WO2012134468A1 - Systèmes et procédés pour l'évaluation de distance pendant le forage - Google Patents

Systèmes et procédés pour l'évaluation de distance pendant le forage Download PDF

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Publication number
WO2012134468A1
WO2012134468A1 PCT/US2011/030639 US2011030639W WO2012134468A1 WO 2012134468 A1 WO2012134468 A1 WO 2012134468A1 US 2011030639 W US2011030639 W US 2011030639W WO 2012134468 A1 WO2012134468 A1 WO 2012134468A1
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WIPO (PCT)
Prior art keywords
drillstring
casing
magnetic
field
axis
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PCT/US2011/030639
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English (en)
Inventor
Paul F. Rodney
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Halliburton Energy Services, Inc.
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Application filed by Halliburton Energy Services, Inc. filed Critical Halliburton Energy Services, Inc.
Priority to US13/577,329 priority Critical patent/US9581718B2/en
Priority to EP11859018.1A priority patent/EP2691797B1/fr
Priority to PCT/US2011/030639 priority patent/WO2012134468A1/fr
Publication of WO2012134468A1 publication Critical patent/WO2012134468A1/fr

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    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • 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
    • E21B47/0228—Determining slope or direction of the borehole, e.g. using geomagnetism using electromagnetic energy or detectors therefor
    • 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
    • E21B47/09—Locating or determining the position of objects in boreholes or wells, e.g. the position of an extending arm; Identifying the free or blocked portions of pipes
    • E21B47/092—Locating or determining the position of objects in boreholes or wells, e.g. the position of an extending arm; Identifying the free or blocked portions of pipes by detecting magnetic anomalies

Definitions

  • SAGD steam-assisted gravity drainage
  • U.S. Patent 6,257,334 steam-Assisted Gravity Drainage Heavy Oil Recovery Process.
  • SAGD uses a pair of vertically-spaced, horizontal wells less than 10 meters apart, and careful control of the spacing is important to the technique's effectiveness.
  • Other examples of directed drilling near an existing well include intersection for blowout control, multiple wells drilled from an offshore platform, and closely spaced wells for geothermal energy recovery.
  • passive ranging One way to direct a borehole in close proximity to an existing well is "active ranging” in which an electromagnetic source is located in the existing well and monitored via sensors on the drillstring. By contrast systems that locate both the source and the sensors on the drillstring are often termed “passive ranging". Passive ranging may be preferred to active ranging because it does not require that operations on the existing well be interrupted.
  • Existing passive ranging techniques rely on magnetic "hot spots" in the casing of the existing well, which limits the use of these techniques to identify areas where there is a significant and abrupt change in the diameter of casing or where the casing has taken on an anomalous magnetic moment, either by pre-polarization of the casing before it is inserted into the wellbore, or as a random event.
  • Fig. 1 shows an illustrative drilling environment in which electromagnetically-guided drilling may be employed
  • Fig. 2 shows an illustrative arrangement for passive ranging
  • Fig. 3 shows an illustrative circuit for measuring induced field components
  • Fig. 3 shows a signal processing circuit incorporating a phase-locked loop
  • Figs. 4A-4B illustrate the effect of a tilted magnetic source
  • Figs. 5A-5B show a predicted cross-axial field strength as a function of distance
  • Figs. 6A-6B show a predicted axial field strength as a function of distance
  • Fig. 7 is a flow diagram of an illustrative forward model
  • Fig. 8 is a flow diagram of an illustrative ranging method.
  • the issues identified in the background are at least partly addressed by an improved system and method for ranging while drilling.
  • the approach described here in effect, induces a dynamic hot spot on the casing that acts as a magnetic source that can be reliably detected from within the drillstring and which can be detected in such a manner as to infer the relative position and orientation of the casing to the drillstring.
  • At least some disclosed method embodiments employ one or more rotating magnets in the drillstring, an array of at least two magnetometers in the drillstring and one or more phase-locked loops that are used to enhance the signal to noise ratio of the magnetic signal scattered off of the casing from the rotating magnetic field.
  • the rotating magnet or magnets may be magnetic dipoles or magnetic multipoles.
  • At least one of the rotating magnets has a magnetic moment that is at an angle to the borehole axis, the angle being neither parallel nor perpendicular to the borehole axis.
  • At least some disclosed system embodiments include a drillstring and a processor.
