WO2016182640A1 - Réduction ou prévention de la dissipation d'un courant électrique et d'un signal magnétique associé dans un puits de forage - Google Patents

Réduction ou prévention de la dissipation d'un courant électrique et d'un signal magnétique associé dans un puits de forage Download PDF

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Publication number
WO2016182640A1
WO2016182640A1 PCT/US2016/025110 US2016025110W WO2016182640A1 WO 2016182640 A1 WO2016182640 A1 WO 2016182640A1 US 2016025110 W US2016025110 W US 2016025110W WO 2016182640 A1 WO2016182640 A1 WO 2016182640A1
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WO
WIPO (PCT)
Prior art keywords
ground
conductor
insulating layer
wellbore
reference conductor
Prior art date
Application number
PCT/US2016/025110
Other languages
English (en)
Inventor
Clinton MOSS
Douglas Ridgway
Troy Martin
Original Assignee
Applied Technologies Associates, 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 US14/884,414 external-priority patent/US9938773B2/en
Application filed by Applied Technologies Associates, Inc. filed Critical Applied Technologies Associates, Inc.
Priority to RU2017134129A priority Critical patent/RU2017134129A/ru
Priority to CA2978192A priority patent/CA2978192C/fr
Publication of WO2016182640A1 publication Critical patent/WO2016182640A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/02—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
    • E21B47/0232—Determining slope or direction of the borehole, e.g. using geomagnetism using electromagnetic energy or detectors therefor at least one of the energy sources or one of the detectors being located on or above the ground surface

