[go: up one dir, main page]
More Web Proxy on the site http://driver.im/

WO1997027502A1 - Systeme de forage a systeme acoustique de mesure operant pendant le forage permettant de determiner des parametres recherches et commander l'orientation du forage - Google Patents

Systeme de forage a systeme acoustique de mesure operant pendant le forage permettant de determiner des parametres recherches et commander l'orientation du forage Download PDF

Info

Publication number
WO1997027502A1
WO1997027502A1 PCT/US1997/001235 US9701235W WO9727502A1 WO 1997027502 A1 WO1997027502 A1 WO 1997027502A1 US 9701235 W US9701235 W US 9701235W WO 9727502 A1 WO9727502 A1 WO 9727502A1
Authority
WO
WIPO (PCT)
Prior art keywords
acoustic
downhole tool
drilling
transmitter
wellbore
Prior art date
Application number
PCT/US1997/001235
Other languages
English (en)
Inventor
James V. Leggett, Iii
Vladimir Dubinsky
John W. Harrell
William Thomas Balogh
Paul J. G. Seaton
Andrew G. Brooks
Roger P. Herbert
Original Assignee
Baker Hughes Incorporated
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 Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Priority to AU17108/97A priority Critical patent/AU1710897A/en
Priority to GB9816245A priority patent/GB2324153B/en
Publication of WO1997027502A1 publication Critical patent/WO1997027502A1/fr
Priority to NO19983432A priority patent/NO321332B1/no

Links

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
    • 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
    • G01V1/48—Processing data

