzles for drilling fluids

Definitions

  • the present invention relates to the field of downhole oil, gas, and/or geothermal exploration and more particularly to the field of drill bits for tool strings of such exploration.
  • drill bits generally serve at least two purposes. Using rotary energy provided by the tool string they bore through downhole formations, thus advancing the tool string further into the ground. They also function to dispense drilling mud pumped through the tool string that lubricates parts and washes cuttings and formation material to the surface.
  • US Patent Number 6,150,822 to Hong, et al discloses a microwave frequency range sensor (antenna or wave guide) disposed in the face of a diamond or PDC drill bit configured to minimize invasion of drilling fluid into the formation ahead of the bit.
  • the sensor is connected to an instrument disposed in a sub interposed in the drill stem for generating and measuring the alteration of microwave energy.
  • US Patent Number 6,814,162 to Moran, et al discloses a drill bit, comprising a bit body, a sensor disposed in the bit body, a single journal removably mounted to the bit body, and a roller cone rotatably mounted to the single journal.
  • the drill bit may also comprise a short-hop telemetry transmission device adapted to transmit data from the sensor to a measurement -while-drilling device located above the drill bit on the drill string.
  • US Patent Number 6,913,095 to Krueger discloses a closed- loop drilling system utilizes a bottom hole assembly ("BHA") having a steering assembly having a rotating member and a non-rotating sleeve disposed thereon.
  • the sleeve has a plurality of expandable force application members that engage a borehole wall.
  • a power source and associated electronics for energizing the force application members are located outside of the non-rotating sleeve.
  • a drill bit assembly has a body portion intermediate a shank portion and a working portion.
  • the working portion has at least one cutting element.
  • the drill bit assembly also has a shaft with an end substantially coaxial to a central axis of the assembly. The second end of the shaft protrudes from the working portion, and at least one downhole logging device is disposed within the shaft.
  • the logging device of the drill bit assembly may engage a downhole formation.
  • the logging device may also be in communication with a downhole network.
  • the drill bit assembly comprises a plurality of logging devices disposed within the shaft. At least a portion of the shaft may be electrically isolated from the body portion when resistivity or similar parameters are being sensed.
  • the logging device may comprise a resistivity sensor, an acoustic sensor, hydrophone, an annular pressure sensor, formation pressure sensor, a gamma ray sensor, density neutron sensor, a geophone array, or an accelerometer, directional drilling sensor, an inclination system that may include a gyroscopic device, a drilling dynamics sensor, another system that may be used to evaluate formation properties, an active sensor, a passive sensor, a nuclear source, a gamma source, a neutron source, an electrical source, an acoustic wave source, a seismic source, a sonic source, or combinations thereof.
  • a method of downhole data retrieval includes the steps of providing a drill bit assembly having a body portion intermediate a shank portion and a working portion and providing a shaft comprising an end substantially protruding from the working portion, the shaft having at least one downhole logging device.
  • the method includes the additional step of relaying data from the downhole logging device to tool string control equipment.
  • the method may include engaging a downhole formation with the end of the shaft.
  • the data may be relayed from the downhole logging device to the tool string control equipment through a downhole network and/or logged by a downhole processing element.
  • the method may also include the step of steering the drill bit assembly based on data received from the logging device.
  • a drill bit assembly has a body portion intermediate a shank portion and a working portion.
  • the working portion has at least one cutting element.
  • a shaft has a first end disposed within the body portion and a second end which is substantially coaxial to a central axis of the assembly. The second end of the shaft substantially protrudes from the working portion, and at least one downhole logging device is in communication with the shaft.
  • the shaft of the drill bit assembly may engage a downhole formation.
  • the downhole logging device may be disposed within the body portion, the working portion, or another area of a tool string.