Definitions

  • the present disclosure relates generally to borehole location systems, and specifically to use of magnetic fields for determination of position of a subsurface wellbore.
  • Directional borehole drilling typically relies on one or more directional devices such as bent subs and rotary steering systems to direct the course of the wellbore.
  • the angle between the reference direction of the directional device and an external reference direction is referred to as the toolface angle, and determines the direction of deviation of the wellbore.
  • Directional drilling proceeds through comparing the placement of the borehole with the desired path, and selecting a toolface angle and other drilling parameters to advance the borehole and correct it towards the planned path. Measurement of toolface thus may be a component for borehole steering and placement.
  • an external reference direction for the toolface may be chosen based on the geometry and location of the wellbore.
  • the usual reference is the direction of acceleration due to gravity. This may be measurable via accelerometers which rotate with the drill string, such as during measurement while drilling (MWD).
  • MWD measurement while drilling
  • the direction of gravity may be aligned or substantially aligned with the drill string axis and may not be able to provide a useful reference direction.
  • accelerometers in vertical or near-vertical wells.
  • magnetic toolface may be used, which applies the onboard magnetometers used in MWD to use the Earth's magnetic field as a reference direction.
  • magnetic toolface may fail at sufficiently high magnetic latitude, or where magnetic interference from nearby wellbores, surface facilities, or other effects alter the local magnetic field.
  • Another alternative for a reference is the true North available from a north- seeking downhole gyroscope, or a reference carried down by a non-north- seeking gyroscope. Gyroscopes may suffer from cost and reliability concerns.
  • the present disclosure provides for an artificial toolface reference system.
  • the artificial toolface system may include a power supply providing current to a ground lead and a reference lead.
  • the artificial toolface system may include a ground point coupled to the ground lead and in electrical connection with the ground.
  • the artificial toolface system may include a reference wellbore.
  • the artificial toolface system may include a reference conductor positioned within the reference wellbore.
  • the reference conductor may be in electrical connection with the reference lead.
  • the reference conductor may have an insulated portion and an uninsulated portion.
  • the uninsulated portion may be in electrical connection with the ground.
  • the insulated portion may have an insulating layer positioned thereabout.
  • the artificial toolface system may include a guidance sensor positioned outside the reference wellbore including at least one magnetometer.
  • the present disclosure also provides for a method.
  • the method may include forming a reference conductor.
  • the reference conductor may have an insulated portion and an uninsulated portion.
  • the insulated portion may have an insulating layer positioned thereabout.
  • the method may include positioning the reference conductor in a reference wellbore such that the uninsulated portion of the reference conductor is in electrical connection with the ground.
  • the method may include coupling a power supply between a ground point and the reference conductor.
  • the ground point may be positioned a distance away from the reference conductor and may be in electrical communication with the ground.
  • the method may include providing a current, with the power supply, through the reference conductor, the ground, and the ground point such that a reference magnetic field is generated along the reference conductor.
  • the method may include measuring the reference magnetic field with a magnetometer positioned outside of the reference wellbore.
  • FIG. 1 depicts an artificial toolface reference system consistent with at least one embodiment of the present disclosure.
  • FIG. 2 depicts an artificial toolface reference system consistent with at least one embodiment of the present disclosure in a subsea application.
  • FIGS. 1 and 2 depict embodiments of artificial toolface reference system 100.
  • Artificial toolface reference system 100 may include power supply 101.
  • Power supply 101 may be any device capable of providing an electrical current as described herein, and may constitute a current supply or voltage supply as understood in the art.
  • Power supply 101 may be in electrical connection between ground lead 103 and reference lead 105.
  • Ground lead 103 may be in electrical connection to grounding point.
  • Reference lead 105 may be in electrical connection to reference conductor 109 positioned in reference wellbore 10.
  • Reference conductor 109 may be any conductor positioned within reference wellbore 10.
  • Reference conductor 109 may be any conductor or combination of conductors axially aligned with reference wellbore 10.
  • reference conductor 109 may be a length or string of tubing or casing, liner, drill pipe, drill collars, pup joints, production tubing, or wireline.
  • reference conductor 109 may be a drill stem or other length of drill string positioned in reference wellbore 10 including a fish or other downhole tool.
  • reference lead 105 may electrically couple to reference conductor 109 at an upper end 110 of reference conductor 109 at or near the surface of the ground 15.
  • reference conductor 109 may be a wire or cable positioned in reference wellbore 10 for communication with or providing power to a piece of downhole equipment.