  • the drillstring includes a magnetic source, at least one magnetometer, and a rotation sensor.
  • the magnetic source induces a magnetic moment in a nearby casing string, which in turn puts off a magnetic field that can be detected by the magnetometer.
  • the processor combines the rotation sensor measurements with the magnetometer measurements to estimate a relative distance and direction to the casing string.
  • the rotation sensor can be a magnetometer spaced further away from the magnetic source, or it can be a gyroscope, accelerometer, borehole wall sensor, or other form of rotation sensing device.
  • the rotation information enables the filtering out of the earth's magnetic field and other static field components thereby enabling detection of the casing string at an estimated range of at least 10 meters.
  • FIG. 1 shows an illustrative geosteering environment.
  • a drilling platform 2 supports a derrick 4 having a traveling block 6 for raising and lowering a drill string 8.
  • a top drive 10 supports and rotates the drill string 8 as it is lowered through the wellhead 12.
  • a drill bit 14 is driven by a downhole motor and/or rotation of the drill string 8. As bit 14 rotates, it creates a borehole 16 that passes through various formations.
  • the drill bit 14 is just one piece of a bottom-hole assembly that includes one or more drill collars (thick- walled steel pipe) to provide weight and rigidity to aid the drilling process.
  • drill collars include logging instruments to gather measurements of various drilling parameters such as position, orientation, weight-on-bit, borehole diameter, etc.
  • the tool orientation may be specified in terms of a tool face angle (rotational orientation), an inclination angle (the slope), and compass direction, each of which can be derived from measurements by magnetometers, inclinometers, and/or accelerometers, though other sensor types such as gyroscopes may alternatively be used.
  • the tool includes a 3 -axis fluxgate magnetometer and a 3 -axis accelerometer.
  • the combination of those two sensor systems enables the measurement of the tool face angle, inclination angle, and compass direction.
  • the tool face and hole inclination angles are calculated from the accelerometer sensor output.
  • the magnetometer sensor outputs are used to calculate the compass direction.
  • the bottom-hole assembly further includes a ranging tool 26 to induce a magnetic moment in nearby casing strings and to collect measurements of the resulting field to determine distance and direction.
  • the driller can steer the drill bit 14 along a desired path 18 relative to the existing well 19 in formation 46 using any one of various suitable directional drilling systems, including steering vanes, a "bent sub", and a rotary steerable system to steer the drill bit along a desired path 18 parallel to an existing borehole.
  • the steering vanes may be the most desirable steering mechanism.
  • the steering mechanism can be alternatively controlled downhole, with a downhole controller programmed to follow the existing borehole 19 at a predetermined distance 48 and position (e.g., directly above or below the existing borehole).
  • a pump 20 circulates drilling fluid through a feed pipe 22 to top drive 10, downhole through the interior of drill string 8, through orifices in drill bit 14, back to the surface via the annulus around drill string 8, and into a retention pit 24.
  • the drilling fluid transports cuttings from the borehole into the pit 24 and aids in maintaining the borehole integrity.
  • a telemetry sub 28 coupled to the downhole tools 26 can transmit telemetry data to the surface via mud pulse telemetry.
  • a transmitter in the telemetry sub 28 modulates a resistance to drilling fluid flow to generate pressure pulses that propagate along the fluid stream at the speed of sound to the surface.
  • One or more pressure transducers 30, 32 convert the pressure signal into electrical signal(s) for a signal digitizer 34.
  • Such telemetry may employ acoustic telemetry, electromagnetic telemetry, or telemetry via wired drillpipe.
  • the digitizer 34 supplies a digital form of the telemetry signals via a communications link 36 to a computer 38 or some other form of a data processing device.
  • Computer 38 operates in accordance with software (which may be stored on information storage media 40) and user input via an input device 42 to process and decode the received signals.
  • the resulting telemetry data may be further analyzed and processed by computer 38 to generate a display of useful information on a computer monitor 44 or some other form of a display device.
  • a driller could employ this system to obtain and monitor drilling parameters, formation properties, and the path of the borehole relative to the existing borehole 19 and any detected formation boundaries.
  • a downlink channel can then be used to transmit steering commands from the surface to the bottom-hole assembly.
  • a magnetic dipole 202 e.g., a permanent magnet or other mechanism for creating a strong magnetic field
  • a drill bit 14 with its moment orthogonal to the symmetry axis of the drill bit, as shown in Fig. 2.
