WO2014123506A2 - Obtention d'une mesure d'échantillon de carotte en fond de trou à l'aide d'une diagraphie pendant le carottage - Google Patents

Obtention d'une mesure d'échantillon de carotte en fond de trou à l'aide d'une diagraphie pendant le carottage Download PDF

Info

Publication number
WO2014123506A2
WO2014123506A2 PCT/US2013/024731 US2013024731W WO2014123506A2 WO 2014123506 A2 WO2014123506 A2 WO 2014123506A2 US 2013024731 W US2013024731 W US 2013024731W WO 2014123506 A2 WO2014123506 A2 WO 2014123506A2
Authority
WO
WIPO (PCT)
Prior art keywords
core sample
coring
coring bit
drilling tool
property
Prior art date
Application number
PCT/US2013/024731
Other languages
English (en)
Other versions
WO2014123506A3 (fr
Inventor
Shadi Sami Ahmad ALSHANNAQ
Original Assignee
Halliburton Energy Services, 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
Application filed by Halliburton Energy Services, Inc. filed Critical Halliburton Energy Services, Inc.
Priority to PCT/US2013/024731 priority Critical patent/WO2014123506A2/fr
Priority to BR112015016149A priority patent/BR112015016149A2/pt
Priority to EP13874532.8A priority patent/EP2954162A4/fr
Priority to CN201380069564.4A priority patent/CN104995373A/zh
Priority to US14/759,340 priority patent/US20150337654A1/en
Priority to CA2897292A priority patent/CA2897292C/fr
Publication of WO2014123506A2 publication Critical patent/WO2014123506A2/fr
Publication of WO2014123506A3 publication Critical patent/WO2014123506A3/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
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling 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
    • E21B25/00—Apparatus for obtaining or removing undisturbed cores, e.g. core barrels or core extractors
    • 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
    • E21B10/00—Drill bits
    • E21B10/02—Core bits
    • 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
    • E21B25/00—Apparatus for obtaining or removing undisturbed cores, e.g. core barrels or core extractors
    • E21B25/10—Formed core retaining or severing 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
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E21B49/02—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil

Definitions

  • the present disclosure relates generally to coring operations of downhole drilling and, more particularly, to a drilling tool and method for obtaining a downhole core sample measurement using logging while coring.
  • core samples are subsequently inspected and analyzed at the surface by various equipment and techniques depending on the type of information to be collected.
  • core samples can provide indications of formation properties such as porosity, permeability, and other physical or petrophysical properties of the downhole formation.
  • a coring drill bit may be used to collect a continuous core sample at the bitface during the drilling operation. Multiple core samples may be collected and stored in proximity to the coring drill bit. After collection of the desired number of samples, the core samples are lifted to the surface to measure properties of the samples. Most laboratories extract only small plugs from the core samples and provide a relatively small number of data points across the whole well. The core samples, however, can be damaged or compromised in the process of lifting the core samples to the surface. Thus, conventional systems typically include components to support and protect the core sample while lifting it to the surface. Contact between drilling fluids and the core sample may compromise later measurements made to the core sample.
  • core samples can further degrade when they are transported to a laboratory, or otherwise handled to study. Incorrect or inconsistent values from core samples may have severe implications for wellbore drilling operations.
  • FIGURE 1 illustrates a schematic diagram of a drilling apparatus for a logging while drilling or a coring tool in a wellbore, in accordance with some embodiments of the present disclosure
  • FIGURE 2 illustrates a perspective view of a coring bit assembly, in accordance with some embodiments of the present disclosure
  • FIGURE 3 illustrates a perspective view of coring bit electronics associated with a coring bit assembly for performing measurements transversely across a core sample, in accordance with some embodiments of the present disclosure
  • FIGURE 4 illustrates a cross-sectional view of the coring bit electronics in the coring bit assembly of FIGURE 3 for performing measurements transversely across a core sample, in accordance with some embodiments of the present disclosure
  • FIGURE 5 illustrates a cross-sectional view of coring bit electronics in a coring bit assembly for performing measurements to detect anisotropic properties across a core sample, in accordance with some embodiments of the present disclosure
  • FIGURE 6 illustrates a perspective view of coring bit electronics in a coring bit assembly for performing measurements transversely and longitudinally across a core sample, in accordance with some embodiments of the present disclosure
  • FIGURE 7 illustrates a flow chart of an example method for performing measurements on a core sample during LWC operation with coring bit electronics, in accordance with some embodiments of the present disclosure.
  • FIGURES 1-7 where like numbers are used to indicate like and corresponding parts.
  • FIGURE 1 illustrates a schematic diagram of a drilling apparatus 100 for a logging while drilling or a coring tool in wellbore 106, in accordance with some embodiments of the present disclosure.
  • Drilling tool 116 may be suspended by drill pipe 104 in wellbore 106 defined by sidewall 108.
  • Drill pipe 104 may include one or more electrical conductors and a multi- strand cable. Drill pipe 104 may include an armored logging cable and may encompassing the cables and conductors. In some embodiments, drill pipe 104 may include drilling tool 116 and may be extended into wellbore 106.
  • drilling tool 116 may include any device or combination of devices suitable for drilling wellbore 106 and/or extracting core samples from wellbore 106. Drilling tool 116 may rotate by the operation of drill pipe 104 to extract a core sample or drill into wellbore 106.
  • logging while drilling may include drilling into the earth and recording information from sensors 120 that may be located proximate the exterior of drilling tool 116 above the drill bit or coring bit 102 to produce a record of various formation parameters.
  • drilling tool 116 may include coring bit assembly 126, drill collar 118, sensors 120, other on-board electronics, telemetry systems, pressure compensators, hydraulic fluid systems, and/or any other suitable devices.
  • Drill collar 118 and sensors 120 may be located above coring bit 102 with respect to drill pipe 104.
  • Drill collar 118 may include electronics that measure sensor 120 outputs and store them as a function of time or transmit them to a surface control unit and/or any other suitable compute.