  • the sensor may be in communication with a downhole network.
  • Fig. 1 is a cross-sectional diagram of a drill bit assembly having a shaft with an energy source disposed therein.
  • Fig. 2 is a cross-sectional diagram of a drill bit assembly showing possible paths of energy emitted from an energy source.
  • Fig. 3 is a cross-sectional diagram of a drill bit assembly having an energy source and an energy receiver controlled by a downhole processing element.
  • Fig. 5 is a cross-sectional diagram of a drill bit assembly having an elongated shaft and both an energy source and an energy receiver disposed in the shaft.
  • Fig. 6 is a cross-sectional diagram of a drill bit assembly having a shaft with an acoustic energy source.
  • Fig. 7 is a cross-sectional diagram of a drill bit assembly showing possible paths of energy emitted at the shaft.
  • Fig. 8 is a cross-sectional diagram of another drill bit assembly having a pressure sensor disposed within a shaft.
  • Fig. 9 is a cross-sectional diagram of another embodiment of a drill bit assembly having acoustic sensors disposed within a shaft.
  • Fig. 10 is a cross-sectional diagram a drill bit assembly showing possible paths of acoustic energy being detected at the shaft.
  • Fig. 11 is a cross-sectional diagram of another embodiment of a drill bit assembly comprising a radioactive energy source in the shaft.
  • Fig. 12 is a cross-sectional diagram of another embodiment of a drill bit assembly comprising a radioactive energy source together with another energy source in the shaft.
  • Fig. 13 is a perspective diagram of one possible data transmission system that may be used in conjunction with the present invention.
  • Fig. 14 is a cross-sectional diagram of a drill bit assembly having energy sources and receivers operably connected to a data transmission system.
  • Fig. 15 is a flowchart diagram of a method of downhole data retrieval.
  • Fig. 16 is a flowchart diagram showing another method of downhole data retrieval.
  • a drill bit assembly 100 comprises a body portion 105 intermediate a working portion 115 and a shank portion 110.
  • the shank portion 110 may be threaded to allow interconnection with a downhole tool string 160.
  • the working portion 115 of the drill bit assembly 100 comprises at least one cutting element 120 such as a poly crystalline diamond cutting element.
  • the drill bit assembly further comprises a shaft 125 having a first end 135 disposed within the body portion and a second end 130 which is substantially coaxial to a central axis 140 of the assembly 100.
  • the second end 130 of the shaft 125 substantially protrudes from the working portion 115.
  • the shaft may simply be a protrusion formed in the working portion of the drill bit assembly.
  • Fluid channels 165 may allow drilling mud or another fluid to pass through the drill bit assembly 100.
  • the shaft 125 may also be used to help steer the assembly 100.
  • considerable data logging benefits may also be realized from the use of a shaft 125 protruding from the working portion 115 of the drill bit assembly 100. This is because the shaft 125 may enable measuring certain attributes of a downhole formation 155 because of its location and because it physically engages the formation 155.
  • the present invention is believed to improve the ability to take downhole measurements, such measurements include at least formation resistivity, salinity, neutron or sonic porosity, natural gamma, pH, formation density, formation pressure, annular pressure, gas, oil or other fluid detection, lithology identification, clay analysis, depth, temperature, formation fracture detection, borehole stability, formation velocity or slowness, or nuclear magnetic resonance NMR.
  • the shaft 125 may comprise an energy source 145.
  • the energy source may be used in conjunction with a corresponding energy receiver 150 located at a different point on the drill bit assembly 100 or along the tool string.
  • the energy source 145 may be an electric terminal configured to pass a current or a voltage into the downhole formation 155 as it engages the downhole formation 155. The electric current or voltage may then be received at the corresponding energy receiver 150. By regulating the distance between the energy source 145 and the energy receiver 150 and by applying either the current or voltage between the energy source and the receiver, valuable resistivity measurements may be made on the downhole formation 155.
  • the energy source 145 may be electrically isolated from the energy receiver 150 by a special dielectric layer 125. In other embodiments it may be feasible to electrically isolate the energy source 145 from the energy receiver by electrically isolating the energy receiver 150.
