EP0806542A2 - Steuerbares Rotary-Bohrsystem - Google Patents

Steuerbares Rotary-Bohrsystem Download PDF

Info

Publication number
EP0806542A2
EP0806542A2 EP97303135A EP97303135A EP0806542A2 EP 0806542 A2 EP0806542 A2 EP 0806542A2 EP 97303135 A EP97303135 A EP 97303135A EP 97303135 A EP97303135 A EP 97303135A EP 0806542 A2 EP0806542 A2 EP 0806542A2
Authority
EP
European Patent Office
Prior art keywords
control unit
bias
drilling system
formation
sensor
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.)
Withdrawn
Application number
EP97303135A
Other languages
English (en)
French (fr)
Other versions
EP0806542A3 (de
Inventor
John Denzil Barr
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.)
ReedHycalog UK Ltd
Original Assignee
Camco International UK Ltd
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 Camco International UK Ltd filed Critical Camco International UK Ltd
Publication of EP0806542A2 publication Critical patent/EP0806542A2/de
Publication of EP0806542A3 publication Critical patent/EP0806542A3/de
Withdrawn legal-status Critical Current

Links

Images

Classifications

    • 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
    • E21B47/01—Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
    • 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
    • E21B4/00—Drives for drilling, used in the borehole
    • E21B4/006—Mechanical motion converting means, e.g. reduction gearings
    • 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
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/0085—Adaptations of electric power generating means for use in boreholes
    • 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
    • E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
    • E21B44/005—Below-ground automatic control systems
    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • E21B7/06—Deflecting the direction of boreholes