  • Sensors 120 may provide continuous measurements of downhole parameters, such as, porosity, resistivity, formation pressure, and/or any other suitable measurements. Sensors 120 may be located on the exterior of drilling tool 116 and may be configured to detect downhole parameters as drilling tool 116 descends and/or drills into wellbore 106. However, due to the location of sensors 120, e.g., above coring bit 102 with reference to drill pipe 104, sensors 120 may provide indirect measurements of the current formation being drilled and may be affected by the downhole environment. For example, sensors 120 may be exposed to mud as mud flows past drilling tool 116. Accuracy of sensors 120 may additionally be affected by standoff between drilling tool 116 and sidewall 108. Further, the direction of sensors 120 with respect to sidewall 108 may be oriented such that the direction may also affect accuracy of measurements.
  • sensors 120 may be located on the exterior of drilling tool 116 and may be configured to detect downhole parameters as drilling tool 116 descends and/or drills into wellbore 106. However, due to the location of sensors 120
  • alternate configurations of drilling apparatus 100 may be arranged for Logging While Coring (LWC) operations.
  • LWC may include extracting a core sample and detecting and/or recording information from sensors that may be located proximate to the interior of drilling tool 116.
  • LWC may include taking, e.g. logging, measurements of a core sample as the core sample is passing through drilling tool 116.
  • coring bit assembly 126 (shown in further detail in FIGURE 2) may include coring bit 102 and may operate to extract a core sample from wellbore 106.
  • coring bit assembly 126 may also include sensors, calipers, electronics, transmitters, receivers, and other elements to perform in-situ measurements of a core sample.
  • the measurements may be transmitted to a surface control unit, drill collar 118, and/or other suitable devices for further analysis.
  • the sensors may continuously collect data from a moving string of cores in critical spots of the well. LWC operation may improve measurement accuracy and resolution, add anisotropic capabilities, and introduce new classes of measurements that may not be achievable with LWD operation.
  • FIGURE 2 illustrates a perspective view of coring bit assembly 126, in accordance with some embodiments of the present disclosure.
  • Coring bit 102 may be any of various types of fixed cutter drill bits, including polycrystalline diamond cutter (PDC) bits, drag bits, matrix drill bits, and/or steel body drill bits operable to extract a core sample from wellbore 106.
  • PDC polycrystalline diamond cutter
  • Coring bit 102 may be designed and formed in accordance with teachings of the present disclosure and may have many different designs, configurations, and/or dimensions according to the particular application of coring bit 102.
  • Coring bit body 306 may have a generally cylindrical body and inner gage 314.
  • Coring bit 102 may further include throat 310 that may extend longitudinally through coring bit 102.
  • Throat 310 of coring bit 102 may allow a core sample to be cut with a smaller diameter than throat 310.
  • Coring bit 102 may include one or more cutting elements 302 disposed outwardly from exterior portions of bit body 306.
  • a portion of cutting element 302 may be directly or indirectly coupled to an exterior portion of bit body 306 while another portion of cutting element 302 may be projected away from the exterior portion of bit body 306.
  • Cutting elements 302 may be any suitable device configured to cut into a formation, including but not limited to, primary cutting elements, back-up cutting elements, secondary cutting elements or any combination thereof.
  • cutting elements 302 may be various types of cutters, compacts, buttons, inserts, and gage cutters satisfactory for use with a wide variety of coring bits 102.
  • Cutting elements 302 may include respective substrates with a layer of hard cutting material disposed on one end of each respective substrate.
  • the hard layer of cutting elements 302 may provide a cutting surface that may engage adjacent portions of wellbore 106.
  • Each substrate of cutting elements 202 may have various configurations and may be formed from tungsten carbide or other materials associated with forming cutting elements for coring bits.
  • Tungsten carbides may include, but are not limited to, monotungsten carbide (WC), ditungsten carbide (W 2 C), macrocrystalline tungsten carbide and cemented or sintered tungsten carbide.
  • Substrates may also be formed using other hard materials, which may include various metal alloys and cements such as metal borides, metal carbides, metal oxides and metal nitrides.
  • the hard cutting layer may be formed from substantially the same materials as the substrate. In other applications, the hard cutting layer may be formed from different materials than the substrate. Examples of materials used to form hard cutting layers may include polycrystalline diamond materials, including synthetic polycrystalline diamonds.
  • coring bit 102 may extract a core sample from a formation of interest approximately the diameter of throat 310.
  • sensors, calipers, electronics, and other elements resident in coring bit assembly 126 may make in-situ measurements of the core sample.
  • Coring bit 102 may be connected to coring mandrel 402.
  • Coring mandrel 402 may have a longitudinal opening 404 that may correspond to throat 310.
  • One end of coring mandrel 402 may be threadably connected to threaded form 406.
