• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
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  • 优先权
    • 专利摘要:
    manufacturing process and pdc detection element tool. the present invention relates to a compact polycrystalline diamond cutter (pdc) for a rotary drill bit which is provided with an integrated sensor and circuits for taking measurements of a fluid property in the well and / or an operating condition of the drill bit. a method of manufacturing the pdc cutter and rotary drill bit is discussed.
    公开号:BR112012027697B1
    申请号:R112012027697-2
    申请日:2011-04-26
    公开日:2020-05-26
    发明作者:Sunil Kumar；Anthony A. DiGiovanni；Dan Scott；Hendrik John；Othon Monteiro
    申请人:Baker Hughes Incorporated；
    IPC主号:
    专利说明:

    Invention Patent Descriptive Report for ROTARY DRILLING DRILL, METHOD OF PERFORMING DRILLING OPERATIONS AND METHOD OF FORMING A ROTATING DRILLING DRILL.
    BACKGROUND OF THE INVENTION
    1. Field of the Invention
    [001] The present invention relates generally to Polycrystalline Diamond Compact drill bits, and in particular to a method and apparatus for PDC drills with integrated sensors and methods for the production of such PDC drills.
    2. Related Technique
    [002] Rotary drill bits are generally used to drill uncoated wells, or well holes, in soil formations. Rotary drill bits include two of their main configurations and combinations. One configuration is the roller cone drill, which typically includes three roller cones mounted on support legs that extend from a drill body. Each roller cone is configured to rotate or turn on a support leg. Teeth are provided on the outer surfaces of each roller cone to cut rock and other soil formations.
    [003] A second main configuration of a rotary drill bit is the fixed cutter bit (often referred to as a drill bit), which conventionally includes a plurality of cutting elements attached to a region of the face of a drill body . Generally, the cutting elements of a fixed cutter drill bit have a disk shape or a substantially cylindrical shape. A hard, superabrasive material, such as mutually bonded polycrystalline diamond particles, can be provided on a substantially circular end surface of each cutting element to form a cutting surface.
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    Such cutting elements are often referred to as compact polycrystalline diamond (PDC) cutters. The cutting elements can be manufactured separately from the drill body and be fixed inside pockets formed on the outer surface of the drill body. A bonding material such as an adhesive or a solder alloy can be used to secure the cutting elements to the drill body. The fixed cutter drill bit can be placed in an uncoated well in such a way that the cutting elements confine against the formation of the soil to be drilled. As the drill bit is turned, the cutting elements engage and shear the surface of the underlying formation.
    [004] During drilling operations, it is common practice to use measurement sensors in conjunction with drilling (MWD) and profiling in conjunction with drilling (LWD) to measure drilling conditions or forming properties and / or fluid and to control drilling operations when using MWD / LWD measurements. The tools are housed in a lower bore assembly (BHA) or formed to be compatible with the drill shank. It is desirable to obtain formation information as close as possible to the tip of the drill bit. [005] The present invention relates to a drill bit having PDC cutting elements including integrated circuits configured to measure drilling conditions, the properties of fluids in the uncoated well, the properties of soil formations, and / or fluid properties in soil formations. When there are sensors in the drill bit, the time delay between the drill penetration into the formation and the time that the MWD / LWD tool detects the property of the formation or the drilling condition is substantially eliminated. In addition, when sensors are on the drill bit, unsafe drilling conditions
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    3/14 are more likely to be detected in time for remedial actions to be taken. In addition, the properties of the primitive formation can be measured without any contamination or with reduced contamination of drilling fluids. For example, the mud cake on the wall of the uncoated well prevents and / or distorts measurements of rock properties, such as resistivity, nuclear and acoustic measurements. The invasion of drilling fluid in the formation contaminates the native fluid and leads to erroneous results. SUMMARY OF THE INVENTION
    [006] One embodiment of the invention is a rotary drill bit configured to be driven in a well and drill a soil formation, wherein the rotary drill bit includes: at least one compact polycrystalline diamond cutter (PDC) that includes: (i) at least one cutting element, and (ii) at least one transducer configured to provide a signal indicative of at least one of: (I) a drill bit operating condition, and (ii) a property of a fluid in the well, and (iii) a property of the surrounding formation.
    [007] Another embodiment of the invention is a method of performing drilling operations. The method includes: driving a rotary drill bit into a well and drilling a soil formation; and the use of at least one transducer in a compact polycrystalline diamond cutter (PDC) coupled to a rotary drill bit body to provide a signal indicative of at least one of: (I) a drill bit operating condition, and (ii) a fluid property in the well, and (iii) a formation property.
    [008] Another embodiment of the invention is a method of forming a rotary drill bit. The method includes: the production of at least one compact polycrystalline diamond cutter (PDC)
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    4/14 which includes: (i) at least one cutting element, (ii) at least one transducer configured to provide a signal indicative of at least one of: (I) a drill bit operating condition, and (ii ) a fluid property in the well, and (iii) a formation property and (iii) a protective layer on one side of at least one transducer opposite at least one cutting element; and use of the protective layer to protect a detection layer that includes at least one transducer against abrasion.