  • the casing 19 is made out of magnetically permeable material (which is usually the case)
  • the field 204 from magnet 202 induces a distribution 206 of magnetic moment along the casing.
  • the direction of the casing's induced moment is the same along the length of the casing, while the magnitude varies in accordance with a distribution similar to that sketched in Fig. 2.
  • the distribution of magnetic moment induced along the casing changes.
  • the moment changes direction along the casing (either parallel to the axis of the casing or anti-parallel to the axis of the casing).
  • the time varying magnetic field induced along the casing sets up a magnetic field that is observable at one or more observation points on the drillstring 8, preferably with a three-axis magnetometer 208, and more preferably with a plurality of three-axis magnetometers 208, 209 constituting a differential magnetometer.
  • the magnitude of the received signal is a strong function of the distance of the observation point or points from the casing, while the phase of the signal and the distribution in time of the signal are functions of the orientation of the rotating magnetic source relative to the casing and of the spatial distribution of the casing.
  • the magnetic field at the observation point(s) is composed of four terms: (1) the earth's magnetic field; (2) the magnetic field from the drillstring's magnetic field source; (3) magnetic fields from currents in the drillstring; and (4) the magnetic field from the induced casing moment.
  • the earth's magnetic field is parallel to the drillstring axis, it creates a static field that can be readily measured and canceled.
  • the earth's magnetic field appears as a sinusoidal oscillation having the same frequency as the rotation of the drillstring. Both the static and oscillatory components can be readily measured and canceled.
  • a remote observation point e.g., magnetometers 209 are used to determine the earth's magnetic field strength and orientation.
  • the second term is the magnetic field from the source.
  • the source has a fixed magnitude and a relatively fixed orientation and distance from the observation point. Accordingly, this term is primarily a static field, although it may acquire a dynamic element to the extent that there is torsion or bending of the drillstring between the point of observation and the source location. This term can be eliminated by placing the magnetic field sensor(s) sufficiently far from the magnetic source that they do not saturate and AC coupling the output of the magnetometers to the signal processing circuitry. Some embodiments may employ torque and strain sensors to detect motion of the source relative to the observation point(s) and compensate accordingly. Alternatively, additional observation points can be used to measure the separate contributions of the source and the earth's magnetic field. (The relatively fixed field from the earth and the faster-decaying field from the source enable the different observation points to distinguish these contributions from each other and from the induced magnetic moment in the casing.)
  • the third term is attributable to electrical currents in the drillstring.
  • Such currents are described, for example, in U.S. Pat. 7,650,292 "Method and apparatus for surveying a borehole with a rotating sensor package", along with techniques for combating such currents.
  • such currents are prevented by creating an insulating gap along the drillstring axis near the observation point. Suitable gap constructions are described in, e.g., U.S. Pats.
  • the fourth term is the magnetic field from the casing, which consists of two parts: a static contribution and a dynamic contribution.
  • the static contribution is normally not measurable at a range considered safe for collision avoidance unless there are magnetic hot spots along the casing, as described earlier.
  • the dynamic contribution comes from the time varying distribution of induced magnetic moment along the casing. At least some system embodiments focus on detecting this dynamic contribution and using that to estimate distance and direction to the casing.
  • Static field contributions e.g., the earth's magnetic field and the static contribution from the casing
  • a reference signal for a phase lock loop or another similar noise filter which can be applied to the observed field so as to single out only the components that are synchronized with rotation. It is anticipated that somewhere between 60 and 90 dB of noise attenuation can be obtained with such a technique given the typical performance of phase-locked loops. From a signal processing standpoint, the simplest way of obtaining such a reference signal is to place a magnetometer far enough from the source 202 that it will not measure an appreciable component of the signal arriving from the casing 19.
  • This magnetometer signal provides both a frequency reference and a copy of the uncorrupted earth's magnetic field that can be subtracted from the magnetic field measured closer to the source at a point where the signal arriving from the casing has a measurable value, thus greatly boosting the signal to noise ratio.
  • this signal provides a frequency reference for a phase-locked loop.
  • Fig. 3 shows an illustrative circuit for such signal processing.
  • a set of operational amplifiers 302 amplifies the voltage from each of the axial and cross-axial magnetometers at observation points 208, 209.
