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WO1992013167A1 - Procede et appareil permettant d'eviter le forage d'un nouveau puits dans un puits existant - Google Patents

Procede et appareil permettant d'eviter le forage d'un nouveau puits dans un puits existant Download PDF

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Publication number
WO1992013167A1
WO1992013167A1 PCT/US1991/003579 US9103579W WO9213167A1 WO 1992013167 A1 WO1992013167 A1 WO 1992013167A1 US 9103579 W US9103579 W US 9103579W WO 9213167 A1 WO9213167 A1 WO 9213167A1
Authority
WO
WIPO (PCT)
Prior art keywords
well
set forth
monitoring
vibrations
casing
Prior art date
Application number
PCT/US1991/003579
Other languages
English (en)
Inventor
Theodore O. Stagg
Edward R. Clinton
Scott D. Selfridge
Original Assignee
Bp Exploration (Alaska) Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from US07/642,189 external-priority patent/US5131477A/en
Application filed by Bp Exploration (Alaska) Inc. filed Critical Bp Exploration (Alaska) Inc.
Publication of WO1992013167A1 publication Critical patent/WO1992013167A1/fr

Links

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
    • E21B47/16—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the drill string or casing, e.g. by torsional acoustic waves
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/02—Determining slope or direction
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/02—Determining slope or direction
    • E21B47/022—Determining slope or direction of the borehole, e.g. using geomagnetism
    • E21B47/0224—Determining slope or direction of the borehole, e.g. using geomagnetism using seismic or acoustic means
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/04—Measuring depth or liquid level