  • the energy source 145 and receiver 150 may function together as a sensor.
  • the energy source 145 may be a radioactive source, an emitting device, an acoustic source, passive source, an active source or combinations thereof.
  • the shaft comprises or is in communication with a sensor a resistivity sensor system, an acoustic sensor system, hydrophone system, an annular pressure sensor system, formation pressure sensor system, a gamma ray sensor system, density neutron sensor system, a geophone array system, or an accelerometer system, directional drilling system, an inclination sensor system that may include a gyroscopic device, a drilling dynamics system, another system that may be used to evaluate formation properties, an active sensor, a passive sensor, or combinations thereof.
  • the assembly 100 comprises a shaft 125 with an energy source 145 disposed in the second end 130 of the shaft.
  • Multiple energy receivers 150 are disposed along the outer edges of the drill bit assembly 100 and the tool string 160. This allows energy emitted from the energy source 145 to be received by the energy receivers 150 at varying distances from the energy source 145. By measuring the differences among the energy received by the energy receivers 150 calculations may be made that characterize the physical properties of the formation 155. In embodiments where the energy emitted from the energy source 145 is electrical current, the path of current may look similar to the lines 210 shown in Fig. 2.
  • a bucking current system may be used to manipulate the path electric energy travels.
  • the bucking current system may be disposed between the energy source 145 and the at least one receiver 150.
  • a bucking current system may comprise of an additional electric energy source and receiver. The energy passed from the additional electric source to the receiver of the bucking system may repel the energy traveling from energy source 145, forcing the energy to travel deeper into the formation which allows measurements further away from drill bit assembly to be taken.
  • a bucking current system may be used to confine the travel of the energy to a path closer to the drill bit assembly.
  • an energy source 145 and energy receivers 150 may be in communication with a local processing element 305.
  • the processing element 305 may provide the electrical potential between the energy source 145 and the receivers 150 and log measurements taken as data. These data may then be routed to downhole tool string control equipment or to surface equipment to be interpreted. Once interpreted, the drill bit assembly 100 may be controlled according to information provided by the measurements.
  • the drill bit assembly comprises a shaft 125 that protrudes substantially from the working portion 115 of the assembly 100.
  • This type of shaft 125 may be used in directional drilling applications that require steering the drill bit assembly 100 during drilling operations. While the shaft 125 is generally coaxial to the central axis 140 of the assembly, steering elements 415 may be used to position the shaft 125 in such a way that a desired trajectory may be followed by the tool string 160 during drilling.
  • the shaft may comprise an asymmetric geometry which is adapted to rotate independent of the body portion of the drill bit assembly.
  • a brake system may be incorporated into the drill bit assembly or in a downhole tool string component attached to the drill bit assembly.
  • the brake may be adapted to position the asymmetric geometry of the shaft in such a manner as to cause the drill string to travel along a predetermined trajectory. Once the shaft is correctly positioned, the brake may release the shaft which, due to the weight of the tool string loaded to it, will rotationally fix against the formation while the drill bit assembly rotates around the shaft.
  • the shaft 125 comprises a sensor 405. While the sensor 405 shown is an induction-type resistivity sensor, in other embodiments the sensor 405 may be a laterolog resistivity sensor, a short normal resistivity sensor, an electromagnetic wave resistivity tool, a nuclear sensor, an acoustic sensor, or a pressure sensor. It is believed that an elongated shaft 125 as shown in this figure may substantially engage the downhole formation 155 and provide data that more accurately represents the characteristics of the formation 155 being drilled.
  • a drill bit assembly 100 mechanically similar to that of Fig. 4 is shown with the shaft 125 comprising both an energy source 145 and a corresponding energy receiver 150.
  • One or both of the energy source 145 and the energy receiver 150 may be electrically isolated from the other with insulative material 505.