  • a second set of differential amplifiers 304 determines a difference between the respective axial measurements at observation points 208, 209, and the respective cross-axial measurements.
  • the differential measurements are filtered and demodulated by a phase lock loop 306 to produce three orthogonal component measurements of the observed magnetic field.
  • An optional frequency multiplier 308 may operate on one of the differential cross-axial measurement signals to provide the reference clock for the phase lock loop.
  • phase-locked loop is preferably a digital phase-locked loop (DPLL).
  • DPLL digital phase-locked loop
  • the circuit in Fig. 3 presumes that the two observation points 208, 209 are related in a fairly rigid sense. Where it is desired to allow for bending and twisting of the drillstring, a microprocessor or other programmable circuit can be used to perform adaptive tracking of the geometrical relationship between the two observation points and to compensate accordingly when deriving differential signals.
  • the earth's magnetic field component can be estimated from the three-axis magnetometer outputs of the magnetometer intended to sense the casing signal (magnetometer 208) since the total field should be constant and the total cross-axial field should vary very slowly as drilling progresses. This, however, will involve more signal processing and may not be as effective as the differential magnetometer approach of Fig. 3.
  • the reference signal for the phase lock loop can be obtained with an accelerometer, inclinometer, gyroscope, or other rotation sensing mechanism.
  • MEMS (microelectromechanical systems) gyros are available with a drift rate of .005 s square root(Hz).
  • the rotation frequency information obtained using the gyro can be combined with the orientation of the gyro relative to the magnetometer axes and information about the tool orientation and magnetic field of the earth to provide estimates of the earth- field component in the signal received at the magnetometers used to sense the signal from the casing.
  • the survey measurements would be made at a point in the drillstring where the source does not interfere with the survey tool.
  • the analysis is amenable to casings with nonlinear profiles in space in that the analysis is reduced to a one-dimensional integral along the axis of the casing.
  • the analysis can be generalized to boreholes and casings of arbitrary shape and orientation, with arbitrary source configuration. For multipole fields, the analysis can be extended as a superposition of dipole fields, though some multipole configurations may require an explicity multipole analysis.
  • the axis of the dipole is orthogonal to the drillstring, and both the drillstring and the casing are vertical. With the dipole moment also orthogonal to the casing, the induced field resembles a one-dimensional monopole on either side of the point of intersection of the axis of the dipole with the casing. This follows from a simple visual inspection of the dipole field. We might expect that in this particular case that the received field at a point along the drillstring axis will have a magnitude that falls off approximately as the inverse fifth power of the distance (since the dipole field decays as an inverse cube and the monopole field decays as an inverse square law).
  • the observation point must be fairly close to the dipole source, or the contributions from the magnetic moments to the observed signal will come disproportionately from the portion of the collar above the point of intersection of the dipole axis with the casing. Hence, it is more reasonable to expect an inverse sixth power dependence for the observed field amplitude.
  • Figs. 4A-4B where the borehole being drilled is vertical and the casing being monitored is on a linear path in a plane with the path of the wellbore being drilled, but not parallel to that path. Further assume that the moment of the magnetic dipole 402 is not orthogonal to the drillstring axis. In Fig. 4A, the moment of the dipole 402 is in the plane of the wellbore being drilled and the casing being monitored. The projection of the magnetic field lines 404 along the axis of the casing 19, produce a large magnetic moment 406 for observation by magnetometer 408. In Fig.
  • the drillstring has rotated 180°, producing magnetic field lines 404 that are less uniform along the casing so as to produce a much weaker magnetic moment 406.
  • the signal received at the observation point will not be symmetrical with the rotation of the drillstring. This would not have been the case if the dipole had been orthogonal to the drillstring axis.
  • the dipole had been orthogonal to the drillstring axis.
  • information has been gained about the orientation of the casing relative to the borehole. The same observation holds even if the casing extends along an arbitrary path non- coplanar with the casing.
  • the source may include a magnetic dipole tilted as illustrated in Figs. 4A-4B and may further include a substantially co-located magnetic dipole that is orthogonal to the drillstring axis (e.g., extending towards the reader out of the plane of Fig. 4A).
  • the field from such a multipole source is the superposition of the fields from the individual dipoles.
  • each dipole will make a contribution to the observed signal, which, for a constant rotation of the drillstring, will be composed of two sinusoids 90° out of phase with each other.