Definitions

  • the invention relates to steerable rotary drilling systems and provides, in particular, methods and apparatus for use with such systems for the acquisition of geophysical data concerning the nature and characteristics of the subsurface formation being drilled, and the use of such data as an input parameter for control of the direction of drilling.
  • fully controllable directional drilling has normally required the drill bit to be rotated by a downhole motor.
  • the drill bit may, for example, be coupled to the motor by a double tilt unit whereby the central axis of the drill bit is inclined to the axis of the motor.
  • the effect of this inclination is nullified by continual rotation ofthe drill string, and hence the motor casing, as the bit is rotated by the motor.
  • the rotation of the drill bit is stopped with the bit tilted in the required direction. Continued rotation of the drill bit by the motor then causes the bit to drill in that direction.
  • rotary drilling is sometimes to be preferred, particularly in long reach drilling, rotary drilling being a system in which a bottom hole assembly, including the drill bit, is connected to a drill string which is rotatably driven from the drilling platform at the surface.
  • Various systems have been proposed for achieving fully steerable rotary drilling.
  • the present invention relates to steerable rotary drilling systems of the kind where the bottom hole assembly includes a drill bit, a bias unit rotatable with the drill bit and including one or more actuators which are displaceable laterally as the bias unit rotates to impart a lateral bias to the drill bit, and a control unit to control the displacement of the actuators and thereby control the direction of drilling.
  • the bottom hole assembly may include sensors such as inclinometers and/or magnetometers which supply calibrated survey data.
  • the bottom hole assembly may include sensors, such as gamma ray detectors, neutron formation sensors or resistivity sensors.
  • U.S. Patents Nos. 5325714, 5467832 and 5448227 disclose arrangements for formation evaluation in the course of drilling using a downhole motor assembly
  • U.S. 5419405 discloses detection of a subterranean target when rotary drilling using a non-rotating controllable stabiliser downhole to control the direction of drilling.
  • U.S. 5419405 also discloses the use of an output signal from the means for detecting a subterranean target as an input parameter to means for automatically controlling the direction of drilling.
  • the present invention relates to the use of formation evaluation data in a steerable rotary drilling system of the kind first referred to.
  • a steerable rotary drilling system where the bottom hole assembly includes a drill bit, a bias unit rotatable with the drill bit and including one or more actuators which are displaceable laterally as the bias unit rotates to impart a lateral bias to the drill bit, and a control unit to control the displacement of said actuator and thereby control the direction of drilling, the bottom hole assembly further including at least one geophysical sensor responsive to a characteristic of formation or formations in the vicinity of the bottom hole assembly, said sensor providing an output signal corresponding to the current value of said characteristic, and means for automatically modifying the operation of the control unit, and hence operation of the rotatable bias unit, in response to said output signal.
  • the path of the borehole drilled by the bit may be automatically and accurately controlled to be the optimum path given the nature of the surrounding formation. For example, it frequently occurs that the borehole is required to extend generally horizontally through a comparatively shallow reservoir of hydrocarbon-bearing formation.
  • the formation evaluation sensors may then locate the upper and lower boundaries of the formation and the input to the control unit may then be used automatically to maintain the drill bit at an optimum level between the upper and/or lower boundaries, as will be described.
  • Said means for automatically modifying the operation of the control unit are preferably located in the bottom hole assembly.
  • said means may be located in the control unit itself.
  • Such arrangement enables the control loop to be closed downhole thus avoiding the necessity and difficulties of frequent transmission of the formation evaluation data to the surface so that the appropriate control signals may then be transmitted downhole from the surface. Closing the control loop downhole enables the data to be sampled, and control signals generated, at higher frequencies than is the case where the data signals have to be sent to the surface, resulting in better, smoother control of the direction of drilling.
  • control loop in the case where the control loop is closed downhole, it may well be desirable for information also to be transmitted to the surface occasionally, using any of the well known current methods of data transmission, so that the automatic operation and steering of the bottom hole assembly can be monitored and operator-controlled corrections made if necessary.
  • one or more of the geophysical sensors may also be located in the control unit itself.
  • one or more of the sensors may be located elsewhere in the bottom hole assembly, data from said sensors being transmitted to the control unit by a short range downhole transmission system of any of the kinds currently employed.
  • the bias unit is preferably a synchronous modulated bias unit where the control unit may cause the actuators to be displaced in synchronism with rotation of the bias unit, and in selected phase relation thereto, whereby, as the bit and bias unit rotate, the or each actuator is displaced outwardly at the same selected rotational position so as to bias the bias unit and drill bit laterally and thereby control the direction of drilling.
  • the control unit may comprise an instrument carrier which can be roll stabilised so as to remain substantially non-rotating in space, the direction of bias of the bias unit being determined by the rotational orientation of the instrument carrier.
  • the control unit may be strapped-down, i.e. rotatable with the bias unit.
  • a steerable rotary drilling system where the bottom hole assembly includes a drill bit, a bias unit rotatable with the drill bit and including one or more actuators which are displaceable laterally as the bias unit rotates to impart a lateral bias to the drill bit, and a control unit to control the displacement of said actuator and thereby control the direction of drilling, the bottom hole assembly including at least one geophysical sensor responsive to a characteristic of formation in the vicinity of the bottom hole assembly, said sensor providing an output signal corresponding to the current value of said characteristic, and being located in the control unit.
  • the geophysical sensor may be a gamma sensor adapted to detect natural gamma ray emissions from the formation.