Definitions

  • This invention relates generally to systems for drilling boreholes for the 0 production of hydrocarbons and more particularly to a drilling system having an acoustic measurement-while-drilling ("MWD") system as part of a bottomhole assembly for measuring acoustic velocities of subsurface formations during drilling ofthe wellbores and determining the location of formation bed boundaries around the bottomhole assembly.
  • MWD acoustic measurement-while-drilling
  • This invention also relates to controlling the 5 drilling direction or the wellbore trajectories based on the location of the bed boundaries.
  • the term "bed boundary” is used to denote a bed boundary, a formation contrast, or a subsurface reflection point.
  • This invention also provides a downhole system for correlating the acoustic measurements with other downhole sensor and MWD measurements and for o mapping seismic data and/or modifying existing seismic data based on acoustic and other measurements made by the downhole assembly.
  • boreholes or wellbores are drilled through hydrocarbon-bearing subsurface formations.
  • a large number of the current drilling activity involves drilling "horizontal" boreholes.
  • Advances in the MWD measurements and drill bit steering systems placed in the drill string enable drilling of the horizontal boreholes with enhanced efficiency and greater success.
  • Hydrocarbon recovery can be maximized by drilling the horizontal and complex wellbores along optimal locations within the hydrocarbon-producing formations (payzones).
  • Crucial to the success of these wellbores is (1) to establish reliable stratigraphic position control while landing the wellbore into the
  • drilling assembly can greatly enhance the chances of drilling boreholes for maximum recovery.
  • Prior art downhole lack in providing such information during drilling of the boreholes.
  • Modem directional drilling systems usually employ a drill string having a drill bit at the bottom that is rotated by a drill motor (commonly referred to as the "mud motor").
  • a plurality of sensors and MWD devices are placed in close proximity to the drill bit to measure certain drilling, borehole and formation
  • Such parameters are then utilized to navigate the drill bit along a desired drill path.
  • sensors for measuring downhole temperature and pressure, azimuth and inclination measuring devices and a formation resistivity measuring device are employed to determine the drill string
  • the resistivity measurements are used to determine the presence of hydrocarbons against water around and/or a short distance in front of the drill bit. Resistivity measurements are most commonly utilized to navigate or "geosteer" the drill bit. However, the depth of investigation
  • resistivity devices usually extends to 2-3 meters. Resistivity measurements do not provide bed boundary information relative to the downhole subassembly. Furthermore, error margin of the depth-measuring devices, usually deployed on the surface, is frequently greater than the depth of investigation of the resistivity devices. Thus, it is desirable to have a downhole system which can relatively accurately map the bed boundaries around the downhole subassembly so that the drill string may be steered to obtain optimal
  • MWD directional survey tools and the formation dip uncertainty.
  • MWD tools are deployed to measure the earth's gravity and magnetic field to determine the inclination and azimuth. Knowledge of the course and position of the wellbore depends entirely on these two angles. Under normal operating conditions, the inclination measurement accuracy is approximately plus or minus 0.2 ° Such an error translates into a target location uncertainty of about 3.0 meters per 1000 meters along the borehole. Additionally, dip rate variations of several degrees are common. The optimal placement of the borehole is thus very difficult to obtain based on the currently available MWD measurements, particularly in thin payzones, dipping formation and complex wellbore designs.
  • PCT application No. PCT/NO/00183 filed by Statoil Corp. disclosed the use of acoustic sensors having a relatively short spacing between the receivers and the transmitter to determine the formation bed boundaries around the downhole subassembly.
  • An essential element in determining the bed boundaries is the determination of the travel time of the reflection acoustic signals from the bed boundaries or other interface anomalies.
  • This application proposes utilizing estimates of the acoustic velocities obtained from prior seismic data or offset wells. Such acoustic velocities are not very precise because they are estimates of actual formation acoustic velocities.
  • the depth measurements can be off by several meters from the true depth of the downhole subassembly, it is highly desirable to utilize actual acoustic formation velocities determined downhole during the drilling operations to determine the location of bed boundaries relative to the drill bit location in the wellbore.
  • the Statoil application discloses acoustic sensor designs to achieve a certain amount of directivity of signals. It also discloses a transmitter coupling scheme and signal processing method for reducing the effects of the tube wave and the body waves. Such methods, however, alone do not provide sufficient reduction of the tube and body wave effects, especially due to strong direct coupling of the acoustic signals between the transmitters and their associated receivers.
  • the present invention addresses the above-noted needs and provides a
  • the bottomhole subassembly includes an acoustic MWD system having one acoustic sensor arrangement that is utilized to determine the acoustic velocities of the borehole formations during drilling and another acoustic sensor arrangement for determining bed boundary information based on the formation acoustic velocities measured downhole.
  • Novel acoustic sensor arrangements are disclosed for relatively precisely determining the bed boundary information.
  • Acoustic isolators between the transmitters and their associated receivers are provided to reduce the body wave and tube wave
  • a steering device or system is included in the bottomhole assembly which can be operated downhole and/or from the surface to steer the drill bit to drill the wellbore along the desired path.
  • the system of the present invention correlates measurements from the various MWD devices and sensors to provide parameters of interest relating to
  • the bed boundary information may be utilized to map the borehole profile, to update or modify seismic data stored in the downhole subassembly and to steer the drill bit so as to obtain the desired borehole profile.
  • the bed boundary and other information computed downhole may be stored downhole for later retrieval and use. Additionally, selected parameters of interest and other information are transmitted to the surface during the drilling operations to aid the driller in controlling the drilling operations including accurately geosteering the drill string.
  • the present invention provides a closed-loop system for drilling boreholes.
  • the system includes a drill string having a drill bit and a downhole subassembly having a plurality of sensors and measurement-while-drilling devices, a downhole computing system and a two-way telemetry system for computing downhole bed boundary information relative to the downhole
  • the downhole subassembly includes an acoustic MWD system which contains a first set of acoustic sensors for determining the formation acoustic velocities during drilling of the wellbore and a second set of acoustic
  • a computing system is provided within the downhole subassembly which processes downhole sensor information and computes the various parameters of interest including the bed boundaries, during drilling of the wellbore.
  • the first and second sets (arrangements) of acoustic sensors contain a transmitter and a receiver array, wherein the transmitter and some of the receivers in the receiver array are common to both sets of acoustic sensors.
  • Each receiver in the receiver array further may contain one or more individual acoustic sensors.
  • the distance between the transmitter and the farthest receiver in one of the acoustic sensor sets is substantially greater than the distance between the transmitter and center of the receivers in the second set.
  • the downhole computing system contains programmed instructions, models, algorithms and other information, including information from prior drilled boreholes, geological information about the subsurface formations and the borehole drill path.
  • the acoustic system contains a common
  • a separate stabilizer is placed equidistant between the transmitter and each of the receiver arrays to cause substantially the same amount of reflections of the transmitted acoustic signals.
  • the symmetrical arrangement aids in substantially reducing the effects of the body
  • acoustic isolators may be placed between the transmitter and each of the receiver arrays to dampen the direct
  • acoustic signals between the transmitter and receives and to increase the travel time therebetween so as to reduce the effect of body waves and tube waves on the receivers.
  • the acoustic system of the present invention determines the actual formation velocities downhole during drilling of the wellbore ad then utilizes such formation velocities to determine the bed boundaries around the downhole subassembly.
  • the drill bit location is computed downhole or is provided to the
  • the bed boundary information is utilized to geosteer the drill string so as to maintain the borehole at a desired place within the formation.
  • the acoustic velocity and bed boundary information is utilized to correct or update seismic maps and to correlate measurements from other MWD measurements.
  • the present invention also provides a method for drilling a borehole utilizing a downhole subassembly having a first and second acoustic sensor arrangement and a computing system for computing measurements downhole during the drilling of the borehole.
  • the method comprises: (a) conveying the downhole subassembly along the wellbore; (b) determining downhole, by the computing system, the velocity of acoustic signals through formations near the
  • downhole subassembly from measurements made from the first acoustic sensor arrangement; and (c) determining downhole, by the computing system, bed boundaries of the formations from measurements from the second acoustic sensor arrangement and the determined acoustic velocities in accordance with programmed instructions provided to the computing system.
  • the drilling direction is adjusted based on the location of the downhole assembly in relation to the formation bed boundaries.
  • FIG. 1 shows a schematic diagram of a drilling system having a drill string that includes an acoustic sensor system according to the present invention.
  • FIG. 2 shows a functional block diagram of the major downhole elements of the system shown in FIG. 1.
  • FIG. 3a shows an embodiment of the acoustic sensor system for use in the system of the present invention.
  • FIG. 3b shows an alternative embodiment of the acoustic sensor system for use in the system of the present invention.
  • FIG. 4 shows an acoustic sensor system arrangement placed between the mud motor and the drill bit for use in the system of FIG. 1.
  • FIG. 5a shows a schematic diagram of an application of the acoustic system configuration of FIG. 4 in a formation having a relatively small dip angle.
  • FIG. 5b shows graphically the common mode deterministic noise reduction for the acoustic sensor configuration shown in FIG. 5a.
  • FIG. 6 shows a functional block diagram for canceling the background noise in the configuration of the acoustic sensor system shown in FIG. 5a.
  • FIG. 7 is a schematic diagram of a drilling assembly having an acoustic