Definitions

  • One specific area of interest is the avoidance of well intersections during drilling of new wells in the vicinity of existing and especially producing wells.
  • the density of drilled wells increases as new wells are drilled to fully develop the field.
  • the density of drilled wells may also be high because of the location of the drill site or permitting.
  • Offshore production facilities are by design very high well density areas, as are some environmentally sensitive areas because of the restricted areas allocated for the drill site.
  • Directional wells are often used to maximize the production of the reservoir formation. To optimize production, directional wells are often drilled such that their paths cross or pass in close proximity to one or more existing wells at one or more points .along their lengths.
  • V.arious procedures have been devised to eliminate the possibility of blow-outs or other undesirable consequences of an intersection.
  • a common procedure is to temporarily plug the existing producing well or wells within close proximity of the new well being drilled at least until the new well has been drilled past the point of possible intersection.
  • the temporary plugging operation is expensive and production is deferred during the "shut-in” period.
  • the temporary plugging operation, or "safe-out” may be avoided by designing and drilling the well in a more expensive manner by steering a course far enough away from the existing wells. This latter approach, however, is undesirable because of high cost and in many instances it is difficult if not impossible to implement due to close spacing of wells at the surface, such as exist on offshore platforms and drill pads.
  • the present invention provides a method and apparatus for noninvasive surface or remote monitoring of activity such as mechanical operations downhole in a cased borehole.
  • the invention may be employed to monitor performance of a mud motor or drill bit by detecting vibrations traveling from the mud motor or drill bit to the surface via the well casing or other tubing string in the well and deciphering the vibrations to extract useful information therefrom.
  • the present invention provides a method and apparatus for preventing the drilling of a new well into a preexisting nearby well or wells, which method and apparatus will afford significant economic benefit to the drilling industry.
  • the invention allows continued production of nearby producing wells while protecting against accidental penetration of the producing wells by warning the driller or initiating other corrective action if the drill bit drilling the new well is coming too close to a producing well or has struck a producing well.
  • a vibration detector is coupled to the wellhead of an existing well or wells. The detector detects the acoustic waves or vibrations transmitted through the existing well that are caused by the drilling of the new well in close proximity to the existing well. When the monitored vibrations meet a predetermined criteria indicating a closely approaching drill bit or the drill bit striking the casing of an existing well, an alarm signal is produced to warn of the close approach or impact so that appropriate responsive action may be taken or automatically initiated.
  • the invention provides a method and apparatus for preventing the drilling of a new well into a nearby existing well in a subterranean formation, characterized by detecting vibrations in the existing well during drilling of the new well, .and monitoring the detected vibrations and issuing an alarm signal when the detected vibrations satisfy a predetermined criteria indicating too close approach of the new well to the existing well.
  • a vibration transducer is used to detect vibrations in the existing well.
  • the vibration transducer preferably is an accelerometer coupled to a 5 metal casing of the existing well, and a pair of matched opposed accelerometers may be used to verify proper operation of the accelerometers.
  • At least one selected band of frequencies corresponding to the acoustic signature of a drill bit drilling the new well is monitored, and the alarm signal may be issued when the amplitude of the selected frequency band exceeds a predetermined level.
  • the alarm signal may actuate a signal 10 light or audible signal, and there may be issued a low alarm corresponding to a closely approaching drill bit and a high alarm corresponding to contact or near contact of a drill bit with the casing in the existing well.
  • FIG. 1 is a schematic illustration showing drilling of a wellbore in close proximity 20 to existing wellbores to which apparatus according to the invention is connected.
  • Fig. 2 is an elevation view showing a vibration detector according to the invention mounted to a wellhead.
  • Fig. 3 is a plan view of the vibration detector looking from the line 3-3 of Fig. 2.
  • Fig. 4 is a diagrammatic illustration of a monitoring system according to the invention.
  • the wellbore 10 is lined with a steel casing 12 that terminates at its upper end at a wellhead 14. From the wellhead, the casing extends downhole to one or more completed zones.
  • An oil and gas field including wellbore 10 typically would
  • the 35 include one or more additional wellbores 16 that have been completed for production to fully develop the field.
  • the depths of the wellbores are dependent on the depths of the subterranean reservoirs containing the hydrocarbons to be produced. In some fields these depths .are greater than 10,000 feet.
  • Fig. 1 also shows a new wellbore 20 being drilled by a conventional drilling rig 21 using drill pipe 26 and a drill bit 28.
  • Directional drilling may be employed to direct the drill bit along a desired path which by design or happenstance may pass near one or more of the existing wellbores 10 and 16.
  • the invention hereinafter described in detail, functions to protect against drilling of the new wellbore 20 into an existing producing well 10, 16.
  • References herein to a drill bit are intended to generically encompass the various types of drilling implements and .associated drilling methods employed to drill wellbores.
  • the apparatus 30 comprises a vibration detector 32 for each well being monitored and a vibration analyzer 34 that monitors the output of the vibration detector or detectors.
  • the vibration detector is coupled to the casing 12 as by mounting to the wellhead 14 to detect acoustic waves or vibrations in the casing. These vibrations include those induced in the casing by the drill bit 28.
  • Drill bits and drilling methods have been found to produce unique acoustic signatures in the frequency spectrum from 0.1 hz to 10,000 hz. These unique and discernible patterns are transmitted though the formation to the steel casing and further by the steel casing to the wellhead 14 where they may be detected by the vibration detector 32.