  • One advantage of such a configuration is that under circumstances in which the shaft 125 engages a downhole formation, the energy emitted from the energy source 145 almost entirely passes through the formation 155 and minimize interference from drilling fluids and other materials used in drilling.
  • the energy source 145 may also be used in conjunction with additional receivers 150 situated further up the downhole tool string 160.
  • a shaft 125 in the downhole assembly may comprise an energy source 145 that produces acoustic energy.
  • the energy source 145 is a piezoelectric device in communication with the shaft 125.
  • the piezoelectric device is adapted to create and pass an acoustic signal through the shaft 125 and into the downhole formation 155, after which reflected portions of the acoustic signal may be received by energy receivers 150 disposed along the tool string 160 or positioned at surface.
  • the acoustic source is adapted to produce a signal comprising multiple frequencies.
  • the acoustic energy source 145 may be in communication with downhole and/or surface control equipment which provide an electrical signal which is converted into the acoustic signal. Such sources may comprise piezoelectric or magnetostrictive elements.
  • the control equipment may be in communication with the source through electrically conductive medium. For example, a coaxial cable, wire, twisted pair of wires or combinations thereof may be secured within both the drill bit assembly and at least a downhole tool string component connected to the drill bit assembly.
  • the medium may be in inductive or electrical communication with each other through couplers 615 positioned so as to allow signal transmission across the connection of the downhole component and the drill bit assembly.
  • the couplers may be disposed within recesses in either primary or secondary shoulder of the connection or they may be disposed within inserts positioned within the bores of the drill bit assembly and the downhole tool string component.
  • acoustic energy may be emitted from the shaft 125 using hydraulic or other mechanical means.
  • the embodiment shown in Fig. 6 may improve drilling dynamics by stabilizing the drill bit assembly and also helping to control the weight loaded to the working portion.
  • the shaft 125 may be controlled hydraulically, electrically, or mechanically to move vertically with respect to the drill bit assembly 100.
  • bearings 610 may also aid in the mechanical functionality of the shaft 125.
  • the embodiment of in Fig 6 may also be operated in a passive mode where vibrations, shocks caused by drilling or some other acoustic energy source (such as from the surface or a cross well operation) may vibrate the shaft. Such vibrations may be converted by a piezoelectric or magnetostrictive element into electric signals. These signal may provide information about the physical properties of the rocks ahead of, around or above the working portion.
  • acoustic waves 701 emitted from the shaft 125 are shown reaching an acoustic impedance boundary 705.
  • Acoustic impedance boundaries 705 may be a result from a feature in the formation such as a fault, a salt body, change in formation hardness, change in formation material, a hydrocarbon formation, or other changes in the formation.
  • Acoustic waves reflect off of such acoustic impedance boundaries 705 and may be sensed by energy receivers 150 at the surface, in the tool string 160, the drill bit assembly and/or in the shaft.
  • Physical attributes of acoustic boundaries 705 such as its spatial location and dimensional or surface attributes, acoustic properties and composition may be realized by interpreting the waves received by the energy receivers 150. These attributes may then be used to direct the tool string 160 in the most beneficial manner with respect to the acoustic boundaries 705.
  • the drill bit assembly 100 may comprise a pressure sensor adapted to measure the compressive strength of the formation 805.
  • the pressure sensor 805 may be in communication with the shaft 125 or be disposed within the shaft.
  • a high strength formation 155 is being penetrated by the drill bit assembly 100 and the strength of the formation 155 causes the shaft 125 to be pushed up into the drill bit assembly 100 and compress the spring 605.
  • the spring 605 may be fairly resilient such that a significant amount of pressure may be required to compress it.
  • the sensor 805 shown is a position sensor that may sense the position of the shaft 125.
  • a sensor may include magnets, hall-effect elements, piezoelectric elements, magnetostrictive elements, capacitive elements or combinations thereof.