  • the formation usually shale, above a target hydrocarbon-bearing formation will normally have a relatively high level of natural radioactivity which will be detected by the gamma sensor.
  • the output signal from the gamma sensor may thus be used to obtain information about the position of the borehole in relation to the upper boundary of the hydrocarbon-bearing formation and to control the path of the borehole so as to maintain it in the upper region of the formation.
  • the gamma sensor may comprise a gamma ray source and detector so that gamma rays from the source are reflected from the surrounding formation and are received by the detector, the attenuation of the gamma rays then being a measure of the density of the formation.
  • a gamma ray source and detector so that gamma rays from the source are reflected from the surrounding formation and are received by the detector, the attenuation of the gamma rays then being a measure of the density of the formation.
  • the geophysical sensors may include a neutron emission source and a detector for measuring the porosity of the formation as described in U.S. 5144126.
  • a neutron emission source and a detector for measuring the porosity of the formation as described in U.S. 5144126.
  • high energy neutrons from the emission source pass into the formation and the depletion of the neutron energy, measured by the detector, is an indication of the amount of hydrogen in the formation, which in turn is an indication of its porosity.
  • the geophysical sensors may also include an electrical resistivity sensor as described, for example, in U.S. 5001675.
  • an electro-magnetic wave is emitted from a suitable transmitter and the returning signals received by a detector enable the resistivity of the surrounding formation to be determined.
  • Another form of sensor is a sonic sensor which measures the velocity of a sound wave propagated through the formation, to derive information concerning its density and elasticity.
  • Another type of sonic sensor comprises a sound wave emitter and a detector to sense the sound waves reflected from the surrounding formation, such arrangement being used to locate boundaries in the formation from which the sound waves are reflected.
  • Figure 1 shows diagrammatically a typical rotary drilling installation of a kind in which the present invention may be employed.
  • the bottom hole assembly includes a drill bit 1, and is connected to the lower end of a drill string 2 which is rotatably driven from the surface by a rotary table 3 on a drilling platform 4.
  • the rotary table is driven by a drive motor indicated diagrammatically at 5 and raising and lowering of the drill string, and application of weight-on-bit, is under the control of draw works indicated diagrammatically at 6.
  • the bottom hole assembly includes a modulated bias unit 10 to which the drill bit 1 is connected and a roll stabilised control unit 9 which controls operation of the bias unit 10 in accordance with an on-board computer program, and/or in accordance with signals transmitted to the control unit from the surface.
  • the bias unit 10 can be controlled to apply a lateral bias to the drill bit 1 in a desired direction so as to control the direction of drilling.
  • the bias unit 10 comprises an elongate main body structure provided at its upper end with a threaded pin 11 for connecting the unit to a drill collar, incorporating the roll stabilised control unit 9, which is in turn connected to the lower end of the drill string.
  • the lower end 12 of the body structure is formed with a socket to receive the threaded pin ofthe rotary drill bit.
  • the drill bit may be of any rotary type.
  • Each hydraulic actuator 13 is supplied with drilling fluid under pressure through a respective passage 14 under the control of a rotatable disc control valve 15 located in a cavity 16 in the body structure of the bias unit.
  • the disc control valve 15 is controlled by an axial shaft 21 which is connected by a coupling 22 to the output shaft of the roll stabilised control unit 9.
  • the roll stabilised control unit maintains the shaft 21 substantially stationary at a rotational orientation which is selected, either from the surface or by a downhole computer program, according to the direction in which the drill bit is to be steered.
  • the disc valve 15 operates to deliver drilling fluid under pressure to the three hydraulic actuators 13 in succession.
  • the hydraulic actuators are thus operated in succession as the bias unit rotates, each in the same rotational position so as to displace the bias unit laterally in a selected direction.
  • the selected rotational position of the shaft 21 in space thus determines the direction in which the bias unit is actually displaced and hence the direction in which the drill bit is steered.
  • FIG. 3 shows diagrammatically, in greater detail, one form of roll stabilised control unit for controlling a bias unit of the kind shown in Figure 2.
  • Other forms of roll stabilised control unit are described in British Patent Specification No. 2257182, and in co-pending Application No. 9503828.7
  • the support for the control unit comprises a tubular drill collar 23 forming part of the drill string.
  • the control unit comprises an elongate generally cylindrical hollow instrument carrier 24 mounted in bearings 25, 26 supported within the drill collar 23, for rotation relative to the drill collar 23 about the central longitudinal axis thereof.
  • the carrier has one or more internal compartments which contain an instrument package 27 comprising sensors for sensing the rotation and orientation of the control unit, and associated equipment for processing signals from the sensors and controlling the rotation of the carrier.
  • a multi-bladed impeller 28 is rotatably mounted on the carrier 24.
  • the impeller comprises a cylindrical sleeve 29 which encircles the carrier and is mounted in bearings 30 thereon.
  • the blades 31 of the impeller are rigidly mounted on the lower end of the sleeve 29.
  • the impeller 28 is coupled to the instrument carrier 24, by an electrical torquer-generator.
  • the sleeve 29 contains around its inner periphery a pole structure comprising an array of permanent magnets 33 cooperating with an armature 34 fixed within the carrier 24.
  • the magnet/armature arrangement serves as a variable drive coupling between the impeller 28 and the carrier 24.
  • a second impeller 38 is mounted adjacent the upper end of the carrier 24.
  • the second impeller is, like the first impeller 28, also coupled to the carrier 24 in such a manner that the torque it imparts to the carrier can be varied.
  • the upper impeller 38 is generally similar in construction to the lower impeller 28 and comprises a cylindrical sleeve 39 which encircles the carrier casing and is mounted in bearings 40 thereon.
  • the blades 41 of the impeller are rigidly mounted on the upper end of the sleeve 39. However, the blades of the upper impeller are so designed that the impeller tends to be rotated clockwise as a result of the flow of drilling fluid down the interior of the collar 23 and across the impeller blades 41.