  • reference conductor 109 may be a wire for a downhole pump (not shown) positioned in reference wellbore 10. As understood in the art, one or more additional wires may be included in the wire for the downhole pump, which may be used as described herein.
  • reference lead 105 is depicted as coupling to reference conductor 109 at the surface of ground 15, in some embodiments, reference lead 105 may be positioned within reference conductor 109 to make electrical contact with reference conductor 109 along its length within reference wellbore 10.
  • a single wire (not shown) may be extended through reference conductor 109 and may make electrical contact therewith at a point on reference conductor 109 away from the surface of ground 15.
  • the wire may contact reference conductor 109 by gravity at, for example and without limitation, a deviation in the direction of reference conductor 109.
  • the wire may be coupled to a centralizer or other device having one or more conductive extensions such as bow springs to contact reference conductor 109.
  • the wire may be electrically coupled to reference conductor 109 through a conductive fluid within reference conductor 109.
  • insulating layer 111 may be positioned about reference conductor 109. Insulating layer 111 may, for example and without limitation, electrically insulate an outer surface of reference conductor 109 from reference wellbore 10 and thus from ground 15. In some embodiments, insulating layer 111 may extend over a portion of reference conductor 109, referred to herein as insulated portion 113. In some embodiments, a portion of reference conductor 109, referred to herein as uninsulated portion 115, may be uninsulated and at least partially not covered by insulating layer 111.
  • uninsulated portion 115 may be positioned at lower end 112 of reference conductor 109, defined herein as being the furthest end of reference conductor 109 from the surface of ground 15.
  • insulating layer may extend from the surface of ground 15 to uninsulated portion 115.
  • insulating layer 111 may be positioned on reference conductor 109 to align with, for example and without limitation, formation zones along reference wellbore 10 having high conductivity.
  • such a high conductivity zone may include a water-bearing sand formation.
  • Insulating layer 111 may be formed from any electrically insulating material.
  • an electrically insulating material is a material which does not substantially conduct electricity as understood in the art.
  • insulating layer 111 may be applied in the form of a coating to an exterior surface of reference conductor 109.
  • insulating layer 111 may be applied individually to one or more tubulars which make up reference conductor 109 in embodiments in which reference conductor 109 is a tubular string. In some such embodiments, the joint between adjacent tubulars may be continuously or discontinuously insulated when the adjacent tubulars are joined.
  • insulating layer 111 may be adhered to reference conductor 109 or may be a covering which is not adhered to reference conductor 109.
  • insulating layer 111 may be applied by spraying, brushing, dipping, electrostatic deposition, wrapping, casting, extruding, or any other suitable method as understood in the art depending on the makeup of insulating layer 111.
  • cold spraying and thermal spraying may be utilized.
  • insulating layer 111 may be sprayed in the form of a fluid or foam onto reference conductor 109.
  • reference conductor 109 may be rotated and moved past one or more fixed spraying orifices.
  • the electrically insulating material of insulating layer 111 may be a single or plural component fluid or foam, whereby the respective parts chemically combine into finished form once dispensed from the spray application system.
  • the rate of curing of insulating layer 111 may be modified through the use of varying temperatures, types and amounts of catalysts, or as otherwise known in the art.
  • the spraying operation may include, for example and without limitation, detonation spraying, flame spraying (powder or wire), high-velocity liquid fuel spraying, high-velocity air fuel spraying, high-velocity oxygen fuel spraying, plasma spraying, and arc spraying.
  • the electrically insulating material of insulating layer 111 may be in the form of a particulate thermosetting powder which fuses to a heated exterior of reference conductor 109. In some embodiments, insulating layer 111 may be extruded onto reference conductor 109.
  • insulating layer 111 may be applied to reference conductor 109 by brush application.
  • reference conductor 109 may be dipped in a bath of the insulating material.
  • reference conductor 109 may be passed through a sizing die to establish the desired thickness of insulating layer 111 as understood in the art.
  • the insulating material of insulating layer 111 may be formed from electrostatically charged particles which may be ejected or sprayed towards reference conductor, and accelerated by an electrostatic charge placed thereon.
  • the thickness of insulating layer 111 may be selected based on the type of reference conductor 109 to be insulated, the insulating material used, and anticipated wellbore conditions.
  • insulating layer 111 may be formed from a plastic or other polymer, such as, for example and without limitation, acrylonitrate butadiene styrene (ABS), an acetate, an acrylic, an acetyl resin, polyamide film, fluoropolymer, polycarbonate, aromatic polyamide, nylon, polyethylene terephthalate, phenolic, epoxy, polyester, polyolefin, polystyrene, polyurethane, polyvinylchloride, polytetrafluoroethylene, thermoplastic, polysulfone, polyetherimide, polyamide-imide, polyphenylene or combinations thereof.
  • ABS acrylonitrate butadiene styrene
  • ABS acrylonitrate butadiene styrene
  • an acetate such as, for example and without limitation, acrylonitrate butadiene styrene (ABS), an acetate, an acrylic, an acetyl resin, polyamide film, fluor