  • FIG. 8 is a functional block diagram of a signal processing circuit for processing acoustic data from the acoustic systems of the present invention.
  • FIG. 9 is a schematic diagram showing subsurface formations along the
  • FIG. 10 is an example of a sonic log that can be produced during drilling of the borehole by the acoustic sensor system of the present invention. DESCRIPTION OF THE PREFERRED EMBODIMENT
  • the present invention provides a drilling system for drilling of boreholes.
  • the drilling system contains a drill string having a downhole subassembly that includes a drill bit at its bottom end and a plurality of sensors and MWD devices, including an acoustic MWD system having a first set of
  • a downhole computer and associated memory are provided for computing various downhole operating parameters, to map the formation around the downhole subassembly, to update stored models and data as a result of the computed parameters and to aid the driller in navigating the drill string
  • the system of the invention also preferably includes devices for
  • the drill string may contain other MWD devices known in the art for providing information about the subsurface geology, borehole conditions and mud motor operating parameters, such as the differential pressure across the mud motor, torque and the condition of the bearing assembly.
  • Selected data is transmitted between the downhole subassembly and surface computing apparatus via a two-way telemetry system.
  • the surface computing apparatus transmits signals to the downhole subassembly for controlling certain desired operations and also for processing the received data according to programmed instruction to improve the drilling operations.
  • FIG. 1 shows a schematic diagram of a drilling system 10 having a downhole assembly containing an acoustic sensor system and the surface devices according to one embodiment of present invention.
  • the system 10 includes a conventional derrick 11 erected on a derrick floor 12 which supports a rotary table 14 that is rotated by a prime mover (not shown) at a desired rotational speed.
  • a drill string 20 that includes a drill pipe section 22 extends downward from the rotary table 14 into a borehole 26.
  • a drill bit 50 attached to the drill string downhole end disintegrates the geological formations when it is rotated.
  • the drill string 20 is coupled to a drawworks 30 via a kelly joint 21, swivel 28 and line 29 through a system of pulleys 27.
  • the drawworks 30 is operated to control the weight on bit and the rate of penetration of the drill string 20 into the borehole 26.
  • the operation of the drawworks is well known in the art and is thus not described in detail herein.
  • a suitable drilling fluid (commonly referred to in
  • mud 31 from a mud pit 32 is circulated under pressure through the drill string 20 by a mud pump 34.
  • the drilling fluid 31 passes from the mud pump 34 into the drill string 20 via a desurger 36, fluid line 38 and the kelly joint 21.
  • the drilling fluid is discharged at the borehole bottom 51 through an opening in the drill bit 50.
  • the drilling fluid circulates uphole through the annular space 27
  • a variety of sensors are appropriately deployed on the surface according to known methods in the art to provide information about various drilling-related parameters, such as fluid flow rate, weight on bit, hook load, etc.
  • a surface control unit 40 receives signals from the downhole sensors and devices via a sensor 43 placed in the fluid line 38 and processes such signals according to programmed instructions provided to the surface control unit.
  • the surface control unit displays desired drilling parameters and other information on a display/monitor 42 which information is utilized by an operator to control the
  • the surface control unit 40 contains a computer, memory for storing data, data recorder and other peripherals.
  • the surface control unit 40 also includes models and processes data according to programmed instructions and responds to user commands entered through a suitable means, such as a
  • the control unit 40 is preferably adapted to activate alarms 44 when certain unsafe or undesirable operating conditions occur.
  • a drill motor or mud motor 55 coupled to the drill bit 50 via a drive shaft (not shown) disposed in a bearing assembly 57 rotates the drill bit 50 when the drilling fluid 31 is passed through the mud motor 55 under pressure.
  • the bearing assembly 57 supports the radial and axial forces of the drill bit, the downthrust of 5 the drill motor and the reactive upward loading from the applied weight on bit.
  • stabilizer 58 coupled to the bearing assembly 57 acts as a centralizer for the lowermost portion of the mud motor assembly.
  • the downhole subassembly 59 (also referred to as the bottomhole assembly or "BHA") which contains the various sensors and MWD devices to provide information about the formation and downhole drilling parameters and the mud motor, is coupled between the drill bit 50 and the drill pipe 22.
  • the downhole assembly 59 preferably is modular in construction, in that the various devices are 5 interconnected sections so that the individual sections may be replaced when desired.
  • the BHA also preferably contains sensors and devices in addition to the above-described sensors.
  • sensors and devices include a
  • a gamma ray device for measuring the formation gamma ray intensity and devices for determining the inclination and azimuth of the drill string.
  • the formation resistivity measuring device 64 is preferably coupled above the lower kick-off subassembly 62 that provides signals, from which resistivity of the formation near or in front of the drill bit 50 is determined.
  • One resistivity measuring device is described in U.S. Patent No. 5,001,675, which is assigned to the assignee hereof and is inco ⁇ orated herein by reference. This patent describes a dual propagation resistivity device ("DPR") having one or more pairs of transmitting antennae 66a and 66b spaced from one or more pairs of receiving antennae 68a
  • DPR dual propagation resistivity device
  • the transmitted electromagnetic waves are perturbed as they propagate through the formation surrounding the resistivity device 64.
  • the receiving antennae 68a and 68b detect the perturbed waves.
  • Formation resistivity is derived from the phase and amplitude of the detected signals.
  • the detected signals are processed by a downhole circuit that is preferably placed in a housing 70 above the mud motor 55 and transmitted to the surface control unit 40 using a suitable telemetry system 72.
  • the inclinometer 74 and gamma ray device 76 are suitably placed along
  • the resistivity measuring device 64 for respectively determining the inclination of the portion of the drill string near the drill bit 50 and the formation gamma ray intensity. Any suitable inclinometer and gamma ray device, however, may be utilized for the purposes of this invention.
  • an azimuth device (not shown), such as a magnetometer or a gyroscopic device, may be utilized to determine the drill string azimuth. Such devices are known in the art and are, thus, not described in detail herein.
  • the mud motor 55 transfers power to the drill bit 50 via one or more hollow shafts that run through the resistivity measuring device 64. The hollow shaft enables the drilling fluid to pass from the mud motor 55 to the drill bit 50.
  • the mud motor 55 may be coupled below resistivity measuring device 64 or at any other suitable place.
  • U.S Patent No. 5,325,714 to Lende assigned to the assignee hereof, which is inco ⁇ orated herein by reference, discloses placement of a resistivity device between the drill bit and the mud motor.
  • the above described resistivity device, gamma ray device and the inclinometer are preferably placed in a common housing that may be coupled to the motor in the manner described in U.S. Patent No. 5, 325,714.
  • U.S. Patent Application Serial No. 08/212,230 assigned to the assignee hereof, which is incorporated herein by reference, discloses a modular system wherein the drill string contains modular assemblies including a modular sensor assembly, motor assembly and kick-off subs. The modular sensor assembly is disposed between the drill bit and the
  • the present invention preferably utilizes the modular system as disclosed in U.S. Serial No. 08/212,230.
  • the downhole assembly of the present invention preferably includes a MWD section 78 which contains a nuclear formation porosity measuring device, a nuclear density device and an acoustic sensor system placed above the mud motor 64 in the housing 78 for providing information useful for evaluating and testing subsurface formations along borehole 26.
  • the preferred configurations of the acoustic sensor system are described later with reference to FIGS. 3a, 3b and 5a.
  • the present invention may utilize any of the known formation density devices.
  • United States Patent No. 5,134,285 which is assigned to the assignee hereof and which is incorporated herein by reference, discloses a formation density device that employs a gamma ray source and a detector which may be
  • gamma rays emitted from the source enter the formation where they interact with the formation and attenuate.
  • the attenuation of the gamma rays is measured by a suitable detector from which density of the formation is determined.
  • the porosity measurement device preferably is the device generally disclosed in United States Patent No. 5,144,126, which is assigned to the assignee hereof and which is incorporated herein by reference.
  • This device employs a neutron emission source and a detector for measuring the resulting gamma rays. In use, high energy neutrons are emitted into the surrounding formation. A suitable detector measures the neutron energy delay due to interaction with hydrogen and atoms present in the formation.
  • Other examples of nuclear logging devices are disclosed in United States Patent Nos. 5,126,564 and 5,083,124.
  • the above-noted devices transmit data to the downhole telemetry system
  • the downhole telemetry also receives signals and data from the uphole control unit 40 and transmits such received signals and data to the appropriate downhole devices.
  • the present invention preferably utilizes a mud pulse telemetry technique to communicate data from downhole sensors and devices during drilling operations.
  • a transducer 43 placed in the mud supply line 38 detects the mud pulses responsive to the data transmitted by the downhole telemetry 72.
  • Transducer 43 generates electrical signals in response to the mud pressure variations and transmits such signals via a conductor 45 to the surface control unit 40.
  • Other telemetry techniques such electromagnetic and acoustic techniques or any other suitable technique may be utilized for the pu ⁇ oses of this invention.
  • FIG. 2 shows a functional block diagram of the major elements of the
  • FIG. 2 illustrates only one arrangement of the elements and a system of data communication therebetween. Other arrangements may be utilized equally effectively for the pu ⁇ ose of this invention.
  • the sensors for determining the downhole operating conditions and the downhole assembly health are denoted by Si - S j
  • the acoustic sensor system is denoted by numeral 160 while the
  • d, - dm remaining downhole MWD devices, such as the nuclear, electromagnetic, directional and the like, are denoted by d, - dm.
  • the sensors S ⁇ -Sj, MWD devices d ⁇ -d m and the desired acoustic sensor system 160 are arranged within
  • a predetermined number of discrete data points output from the sensors and MWD devices are stored within a buffer which, in FIG. 2, is included as a partitioned portion of the memory capacity of the computer 150.
  • the buffer storage can comprise a separate element (not shown).
  • Sensor response relationships or "models" for the acoustic sensor system and other sensors in the downhole subassembly are preferably stored in a