  • Some alternative embodiments employ multipole sources constructed from dipoles such that (e.g.) all of the north poles face outward from the drillstring and all of the south poles face inward. In this case, the observed frequency would be the number of poles times the rotational frequency.
  • B is the magnitude of the magnetic field in nanoteslas (nT) and r is the distance from the dipole in meters (m). This is a fairly strong, but achievable field. It is further assumed that the casing has an outer radius of 6.75 inches, an inner radius of 6.125 inches and a relative magnetic permeability of 500. Strictly speaking, magnetic permeability is not a concept that applies to ferrous materials, but it is a reasonable approximation.
  • Figs. 5A and 5B show the expected cross-axial field in nT as a function of distance of the observation point from the source in feet (Zo) and as a function of distance between the casing and the well being drilled (Xo).
  • Fig. 5A shows a 3D plot
  • Fig. 5B shows a contour plot.
  • Figs. 6 A and 6B similarly show the expected axial magnetic field component in nT as a function of distance of the observation point from the source in feet (Zo) and as a function of distance between the casing and the borehole being drilled (Xo).
  • a typical magnetometer used in borehole surveying can measure magnetic fields with a calibrated accuracy of 70 nT (see, e.g., Williamson, SPE 56702) and a resolution of about 2 nT. If the signal is detected with a lock-in amplifier, signals 60 dB or more beneath the noise can be recovered.
  • a lock-in amplifier is also known as a phase-sensitive detector. For the purposes of this disclosure, it will serve as an example of a phase-locked loop.
  • a lock-in amplifier can be implemented either as an analog or a digital device.) With the observation point 30 feet from the source, and using a lock-in amplifier with a 60 dB gain, the observed signal of 0.7 nT will appear as a 700 nT signal. Even if the lock-in only achieves 20 dB of noise rejection, the observed signal will be 7 nT, which is a strong enough signal for further processing.
  • the peak response occurs when the observation point (which is situated along the drillstring axis) is at about half the distance between the well being drilled and the casing being monitored. This appears to be a good rule of thumb.
  • the design can be optimized by selecting the strongest practically achievable source and source configuration, determining the maximum signal to noise ratio within the specified acquisition time, and setting the observation point at a location for maximum sensitivity at the maximum desired (and practically achievable) range to the casing to be monitored.
  • a better practice may be to operate with an array of sensors at selected observation points along the drillstring.
  • the sensitivities of the magnetometers should be matched as closely as is possible so as to achieve the maximum cancellation of the earth's field component of the observed signals.
  • the gain of such sensors is a function of the ambient temperature and can be calibrated using well known procedures, but the extreme rigor required of survey tools in determining biases and misalignments need not be taken. The gains can be calibrated with all of the magnetometers assembled on the casing ranging tool in a uniform and known magnetic field and over a range of ambient temperatures.
  • the signals should be interpreted so as to determine the range to the casing and the approach angle relative to the casing.
  • we first create a general response model using the technique illustrated in the appendix.
  • the general steps of this technique 700 begin in block 702 with a specification of the nature of the source (i.e., whether the source is a dipole, a crossed dipole or some other specific multipole configuration), the geometry of the source (i.e., the orientation of the poles relative to the drillstring axis and how they rotate), the magnitude of the source, and the position of the source relative to the observation points.
  • the technique also provides a (possibly tentative) casing trajectory.
  • the casing trajectory is specified as a one parameter curve in three-dimensional space, the parameter being distance along the casing from a given point, e.g., the well head or a point of intersection between the borehole trajectory and the casing trajectory.
  • the curve can be specified in an arbitrary fashion, including other parameters, but the single-parameter formulation is used to simplify the integral.
  • the system models the magnetic field emanating from the source. This can certainly be done numerically, but in many instances this can be done with a closed form analytical expression.
  • the system determines for each position along the length of the casing trajectory the component of the source's magnetic field that lies parallel to the casing axis. That component induces a magnetic moment that produces a field at the observation point(s).
  • the system integrates the fields from the magnetic moments distributed along the length of the casing to obtain the total induced field at the observation point(s).
  • Procedure 800 begins in block 802 with an estimation of the well casing trajectory. As this estimate will be adapted, it can be based on logging measurements from the well, or it can be an arbitrary starting point (e.g., a vertical well at some distance from the borehole). Drilling commences in block 804, creating a borehole that enters into the proximity of the existing well casing. What constitutes "proximity” may vary based on the capabilities of the system, but it is expected to include a range of at least 10 meters.