  • insulating layer 111 may be formed from a composite material such as fiberglass material.
  • the fiber reinforcement may be in the form of a fiber tape, fill, or sheeting.
  • insulating layer 111 may be formed from a rubber including, for example and without limitation, neoprene rubber or silicone rubber.
  • insulating layer 111 may be formed from a foam.
  • insulating layer 111 may be formed from varnish.
  • insulating layer 111 may be formed from a ceramic or mineral, such as mica.
  • insulating layer 111 may be formed from one or more of the above listed materials without deviating from the scope of this disclosure. Additionally, one having ordinary skill in the art with the benefit of this disclosure will understand that insulating layer 11 1 may be formed from different materials and/or by different methods at different points along insulated portion 113 without deviating from the scope of this disclosure.
  • Grounding point 107 may be in electrical connection with the surrounding ground 15 or, in a subsea application as depicted in FIG. 2, may be in electrical connection to seawater 25 which may provide an electrical connection with ground 15.
  • ground lead 103 may extend to ground 15.
  • Grounding point 107 may include, for example and without limitation, one or more grounding stakes driven into ground 15 or conductors in electrical contact with seawater 25.
  • grounding point 107 may be an existing casing or well.
  • grounding point 107 may be positioned at a distance from reference wellbore 10.
  • grounding point 107 may be any other electrical ground including, without limitation, culverts, gates, or other structures.
  • reference conductor 109 may be electrically conductive, such that current i travels from power supply 101 through reference lead 105 into reference conductor 109. Because reference conductor 109 is conductive, current flows through reference conductor 109. Insulating layer 111 may prevent or reduce flow of current i from reference conductor 109 to ground 15 across insulated portion 113. Current i may travel through uninsulated portion 115 into ground 15, through which current i propagates to grounding point 107 to return to power supply 101 through ground lead 103. Insulating layer 111 may thus prevent or reduce current leakage along insulated portion 113.
  • grounding point 107 may be positioned a sufficient distance from reference wellbore 10 such that current i leaves reference conductor 109, without being bound by theory, in a substantially isotropic manner according to Ohm's law.
  • reference magnetic field B As current i flows through reference conductor 109, reference magnetic field B is generated thereby, without being bound by theory, according to Ampere's law.
  • Reference magnetic field B extends along the length of reference conductor 109 and is in a plane orthogonal to the flow of current i.
  • the magnitude of reference magnetic field B at a given point along reference conductor 109 is proportional to the magnitude of current i at the point.
  • Preventing or reducing current leakage along insulated portion 113 may, for example and without limitation or limitation to theory, allow a higher magnitude reference magnetic field B to be generated along a longer portion of reference conductor 109 than would be generated with an uninsulated reference conductor 109, as a larger amount of current i travels the length of reference conductor 109.
  • Current i may exit reference conductor 109 into ground 15 at uninsulated portion 115. Because current i extends substantially isotropically from reference conductor 109 into ground 15, the current passing through ground 15 between reference conductor 109 and grounding point 107 may not produce a magnetic field as understood in the art.
  • FIG. 1 also depicts guided wellbore 20.
  • Guided wellbore 20 may include guided drilling string 121.
  • Guided drilling string 121 may include guidance sensor 123.
  • Guided drilling string 121 may also include one or more downhole tools for forming guided wellbore 20, including, for example and without limitation, drill bit 125, BHA 127.
  • guidance sensor 123 may be included in BHA 127 as shown in FIG. 1.
  • guidance sensor 123 may be included as part of a MWD system.
  • guided drilling string 121 may include one or more downhole tools having reference directions, including, for example and without limitation, a rotary steerable system, bent sub, or other tool.
  • the radial orientation of the reference direction within guided wellbore 20 is determined.
  • the orientation of the reference direction of the downhole tool may be referred to as the toolface of guided drilling string 121.
  • the direction of the bend may correspond with the reference direction, and the angle between the reference direction and a magnetic field defining the toolface of guided drilling string 121.
  • guidance sensor 123 may include one or more magnetometers adapted to detect reference magnetic field B.
  • guidance sensor 123 may include a magnetometer array which may determine the magnitude and orientation of a magnetic field passing therethrough.
  • the magnetometer array may be a biaxial magnetometer array aligned such that the axes of the magnetometer array are mutually orthogonal and orthogonal to the longitudinal axis of guided wellbore 20.
  • a triaxial magnetometer array may be utilized.
  • one or more other sensors such as accelerometers may be included with guidance sensor 123 in order to make additional measurements.
  • a heading and distance to reference wellbore 10 from guidance sensor 123 may be determined.
  • the direction of the toolface of guided drilling string 121 may be calculated utilizing measurements of reference magnetic field B.
  • an xyz coordinate system will be established, wherein the z axis is parallel to the central axis of guided drilling string 121 at guidance sensor 123.