  • the impeller 38 is coupled the carrier 24 by an electrical torquer-generator.
  • the sleeve 39 contains around its inner periphery an array of permanent magnets 42 cooperating with an armature 43 fixed within the carrier 24.
  • the magnet/armature arrangement serves as a variable drive coupling between the impeller 38 and the carrier.
  • the main bearings 25, 26 and the disc valve 15 of the bias unit apply a clockwise input torque to the carrier 24 and a further clockwise torque is applied by the upper impeller 38 through the torquer-generator 42,43 and its bearings 40. These clockwise torques are opposed by an anti-clockwise torque applied to the carrier by the lower impeller 28.
  • the torque applied to the carrier 24 by each impeller may be varied by varying the electrical load on each generator constituted by the magnets 33 or 42 and the armature 34 or 43. This variable load is applied by generator load control units under the control of a micro-processor in the instrument package 27.
  • the input signal may be transmitted to the control unit from the surface, or may be derived from a downhole program defining the desired path of the borehole being drilled in accordance with survey and geophysical data derived downhole.
  • the processor is pre-programmed to process the feedback signal which is indicative of the rotational orientation of the carrier 24 in space, and the input signal which is indicative of the desired rotational orientation of the carrier, and to feed a resultant output signal to generator load control units.
  • the output signal is such as to cause the generator load control units to apply to the torquer-generators 33, 34 and 42,43 electrical loads of such magnitude that the net anticlockwise torque applied to the carrier 24 by the two torquer-generators opposes and balances the other clockwise torques applied to the carrier, such as the bearing torque, so as to maintain the carrier non-rotating in space, and at the rotational orientation demanded by the input signal.
  • the output from the control unit 9 is provided by the rotational orientation of the carrier itself and the carrier is thus mechanically connected by a single control shaft 35 to the input shaft 21 of the bias unit 10 shown in Figure 2.
  • Figure 4 shows diagrammatically the bottom hole assembly of one form of drilling system in accordance with the present invention, the bottom hole assembly being shown located in a comparatively narrow horizontal band 50 of hydrocarbon-bearing formation bounded by upper and lower layers of different formation 51 and 52.
  • the control unit 9 for the bias unit 10 incorporates a gamma detector 53, the gamma detector being located at the lower end of the control unit 9 so as to be as close as possible to the drill bit 1.
  • the gamma detector may be a directional or non-directional sensor. It may be responsive to the natural radioactivity of the formation in the vicinity of the drill bit or it may include a gamma ray emission device, the detector measuring the attenuation of the returning gamma radiation.
  • the gamma sensor can detect the presence and location of a layer of shale 51 forming the upper boundary of the hydrocarbon-bearing layer 50.
  • the gamma sensor 53 produces an output signal indicative of the location of the upper boundary layer 51 which is transmitted to the control unit 9.
  • the control unit 9 incorporates means to modify the rotational orientation of the control unit so as to modify the bias imparted to the drill bit 1 by the bias unit 10, as previously described, so as to steer the bit and maintain it at a desired distance from the boundary layer 51.
  • control unit 9 may be capable of roll stabilisation as previously described, it will be appreciated that for the purposes of the present invention it could equally well be a strapped-down control unit rotating with the bias unit 10.
  • Figure 4 illustrates the location of a resistivity sensor 54 above the control unit 9 and rotatable with the drill string.
  • the resistivity sensor 54 may be a directional or non-directional sensor.
  • short range telemetry of any of the well known kinds, such as mud pulse telemetry or magnetic or electro-magnetic telemetry, may be used to transmit data signals from the resistivity sensor 54 to the control unit 9 so that operation of the control unit is automatically modified in accordance with the information from the resistivity sensor 54 to steer the drill bit 1 in an appropriate path.
  • any other form of geophysical sensor may also be located at any appropriate position in the bottom hole assembly, including geophysical sensors of any ofthe kinds previously referred to, and data signals from such sensors used automatically to modify operation of the control unit 9 so as to steer the drill bit in the appropriate direction according to the detected characteristics of the surrounding formation.
  • control loop includes a surface station.
  • data signals from the geophysical sensors may be passed, by suitable short range telemetry, to a telemetry transmitter 55 incorporated in the bottom hole assembly.
  • Corresponding signals are then sent to a surface station by the unit 55, e.g. using mud pulse telemetry.
  • the surface unit then processes the signals and transmits appropriate control signals back downhole to the control unit 9.
  • Such arrangement has the advantage that although the drill bit may still be steered automatically in accordance with the geophysical and other data, operator-controlled signals can be introduced into the loop to modify the direction of drilling in accordance with other requirements.
  • a directional gamma detector 53 in the control unit 9 may provide additional advantage in the case where the control unit is capable of roll stabilisation and/or controlled rotation.
  • a directional gamma detector is screened on one side so as to detect gamma radiation from only a limited region of the formation.
  • the detector In previous arrangements where the detector is simply mounted on a collar to rotate with the drill string, the detector must be actuated in synchronism with rotation of the drill string, so as to be facing in the required direction each time a gamma radiation reading is taken.
  • the rate of rotation of the drill string must be considerably reduced below its normal drilling speed while gamma readings are being taken, and this interferes with normal drilling.
  • control unit may be temporarily roll stabilised with the detector facing in the required direction, or may be rotated at any desired slow speed, while the drill string continues to rotate at its normal drilling speed. Gamma readings may therefore be taken without interfering with drilling.
EP97303135A 1996-05-09 1997-05-08 Steuerbares Rotary-Bohrsystem Withdrawn EP0806542A3 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB9609659 1996-05-09
GB9609659A GB2312905A (en) 1996-05-09 1996-05-09 Automatically steered drill assembly