  • procedure 800 tracks the path of the drillstring (and hence the borehole) in block 806.
  • the magnetic source induces a magnetic moment in the casing of the existing well in block 808.
  • the magnetometers at the observation point(s) measure the field from the induced magnetic moment.
  • the procedure employs the technique 700 (Fig. 7) to determine the expected measurements of the magnetic moment field.
  • the expected measurements may include not only the measurements made by the magnetometers in their current positions and orientations, but also the expected measurements at previous positions and orientations of the magnetometers.
  • the procedure 800 compares the actual measurements to the expected measurements. If a mismatch is detected, the estimated well trajectory is adjusted in block 816 and blocks 812-814 are repeated until a satisfactory match is obtained.
  • One illustrative technique is a binary search that, starting with modeled measurements for at least three different distances at four different directions (e.g., 0, 90°, 180°, and 270° from the currently estimated casing direction), systematically searches for an optimum distance and direction. In at least some embodiments, the binary search will be used to optimize the mean square error between the observed signals and the modeled signals.
  • the search is continued until a specified accuracy is attained, or a fixed number of iterations have been carried out.
  • the routine then reports the distance from the drill bit to the casing and the relative orientation between the drillstring trajectory and the casing trajectory. In the latter case, this same information is provided along with an error statement.
  • the relative distance and direction may optionally be employed as the drilling progresses to achieve and maintain a desired direction and distance between the borehole and the existing casing.
  • the borehole may be drilled to intersect the casing or directed to avoid the casing.
  • the procedure determines whether drilling is complete and if not, procedure repeats blocks 806-820 until drilling ceases.
  • Procedure 800 can be implemented in an application specific integrated circuit or in software on a programmable processor. Although the specific implementation of this procedure may be tedious, such procedures are well known in the art and can be readily derived from the equations in the appendix. Since the response model has been reduced to a one-dimensional integral, and since the form of that integral (due to the nature of the fields) is rapidly converging, the procedure can be carried out quickly in a downhole processor or, if the signals are telemetered to the earth's surface, analysis can be carried out using a computer at the earth's surface. Using uncompiled code and a 2.17 GHz Intel ® CoreTM2 Duo CPI T7500, it took about .5 ms to calculate a single point in the model described in the appendix.
  • a reference signal is desirable to indicate the rotation of the magnet mounted on the drillstring.
  • This reference signal can be derived using a distant magnetometer, or other rotation tracking methods can be employed (e.g., gyroscopes, accelerometers to track the gravity vector, optical or acoustic sensors tracking borehole wall variation, etc.).
  • the permanent magnet can be replaced with an electromagnet, enabling optional modulation of the magnetic field.
  • modulation could alternatively be provided with a mechanical shield of magnetically permeable material that moves to alternately shunt and release magnetic field lines from the ranging tool. (One suitable example of such a shield mechanism is disclosed in U.S. Pat.
  • Electromagnets or magnetic shields can alternatively be employed to implement time division multiplexing, where only one of multiple magnetic field sources is active (uncovered) at a time.
  • the measure magnetic field values may be converted to pixel colors or intensities and displayed as a function of borehole azimuth and distance along the borehole axis. Assuming the reference borehole is within detection range, the reference borehole will appear as a bright (or, if preferred, a dark) band in the image. The color or brightness of the band indicates the distance to the reference borehole, and the position of the band indicates the direction to the reference borehole.
  • a driller can determine in a very intuitive manner whether the new borehole is drifting from the desired course and he or she can quickly initiate corrective action. For example, if the band becomes dimmer, the driller can steer towards the reference borehole. Conversely, if the band increases in brightness, the driller can steer away from the reference borehole. If the band deviates from its desired position directly above or below the existing borehole, the driller can steer laterally to re-establish the desired directional relationship between the boreholes.
  • Our disclosed approach is expected to provide a commercial and competitive advantage in that it provides a means of ranging with confidence near casings that have not been pre- polarized.
  • r is the distance from the center of the dipole to the observation point
  • ⁇ is the angle between a vector from the center of the dipole to the observation point and the magnetic moment m ⁇ is the azimuthal angle.
  • ⁇ vanishes and hence, ⁇ will not be considered further in this analysis.