  • the downhole electronics for processing signals downhole and to perform other computations includes the computer or controller 150, memory 145 and 146, and other desired components, such as signals processors, amplifiers, etc. (not shown). For simplicity, the use of such components is known and are thus, not included in FIG. 2.
  • the parameters of interest are transmitted to the surface via the up-link telemetry path 127 or stored in the memory 146 for
  • the acoustic sensor system 160 and other sensors 152 and d ⁇ -d m are placed axially along the downhole subassembly, their responses do not correspond to the same measure point within the borehole 26 (see FIG. 1).
  • the computer 150 shifts the data to a common depth point. Also, the various devices d ⁇ -d m do not necessarily exhibit the same vertical resolution. Therefore, vertical resolution matching is performed by the computer 150 before combining or correlating measurements from different sensors.
  • the power source 144 supplies power to the telemetry element 142, computer 150, memories 146 and 148 and associated control circuits (not shown).
  • Information from the surface is transmitted over the downlink telemetry path illustrated conceptually by the broken arrow 129 to the downhole receiving element of the downhole telemetry unit 142, and then transmitted to the data storage unit 148
  • FIG. 3a is a schematic diagram of a portion 200 of the downhole subassembly showing an embodiment of the acoustic system of the present invention placed in the MWD section 78 shown in FIG. 1.
  • the subsystem of FIG. 3a is preferably placed between the mud motor 55 and the downhole telemetry section 72.
  • the subsystem 200 contains a nuclear density device 202 and a
  • the density device 202 and the porosity device 204 may be enclosed in a common housing 208 or formed as individual sections or modules.
  • a first acoustic transmitter or a set of transmitters T t is placed
  • a second acoustic transmitter or set of transmitters T 2 is placed past the porosity device and a second acoustic isolator 210.
  • a plurality of acoustic receivers R1 - Rn are placed axially spaced from each other between the transmitters Ti and T 2 .
  • distance d 2 between the transmitter Ti and the center of the far receiver of the array 212 is preferably less than four and one half (4.5) meters while the distance di between transmitter T 2 and the near receiver of the array 212 is no less than
  • Each of the transmitters and the receivers are coupled to electronic
  • the acoustic system for determining the formation acoustic velocities is selectively activated when drilling and the acoustic system for determining the bed boundary information is activated when the drilling activity is stopped so as to substantially reduce acoustic noise generated by the drill bit.
  • both the velocity and bed boundary measurements may be while the drilling is in progress. Other suitable modes of operation may also be utilized in the system of the present invention.
  • an array of two or more receivers is preferred over a smaller number of receivers to obtain more accurate acoustic measurements. It is known that the quality of acoustic measurements may be enhanced by utilizing receiver arrays having a large number of receivers. In operation, the
  • the transmitters are preferably energized several times over a known time period and the received signals are stacked to improve resolution. Such data processing techniques are known in the art and are thus not described in detail herein.
  • the transmitter Ti is preferably operated at a preselected frequency between 5 to 20 KHz while the transmitter T 2 is operated at a frequency between 100 Hz to 5 KHz.
  • the downhole computer 150 determines the time of travel of the acoustic
  • the computer determines the distance between a measure point in the subassembly 200 and the bed boundaries around the downhole subassembly from data received by the receivers in response to the signals transmitted by the transmitter T 2 and by utilizing the actual acoustic velocity measurements determined by the computer.
  • the distance d 2 is preferably less than 4.5 meters, which has been determined in the art to be sufficient for determining the acoustic velocities through the formations surrounding the transmitter and receiver array.
  • large distance between the transmitter and receiver is detrimental in that the tube waves and body waves may constitute dominant signals received by the receivers, which are then filtered or removed by mathematical techniques known in the art, prior to processing the signals reflected from the bed
  • acoustic isolators 206 and 208 are respectively placed between the transmitters Ti and T 2 and the receivers.
  • a portion of the isolator preferably extends beyond the housing 211, i.e., into the annulus between the borehole and the downhole subassembly so as to dampen or reduce the direct coupling effect of the tube waves.
  • the transmitters may be operated by sweeping the frequencies within their respective ranges or may be operated at different discrete multiple frequencies to remove the noise and to thereby improve the signal quality.
  • the downhole computer 150 may be programmed to operate the acoustic sensor systems at the desired frequencies and the desired time intervals. The frequency used typically depends upon the depth of investigation and resolution desired for a particular application.
  • the acoustic system embodiment of FIG. 3a shows two transmitter and a single receiver array. Some or all of the receivers in the array may be utilized as the short-spaced receivers and similarly some or all receivers in the array may be utilized as the long-spaced receivers.
  • the acoustic elements in the present invention may be configured to contain a single transmitter and a short- spaced receiver or receiver array and a long-spaced receiver or receiver array as shown in FIG 3b. In such a configuration, the single transmitter T is preferably placed at
  • a near receiver array (Rnear) 220 having receivers Ri-R m is placed at a distance di and a far receiver array (R ⁇ ) 222 having receivers RVR' n is placed at a distance d 2 from the transmitter T.
  • the acoustic isolator 222 in this configuration is placed between the transmitter T and the long-spaced receiver array 222.
  • the single transmitter T may be operated during one time interval at a first frequency or set of frequencies for the short- spaced receivers 220 and operated in a second time interval at a second frequency or set of frequencies for the long-spaced receivers 222.
  • all of the acoustic sensors are placed above
  • the mud motor 55 may be placed above the mud motor and the others below the mud motor.
  • FIG. 4 shows an alternative embodiment of the downhole subassembly
  • the acoustic sensors (transmitters and receivers) are placed between the drill bit 50 and the mud motor power section 55 section.
  • the lower stabilizer 58a and upper stabilizer 58b are utilized as acoustic noise isolators.
  • the acoustic sensors are preferably disposed in the housing which contains the resistivity measuring device, the gamma ray density device and the inclinometer, collectively denoted by numeral 80.
  • the remaining elements of the downhole subassembly are contained in the
  • the acoustic receivers Ri and R 2 are preferably arranged symmetrically about the transmitter T so as to cancel the direct coupling acoustic noise during processing of the received reflected signals, as more fully described below in reference to FIGS. 5a-5c.
  • FIG. 5a shows the acoustic sensor system having two receivers or arrays of receivers R1 and R2 placed symmetrically about a transmitter between two substantially identical stabilizers 260 and 262 placed on either side of the transmitter T.
  • all deterministic signals relating to the acoustic transmitter arrive at each pair of the symmetrically placed receivers at the same time with identical amplitudes as shown by amplitude versus time reflection waves shown in FIG. 5b.
  • Signals received by each of the receivers of the receiver arrays Ri and R 2 are labeled r to r n .
  • the receivers R1 and R2 each receive the identical signals at the same time.
  • each receiver pair The signals received by each receiver pair are subtracted from each other to determine the differential for the corresponding pair of receivers.
  • the common noise signals cancel out leaving the informative or useful reflection signals as the differential signals except in certain unique situation, such as when the acoustic sensor array is exactly parallel to the reflecting bed boundary.
  • the system may be adapted to process signals from each receiver or receiver arrays independently to determine the bed boundary conditions. As shown in FIG. 5a, the informative signals r$ that correspond to the
  • each receiver in any of the embodiments may contain one or more acoustic sensors.
  • the acoustic system may include one or more acoustic isolators such as isolators 270a and 270b respectively placed between the transmitter and the receiver arrays R1 and R2 to reduce the effect of the body waves and tube waves between the transmitter and the receivers.
  • acoustic isolators such as isolators 270a and 270b respectively placed between the transmitter and the receiver arrays R1 and R2 to reduce the effect of the body waves and tube waves between the transmitter and the receivers.
  • the these isolators preferably extends a certain distance beyond the housing 272 so as to reduce the effect of the tube waves.
  • These isolators may be partially embedded in the housing 272 and may be made from any desired material or combination of materials.
  • the body wave isolation portion may be made from a suitable elastomeric material while the tube wave portion of the isolator may be made from a suitable metal.
  • the system may be adapted to utilize multi-frequency acoustic pulses.
  • the sequential use of different excitation frequencies for the short-spaced receivers can be successfully used for calculating the distance between downhole subassembly and the bed boundary.
  • the quality of the acoustic wave propagation through the medium could be different for different frequencies.
  • multi-frequency investigation with a correlation analysis may be utilized to obtain more accurate inte ⁇ retation of the results.
  • Any known signal processing method may be utilized for processing the acoustic signals in this invention.
  • the processing techniques are substantially similar to the well known seismic signals processing techniques, particularly the single well seismic techniques.
  • Such techniques include making preliminary corrections (static and dynamic), building stacked data sets, convolution and time-varying Weiner methods and other shaping filtering techniques and seismic filtering techniques, such as casual feedforward filtering, casual feedback filtering, minimum delay, and least square wavelet filtering, etc.
  • Such methods are typically based on known signal processing techniques, such as the complex transfer function calculation, spectral and Cepstrum analysis, Hubert transform, etc.
  • the system of the present invention preferably utilizes a technique for canceling the background noise that is not related to the acoustic source in the system.
  • noise includes natural acoustic noise of the earth and random noise from the various sources around the wellbore, such as noise generated by
  • FIG. 6 shows a functional block diagram of a preferred background cancellation method. This method assumes that the statistical parameters of the background noise remain the same during
  • the system is programmed to record and memorize the background noise pattern in an associated memory as shown by block 302. Then during the investigation of the bed boundaries, the recorded noise pattern is correlated with the signals (signal+ noise) 301 received by the acoustic receivers of the system by calculating a