  • the position of the shaft 125 may be indicative of the pressure of the formation 155.
  • the sensor 805 may track the position of the shaft 125, but in some embodiments a small tracking device 810 on the shaft 125 may provide more accurate measurements.
  • a strain sensor may used to measure the strain in the shaft, spring, or both.
  • sensors 405 disposed within the shaft of a drill bit assembly 100 may be acoustic sensors such as geophones. Acoustic sensors may be particularly useful for seismic and sonic wave measurements.
  • an acoustic source may generate a great deal of acoustic energy at the surface of the earth. The acoustic energy then propagates through the earth until it reaches the acoustic sensors.
  • the waveform of the acoustic energy received at the various sensors 405 may be indicative of the physical characteristics of the formation 155 being drilled, it may be particularly useful to have acoustic sensors disposed in the shaft 125 that engages the downhole formation 155. Sensors may not be limited to being positioned in the shaft but may additionally be positioned elsewhere on the tool string as part an array.
  • an acoustic signal may be generated downhole through acoustic sources disposed in the drill bit assembly 100 or other locations on the tool string 160.
  • the acoustic signal may also come from another well bore, or in some embodiments, the acoustic signal may be generated by the vibrations in the earth generated as the drill bit assembly advances in the earth.
  • the acoustic signal may be generated by the process of pressurizing and fracturing the formation along weakness in the formation. In such an embodiment, the bore hole may be pressurized to an extent that the formation breaks at its weakest points.
  • the vibrations generated by the fracturing of the formation may be recorded by the sensors 405.
  • the sensors 405 may be in communication with a local storage module 905 that may log their data and/or provide them with electrical power.
  • the control module 905 may communicate with tool string control equipment to assist in planning the trajectory of the tool string 160.
  • Fig. 10 shows a cross-sectional view of the drill bit assembly with acoustic waves 1005 reflected off of an acoustic impedance boundary 705 that is ahead of or otherwise proximal to the bit and being received by the sensors 405 in the shaft, along the tool string, or at the surface.
  • sensors 405 may sense gamma rays, radioactive energy, resistivity, torque, pressure, or other drilling dynamics measurements or combinations thereof from the downhole formation 155 being drilled.
  • a drill bit assembly 100 may comprise a shaft 125 with an energy source 145 that is radioactive or emits subatomic particles.
  • sources include active gamma sources and neutron sources.
  • At least one energy receiver 150 may be disposed within the drill bit assembly 100 and receive the radioactive energy or subatomic particles that are transmitted through the downhole formation 155.
  • the energy source may be disposed within the drill bit assembly, tool string, or at the surface and the sensor is disposed in or in communication with the shaft.
  • the gamma source may be cesium 137.
  • the neutron source may comprise an Americium Beryllium source or it may comprise a pulsed neutron generator which uses deuterium and/or tritium ions.
  • the gamma or neutron source may be disposed within the body of the drill bit assembly.
  • the drill bit assembly 100 may comprise multiple energy sources 145 in the shaft 125.
  • the shaft 125 may comprise a gamma ray source in addition to an electrical current source.
  • Corresponding energy receivers 150 may work in conjunction with the energy sources 145 to provide gamma and resistivity measurements, respectively.
  • a drill bit assembly 100 may be in communication with one or more tools in a network.
  • a downhole network 1300 may comprise one or more downhole tool string components 1305 linked together in a tool string 160 and in communication with surface equipment 1303. Data may be transmitted up and down the tool string 160 and between different tool components 1305.
  • the tool string 160 may be suspended by a derrick 1301.
  • Data may be transmitted along the tool string 160 through techniques known in the art.
  • a preferred method of downhole data transmission using inductive couplers disposed in tool joints is disclosed in the U.S. Patent 6,670,880 to Hall, et al, which is herein incorporated by reference for all it discloses.
  • An alternate data transmission path may comprise direct electrical contacts in tool joints such as in the system disclosed in U.S. Patent 6,688,396 to Floerke, et al., which is herein incorporated by reference for all that it discloses.