Publications (2)

Publication Number Publication Date
EP0806542A2 true EP0806542A2 (de) 1997-11-12
EP0806542A3 EP0806542A3 (de) 1998-09-02

Family

ID=10793399

Family Applications (1)

Application Number Title Priority Date Filing Date
EP97303135A Withdrawn EP0806542A3 (de) 1996-05-09 1997-05-08 Steuerbares Rotary-Bohrsystem

Country Status (2)

Country Link
EP (1) EP0806542A3 (de)
GB (1) GB2312905A (de)

Cited By (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2002008563A1 (fr) * 2000-07-25 2002-01-31 Total Fina Elf S.A. Procede et dispositif de forage rotary d'un puits
US6467557B1 (en) 1998-12-18 2002-10-22 Western Well Tool, Inc. Long reach rotary drilling assembly
US6470974B1 (en) 1999-04-14 2002-10-29 Western Well Tool, Inc. Three-dimensional steering tool for controlled downhole extended-reach directional drilling
GB2392931A (en) * 2002-09-16 2004-03-17 Schlumberger Holdings Downhole closed loop control of azimuthal drilling direction
GB2393197A (en) * 2002-09-19 2004-03-24 Lattice Intellectual Property Pitch sensor for a steerable drill
GB2415972A (en) * 2004-07-09 2006-01-11 Halliburton Energy Serv Inc Closed loop steerable drilling tool
WO2009047729A2 (en) * 2007-10-12 2009-04-16 Schlumberger Canada Limited Downhole load sharing motor assembly
DE102011103220B3 (de) * 2011-06-01 2012-10-18 Tracto-Technik Gmbh & Co. Kg Doppelrohrgestängeschuss mit einer im Doppelrohrgestängeschuss angeordneten Sonde, ein Horizontalbohrgerät und ein Sondengehäuse
EP2828479A4 (de) * 2012-03-23 2016-04-20 Baker Hughes Inc Umweltfreundlich betriebener sender zur standortidentifizierung von bohrlöchern
US9933544B2 (en) 2014-12-24 2018-04-03 Halliburton Energy Services, Inc. Near-bit gamma ray sensors in a rotating section of a rotary steerable system
WO2020132097A1 (en) 2018-12-19 2020-06-25 Doublebarrel Downhole Technologies Llc Geosteering in a lateral formation
WO2023193522A1 (zh) * 2022-04-08 2023-10-12 中海油田服务股份有限公司 推靠式旋转导向装置

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1163419B1 (de) 1999-11-10 2004-06-16 Schlumberger Holdings Limited Steuerungsverfahren für steuerbares bohrsystem
GB2398091B (en) * 2001-05-14 2005-06-29 Baker Hughes Inc Method and apparatus for monitoring and recording of the operating condition of a downhole drill bit during drilling operations

Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2039093A (en) * 1978-12-26 1980-07-30 Conoco Inc Drill machine guidance using natural occurring radiation
US4905774A (en) * 1986-05-27 1990-03-06 Institut Francais Du Petrole Process and device for guiding a drilling tool through geological formations
GB2257182A (en) * 1991-06-25 1993-01-06 Camco Drilling Group Ltd Improvements in or relating to steerable rotary drilling systems
GB2259316A (en) * 1991-08-30 1993-03-10 Camco Drilling Group Ltd Modulated bias units for steerable rotary drilling systems
EP0594418A1 (de) * 1992-10-23 1994-04-27 Halliburton Company Automatisches Bohrsystem zur Verwendung im Bohrloch
US5325714A (en) * 1993-05-12 1994-07-05 Baker Hughes Incorporated Steerable motor system with integrated formation evaluation logging capacity
US5419405A (en) * 1989-12-22 1995-05-30 Patton Consulting System for controlled drilling of boreholes along planned profile
US5495237A (en) * 1992-12-07 1996-02-27 Akishima Laboratories (Mitsui Zosen) Inc. Measuring tool for collecting down hole information and metering valve for producing mud-pulse used in the same

Family Cites Families (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5230386A (en) * 1991-06-14 1993-07-27 Baker Hughes Incorporated Method for drilling directional wells
BE1007274A5 (fr) * 1993-07-20 1995-05-09 Baroid Technology Inc Procede de commande de la tete d'un dispositif de forage ou de carottage et installation pour la mise en oeuvre de ce procede.
GB9503827D0 (en) * 1995-02-25 1995-04-19 Camco Drilling Group Ltd "Improvements in or relating to steerable rotary drilling systems

Patent Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2039093A (en) * 1978-12-26 1980-07-30 Conoco Inc Drill machine guidance using natural occurring radiation
US4905774A (en) * 1986-05-27 1990-03-06 Institut Francais Du Petrole Process and device for guiding a drilling tool through geological formations
US5419405A (en) * 1989-12-22 1995-05-30 Patton Consulting System for controlled drilling of boreholes along planned profile
GB2257182A (en) * 1991-06-25 1993-01-06 Camco Drilling Group Ltd Improvements in or relating to steerable rotary drilling systems
GB2259316A (en) * 1991-08-30 1993-03-10 Camco Drilling Group Ltd Modulated bias units for steerable rotary drilling systems
EP0594418A1 (de) * 1992-10-23 1994-04-27 Halliburton Company Automatisches Bohrsystem zur Verwendung im Bohrloch
US5495237A (en) * 1992-12-07 1996-02-27 Akishima Laboratories (Mitsui Zosen) Inc. Measuring tool for collecting down hole information and metering valve for producing mud-pulse used in the same
US5325714A (en) * 1993-05-12 1994-07-05 Baker Hughes Incorporated Steerable motor system with integrated formation evaluation logging capacity