  • Such a component is removed from the received signals with a correcting scale coefficient k, block 305.
  • the coefficient k is estimated based on the level of coherence between the received signal and the recorded noise.
  • the signal from the transfer function calculation unit 304 is passed to a coherence level acceptance unit 306.
  • the noise signal portion based on the coefficient k is removed from the output signal of the coherence level acceptance unit 306 as shown by subtractor block 308 to obtain a noise cleaned signal 310.
  • the present invention preferably utilizes the Cepstrum and Wavelet technique to detect small amplitude informative reflections combined with other non-informative reflections, such as reflections coming from the stabilizers, and having the same frequency content.
  • informative signals are detected by utilizing a few time-to-frequency and reverse conversions along with logarithmic treatment for separating multiplicative components.
  • FIG. 7 is a schematic diagram of a drilling assembly 400 disposed in a formation 405.
  • the drilling assembly 400 includes a drill bit 412 at an end of the drilling assembly 400 and an acoustic MWD tool 410.
  • the acoustic system 410 includes a housing or body 414.
  • the acoustic tool 410 contains two spaced-
  • receivers Ri and R 2 are disposed on either side of the transmitter T1.
  • the receiver Ri is shown disposed downhole of the transmitter Ti and the receiver R 2 is shown disposed uphole of the transmitter Ti.
  • the receiver Ri is shown to contain a plurality of individual acoustic sensors R ⁇ '-
  • the receiver R 2 is shown to contain an array spaced-apart receivers R 2a -R 2n , each such receiver having a plurality of individual acoustic sensors circumferentially disposed around the tool body 414.
  • the receiver Ri and the receiver R 2 * of receiver R 2 are symmetrically disposed about the transmitter Ti, i.e, equidistant (di) from the transmitter Ti.
  • the receivers in the array R 2 are preferably
  • the transmitter Ti and receivers Ri and R ⁇ a are utilized to measure the
  • a second transmitter T is shown disposed uphole
  • FIG. 7 is shown with receivers
  • the acoustic sensor arrangement containing the transmitter T 2 and the receivers R3 and R 2n form a second symmetrical arrangement similar to the first symmetrical arrangement of transmitter Ti and receivers Ri and R ⁇ a, but spaced apart by a predetermined distance d 3 .
  • the second symmetrical sensor arrangement is utilized to determine the bed boundary distance d ⁇ in the same manner as the distance d M is determined by the first symmetrical sensor arrangement.
  • the distance or equivalently the acoustic travel times are then utilized to calculate the formation dip, which is typically defined by the angle alpha, by any of the methods well known in the art.
  • the drill bit 412 produces acoustic energy, which is transmitted into the formation 405. Therefore, the drill bit can be utilized as a transmitter of acoustic energy to determine a parameter of interest during drilling.
  • the acoustic energy transmitted by the drill bit does not produce a controlled and repeatable wave signature like the ones produced by commonly used transmitters in downhole acoustic tools.
  • an acoustic receiver 416 is placed near the drill bit 412 to provide signals corresponding to the acoustic energy produced by the drill bit
  • the processing in the tool 400 determines and stores the signature of the acoustic energy transmitted by the drill bit 412 in an associated memory.
  • One or more acoustic receivers (R ⁇ -R3)in the tool 400 are utilized to detect acoustic signals reflected by the formations or faults responsive to the acoustic energy transmitted by the drill bit 412. The detected signals are processed downhole or at the surface during drilling, utilizing the drill bit signal
  • the drill bit may be utilized in place of or in addition to one of the other transmitters to l o provide additional information.
  • the drill bit provides a source at the deepest point in the wellbore 405. It induces acoustic energy radially around the borehole (as shown by lines 413a) and in all other directions, including in the drilling direction (as shown by lines
  • Any acoustic energy 413b' reflected back to the receivers in the tool 400 by reflection points, such as 415, downhole from the drill bit 412 can be
  • acoustic sensors may be placed at the surface to detect 0 signals generated by the drill bit and from subsurface reflectors in response thereto. Such detected signals can be processed to obtain seismic information about subsurface formations, which can be used to generate seismic maps or to update existing information.
  • the acoustic system of FIG. 7 includes one acoustic sensor arrangement (Ti, and R 2 ) for determining the acoustic velocity of the formation 405 surrounding the tool 400, a second acoustic sensor arrangement (Ti, Ri and R ) for determining the first bed boundary information (such as the acoustic travel time an/or the distance), and a third acoustic arrangement (T 2 , R 3 and R 2 ) for determining the second bed boundary information, independent of the first bed
  • the acoustic sensor arrangement defined by the drill bit 412 as the transmitter and an appropriate number of receivers may be utilized in determining the acoustic velocities and/or the bed boundary information.
  • the information obtained from the acoustic tool 400 described above may be utilized to corroborate and/or update seismic data, borehole profile data stored in the tool 400 or at the surface by transmitting such information to the surface via a suitable telemetry associated with the drilling assembly 400.
  • the control system in the tool 400 may include one or more processors which preferably utilize specific expert system algorithms, to generate specific steering instructions and cause the steering device to drill the borehole along a desired drill path.
  • the tool 410 may transmit signals and data to the surface for use by an operator for system management or for transmittal to reservoir engineers located at great distances from the drilling site, for ultimate reservoir penetration. Such information is especially useful for highly deviated, horizontal and complex boreholes.
  • FIG. 8 is a functional block diagram of a signal processing circuit 450 for use in the acoustic sensor system of the present invention.
  • the signal processing circuit 450 for use in the acoustic sensor system of the present invention.
  • processing circuit 450 in FIG. 8 is shown to contain two transmitters 452a and
  • the processing circuit 450 contains a controller 470 (microprocessor or microcontroller) and associated memory 472, which may be composed of one or several memory types or units.
  • programmed instructions for the controller 470 for controlling the operation of the acoustic systems of the present invention as previously described are stored in the memory 472. Any other information, such as the desired borehole profile, seismic data or models, look-up tables, algorithms, etc. required for use by the controller is preferably stored in the memory 472.
  • the controller 470 interfaces (sends and receives data and signals) with systems at the surface via a downhole telemetry system 474.
  • Each of the transmitters 452a and 452b are adapted to transmit acoustic signals at a frequency selected from a range of frequency and/or to sweep a desired range of frequency.
  • An amplifier 454a coupled to the antenna 452a generates the desired signal to be transmitted by the transmitter 452a and an amplifier 454b for the transmitter 452b.
  • the controller 474 causes the transmitters to generate the desired signals at the desired times according to programmed instructions.
  • the receivers Ri-Rn detect the acoustic signals.
  • a signal conditioner 458 receives the signals detected by the receivers
  • R ⁇ -Rnch conditions such signals and passes the conditioned signals to an analog- to-digital converter (ADC) 460, which converts the conditioned signals to digital signals.
  • ADC analog- to-digital converter
  • the signal conditioner 458 may be composed of separate signal
  • DSP digital signal processor
  • the controller can be programmed to perform any number of tasks or operations.
  • the controller 470 may be programmed to compute and/or determine the desired operating parameters, compare the drilling assembly position with the desired borehole profile, update seismic models stored downhole, cause the steering device to alter the drilling direction,
  • the controller 470 may receive instructions or commands from the surface via the telemetry 474 to perform certain tasks and it may be programmed to transmit any information uphole via the telemetry 474.
  • FIGS. 9 and 10 illustrate determination of the acoustic velocities of the
  • the acoustic system 500 in the drill string 502 determines the acoustic velocities of the formations, such as acoustic velocity Va1 for the formation I, acoustic velocity
  • acoustic velocity Va3 for the formation III in the manner described earlier.
  • the acoustic velocities are depth correlated by the processing system in the downhole tool utilizing any known method to obtain accurate measure of the acoustic velocity corresponding to each of the formations and to delineate formation change. Resistivity measurements can be utilized to corroborate the change in formation. Since the actual acoustic velocities are measured as the drilling is progressing, such velocities can be used substantially in real time to aid in determining other parameters of interest during drilling of the wellbore. Such acoustic velocities can be utilized to update the seismic models, reservoir analysis, bed boundary information, while drilling.
  • FIG. 10 shows an example cf a synthetic sonic log a 550 as a function of the borehole depth shown along the vertical direction.
  • the acoustic system described above measures the acoustic velocities and determines the sonic log while drilling.
  • the log can be stored in the downhole tool and/or transmitted uphole while drilling for use at the surface by the driller or a log analyst.
  • the acoustic measurements according to the present invention provide bed boundary information around the borehole being drilled.
  • the acoustic system provides substantially deeper depth of investigation compared to the resistivity techniques.
  • the downhole computer or controller is programmed to compute and map the bed boundary around the downhole assembly. Such information can be utilized by the driller to continually steer the drill bit along the desired direction.
  • the bed boundary information enables the driller to maintain the drill bit at a desired distance from the bed boundary. It enables the driller to avoid penetrating undesired formations, which sometimes
  • the downhole assembly also may include a device for providing resistivity measurements of the formations, such as described in the U.S. Patent No. 5,325,714 to Lende. Such measurements can be used in conjunction with the acoustic measurements to further improve the steering of the
  • the downhole subassembly of the present invention may be adapted to include downhole devices which may be activated by the downhole computing system to continuously locate the wellbore at optimum location within the formation.
  • United States Patent Application serial No. 08/544,422 by Kruger et al. discloses a closed loop system for steering the drill string by without retrieving
  • the drill downhole subassembly which is incorporated herein by reference.
  • the present invention may be adapted to utilize such a steering system.
  • the present invention also utilizes the acoustic sensor data in
  • the distance between the downhole assembly and the reflector is computed by the downhole computing system for a