  • the amplitude of monitored signature frequencies is believed to increase in proportion to the decrease in the distance between the active drill bit and the monitored casing.
  • the converse is also believed to be true, i.e., the apparent acoustic energy detected by the vibration detector 32 decreases as the drill bit proceeds past the shortest distance between the drill bit and the monitored casing, although at a rate slower than the drill bit approach.
  • the increase in amplitude of the drill bit signature frequency or frequencies may be used to establish a criteria on which to base issuance of a signal warning that the drill bit is coming too close to the existing well so that appropriate corrective action may be taken such as steering the drill bit away from the existing well.
  • forceful metal to metal contact between the drill bit and the metal casing will result in a perceived acoustic (including sub-acoustic) signal at the wellhead in the frequency range of 0.5 hz to 30 hz at a level more than 10 times the level of the sign.al prior to contact.
  • This manyfold increase in acoustic energy may be used as a criteria for issuing an immediate and positive alarm so that the drilling equipment may be stopped immediately and before perforation of the production tubing or casing by the drill bit.
  • Metal contact between the drill bit and casing may result in generation of an acoustic signal having a frequency corresponding to the natural resonance of the casing string and accordingly the frequency of such signal may vary from well to well.
  • the vibration detector 32 in the illustrated preferred embodiment comprises a pair of accelerometers 40 and 42 which function as vibration transducers.
  • the accelerometers are secured by bolts to a support plate 44 of a mounting bracket 46.
  • the mounting bracket 46 also includes a mounting lug 48 which is joined by a union nut 50 to a threaded stub 52 on the support plate 44.
  • the mounting lug 48 is configured for attachment to the wellhead at a flange bolt 54.
  • the mounting lug 48 has a spade end portion 56 (see Fig.
  • the illustrated mounting arrangement provides for optimum accelerometer .alignment.
  • Many accelerometers are by design affected in their output by placement in regard to the direction of the vibration path. Their greatest output or greatest sensitivity is when the accelerometer is placed with its axis parallel to the direction of the vibration path.
  • the axes of the accelerometers 40 and 42 are parallel to the casing axis at the wellhead which is parallel to the direction of the path of vibrations travelling along the length of the casing. This is advantageous in that the accelerometers will inherently reject transaxial vibrations which may be caused, for example, by equipment located in the vicinity of the well head.
  • the support plate 44 When mounting the vibration device 32 to the wellhead 14, preferably the support plate 44, with the accelerometers 40 and 42 thereon, is detached from the mounting lug 48 when the mounting lug is securely attached to the wellhead. This avoids the danger of damaging the accelerometers during the mounting procedure. After securely attaching the mounting lug to the wellhead flange, the support plate 44 with the accelerometers thereon can be gently but securely attached and aligned to the proper orientation by using the union nut 50.
  • the accelerometers 40 and 42 preferably are high quality industrial units such as Model No. 8315 accelerometers available from Bruel & Kjer of Copenhagen, Denmark. These accelerometers have a frequency range of 0.1 hz to 17,000 hz and are, by design, Class I, Div. I rated for hazardous areas.
  • the accelerometers are connected by an appropriate interconnecting cable to a power supply and an intervening intrinsically safe barrier diagrammatically represented at 76 in Fig. 4.
  • an intrinsically safe barrier is an energy-limiting device in the circuit connecting the instrument in the hazardous area and a power source/controller in the safe area.
  • the accelerometers 40 and 42 preferably are a matched pair providing redundancy. As shown, the accelerometers are oppositely disposed .and preferably are precisely on center with respect to one another. The outputs of the two accelerometers may be compared to verify proper operation. For example, the outputs may be paired and opposed such that if the combined output of the two accelerometers provides a null reading, this verifies that each output is equal giving assurance of proper operation of the accelerometers.
  • a vibration device 32 may be mounted as shown to the wellhead of each existing well. If the mounting devices are identically mounted such as by use of the mounting bracket 46, the vibration devices will provide equal output for identical acoustic input from well to well.
  • the accelerometers may be calibrated from time to time with an acceleration table. For improved repeatability and convenience, the calibration procedure may be carried out by using the support plate 44 as a convenient means to attach the accelerometer pair to the calibration table. That is, the support plate 44 may be detached from the mounting lug 48 and attached to the calibration table for performance of the calibration procedure. After the accelerometers have been calibrated, the support plate may be reattached to the mounting lug already installed on the wellhead.
  • plural vibration devices mounted to respective wellheads are indicated at 32a-32c.
  • multiple vibration detectors may be required to monitor multiple existing wells in the vicinity of a new well being drilled.
  • Each detector has associated therewith a power supply and an intervening intrinsically safe barrier 76a-76c.
  • a multi-channel multiplexer 80 may be employed to select as necessary the outputs from each pair of accelerometers for passage to an analyzer 82. The rate of sampling, duration and sequencing of each sample may be determined and adjusted as required. Signal amplification may be provided as needed.
  • filters 84 may be employed to attenuate or remove unwanted information so that only frequencies of interest are passed to the analyzer.
  • the analyzer 82 will monitor the drill bit signature frequencies and compare the same to a predetermined criteria indicating too close approach of the drill bit. For example, the drill bit frequencies which identify the drill bit passing through the formation may be monitored and, when the level of the monitored frequencies reaches a predetermined point, an alarm signal is issued. This signal may be transmitted to a monitor panel 88 to activate a caution light 90 warning of an approaching close intersection.
  • the analyzer 82 also preferably monitors for metal to metal contact in a frequency range normally lower than the frequency band of the drill bit signature. Metal to metal contact or even a very close approach is expected to cause a manyfold increase in amplitude in the lower frequency range. Upon detection of such an increase which may be tenfold or more, a high alarm signal may be issued. The high alarm signal may be used to activate a high alarm light 92 on the monitor panel 80.