  • the x and y axes are defined as mutually orthogonal and orthogonal to the z axis.
  • guidance sensor 123 may include a magnetometer aligned with the x and y axes for a biaxial magnetometer or for all three of these axes for a triaxial magnetometer.
  • the magnitude and direction of reference magnetic field B may be calculated at a point away from its source as: ⁇ 0 ⁇ X f
  • Guidance sensor 123 may take a magnetic field reading within guided wellbore 121, denoted herein as B pos . Because guidance sensor 123 may be exposed to other magnetic fields, such as, for example and without limitation, the magnetic field of the Earth and any nearby cased wellbores or other magnetic anomalies, power supply 101 may reverse current i flowing through reference conductor 109, causing reference magnetic field B to reverse polarity. Guidance sensor 123 may take another reading of reference magnetic field B, denoted herein as Bneg.
  • the first reading may be taken with reference conductor 109 at a positive or negative polarity as long as the two readings are taken at opposite polarities of reference conductor 109. Because any magnetic fields other than B are present for both readings, by finding the difference between B pos and Bneg, the magnetic field values of reference magnetic field B may be isolated, according to:
  • power supply 101 may instead provide periodic or aperiodic alternating currents.
  • guidance sensor 123 may take a reading of reference magnetic field B with either positive or negative polarity and take a reading of magnetic fields with power supply 101 providing no current to reference conductor 109. In such an embodiment, the detected natural magnetic fields may be similarly subtracted from reference magnetic field B to isolate the magnetic field values of reference magnetic field B.
  • the previously described operation may be used for each of the magnetometers in guidance sensor 123.
  • the angle between toolface and reference wellbore 10 may be determined by: because reference magnetic field B is oriented orthogonally to the vector between reference wellbore 10 and guided wellbore 20.
  • the calculated toolface may be referenced to, for example and without limitation, a target location, true or magnetic north, or to gravity high side can be computed by projecting the desired reference direction q into the plane perpendicular to the tool axis, as shown by:
  • ⁇ q q— q ⁇ zz
  • z is the axis of guided drilling string 121 in world coordinates: sin(0) cos(0)
  • the distance and heading to reference wellbore 10 may be computed by standard methods. This heading may be used as a toolface for guided drilling string 121, defining an artificial toolface or artificial magnetic toolface.
  • This heading may be used as a toolface for guided drilling string 121, defining an artificial toolface or artificial magnetic toolface.
  • a single measurement of reference magnetic field B cannot simultaneously determine both direction and toolface.
  • a gradient magnetic field measurement may resolve this ambiguity as can a relative displacement in the horizontal plane.
  • the direction determination may be improved by including a more detailed geometry of reference wellbore 10, the surveyed geometry of ground lead 103, and the resistivity of ground 15 in the model of reference magnetic field B.
  • the field at the position of guidance sensor 123 may be computed by integrating the Biot-Savart law in differential form over all the power supplies.
  • the location of ground point 107 may be selected such that it is in the opposite direction from reference wellbore 10 as guided wellbore 20. By using such an arrangement, any magnetic field generated in ground lead 103 may be parallel to reference magnetic field B. The above described distance measurement may be modified to account for any additional magnetic field therefrom. In some embodiments, the effect of any magnetic field generated in ground lead 103 may be accounted for in the magnetic model as discussed herein above by knowing the location of ground point 107.
  • power supply 101 may supply an AC waveform to ground lead 103 and reference lead 105. In some embodiments, power supply 101 may provide switched DC current to ground lead 103 and reference lead 105. In some embodiments, multiple reference wells 10 having artificial toolface reference systems 100 may be positioned about guided wellbore 20. In some such embodiments, each artificial toolface reference system 100 may be actuated in sequence or simultaneously.
  • one or more accelerometers may be used to determine a gravity toolface to determine whether guided drilling string 121 has rotated.
  • accelerometer derived gravity toolface data may be subject to significant error such as quantization error due to the low inclination angle of guided wellbore 20.
  • the artificial magnetic toolface is not usable for this purpose, as reference magnetic field B causes different values for the determined magnetic toolface when power supply 101 provides positive, negative, or no current.
  • a second set of measurements may be taken with power supply 101 providing positive, negative, or no current, referred to herein as a positive shot, negative shot, and neutral shot respectively, to match the first set of measurements.
  • the determined magnetic toolface based on the second positive shot may be compared with that determined from the first positive shot, that of the second negative shot with the first negative shot, and that of the neutral shot with the first neutral shot. By determining the difference therebetween, it can be determined whether any rotation of guided drill string 121 occurred between measurements.
  • accelerometers and gravity toolface other sensors may be used to identify movement of the tool including, for example and without limitation, one or more gyros to determine a gyro toolface.