Landscapes

  • 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

La présente invention concerne un système (10) de forage de puits (26) comportant un sous-ensemble (59) de fond de puits équipé d'un système acoustique de mesures opérant pendant le forage. Ce système acoustique, qui est équipé d'un émetteur acoustique (T1) et d'un récepteur acoustique (R) destinés à déterminer la vitesse de propagation acoustique au travers des formations entourant le trou de forage, est également équipé d'un émetteur acoustique (T2) et d'un ensemble de récepteurs acoustiques (R1-Rn) destinés à déterminer les limites de strates entourant la formation environnante du trou de forage en exploitant les vitesses de propagation acoustique. Le sous-ensemble (59) de fond de puits comporte également un système de calcul (150) qui effectue en fond de trou des calculs et émet en tête de puits certaines réponses pendant les opérations de forage. L'information de limite de strate sert à forer le puits selon un tracé de trou de forage voulu. Le système de calcul (150) de fond de puits fait une corrélation des mesures de capteur acoustique avec d'autres mesures faites pendant le forage et émet en tête de puits une information de corrélation sélectionnée. Le système de calcul (150) de fond de puits contient un profil de puits tenu à jour au moyen de l'information de limite de strate. Le système est également adaptable pour la correction ou la mise à jour de données sismiques et de données de décalage de puits obtenues grâce aux mesures du système à capteur acoustique.
PCT/US1997/001235 1996-01-26 1997-01-24 Systeme de forage a systeme acoustique de mesure operant pendant le forage permettant de determiner des parametres recherches et commander l'orientation du forage WO1997027502A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
AU17108/97A AU1710897A (en) 1996-01-26 1997-01-24 A drilling system with an acoustic measurement-while-drilling system for determining parameters of interest and controlling the drilling direction
GB9816245A GB2324153B (en) 1996-01-26 1997-01-24 A drilling system with an acoustic measurement-while-drilling system for determining parameters of interest and controlling the drilling direction
NO19983432A NO321332B1 (no) 1996-01-26 1998-07-24 Anordning for akustisk maling av lydhastighet og laggrense-posisjoner i grunnformasjoner under boring av et borehull

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US1065296P 1996-01-26 1996-01-26
US60/010,652 1996-01-26

Publications (1)

Publication Number Publication Date
WO1997027502A1 true WO1997027502A1 (fr) 1997-07-31

Family

ID=21746748

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US1997/001235 WO1997027502A1 (fr) 1996-01-26 1997-01-24 Systeme de forage a systeme acoustique de mesure operant pendant le forage permettant de determiner des parametres recherches et commander l'orientation du forage

Country Status (4)

Country Link
AU (1) AU1710897A (fr)
GB (1) GB2324153B (fr)
NO (1) NO321332B1 (fr)
WO (1) WO1997027502A1 (fr)