Cited By (25)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6467557B1 (en) 1998-12-18 2002-10-22 Western Well Tool, Inc. Long reach rotary drilling assembly
US6942044B2 (en) 1999-04-14 2005-09-13 Western Well Tools, Inc. Three-dimensional steering tool for controlled downhole extended-reach directional drilling
US6470974B1 (en) 1999-04-14 2002-10-29 Western Well Tool, Inc. Three-dimensional steering tool for controlled downhole extended-reach directional drilling
US6708783B2 (en) 1999-04-14 2004-03-23 Western Well Tool, Inc. Three-dimensional steering tool for controlled downhole extended-reach directional drilling
FR2812338A1 (fr) * 2000-07-25 2002-02-01 Total Fina Elf S A Procede et dispositif de forage rotary d'un puits
GB2373523A (en) * 2000-07-25 2002-09-25 Total Fina Elf S A Method and device for rotary well drilling
US6702042B2 (en) * 2000-07-25 2004-03-09 Total Fina Elf S.A. Method and device for rotary well drilling
WO2002008563A1 (fr) * 2000-07-25 2002-01-31 Total Fina Elf S.A. Procede et dispositif de forage rotary d'un puits
GB2373523B (en) * 2000-07-25 2004-03-31 Total Fina Elf S A Method and device for rotary well drilling
GB2392931A (en) * 2002-09-16 2004-03-17 Schlumberger Holdings Downhole closed loop control of azimuthal drilling direction
GB2393197B (en) * 2002-09-19 2006-02-15 Lattice Intellectual Property Pitch sensing in drilling machines
GB2393197A (en) * 2002-09-19 2004-03-24 Lattice Intellectual Property Pitch sensor for a steerable drill
US7287337B2 (en) 2002-09-19 2007-10-30 Theodore Roy Dimitroff Pitch sensing in drilling machines
US8393413B2 (en) 2004-07-09 2013-03-12 Halliburton Energy Services, Inc. Closed loop control bore hole drilling system
GB2415972A (en) * 2004-07-09 2006-01-11 Halliburton Energy Serv Inc Closed loop steerable drilling tool
WO2009047729A2 (en) * 2007-10-12 2009-04-16 Schlumberger Canada Limited Downhole load sharing motor assembly
WO2009047729A3 (en) * 2007-10-12 2009-06-04 Schlumberger Ca Ltd Downhole load sharing motor assembly
GB2466408A (en) * 2007-10-12 2010-06-23 Schlumberger Holdings Downhole load sharing motor assembly
DE102011103220B3 (de) * 2011-06-01 2012-10-18 Tracto-Technik Gmbh & Co. Kg Doppelrohrgestängeschuss mit einer im Doppelrohrgestängeschuss angeordneten Sonde, ein Horizontalbohrgerät und ein Sondengehäuse
US9291008B2 (en) 2011-06-01 2016-03-22 Tracto-Technik Gmbh & Co. Kg Dual pipe rod assembly section, horizontal drilling device and probe housing
EP2828479A4 (de) * 2012-03-23 2016-04-20 Baker Hughes Inc Umweltfreundlich betriebener sender zur standortidentifizierung von bohrlöchern
US9933544B2 (en) 2014-12-24 2018-04-03 Halliburton Energy Services, Inc. Near-bit gamma ray sensors in a rotating section of a rotary steerable system
WO2020132097A1 (en) 2018-12-19 2020-06-25 Doublebarrel Downhole Technologies Llc Geosteering in a lateral formation
EP3899190A4 (de) * 2018-12-19 2022-08-10 Doublebarrel Downhole Technologies LLC Geolenkung in einer lateralen formation
WO2023193522A1 (zh) * 2022-04-08 2023-10-12 中海油田服务股份有限公司 推靠式旋转导向装置

Also Published As

Publication number Publication date
GB2312905A (en) 1997-11-12
GB9609659D0 (en) 1996-07-10
EP0806542A3 (de) 1998-09-02

Similar Documents

Publication Publication Date Title
CA2480813C (en) Apparatus and method for resistivity measurements during rotational drilling
US7114565B2 (en) Measurement-while-drilling assembly using real-time toolface oriented measurements
US6089332A (en) Steerable rotary drilling systems
CA2170183C (en) Improvements in or relating to steerable rotary drilling systems
US5325714A (en) Steerable motor system with integrated formation evaluation logging capacity
US5163521A (en) System for drilling deviated boreholes
US8220540B2 (en) Apparatus and methods for estimating loads and movements of members downhole
US6179066B1 (en) Stabilization system for measurement-while-drilling sensors
US5842149A (en) Closed loop drilling system
US7195062B2 (en) Measurement-while-drilling assembly using real-time toolface oriented measurements
EP0806542A2 (de) Steuerbares Rotary-Bohrsystem
US5685379A (en) Method of operating a steerable rotary drilling system
US7723991B2 (en) Apparatus and method for azimuthal MWD resistivity imaging at multiple depths of investigation
EP0857249A2 (de) Drehbohrsystem in geschlossener schleife
US20120109527A1 (en) Apparatus and Methods for Drilling Wellbores by Ranging Existing Boreholes Using Induction Devices
WO2000028188A1 (en) Self-controlled directional drilling systems and methods
WO2008039720A2 (en) Resistivity tools with collocated antennas
US10000971B2 (en) Steering tool with eccentric sleeve and method of use
CN107110993A (zh) 旋转导向工具中的伽马检测传感器
US9062497B2 (en) Phase estimation from rotating sensors to get a toolface
CA2500382C (en) Measurement-while-drilling assembly using real-time toolface oriented measurements

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

AK Designated contracting states

Kind code of ref document: A2

Designated state(s): DE FR NL

PUAL Search report despatched

Free format text: ORIGINAL CODE: 0009013

AK Designated contracting states

Kind code of ref document: A3

Designated state(s): DE FR NL

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE APPLICATION IS DEEMED TO BE WITHDRAWN

18D Application deemed to be withdrawn

Effective date: 19990303