  • the analyzer 82 may also interrogate each vibration detector to verify proper operation. Should an anomaly appear, e.g., a non-null combined output of the opposed and paired accelerometers, the analyzer can generate a third alarm signal announcing a malfunction in the system. The third alarm signal may be used to activate a corresponding light 94 on the monitor panel.
  • the analyzer interrogation can detect among other faults cut or damaged cables, or intermittent connections thereby avoiding common problems that may occur in the oil field workplace.
  • the outputs of the paired accelerometers are simultaneously multiplexed to the analyzer and a frequency response function is automatically computed each time the pair is scanned.
  • Conventional two channel frequency spectrum analyzers are known to have provision for computing the frequency response function.
  • the frequency in the frequency range of interest having the greatest amplitude is selected for performance of the comparison.
  • the frequency response function is essentially the ratio of one Fourier transform to the other at a specific frequency, and this ratio can be used to identify if there is a problem with one of the accelerometers, such as when the ratio deviates more than a predetermined amount from unity. In this set-up, a ratio of 1.0 indicates matched performance and no malfunction.
  • the frequency at which the comparison is made preferably is selected automatically for each reading. An appropriately programmed computer may be used to perform these procedures automatically.
  • the monitor panel 88 may be appropriately located as at the drilling control station for the new well being drilled. In addition to providing a visual alarm, corresponding audible alarms may be sounded. Drilling rig personnel seeing and/or hearing an alarm may then take appropriate action. In the case of a caution signal, the drilling rig personnel may initiate redirection of the drilling bit away from the existing well or wells. In the case of a high alarm, the drilling rig personnel normally would immediately cease drilling to avoid perforation of the existing casing being contacted by the drill bit. If desired, the high alarm signal, or even the warning signal, may be employed to effect automatic shutdown of the drilling equipment.
  • a spectrum analyzer 98 may be employed in the illustrated monitoring system to permit visual observation of acoustic frequency information by trained technicians as during drilling periods when close passage of the drilling bit by existing wells is anticipated. In response to observed vibration data the technician may issue an alarm warning of a close approach or actual contact of the drill bit with the well being monitored.
  • output data of the spectrum analyzer and/or analyzer 82 may be stored for later analysis by suitable means such as in a hard disk 100 coupled to or included in an appropriately programmed computer.
  • appropriately programmed computer equipment may be employed to perform the comparative analysis of the frequency data to determine when an alarm signal is to be generated and further to control analyzer interrogation. The computer equipment may also be used for overall detector system control, as would usually be the case.
  • earphones and more particularly electrostatic headphones, may be used to provide real-time monitoring of the drilling activity as well as verifying proper functioning of the transducers to which the earphones are connected via suitable electronic equipment.
  • the earphones should be of a high quality for maximizing reproduction at low frequencies as the frequency spectrum of principal interest is from 8 to 400 Hz. In those instances where the headphones are used in a noisy environment, the headphones should provide very tight ear-transducer coupling to minimize external sounds.
  • Equipping the driller with such earphones during periods of close intersection drilling would provide the driller with meaningful information. Increases or decreases in drill rotation speed would be instantly discernible to the driller as would increases or reductions in drill stem weight as verified by corresponding changes in sound intensity as transmitted to the headphones.
  • a simple system for providing protection against accidental intersection may consist of a single accelerometer, amplifier and headphones coupled with an experienced driller.
  • a multichannel strip chart recorder 102 may be employed to provide a real time print out of the totalized acoustic energy in multiple channels for immediate and/or future reference. The charts could also note low and high level alarms as transmitted to the driller, identifying the time of the alarms, the real depth of the drill bit at the time of the alarm, and the channel of interest.
  • the recorder is automatically controlled by a computer.
  • the acoustic signatures may vary accordingly.
  • the acoustic signatures can be analyzed by a spectrum analyzer to identify the appropriate frequency band or bands to be monitored by the analyzer.
  • useful frequency signatures of conventional drill bits and associated drilling methods will fall in the range of 0.1 hz to 10,000 hz and more particularly in the range of 0.5 hz to 1 ,000 hz with the most significant region being 100 hz to 500 hz.
  • useful frequencies are believed to exist in the range of 1 hz to 50 hz and more particularly in the range of 5 hz to 20 hz.
  • the present invention provides a method and apparatus for noninvasive surface monitoring of mechanical operations downhole.
  • the system may be employed to monitor performance of a mud motor by extracting useful information from vibrations traveling from the mud motor to the surface via the well casing.
  • the system may be used to assist in production and drilling operations such as fishing, well cleanouts and other downhole mechanical operations inside a cased well. Vibrations transmitted to the surface through the casing may be deciphered to extract the information of interest therefrom.
  • the present invention provides a method and apparatus that does not require use of a sensor, logging tool or other device that is lowered into a well. Instead, the invention provides for sensing of vibrations in the casing of a well which casing serves to transmit downhole noise (vibrations) to the vibration sensor or sensors preferably located at the surface. What has been found is that useful information can be extracted from vibrations travelling to the surface via an existing well casing.
  • downhole vibrations may be transmitted to the surface via a production string or other metal tubing string disposed in the well.
  • the production string will be coupled to the well head along with the casing, in which case vibration devices mounted to the well head would detect vibrations transmitted along both the production string and casing.