  • Inner barrel 408 may pass through coring mandrel 402 and/or threaded form 406. Further, inner barrel 408 may contain inner sleeve 410 that may capture core sample 412. Inner sleeve 410 may be encompassed by inner barrel 408 and/or may extend beyond inner barrel 408. Threaded form 406 may connect inner barrel 408 to coring bit 102 via coring mandrel 402.
  • coring bit electronics 414 may be contained in coring mandrel 402. Coring bit electronics 414 may also be located in inner barrel 408 (not expressly shown), inner sleeve 410 (not expressly shown), and/or any combination of coring mandrel 402, inner barrel 408, and inner sleeve 410, and/or any other suitable location. Coring bit electronics 414 may include any receivers, transmitters, transceivers, sensors, calipers, and/or other electronic components that may be used in a downhole measurement system. Sensors may include multiple types, including but not limited to, resistivity, dielectric, sonic, nuclear, or nuclear magnetic resonance (NMR).
  • NMR nuclear magnetic resonance
  • Coring bit electronics 414 may also include any necessary electronics to provide communication between the receivers, transmitters, transceivers, sensors, calipers, and/or other electronic components.
  • the spacing, exact location, and transmitter-receiver arrangement of coring bit electronics 414 may depend on factors including, but not limited to, the direction of measurement and/or the type of sensors, calipers, and/or other types of measurement tools.
  • Implanting coring bit electronics 414 in coring mandrel 402, inner barrel 408, inner sleeve 410, and/or any other suitable location may allow coring bit electronics 414 to perform direct and/or continuous measurements as core sample 412 moves through coring bit assembly 126. Accordingly, some embodiments of the present disclosure may allow measurements of core sample 412 to be made in drilling tool 116 (as shown with reference to FIGURE 1). Following extraction from wellbore 106, core sample 412 may be stored and later retrieved and lifted to the surface. Core sample 412 may be lifted to the surface by retrieving inner sleeve 410 and/or by extraction of drilling tool 116 from wellbore 106.
  • contamination may affect measurements made by sensors 120 due to characteristics of the wellbore environment, including tool standoff, washouts, mud flows and/or other situations that may compromise measurement integrity of sensors 120. Similar conditions may apply during wireline operations, which may include lowering sensors into a wellbore after removal of a drilling tool. However, during LWC operation the measurements made by coring bit electronics 414 of a core sample may not be affected by such wellbore situations. Measurements by coring bit electronics 414 may have the advantage of a measurement environment confined around core sample 412 being relatively small. The distance between multiple sensors and/or other elements may also be relatively small in the confined environment of coring bit assembly 126.
  • coring bit electronics 414 may be simpler in configuration and design than sensors 120.
  • the confined space may minimize the transverse movement of core sample 412 in coring mandrel 402, inner barrel 408, and/or inner sleeve 410 allowing for less eccentricity related impact and more consistent measurements.
  • the power requirements for coring bit electronics 414 may be less than the power requirements for sensors 120.
  • LWC operation utilizing coring bit electronics 414 may include measuring parameters of core sample 412 in multiple directions, e.g., x-axis, y-axis, and z-axis. Resolution of measurements may also be improved since resolution may be a function of the distance between sensors. LWC operation utilizing coring bit electronics 414 may provide a minimum distance between a transmitter and a receiver, and thus, may provide enhancements to resolution than may be achieved with LWD.
  • LWC may provide real-time formation measurements that may have better correlation with the core laboratories measurements. LWC may further overcome issues regarding core porosity and mechanical properties that may occur after a core sample is removed from the wellbore to a laboratory for measurement.
  • the LWC tool may be operated as the sole logging tool or in conjunction with other logging techniques. This may be done in order to obtain increasingly accurate, high-resolution and anisotropic data in the critical spots of the wellbore.
  • the collected data may also be used to calibrate readings from LWD or wireline sensors outside the cored range to enhance their accuracy without the need to wait for laboratory data.
  • FIGURE 3 illustrates a perspective view of the coring bit electronics in a coring bit assembly for performing measurements transversely across a core sample, in accordance with some embodiments of the present disclosure.
  • a portion of coring mandrel 402 containing a portion of core sample 412 is shown.
  • Coring mandrel 402, inner barrel 408, inner sleeve 410 (shown in FIGURE 2), and/or any other suitable location may include coring bit electronics 414.