  • Another data transmission system that may also be adapted for use with the present invention is disclosed in U.S.
  • Patent 6,641,434 to Boyle, et al. which is also herein incorporated by reference for all that it discloses.
  • alternative forms of telemetry may be used to communicate with the drill bit assembly, such as telemetry systems that communicate through the drilling mud or through the earth. Such telemetry systems may use electromagnetic of acoustic waves.
  • the alternative forms of telemetry may be the primary telemetry system for communication with the drill bit assembly or they may be back-up systems designed to maintain some communication if the primary telemetry system fails.
  • a data swivel 1302, or a wireless top-hole data connection may facilitate the transfer of data between the rotatable tool string 160 and the stationary surface equipment 1303.
  • Downhole tool string components 1305 may comprise drill pipes, jars, shock absorbers, mud hammers, air hammers, mud motors, turbines, reamers, under-reamers, fishing tools, steering elements, MWD tools, LWD tools, seismic sources, seismic receivers, pumps, perforators, packers, other tools with an explosive charge, and mud-pulse sirens.
  • Having a network 1300 in the tool string 160 may enable high-speed communication between each device connected to it and facilitate the transmission and receipt of data between sensors 405, energy sources 145, and energy receivers 150 in the shaft 125 of the drill bit assembly 100.
  • a drill bit assembly 100 with an energy source 145, energy receivers 150, and sensors 405 designed to operate in a downhole network 1300 is shown.
  • the energy source 145 and sensors 405 are disposed within the shaft 125.
  • a processing element 305 may control the energy source 145, their corresponding energy receivers 150, and the sensors 405.
  • the processing element 305 may also serve to log data received or interpret measurements from the energy receivers 150 or the sensors 405.
  • the processing element 305 may be in communication with the downhole network 1300 through a system of inductive couplers 615 and coaxial cable 1403 disposed within the tool string 160 as has been previously discussed.
  • a method 1500 of downhole data retrieval comprises the steps of providing 1505 a drill bit assembly having a body portion intermediate a shank portion and a working portion, providing 1510 a shaft comprising an end substantially protruding from the working portion, the shaft having at least one sensor, and relaying 1515 data from the sensor to tool string control equipment.
  • the method 1500 may include the step of engaging a downhole formation with the end of the shaft. This may provide optimal measurements and/or data from the sensor disposed within the shaft.
  • the data may be relayed 1515 from the sensor to tool string control equipment such as downhole intelligent steering equipment or surface control equipment through a downhole network.
  • the tool string control equipment may then change drilling parameters according to the data received to optimize drilling efficiency. For example, the drill bit assembly may be steered according to data received from the sensor.
  • the data may also be logged in a local storage module for later retrieval or delayed transmission to tool string control equipment.
  • another method 1600 of downhole data retrieval comprises the steps of providing 1605 a drill bit assembly having a body portion intermediate a shank portion and a working portion, providing 1610 a shaft comprising an end substantially protruding from the working portion, the shaft having at least one energy source, emitting 1615 energy from the energy source into a formation and receiving 1620 at least a portion of the emitted energy downhole in a downhole tool.
  • the method 1600 may also include the step of engaging a downhole formation with the end of the shaft.
  • the portion of the emitted energy received 1620 in the downhole tool may be used to sense parameters of the formation, such as resistivity, composition, physical dimensions, and other properties.
  • the portion of emitted energy received 1620 may also be logged as data and be stored in a local storage module such as a processing element.
  • Other properties of the energy received 1620 may also be logged as data such as distortions or transformations in waveforms.
  • the data may be sent to tool string control equipment through a downhole network.
  • the tool string control equipment may then change drilling parameters according to the data received to optimize drilling efficiency.
  • the method 1600 may include the step of steering the drill bit assembly based on the data.