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  • Physics & Mathematics (AREA)
  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geophysics (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Acoustics & Sound (AREA)
  • Remote Sensing (AREA)
  • Geophysics And Detection Of Objects (AREA)
  • Earth Drilling (AREA)

Abstract

Appareil et procédé permettant d'effectuer la surveillance non invasive depuis la surface ou à distance de l'activité dans le trou de fond d'un puits de forage doublé de béton (10), à l'aide desquels les vibrations transmises par le cuvelage (12) sont détectées par un transducteur de vibrations (32) couplé au cuvelage (12) pour fournir des informations concernant l'activité existant dans le trou de forage doublé de béton. Dans un mode d'exécution, un détecteur (32) de vibrations ou d'ondes acoustiques est couplé à la tête de puits (14) d'un ou de plusieurs puits existants (10). Le détecteur détecte les ondes ou les vibrations acoustiques transmises par le puits existant (10), qui sont provoquées par le forage du nouveau puits (20) au voisinage proche du cuvelage de puits existant (12). Lorsque les vibrations détectées et surveillées correspondent à un critère prédéterminé indiquant qu'un trépan (28) se trouve au proche voisinage du cuvelage ou que le trépan heurte le cuvelage (12) d'un puits existant (10), un signal d'alarme se déclenche pour avertir l'opérateur que le trépan s'est approché de cuvelage ou l'a heurté, afin que des mesures appropriées puissent être prises en réaction au signal d'alarme.
PCT/US1991/003579 1991-01-16 1991-05-22 Procede et appareil permettant d'eviter le forage d'un nouveau puits dans un puits existant WO1992013167A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US07/642,189 US5131477A (en) 1990-05-01 1991-01-16 Method and apparatus for preventing drilling of a new well into an existing well
US642,189 1991-01-16

Publications (1)

Publication Number Publication Date
WO1992013167A1 true WO1992013167A1 (fr) 1992-08-06

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Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0905351A3 (fr) * 1997-09-30 2000-07-12 Halliburton Energy Services, Inc. Localisation de la source d'un signal dans un puits de forage
WO2009073008A1 (fr) * 2007-12-06 2009-06-11 Halliburton Energy Services, Inc. Guidage acoustique pour un placement de puits de forage
GB2474130A (en) * 2009-10-02 2011-04-06 Clamp On As Method for collision risk mitigation using intelligent non-invasive ultrasonic sensors for directional drilling
WO2011015824A3 (fr) * 2009-08-07 2011-11-24 Schlumberger Holdings Limited Système d'évitement de collision avec analyse de vibration de forage de puits décalé
CN104963676A (zh) * 2015-06-25 2015-10-07 中国石油天然气股份有限公司 一种钻井防碰预警装置及方法
US9376909B2 (en) 2012-01-24 2016-06-28 Baker Hughes Incorporated Indicator and method of verifying a tool has reached a portion of a tubular
US9957789B2 (en) 2010-11-24 2018-05-01 Welltec A/S Downhole system having a wireless unit
CN115045648A (zh) * 2022-05-12 2022-09-13 西安康际石油科技有限公司 一种提捞井各种状态的识别及报警方法