  • Coring bit electronics 414 may include transmitter 502, receiver 504, sensors, calipers, and/or other electronics or elements suitable for measurement of core sample 412. This configuration may allow the measurement of properties across core sample 412 in the transverse direction, e.g., the x-axis direction. Additionally, some embodiments of the present disclosure may include receiver 504 without transmitter 502.
  • coring bit 102 may extract core sample 412 from the formation.
  • Core sample 412 may be captured by inner sleeve 410 and pass through inner barrel 408.
  • coring bit electronics in coring mandrel 402 may make measurements of various characteristics and properties of core sample 412, for example.
  • the measurements may be taken continuously as core sample 412 passes through coring bit assembly, and/or the measurements may be interval based and may be programmed to take a measurement based on either elapsed time and/or length of core sample 412. Additionally, the measurements may be taken as needed based on a predefined measurement protocol.
  • measurements made by coring bit electronics 414 may be communicated to a surface control unit and/or any other suitable unit for receiving signals from coring bit electronics 414.
  • Logs may be created using information from coring bit electronics 414 and the logs may exhibit improved accuracy than would be achieved by sensors 120 or achieved after core sample 412 is removed to the surface.
  • additional classes of measurements e.g., computed tomography and/or other scanning techniques may be available to coring bit assembly 126, in accordance with some embodiments of the present disclosure.
  • FIGURE 4 illustrates a cross-sectional view of coring bit electronics 414 in coring bit assembly 126 of FIGURE 3 for performing measurements transversely across a core sample, in accordance with some embodiments of the present disclosure.
  • Transmitter 502 and/or receiver 504 may be mounted within or attached to coring mandrel 402. Although the present embodiment is illustrated with respect to coring mandrel 402, transmitter 502 and/or receiver 504 may also and/or alternatively be mounted within or attached to inner barrel 408, inner sleeve 410, and/or mounted in any suitable location. Transmitter 502 may be located substantially opposite from receiver 504 with respect to core sample 412.
  • Sensors, calipers, and/or other measurement tools may be included as part of or near to transmitters 502 and/or receivers 504. Further, transmitter 502 and/or receiver 504 may be transceivers in order to transmit and receive from both sides of coring mandrel 402, inner barrel 408, and/or inner sleeve 410. In operation of embodiments of the present disclosure, a signal may be sent from transmitter 502 and received by receiver 504. The characteristics and properties of the signal received by receiver 504 may indicate various properties of core sample 412, e.g., porosity, permeability, and other physical or petrophysical properties of core sample 412. The resultant signals and/or measurements may be communicated to a surface control unit via any suitable method for communicating data.
  • FIGURE 5 illustrates a cross-sectional view of coring bit electronics 414 in coring bit assembly 126 for performing measurements to detect anisotropic properties across core sample 412, in accordance with some embodiments of the present disclosure.
  • coring bit electronics 414 may contain two transmitters 502a and 502b and two receivers 504a and 504b.
  • Transmitter 502a may be arranged substantially opposite from receiver 504a with respect to core sample 412, e.g., along the x-axis.
  • transmitter 502a may be arranged substantially opposite from receiver 504b with respect to core sample 412 and approximately ninety degrees rotated from transmitter 502a and receiver 504a, e.g., along the y-axis.
  • Sensors, calipers, and/or other measurement tools may be included as part of or near to transmitters 502 and/or receivers 504. Further, transmitters 502 and/or receivers 504 may be transceivers in order to transmit and receive from both sides of coring mandrel 402 and/or inner barrel 408. In operation of embodiments of the present disclosure, a signal may be sent from transmitter 502a and received by receiver 504a. Additionally, a signal may be sent from transmitter 502b and received by receiver 504b. The characteristics and properties of the signal received by receivers 404 may indicate various properties of core sample 412, e.g., porosity, permeability, and/or other physical or petrophysical properties of core sample 412.
  • the resultant signals and/or measurements may be communicated to a surface control unit via any suitable method for communicating data.
  • the configuration shown in FIGURE 5 may allow the detection of anisotropic properties in core sample 412 (e.g., detection of unequal physical properties along different axes) by measuring core sample 412 properties in both the x-axis and y-axis directions.
  • FIGURE 6 illustrates a perspective view for coring bit electronics 414 in coring bit assembly 126 for performing measurements transversely and longitudinally across core sample 412, in accordance with some embodiments of the present disclosure.
  • Transmitters 502 and/or receivers 504 may be mounted within or attached to coring mandrel 402. Although the present embodiment is illustrated with respect to coring mandrel 402, transmitters 502 and/or receivers 504 may also and/or alternatively be mounted within or attached to inner barrel 408, inner sleeve 410, and/or mounted in any suitable location.