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  • Physics & Mathematics (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geophysics (AREA)
  • Electromagnetism (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics And Detection Of Objects (AREA)
  • Measuring Magnetic Variables (AREA)

Abstract

L'invention concerne un système de référence de face de coupe artificielle qui comprend une alimentation électrique fournissant un courant à un câble de terre et à un câble de référence. Un point de terre est couplé au câble de terre et relié électriquement à la terre. Un puits de forage de référence comprend un conducteur de référence relié électriquement à la terre. Le conducteur de référence est relié électriquement au câble de référence. Le conducteur de référence comprend une partie non isolée et une partie isolée autour de laquelle est placée une couche isolante. Un capteur de guidage positionné à l'extérieur du puits de forage de référence comprend au moins un magnétomètre. L'alimentation électrique peut être utilisée pour fournir un courant par l'intermédiaire du conducteur de référence, dans la terre par l'intermédiaire de la partie isolée, et par l'intermédiaire du point de terre de telle sorte qu'un champ magnétique de référence est généré le long du conducteur de référence. Le capteur de guidage peut mesurer le champ magnétique de référence à l'aide d'un magnétomètre. Une face de coupe magnétique artificielle peut être calculée à partir de cette mesure.
PCT/US2016/025110 2015-04-01 2016-03-31 Réduction ou prévention de la dissipation d'un courant électrique et d'un signal magnétique associé dans un puits de forage WO2016182640A1 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
RU2017134129A RU2017134129A (ru) 2015-04-01 2016-03-31 Уменьшение или предотвращение рассеяния электрического тока и связанного магнитного сигнала в стволе скважины
CA2978192A CA2978192C (fr) 2015-04-01 2016-03-31 Reduction ou prevention de la dissipation d'un courant electrique et d'un signal magnetique associe dans un puits de forage

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US201562141636P 2015-04-01 2015-04-01
US62/141,636 2015-04-01
US14/884,414 US9938773B2 (en) 2014-10-17 2015-10-15 Active magnetic azimuthal toolface for vertical borehole kickoff in magnetically perturbed environments
US14/884,414 2015-10-15

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WO2016182640A1 true WO2016182640A1 (fr) 2016-11-17

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Cited By (1)

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CN107165617A (zh) * 2017-07-20 2017-09-15 合肥裕朗机电科技有限公司 一种自浮式电子单点测量仪器

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US2981788A (en) * 1958-12-03 1961-04-25 Anaconda Wire & Cable Co Power cables
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
US5676212A (en) * 1996-04-17 1997-10-14 Vector Magnetics, Inc. Downhole electrode for well guidance system
US7568532B2 (en) * 2006-06-05 2009-08-04 Halliburton Energy Services, Inc. Electromagnetically determining the relative location of a drill bit using a solenoid source installed on a steel casing
US20120061143A1 (en) * 2009-06-01 2012-03-15 Halliburton Energy Services, Inc. Guide Wire for Ranging and Subsurface Broadcast Telemetry
WO2014089402A2 (fr) * 2012-12-07 2014-06-12 Halliburton Energy Services Inc. Système de télémétrie à excitation superficielle pour application de drainage par gravité au moyen de vapeur (sagd)

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2981788A (en) * 1958-12-03 1961-04-25 Anaconda Wire & Cable Co Power cables
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
US5676212A (en) * 1996-04-17 1997-10-14 Vector Magnetics, Inc. Downhole electrode for well guidance system
US7568532B2 (en) * 2006-06-05 2009-08-04 Halliburton Energy Services, Inc. Electromagnetically determining the relative location of a drill bit using a solenoid source installed on a steel casing
US20120061143A1 (en) * 2009-06-01 2012-03-15 Halliburton Energy Services, Inc. Guide Wire for Ranging and Subsurface Broadcast Telemetry
WO2014089402A2 (fr) * 2012-12-07 2014-06-12 Halliburton Energy Services Inc. Système de télémétrie à excitation superficielle pour application de drainage par gravité au moyen de vapeur (sagd)

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN107165617A (zh) * 2017-07-20 2017-09-15 合肥裕朗机电科技有限公司 一种自浮式电子单点测量仪器

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RU2017134129A (ru) 2019-04-03
CA2978192A1 (fr) 2016-11-17
CA2978192C (fr) 2019-03-12

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