  • ⁇ is the magnetic permeability of the medium (assumed infinite and homogeneous) in which the dipole is observed. This latter assumption will be violated by the very nature of the problem we are trying to solve, but I will work in the approximation that it is valid.
  • the magnet is in a vertical well with the axis of the moment orthogonal to the well axis, i.e. with the magnetic moment in the horizontal plane.
  • a string of casing is located in space along a straight line.
  • the center dipole source will be defined as the origin of the coordinate system.
  • the point defining the center of the dipole and the path of the center line of the casing define a unique plane.
  • the magnetic field of the source must be expressed in the x, y, z coordinate system defined by these equations.
  • the dipole moment is orthogonal to the drill pipe (assumed vertical for simplicity - for a commercial algorithm, this will need to be modified, but for a scoping analysis, no generality is lost with this assumption). It is further assumed that the moment of the dipole makes an angle ⁇ with rexpect to the x-axis.
  • the polar angle ⁇ must be calculated in terms of ⁇ and the point at which the field interacts with the casing. Taking a unit vector along the dipole moment and resolving it along the x- and y-axes, and then taking the inner product between the interaction vector (x,y,z) and the unit vector,
  • the next step is to project the B-field along the casing and calculate the moment induced along the z-axis of the casing.
  • the moment induced orthogonal to the casing should also be taken into account, but this is expected to have only a minor effect on the analysis, which could/should be taken into account when the source is very close to the casing. I will need to work out the criteria for this.
  • the component of the field along the casing is calculated by expressing x, y and z in terms of the parameter t, the distance along the casing and projecting the field along the casing.
  • the unit vector along the casing is given by
  • the magnetic moment induced along the casing will act as a source. It is calculated as follows: (starting with a general relation and then particularizing it)
  • ⁇ ⁇ is the relative permeability of the casing.
  • the primed gradient can be commuted through the integral and does not operate on Be.
  • the induced moment should go as the cube of the distance from the source. When this is induced as a net dipole moment, it will set up another dipole field that should fall off as an inverse cube. However, there are orientations when the dipole source magnet is directly facing the casing, at the same depth as the source magnet, the induced field looks more like a monopole field.

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  • Geophysics And Detection Of Objects (AREA)

Abstract

L'invention porte sur un système et sur un procédé améliorés pour l'évaluation de distance pendant le forage, lesquels induisent effectivement un point chaud dynamique sur le tubage d'un puits voisin. Le point chaud induit joue le rôle de source magnétique qui peut être détectée de façon fiable à partir de l'intérieur du train de tiges de forage, et de manière à déduire la position et l'orientation relatives du tubage par rapport au train de tiges de forage. Au moins certains modes de réalisation du procédé décrit emploient un ou plusieurs aimants rotatifs dans le train de tiges de forage, un groupement d'au moins deux magnétomètres dans le train de tiges de forage et une ou plusieurs boucles verrouillées en phase qui sont utilisées pour améliorer le rapport signal/bruit du signal magnétique dispersé à partir du tubage à partir du champ magnétique tournant. Le ou les aimants rotatifs peuvent être des dipôles magnétiques ou des multipôles magnétiques, et peuvent être modulés de façon à permettre l'utilisation de multiples sources de champ magnétique.