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US3285350A (en) * 1964-04-23 1966-11-15 Henderson John Keller Method and apparatus for controllably drilling off-vertical holes
US3817345A (en) * 1971-07-30 1974-06-18 Senturion Sciences Continuous bit positioning system
US4001773A (en) * 1973-09-12 1977-01-04 American Petroscience Corporation Acoustic telemetry system for oil wells utilizing self generated noise
US4003017A (en) * 1973-06-18 1977-01-11 Senturion Sciences, Inc. Continuous bit positioning system
US4016942A (en) * 1972-06-10 1977-04-12 Trunkline Gas Company Method and apparatus for indicating the position of one well bore with respect to a second well bore
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US4458767A (en) * 1982-09-28 1984-07-10 Mobil Oil Corporation Method for directionally drilling a first well to intersect a second well
US4593770A (en) * 1984-11-06 1986-06-10 Mobil Oil Corporation Method for preventing the drilling of a new well into one of a plurality of production wells
US4700142A (en) * 1986-04-04 1987-10-13 Vector Magnetics, Inc. Method for determining the location of a deep-well casing by magnetic field sensing
US4715451A (en) * 1986-09-17 1987-12-29 Atlantic Richfield Company Measuring drillstem loading and behavior

Patent Citations (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3285350A (en) * 1964-04-23 1966-11-15 Henderson John Keller Method and apparatus for controllably drilling off-vertical holes
US3282355A (en) * 1965-10-23 1966-11-01 John K Henderson Method for directional drilling a relief well to control an adjacent wild well
US3817345A (en) * 1971-07-30 1974-06-18 Senturion Sciences Continuous bit positioning system
US4016942A (en) * 1972-06-10 1977-04-12 Trunkline Gas Company Method and apparatus for indicating the position of one well bore with respect to a second well bore
US4003017A (en) * 1973-06-18 1977-01-11 Senturion Sciences, Inc. Continuous bit positioning system
US4001773A (en) * 1973-09-12 1977-01-04 American Petroscience Corporation Acoustic telemetry system for oil wells utilizing self generated noise
US4372398A (en) * 1980-11-04 1983-02-08 Cornell Research Foundation, Inc. Method of determining the location of a deep-well casing by magnetic field sensing
US4458767A (en) * 1982-09-28 1984-07-10 Mobil Oil Corporation Method for directionally drilling a first well to intersect a second well
US4593770A (en) * 1984-11-06 1986-06-10 Mobil Oil Corporation Method for preventing the drilling of a new well into one of a plurality of production wells
US4700142A (en) * 1986-04-04 1987-10-13 Vector Magnetics, Inc. Method for determining the location of a deep-well casing by magnetic field sensing
US4715451A (en) * 1986-09-17 1987-12-29 Atlantic Richfield Company Measuring drillstem loading and behavior

Cited By (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0905351A3 (fr) * 1997-09-30 2000-07-12 Halliburton Energy Services, Inc. Localisation de la source d'un signal dans un puits de forage
EP1666698A1 (fr) * 1997-09-30 2006-06-07 Halliburton Energy Services, Inc. Localisation de la source d'un signal dans un puits de forage
WO2009073008A1 (fr) * 2007-12-06 2009-06-11 Halliburton Energy Services, Inc. Guidage acoustique pour un placement de puits de forage
WO2011015824A3 (fr) * 2009-08-07 2011-11-24 Schlumberger Holdings Limited Système d'évitement de collision avec analyse de vibration de forage de puits décalé
US9127530B2 (en) 2009-08-07 2015-09-08 Schlumberger Technology Corporation Collision avoidance system with offset wellbore vibration analysis
GB2474130A (en) * 2009-10-02 2011-04-06 Clamp On As Method for collision risk mitigation using intelligent non-invasive ultrasonic sensors for directional drilling
US9957789B2 (en) 2010-11-24 2018-05-01 Welltec A/S Downhole system having a wireless unit
US9376909B2 (en) 2012-01-24 2016-06-28 Baker Hughes Incorporated Indicator and method of verifying a tool has reached a portion of a tubular
US10119391B2 (en) 2012-01-24 2018-11-06 Baker Hughes, A Ge Company, Llc Indicator and method of verifying a tool has reached a portion of a tubular
CN104963676A (zh) * 2015-06-25 2015-10-07 中国石油天然气股份有限公司 一种钻井防碰预警装置及方法
CN115045648A (zh) * 2022-05-12 2022-09-13 西安康际石油科技有限公司 一种提捞井各种状态的识别及报警方法

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