Cited By (21)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0900917A1 (fr) * 1997-09-02 1999-03-10 Anadrill International SA Appareil et système pour la mesure pendant le forage près du trépan
GB2333155A (en) * 1998-01-07 1999-07-14 Anadrill Int Sa Acoustic measurement while drilling system using compressional waves reflected from within formation
WO2000003269A1 (fr) * 1998-07-08 2000-01-20 Baker Hughes Incorporated Traitement de la similarite des donnees pour un systeme de mesure acoustique et forage simultane, permettant l'imagerie des limites de formations
US6188222B1 (en) 1997-09-19 2001-02-13 Schlumberger Technology Corporation Method and apparatus for measuring resistivity of an earth formation
WO2001025823A1 (fr) * 1999-10-01 2001-04-12 Schlumberger Holdings Limited Procede d'actualisation d'un modele de terrain a l'aide de mesures rassemblees pendant la construction d'un puits
EP0950795A3 (fr) * 1998-04-15 2001-08-08 Halliburton Energy Services, Inc. Outil et procédé pour tester et évaluer de formations géologiques
EP1335105A2 (fr) * 1999-02-19 2003-08-13 Dresser Industries Inc. Méthode pour collectionner des données géologiques
WO2004011775A2 (fr) * 2002-07-30 2004-02-05 Baker Hughes Incorporated Ensemble de mesure de fond pendant le forage faisant intervenir des mesures en temps reel axees sur la face de coupe
CN103696760A (zh) * 2012-09-28 2014-04-02 中国石油天然气股份有限公司 近钻头随钻测量声波短距离传输方法和传输装置
CN103726835A (zh) * 2013-08-14 2014-04-16 中国石油大学(华东) 随钻反射声波测量声系
US8813869B2 (en) 2008-03-20 2014-08-26 Schlumberger Technology Corporation Analysis refracted acoustic waves measured in a borehole
US9074467B2 (en) 2011-09-26 2015-07-07 Saudi Arabian Oil Company Methods for evaluating rock properties while drilling using drilling rig-mounted acoustic sensors
US9234974B2 (en) 2011-09-26 2016-01-12 Saudi Arabian Oil Company Apparatus for evaluating rock properties while drilling using drilling rig-mounted acoustic sensors
RU2581074C1 (ru) * 2014-11-27 2016-04-10 Шлюмберже Текнолоджи Б.В. Способ акустического каротажа
US9447681B2 (en) 2011-09-26 2016-09-20 Saudi Arabian Oil Company Apparatus, program product, and methods of evaluating rock properties while drilling using downhole acoustic sensors and a downhole broadband transmitting system
US9624768B2 (en) 2011-09-26 2017-04-18 Saudi Arabian Oil Company Methods of evaluating rock properties while drilling using downhole acoustic sensors and telemetry system
US9903974B2 (en) 2011-09-26 2018-02-27 Saudi Arabian Oil Company Apparatus, computer readable medium, and program code for evaluating rock properties while drilling using downhole acoustic sensors and telemetry system
US10180061B2 (en) 2011-09-26 2019-01-15 Saudi Arabian Oil Company Methods of evaluating rock properties while drilling using downhole acoustic sensors and a downhole broadband transmitting system
US10551516B2 (en) 2011-09-26 2020-02-04 Saudi Arabian Oil Company Apparatus and methods of evaluating rock properties while drilling using acoustic sensors installed in the drilling fluid circulation system of a drilling rig
US10557345B2 (en) 2018-05-21 2020-02-11 Saudi Arabian Oil Company Systems and methods to predict and inhibit broken-out drilling-induced fractures in hydrocarbon wells
US10753203B2 (en) 2018-07-10 2020-08-25 Saudi Arabian Oil Company Systems and methods to identify and inhibit spider web borehole failure in hydrocarbon wells

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3881168A (en) * 1973-12-11 1975-04-29 Amoco Prod Co Seismic velocity determination
US4683557A (en) * 1984-10-05 1987-07-28 Mobil Oil Corporation Acoustic logging method for identifying subsurface formation boundaries
EP0553908A2 (fr) * 1992-01-21 1993-08-04 Anadrill International SA Méthode et dispositif pour la mesure pendant le forage près du trépan
WO1996021871A1 (fr) * 1995-01-12 1996-07-18 Baker Hughes Incorporated Systeme acoustique de mesure au cours du forage utilisant de multiples emetteurs et recepteurs segmentes

Family Cites Families (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3302166A (en) * 1964-03-16 1967-01-31 Mobil Oil Corp Multiple receiver acoustic well logging
GB1599067A (en) * 1978-05-30 1981-09-30 Energy Secretary Of State For Ultrasonic testing
US4601024A (en) * 1981-03-10 1986-07-15 Amoco Corporation Borehole televiewer system using multiple transducer subsystems
US5089989A (en) * 1989-06-12 1992-02-18 Western Atlas International, Inc. Method and apparatus for measuring the quality of a cement to a casing bond
EP0553980A2 (fr) * 1992-01-27 1993-08-04 Matsushita Electric Industrial Co., Ltd. Méthode d'enregistrement et de reproduction magnétique de signaux vidéo
FR2703470B1 (fr) * 1993-03-29 1995-05-12 Inst Francais Du Petrole Dispositif d'émission-réception permanent pour la surveillance d'une formation souterraine et méthode de mise en Óoeuvre.

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3881168A (en) * 1973-12-11 1975-04-29 Amoco Prod Co Seismic velocity determination
US4683557A (en) * 1984-10-05 1987-07-28 Mobil Oil Corporation Acoustic logging method for identifying subsurface formation boundaries
EP0553908A2 (fr) * 1992-01-21 1993-08-04 Anadrill International SA Méthode et dispositif pour la mesure pendant le forage près du trépan
WO1996021871A1 (fr) * 1995-01-12 1996-07-18 Baker Hughes Incorporated Systeme acoustique de mesure au cours du forage utilisant de multiples emetteurs et recepteurs segmentes

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
R.J.ROBERTS & J.D.PLATT: "Vertical seismic profiling technique emerges as a valuable drilling tool", OIL AND GAS JOURNAL, vol. 82, no. 12, 19 March 1984 (1984-03-19), TULSA US, pages 103 - 111, XP002033665 *