PCT/US2011/030639 2010-03-31 2011-03-31 Systèmes et procédés pour l'évaluation de distance pendant le forage WO2012134468A1 (fr)

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US13/577,329 US9581718B2 (en) 2010-03-31 2011-03-31 Systems and methods for ranging while drilling
EP11859018.1A EP2691797B1 (fr) 2011-03-31 2011-03-31 Systèmes et procédés pour l'évaluation de distance pendant le forage
PCT/US2011/030639 WO2012134468A1 (fr) 2011-03-31 2011-03-31 Systèmes et procédés pour l'évaluation de distance pendant le forage

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CN107076804A (zh) * 2014-11-17 2017-08-18 哈里伯顿能源服务公司 快速磁热点检测器
FR3063766A1 (fr) * 2017-03-09 2018-09-14 Pathcontrol Procede d'identification de position d'un puits par telemetrie magnetique passive
US10544670B2 (en) 2014-06-17 2020-01-28 Halliburton Energy Services, Inc. Reluctance sensor for measuring a magnetizable structure in a subterranean environment
US10767466B2 (en) 2016-02-12 2020-09-08 Halliburton Energy Services, Inc. Active ranging-while-drilling with magnetic gradiometry
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CN115949388A (zh) * 2023-02-20 2023-04-11 四川轻化工大学 一种套管防碰测距预警方法及测量单元
CN117027764A (zh) * 2022-05-20 2023-11-10 中国石油天然气集团有限公司 钻井定位装置、方法和系统
EP4407141A1 (fr) * 2023-01-25 2024-07-31 TRACTO-TECHNIK GmbH & Co. KG Système de tiges du fond

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US10539706B2 (en) 2013-12-27 2020-01-21 Halliburton Energy Services, Inc. Target well ranging method, apparatus, and system
EP2909438A4 (fr) * 2013-12-27 2015-12-09 Halliburton Energy Services Inc Méthode, appareil et système de télémétrie de puits cible
US10544670B2 (en) 2014-06-17 2020-01-28 Halliburton Energy Services, Inc. Reluctance sensor for measuring a magnetizable structure in a subterranean environment
US10031153B2 (en) 2014-06-27 2018-07-24 Schlumberger Technology Corporation Magnetic ranging to an AC source while rotating
WO2015200745A1 (fr) * 2014-06-27 2015-12-30 Schlumberger Canada Limited Télémétrie magnétique en rotation
WO2015200751A1 (fr) * 2014-06-27 2015-12-30 Schlumberger Canada Limited Télémétrie magnétique au niveau d'une source c.a. lors de la rotation
US10094850B2 (en) 2014-06-27 2018-10-09 Schlumberger Technology Corporation Magnetic ranging while rotating
US10508533B2 (en) 2014-08-11 2019-12-17 Halliburton Energy Services, Inc. Well ranging apparatus, systems, and methods
US10605072B2 (en) 2014-08-11 2020-03-31 Halliburton Energy Services, Inc. Well ranging apparatus, systems, and methods
US9879521B2 (en) 2014-08-11 2018-01-30 Halliburton Energy Services, Inc. Well ranging apparatus, systems, and methods
US10767467B2 (en) 2014-08-11 2020-09-08 Halliburton Energy Services, Inc. Well ranging apparatus, systems, and methods
US9874085B2 (en) 2014-08-11 2018-01-23 Halliburton Energy Services, Inc. Well ranging apparatus, systems, and methods
US10273799B2 (en) 2014-08-11 2019-04-30 Halliburton Energy Services, Inc. Well ranging apparatus, systems, and methods
US9752426B2 (en) 2014-08-11 2017-09-05 Halliburton Energy Services, Inc. Well ranging apparatus, systems, and methods
US10539004B2 (en) 2014-08-11 2020-01-21 Halliburton Energy Services, Inc. Well ranging apparatus, systems, and methods
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WO2016025247A1 (fr) * 2014-08-11 2016-02-18 Halliburton Energy Services, Inc. Appareil, systèmes, et procédés de télémétrie de puits
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CN107076804A (zh) * 2014-11-17 2017-08-18 哈里伯顿能源服务公司 快速磁热点检测器
US11442196B2 (en) 2015-12-18 2022-09-13 Halliburton Energy Services, Inc. Systems and methods to calibrate individual component measurement
US10767466B2 (en) 2016-02-12 2020-09-08 Halliburton Energy Services, Inc. Active ranging-while-drilling with magnetic gradiometry
FR3063766A1 (fr) * 2017-03-09 2018-09-14 Pathcontrol Procede d'identification de position d'un puits par telemetrie magnetique passive
US10871065B2 (en) 2017-03-09 2020-12-22 Pathcontrol Method for the identification of the position of a well by passive magnetic telemetry
CN117027764A (zh) * 2022-05-20 2023-11-10 中国石油天然气集团有限公司 钻井定位装置、方法和系统
CN117027764B (zh) * 2022-05-20 2024-02-09 中国石油天然气集团有限公司 钻井定位装置、方法和系统
EP4407141A1 (fr) * 2023-01-25 2024-07-31 TRACTO-TECHNIK GmbH & Co. KG Système de tiges du fond
CN115949388A (zh) * 2023-02-20 2023-04-11 四川轻化工大学 一种套管防碰测距预警方法及测量单元
CN115949388B (zh) * 2023-02-20 2024-05-07 四川轻化工大学 一种套管防碰测距预警方法及测量单元

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EP2691797A4 (fr) 2015-11-11
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