  • coring bit electronics 414 may include two receivers 504a and 504b and transmitter 502a.
  • Transmitter 502a may be arranged substantially opposite from receiver 504a with respect to core sample 412, e.g., along the x-axis.
  • Receiver 504b may be arranged axially with transmitter 502b, e.g., along the z-axis.
  • Sensors, calipers, and/or other measurement tools may be included as part of or near to transmitter 502a and/or receivers 504a and 504b.
  • transmitter 502a and/or receivers 504a and 504b may be transceivers in order to transmit and receive from both sides of coring mandrel 402, inner barrel 408, and/or inner sleeve 410.
  • a signal may be sent from transmitter 502a and received by receiver 504a and/or receiver 504b.
  • the characteristics and properties of the signal received by receivers 504 may indicate various properties of core sample 412, e.g., porosity, permeability, and/or other physical or petrophysical properties of core sample 412.
  • the resultant signals and/or measurements may be communicated to a surface control unit via any suitable method for communicating data.
  • the configuration shown in FIGURE 6 may allow both transverse measurement (e.g., between transmitter 502a and receiver 504a) and longitudinal measurement (e.g., between transmitter 502a and receiver 504b).
  • coring bit electronics 414 may include more or fewer components, including transmitters 502 and receivers 504, than shown in FIGURES 2-6.
  • coring bit electronics 414 may allow for measurements based on electromagnetic radiation or a light spectrum, such as visible light, infra-red, ultraviolet, and/or x-ray.
  • consideration may be made of the type of components, placement of components, corrections for polarization of transmitted waves, and other considerations. For example, continuity of the core string may become a challenge that may be corrected by the addition of an internal mechanical or electronic caliper to the coring bit electronics.
  • FIGURE 7 illustrates a flow chart of example method 700 for performing measurements on core sample 412 during LWC operation with coring bit electronics (e.g., 414 of FIGURES 2-6), in accordance with some embodiments of the present disclosure.
  • the steps of method 700 may be performed by various computer programs, models or any combination thereof, configured to operate a drilling tool, perform measurements, and log/analyze results.
  • the programs and models may include instructions stored on a computer readable medium and operable to perform, when executed, one or more of the steps described below.
  • the computer readable media may include any system, apparatus or device configured to store and retrieve programs or instructions such as a hard disk drive, a compact disc, flash memory or any other suitable device.
  • the programs and models may be configured to direct a processor or other suitable unit to retrieve and execute the instructions from the computer readable media.
  • the computer programs and models used to operate a drilling tool, perform measurements, and log/analyze results may be referred to as a "drilling engineering tool" or "engineering tool.”
  • method 700 is described with respect to drilling tool 116 of FIGURE 1; however, method 700 may be used to perform measurements, and log/analyze results using any suitable drilling tool.
  • Method 700 may start and at step 706, the engineering tool may direct a drilling tool to extract a core sample from a wellbore.
  • the engineering tool may direct a drilling tool to extract a core sample from a wellbore.
  • coring bit 102 may be directed to operate and cut core sample 412 from wellbore 106.
  • method 700 may continue to step 708.
  • the engineering tool may direct the coring bit assembly to obtain measurements of the core sample using the coring bit electronics and log results.
  • coring bit electronics 414 contained in coring bit assembly 126 may perform transverse measurements using transmitter 502 and/or receiver 504. The measurements may be transmitted to a surface control unit and logged and/or analyzed.
  • the engineering tool may determine if all measurements have been successfully captured and logged. If more measurements are required, method 700 may return to step 708 to perform additional measurements. If no additional measurements are required, method 700 may proceed to step 712.
  • the engineering tool may direct the drilling tool to remove the core sample.
  • core sample 412 may be removed to the surface or core sample 412 may be deposited into a storage compartment for later removal.
  • drilling tool 116 may deposit core sample 412 in a storage tube (not shown).
  • the engineering tool may determine if more core samples are required. If more core samples are required, method 700 may return to step 706. For example, if more measurements are required, another core sample 412 may be obtained from wellbore 106. This cycle may be repeated until all of core samples 412 are collected, after which, at step 716 drilling tool 116 may be removed from wellbore 106. Following removal of drilling tool 116, method 700 may end.