Landscapes

  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Remote Sensing (AREA)
  • Geophysics (AREA)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)
  • Geophysics And Detection Of Objects (AREA)
  • Drilling Tools (AREA)
  • Drilling And Boring (AREA)
  • Arrangements For Transmission Of Measured Signals (AREA)

Abstract

Dans certains aspects, l'invention porte sur un ensemble trépan comprenant une partie corps, qui est située entre une partie tige et une partie de travail. La partie de travail comprend au moins un élément de coupe. Dans certains modes de réalisation, l'ensemble trépan comprend un arbre possédant une extrémité sensiblement coaxiale par rapport à l'axe central de l'ensemble. L'extrémité de l'arbre est sensiblement protubérante par rapport à la partie de travail, et au moins un dispositif de diagraphie en fond de trou est disposé à l'intérieur de l'arbre ou en communication avec ce dernier.
EP07759037.0A 2006-03-24 2007-03-21 Ensemble trépan équipé d'un dispositif de diagraphie Ceased EP1999342A4 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US11/277,380 US7337858B2 (en) 2005-11-21 2006-03-24 Drill bit assembly adapted to provide power downhole
US30602206A 2006-12-14 2006-12-14
US30630706A 2006-12-22 2006-12-22
PCT/US2007/064544 WO2007130749A2 (fr) 2006-03-24 2007-03-21 Ensemble trépan équipé d'un dispositif de diagraphie

Publications (2)

Publication Number Publication Date
EP1999342A2 true EP1999342A2 (fr) 2008-12-10
EP1999342A4 EP1999342A4 (fr) 2014-11-05

Family

ID=38668421

Family Applications (1)

Application Number Title Priority Date Filing Date
EP07759037.0A Ceased EP1999342A4 (fr) 2006-03-24 2007-03-21 Ensemble trépan équipé d'un dispositif de diagraphie

Country Status (9)

Country Link
EP (1) EP1999342A4 (fr)
CN (1) CN101454537B (fr)
AU (1) AU2007248310B2 (fr)
BR (1) BRPI0709363A2 (fr)
CA (1) CA2647416C (fr)
MX (1) MX2008012078A (fr)
MY (1) MY144681A (fr)
NO (1) NO20084384L (fr)
WO (1) WO2007130749A2 (fr)

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CN104405291A (zh) * 2014-12-05 2015-03-11 吉林大学 一种组合式原位浅层地温测量钻头

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US8210280B2 (en) * 2008-10-13 2012-07-03 Baker Hughes Incorporated Bit based formation evaluation using a gamma ray sensor
US8573327B2 (en) * 2010-04-19 2013-11-05 Baker Hughes Incorporated Apparatus and methods for estimating tool inclination using bit-based gamma ray sensors
CN105113993A (zh) * 2015-08-20 2015-12-02 郑州神利达钻采设备有限公司 旋转钻头
CN105370271B (zh) * 2015-11-30 2018-05-01 北京六合伟业科技股份有限公司 一种用于可燃冰探测的测量装置
CN109067250B (zh) * 2018-08-20 2019-11-15 南京海精电子技术有限公司 一种具有防缠绕功能的深海水听器
CN112112592B (zh) * 2020-10-16 2023-10-03 吉林大学 一种深井测量仪器输送装置与方法

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US3700049A (en) * 1970-10-02 1972-10-24 Inst Francais Du Petrole Device for connecting a drill bit to a drill string provided with a penetrometer
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WO2007130749A3 (fr) 2008-10-16
CN101454537A (zh) 2009-06-10
BRPI0709363A2 (pt) 2011-07-12
AU2007248310A1 (en) 2007-11-15
MX2008012078A (es) 2009-04-06
CA2647416C (fr) 2014-05-06
CA2647416A1 (fr) 2007-11-15
MY144681A (en) 2011-10-31
WO2007130749A2 (fr) 2007-11-15
CN101454537B (zh) 2013-02-06
NO20084384L (no) 2008-10-20
AU2007248310B2 (en) 2012-06-07

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