Cited By (36)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0900917A1 (fr) * 1997-09-02 1999-03-10 Anadrill International SA Appareil et système pour la mesure pendant le forage près du trépan
US6057784A (en) * 1997-09-02 2000-05-02 Schlumberger Technology Corporatioin Apparatus and system for making at-bit measurements while drilling
US6188222B1 (en) 1997-09-19 2001-02-13 Schlumberger Technology Corporation Method and apparatus for measuring resistivity of an earth formation
GB2333155A (en) * 1998-01-07 1999-07-14 Anadrill Int Sa Acoustic measurement while drilling system using compressional waves reflected from within formation
GB2333155B (en) * 1998-01-07 2000-07-19 Anadrill Int Sa Seismic detection apparatus and method
EP0950795A3 (fr) * 1998-04-15 2001-08-08 Halliburton Energy Services, Inc. Outil et procédé pour tester et évaluer de formations géologiques
WO2000003269A1 (fr) * 1998-07-08 2000-01-20 Baker Hughes Incorporated Traitement de la similarite des donnees pour un systeme de mesure acoustique et forage simultane, permettant l'imagerie des limites de formations
GB2354325B (en) * 1998-07-08 2002-12-04 Baker Hughes Inc Semblance processing for an acoustic measurement-while-drilling system for imaging of formation boundaries
GB2354325A (en) * 1998-07-08 2001-03-21 Baker Hughes Inc Semblance processing for an acoustic measurement-while-drilling system for imaging of formation boundaries
EP1335105A2 (fr) * 1999-02-19 2003-08-13 Dresser Industries Inc. Méthode pour collectionner des données géologiques
EP1335105A3 (fr) * 1999-02-19 2006-06-07 Halliburton Energy Services, Inc. Méthode pour collectionner des données géologiques
US6766254B1 (en) 1999-10-01 2004-07-20 Schlumberger Technology Corporation Method for updating an earth model using measurements gathered during borehole construction
WO2001025823A1 (fr) * 1999-10-01 2001-04-12 Schlumberger Holdings Limited Procede d'actualisation d'un modele de terrain a l'aide de mesures rassemblees pendant la construction d'un puits
WO2004011775A3 (fr) * 2002-07-30 2004-04-29 Baker Hughes Inc Ensemble de mesure de fond pendant le forage faisant intervenir des mesures en temps reel axees sur la face de coupe
GB2408106A (en) * 2002-07-30 2005-05-18 Baker Hughes Inc Measurement-while-drilling assembly using real-time toolface oriented measurements
GB2408106B (en) * 2002-07-30 2006-04-12 Baker Hughes Inc Measurement-while-drilling assembly using real-time toolface oriented measurements
WO2004011775A2 (fr) * 2002-07-30 2004-02-05 Baker Hughes Incorporated Ensemble de mesure de fond pendant le forage faisant intervenir des mesures en temps reel axees sur la face de coupe
NO338415B1 (no) * 2002-07-30 2016-08-15 Baker Hughes Inc Måling-under-boringsenhet og fremgangsmåte som anvender sanntids verktøyflateorienterte målinger
US8813869B2 (en) 2008-03-20 2014-08-26 Schlumberger Technology Corporation Analysis refracted acoustic waves measured in a borehole
US9903974B2 (en) 2011-09-26 2018-02-27 Saudi Arabian Oil Company Apparatus, computer readable medium, and program code for evaluating rock properties while drilling using downhole acoustic sensors and telemetry system
US9989661B2 (en) 2011-09-26 2018-06-05 Saudi Arabian Oil Company Methods for evaluating rock properties while drilling using drilling rig-mounted acoustic sensors
US9234974B2 (en) 2011-09-26 2016-01-12 Saudi Arabian Oil Company Apparatus for evaluating rock properties while drilling using drilling rig-mounted acoustic sensors
US11231512B2 (en) 2011-09-26 2022-01-25 Saudi Arabian Oil Company Apparatus and methods of evaluating rock properties while drilling using acoustic sensors installed in the drilling fluid circulation system of a drilling rig
US10669846B2 (en) 2011-09-26 2020-06-02 Saudi Arabian Oil Company Apparatus, computer readable medium, and program code for evaluating rock properties while drilling using downhole acoustic sensors and a downhole broadband transmitting system
US9447681B2 (en) 2011-09-26 2016-09-20 Saudi Arabian Oil Company Apparatus, program product, and methods of evaluating rock properties while drilling using downhole acoustic sensors and a downhole broadband transmitting system
US9624768B2 (en) 2011-09-26 2017-04-18 Saudi Arabian Oil Company Methods of evaluating rock properties while drilling using downhole acoustic sensors and telemetry system
US10551516B2 (en) 2011-09-26 2020-02-04 Saudi Arabian Oil Company Apparatus and methods of evaluating rock properties while drilling using acoustic sensors installed in the drilling fluid circulation system of a drilling rig
US10180061B2 (en) 2011-09-26 2019-01-15 Saudi Arabian Oil Company Methods of evaluating rock properties while drilling using downhole acoustic sensors and a downhole broadband transmitting system
US9074467B2 (en) 2011-09-26 2015-07-07 Saudi Arabian Oil Company Methods for evaluating rock properties while drilling using drilling rig-mounted acoustic sensors
US10036246B2 (en) 2011-09-26 2018-07-31 Saudi Arabian Oil Company Apparatus, computer readable medium, and program code for evaluating rock properties while drilling using downhole acoustic sensors and a downhole broadband transmitting system
CN103696760A (zh) * 2012-09-28 2014-04-02 中国石油天然气股份有限公司 近钻头随钻测量声波短距离传输方法和传输装置
CN103696760B (zh) * 2012-09-28 2017-07-14 中国石油天然气股份有限公司 近钻头随钻测量声波短距离传输方法和传输装置
CN103726835A (zh) * 2013-08-14 2014-04-16 中国石油大学(华东) 随钻反射声波测量声系
RU2581074C1 (ru) * 2014-11-27 2016-04-10 Шлюмберже Текнолоджи Б.В. Способ акустического каротажа
US10557345B2 (en) 2018-05-21 2020-02-11 Saudi Arabian Oil Company Systems and methods to predict and inhibit broken-out drilling-induced fractures in hydrocarbon wells
US10753203B2 (en) 2018-07-10 2020-08-25 Saudi Arabian Oil Company Systems and methods to identify and inhibit spider web borehole failure in hydrocarbon wells

Also Published As

Publication number Publication date
GB2324153B (en) 2000-05-03
GB9816245D0 (en) 1998-09-23
GB2324153A (en) 1998-10-14
NO983432D0 (no) 1998-07-24
NO983432L (no) 1998-09-24
AU1710897A (en) 1997-08-20
NO321332B1 (no) 2006-04-24

Similar Documents

Publication Publication Date Title
US6088294A (en) Drilling system with an acoustic measurement-while-driving system for determining parameters of interest and controlling the drilling direction
US6023443A (en) Semblance processing for an acoustic measurement-while-drilling system for imaging of formation boundaries
US6427124B1 (en) Semblance processing for an acoustic measurement-while-drilling system for imaging of formation boundaries
US6272434B1 (en) Drilling system with downhole apparatus for determining parameters of interest and for adjusting drilling direction in response thereto
US6470275B1 (en) Adaptive filtering with reference accelerometer for cancellation of tool-mode signal in MWD applications
US7063174B2 (en) Method for reservoir navigation using formation pressure testing measurement while drilling
WO1997027502A1 (fr) Systeme de forage a systeme acoustique de mesure operant pendant le forage permettant de determiner des parametres recherches et commander l'orientation du forage
US6614360B1 (en) Measurement-while-drilling acoustic system employing multiple, segmented transmitters and receivers
US6084826A (en) Measurement-while-drilling acoustic system employing multiple, segmented transmitters and receivers
US7114565B2 (en) Measurement-while-drilling assembly using real-time toolface oriented measurements
US8800684B2 (en) Method and apparatus for borehole positioning
US10782433B2 (en) Method for an automatic detection of acoustic reflectors and their parameters from borehole acoustic array data
GB2420412A (en) Generating acoustic signals for well logging
CA2477509A1 (fr) Dispositif et methode de diagraphie de positionnement acoustique avant le trepan
US20070127314A1 (en) Method and apparatus for detecting overpressured zone ahead of a drill bit using resistivity and seismic measurements
WO2008040030A2 (fr) Amélioration de l'évaluation d'une formation en utilisant une position d'outil de trou de forage estimée
WO2006089014A1 (fr) Correction en temps et profondeur de mesures de cable et mwd au moyen de la correlation de mesures de surface et de fond de puits
WO2007015992A1 (fr) Compensation de la disposition d'un outil au cours de mesures de resistivite lwd (diagraphie en cours de forage)
NO20240168A1 (en) Multipole shear wave splitting
US20090000859A1 (en) Method and Apparatus for Phased Array Acoustic Well Logging
GB2339908A (en) Downhole tool
US20060192560A1 (en) Well placement by use of differences in electrical anisotropy of different layers

Legal Events

Date Code Title Description
AK Designated states

Kind code of ref document: A1

Designated state(s): AL AM AT AU AZ BB BG BR BY CA CH CN CZ DE DK EE ES FI GB GE HU IL IS JP KE KG KP KR KZ LK LR LS LT LU LV MD MG MK MN MW MX NO NZ PL PT RO RU SD SE SG SI SK TJ TM TR TT UA UG UZ VN AM AZ BY KG KZ MD RU TJ TM

AL Designated countries for regional patents

Kind code of ref document: A1

Designated state(s): KE LS MW SD SZ UG AT BE CH DE DK ES FI FR GB GR IE IT LU MC NL PT SE BF BJ CF CG CI CM GA GN

DFPE Request for preliminary examination filed prior to expiration of 19th month from priority date (pct application filed before 20040101)
121 Ep: the epo has been informed by wipo that ep was designated in this application
ENP Entry into the national phase

Ref country code: GB

Ref document number: 9816245

Kind code of ref document: A

Format of ref document f/p: F

REG Reference to national code

Ref country code: DE

Ref legal event code: 8642

NENP Non-entry into the national phase

Ref country code: JP

Ref document number: 97527062

Format of ref document f/p: F

122 Ep: pct application non-entry in european phase