Landscapes

  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Soil Sciences (AREA)
  • Sampling And Sample Adjustment (AREA)
  • Processing Of Stones Or Stones Resemblance Materials (AREA)

Abstract

L'invention concerne un outil et un procédé de forage qui permettent d'obtenir une mesure d'échantillon de carotte en fond de trou à l'aide d'une diagraphie pendant le carottage. Un outil de forage comprend une couronne de carottage configurée pour obtenir un échantillon de carotte d'un puits. Un mandrin de carottage est couplé à la couronne de carottage et comprend un alésage de jauge interne. Un cylindre interne est disposé à l'intérieur de l'alésage de jauge interne et un manchon interne, configuré pour recevoir l'échantillon de carotte, est disposé à l'intérieur du cylindre interne. Des composants électroniques de la couronne de carottage sont couplés au mandrin de carottage.
PCT/US2013/024731 2013-02-05 2013-02-05 Obtention d'une mesure d'échantillon de carotte en fond de trou à l'aide d'une diagraphie pendant le carottage WO2014123506A2 (fr)

Priority Applications (6)

Application Number Priority Date Filing Date Title
PCT/US2013/024731 WO2014123506A2 (fr) 2013-02-05 2013-02-05 Obtention d'une mesure d'échantillon de carotte en fond de trou à l'aide d'une diagraphie pendant le carottage
BR112015016149A BR112015016149A2 (pt) 2013-02-05 2013-02-05 ferramenta de perfuração, e, método para desempenhar medições em uma amostra de núcleo
EP13874532.8A EP2954162A4 (fr) 2013-02-05 2013-02-05 Obtention d'une mesure d'échantillon de carotte en fond de trou à l'aide d'une diagraphie pendant le carottage
CN201380069564.4A CN104995373A (zh) 2013-02-05 2013-02-05 使用随取芯测井获得井下岩芯样本测量值
US14/759,340 US20150337654A1 (en) 2013-02-05 2013-02-05 Obtaining a downhole core sample measurement using logging while coring
CA2897292A CA2897292C (fr) 2013-02-05 2013-02-05 Obtention d'une mesure d'echantillon de carotte en fond de trou a l'aide d'une diagraphie pendant le carottage

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2013/024731 WO2014123506A2 (fr) 2013-02-05 2013-02-05 Obtention d'une mesure d'échantillon de carotte en fond de trou à l'aide d'une diagraphie pendant le carottage

Publications (2)

Publication Number Publication Date
WO2014123506A2 true WO2014123506A2 (fr) 2014-08-14
WO2014123506A3 WO2014123506A3 (fr) 2015-06-25

Family

ID=51300231

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2013/024731 WO2014123506A2 (fr) 2013-02-05 2013-02-05 Obtention d'une mesure d'échantillon de carotte en fond de trou à l'aide d'une diagraphie pendant le carottage

Country Status (6)

Country Link
US (1) US20150337654A1 (fr)
EP (1) EP2954162A4 (fr)
CN (1) CN104995373A (fr)
BR (1) BR112015016149A2 (fr)
CA (1) CA2897292C (fr)
WO (1) WO2014123506A2 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2016033140A1 (fr) * 2014-08-26 2016-03-03 Baker Hughes Incorporated Modules d'activation pour obstruer des entrées de tubes internes d'outils de carottage et outils de carottage et procédés associés

Families Citing this family (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10767431B2 (en) 2016-03-03 2020-09-08 Halliburton Energy Services, Inc. Inner barrel crimping connection for a coring tool
WO2017151131A1 (fr) * 2016-03-03 2017-09-08 Halliburton Energy Services, Inc. Zone de cisaillement de cylindre interne pour un outil de carottage
CN107299828A (zh) * 2017-04-28 2017-10-27 北京捷威思特科技有限公司 井壁取芯器水平井工作方法
JP6936451B2 (ja) * 2017-04-28 2021-09-15 国立研究開発法人 海上・港湾・航空技術研究所 地盤試料のスキャン方法、地盤試料の供試体の生産方法、地盤試料の土質試験方法及び地盤試料のスキャン装置
CN109681140B (zh) * 2018-12-26 2023-09-01 深圳大学 岩样保真取芯装置
CN110940554A (zh) * 2019-12-27 2020-03-31 宁波工程学院 多功能取芯检测装置
CN114233224B (zh) * 2021-12-29 2023-12-12 东营市宇彤机电设备有限责任公司 一种测井数控取心仪便携检测集成系统
CN115653564A (zh) * 2022-10-21 2023-01-31 中建工程产业技术研究院有限公司 一种物探和钻探集成探头
CN116695664B (zh) * 2023-07-28 2023-10-13 宏新建设集团有限公司 一种软土地基注浆充盈度检测取样装置

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5984023A (en) 1996-07-26 1999-11-16 Advanced Coring Technology Downhole in-situ measurement of physical and or chemical properties including fluid saturations of cores while coring
WO2007104103A1 (fr) 2006-03-14 2007-09-20 2Ic Australia Pty Ltd Procede d'orientation d'un echantillon de carotte
US20090078467A1 (en) 2007-09-25 2009-03-26 Baker Hughes Incorporated Apparatus and Methods For Continuous Coring

Family Cites Families (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3577643A (en) * 1967-05-18 1971-05-04 Shell Oil Co Borehole deformation gage
US5568838A (en) * 1994-09-23 1996-10-29 Baker Hughes Incorporated Bit-stabilized combination coring and drilling system
BE1009966A3 (fr) * 1996-01-15 1997-11-04 Baroid Technology Inc Carottier.
BE1010325A3 (fr) * 1996-06-05 1998-06-02 Dresser Ind Carottier.
GB0724972D0 (en) * 2007-12-21 2008-01-30 Corpro Systems Ltd Monitoring apparatus for core barrel operations
US7913775B2 (en) * 2007-12-27 2011-03-29 Schlumberger Technology Corporation Subsurface formation core acquisition system using high speed data and control telemetry
US8499856B2 (en) * 2010-07-19 2013-08-06 Baker Hughes Incorporated Small core generation and analysis at-bit as LWD tool

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5984023A (en) 1996-07-26 1999-11-16 Advanced Coring Technology Downhole in-situ measurement of physical and or chemical properties including fluid saturations of cores while coring
WO2007104103A1 (fr) 2006-03-14 2007-09-20 2Ic Australia Pty Ltd Procede d'orientation d'un echantillon de carotte
US20090078467A1 (en) 2007-09-25 2009-03-26 Baker Hughes Incorporated Apparatus and Methods For Continuous Coring

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See also references of EP2954162A4

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2016033140A1 (fr) * 2014-08-26 2016-03-03 Baker Hughes Incorporated Modules d'activation pour obstruer des entrées de tubes internes d'outils de carottage et outils de carottage et procédés associés
US9745811B2 (en) 2014-08-26 2017-08-29 Baker Hughes Incorporated Activation modules for obstructing entrances to inner barrels of coring tools and related coring tools and methods
US10435974B2 (en) 2014-08-26 2019-10-08 Baker Hughes Incorporated Activation modules for obstructing entrances to inner barrels of coring tools and related coring tools and methods

Also Published As

Publication number Publication date
CA2897292C (fr) 2016-04-05
WO2014123506A3 (fr) 2015-06-25
EP2954162A2 (fr) 2015-12-16
CN104995373A (zh) 2015-10-21
US20150337654A1 (en) 2015-11-26
EP2954162A4 (fr) 2016-04-20
CA2897292A1 (fr) 2014-08-14
BR112015016149A2 (pt) 2017-07-11

Similar Documents

Publication Publication Date Title
CA2897292C (fr) Obtention d'une mesure d'echantillon de carotte en fond de trou a l'aide d'une diagraphie pendant le carottage
US7532129B2 (en) Apparatus and methods for conveying and operating analytical instrumentation within a well borehole
US10941656B2 (en) Downhole configurable testing apparatus and methods
NO20140613A1 (no) Borehullsavbildning og formasjonsevaluering under boring
US10061047B2 (en) Downhole inspection with ultrasonic sensor and conformable sensor responses
US10641917B2 (en) Pipe and borehole imaging tool with multi-component conformable sensors
US10094948B2 (en) High resolution downhole flaw detection using pattern matching
EP3025023A1 (fr) Détection multiple à la fois de l'entartrage et de la corrosion dans des tuyaux de fond de trou à l'aide de capteurs concordants
US9341053B2 (en) Multi-layer sensors for downhole inspection
US10067258B2 (en) Downhole measurement and survey tools with conformable sensors
US9650888B2 (en) Multi-mode measurements with a downhole tool using conformable sensors
EP3025021A1 (fr) Inspection, détection et imagerie de fond à l'aide de capteurs conformables
US9823380B2 (en) Compensated borehole and pipe survey tool with conformable sensors
US9915749B2 (en) Sensors, tools and systems containing a metallic foam and elastomer composite
US8272260B2 (en) Method and apparatus for formation evaluation after drilling
CA2927140C (fr) Systemes de fond pour la communication de donnees

Legal Events

Date Code Title Description
DPE1 Request for preliminary examination filed after expiration of 19th month from priority date (pct application filed from 20040101)
ENP Entry into the national phase

Ref document number: 2897292

Country of ref document: CA

REEP Request for entry into the european phase

Ref document number: 2013874532

Country of ref document: EP

WWE Wipo information: entry into national phase

Ref document number: 14759340

Country of ref document: US

Ref document number: 2013874532

Country of ref document: EP

REG Reference to national code

Ref country code: BR

Ref legal event code: B01A

Ref document number: 112015016149

Country of ref document: BR

121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 13874532

Country of ref document: EP

Kind code of ref document: A2

ENP Entry into the national phase

Ref document number: 112015016149

Country of ref document: BR

Kind code of ref document: A2

Effective date: 20150703