    BRIEF DESCRIPTION OF THE DRAWINGS
    [009] For a detailed understanding of the present invention, reference should be made to the following detailed description of the invention, taken in conjunction with the attached drawings:
    [0010] figure 1 is a partial side cross-sectional view of a rotary soil drill bit incorporating the teachings of the present invention and includes a drill body comprising a composite material of matrix particles;
    [0011] figure 2 is an elevation view of a Compact part of Polycrystalline Diamond of a drill bit according to the present invention;
    [0012] figure 3 shows an example of a platform that includes an array of sensors;
    [0013] figure 4 shows an example of a cutter that includes a sensor and a PDC cutting element;
    [0014] figures 5 (a) - 5 (f) show various arrangements for the placement of sensors;
    [0015] figure 6 shows an antenna on the surface of the PDC cutter;
    [0016] figures 7 (a) - (e) illustrate the sequence in which different layers of the PDC cutter are made;
    [0017] figures 8 (a) - 8 (b) show the main operations necessary to obtain the layered formation of figures 7 (a) - 7 (e);
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    [0018] figure 9 shows the basic structure of a platform that includes the sensors of figure 3;
    [0019] figures 10 (a) - 10 (a) - (b) show the steps in manufacturing the set of figure 3;
    [0020] figures 11 (a) - (b) show the steps in manufacturing the set of figure 5 (f); and
    [0021] Figure 12 illustrates the use of transducers in two different cutting elements for measuring the acoustic properties of the formation.
    DETAILED DESCRIPTION OF THE INVENTION
    [0022] A rotary drill bit for soil drilling 10 incorporating the teachings of the present invention is shown in figure 1. Drill bit 10 includes a drill body 12 which comprises a composite material of matrix particles 15 which includes a plurality of hard phase particles or regions dispersed throughout a low melting binder material. The hard phase particles or regions are hard in the sense that they are relatively harder than the surrounding binder material. In some embodiments, the drill body 12 may comprise predominantly the composite material of matrix particles 15, which is described in more detail below. The drill body 12 can be attached to a metal rod 20, which can be formed of steel and can include a threaded pin to the American Petroleum Institute (API) 28 to attach drill bit 10 to a drill column (not shown) ). The drill body 12 can be attached directly to the rod 20, for example, by using one or more retaining members 46 in conjunction with brazing and / or welding, as discussed in more detail below.
    [0023] As shown in figure 1, the drill body 12 can include wings or blades 30 which are separated from each other by the scrap notches 32. The internal fluid passages 42 can be
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    6/14 extend between the face 18 of the drill body 12 and a longitudinal hole 40, which extends through the steel rod 20 and at least partially through the drill body 12. In some embodiments, nozzle inserts (not shown) can be provided on face 18 of the drill body 12 within the internal fluid passages 42.
    [0024] The drill bit 10 can include a plurality of cutting elements on its face 18. As an example and not by way of limitation, a plurality of compact polycrystalline diamond cutters (PDC) 34 can be provided on each of the blades 30, as shown in figure 1. PDC cutters 34 can be provided along the blades 30 within the pockets 36 formed on the face 18 of the drill body 12, and can be supported from behind by the buttresses 38, which can be integrally formed with the drill body 12. During drilling operations, the drill bit 10 can be positioned at the bottom of a well hole and rotated while drilling fluid is pumped into face 18 of the drill body 12 through longitudinal hole 40 and internal fluid passages 42. While PDC 34 cutters cut or mate with the underlying soil formation, the cuts and debris from the formation are mixed and suspended within the drilling fluid, which passes through the scrap notches 32 and the annular space between the bore hole and the drill column to the surface of the soil formation.
    [0025] Now returning to figure 2, a cross section of an exemplary PDC 34 cutter is shown. This includes a PDC 213 cutting element. This can also be indicated as part of the diamond table. A thin layer 215 of material such as Sis ^ / AbOs is provided for passivating / adhering other cutter elements 34 to cutting elements 213. Chemical mechanical polishing (CMP) can be used for the upper surface of passivation layer 215. The cutting element can be provided with a substrate 211.
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    [0026] Layer 217 includes traces of metals and patterns for the electrical circuits associated with a sensor. Above the circuit, the layer is a layer or a plurality of layers 219 that can include a piezoelectric element and a p-n-p transistor. These elements can be configured as a Wheatstone bridge to make measurements. The upper layer 221 is a protective layer (passivation) that is conformable. The conformation layer 221 makes it possible to uniformly cover 217 and / or 219 with a protective layer. Layer 221 can be made of diamond-type carbon (DLC).
    [0027] The detection material shown above is a piezoelectric material. The use of piezoelectric material makes it possible to measure the stress on the cutter 34 during drilling operations. This should not be interpreted as a limitation, and a variety of sensors can be incorporated into layer 219. For example, an array of electrical platforms to measure the electrical potential of the adjacent formation or to investigate high frequency attenuation (HF) can be used. Alternatively, an array of ultrasonic transducers for the formation of acoustic images, determination of velocity, acoustic determination of acoustic attenuation and shear wave propagation can be used.
    [0028] Sensors for other physical properties can be used. These include accelerometers, gyroscopes and inclinometers. Microelectromechanical system (MEMS) or nanoelectromechanical system (NEMS) style sensors and related signal conditioning circuits can be built directly inside the PDC or on the surface. These are examples of sensors for a physical condition of the cutter and the drill string.
    [0029] The chemical sensors that can be incorporated include sensors for elemental analysis: carbon nanotube (CNT), sen
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    8/14 complementary metal oxide semiconductor sores (CMOS) to detect the presence of various trace elements based on the principle of selectively blocked field effect transistors (FET) or ion sensitive field effect transistors (ISFET) for pH, H2S and other ions; sensors for hydrocarbon analysis; sensors based on CNT, DLC that operate in chemical electropotential; and sensors for carbon / oxygen analysis. These are examples of sensors for analyzing a fluid in the well.
    [0030] Acoustic sensors for the formation of acoustic image of the rock can be provided. For the purposes of the present invention, all of these types of sensors can be indicated as transducers. The broad meaning of the term's dictionary should be: a device powered by the energy of one system and the supply of energy in the same or some other form to a second system. This includes sensors that provide an electrical signal in response to a measurement such as radiation, as well as a device that uses electrical energy to produce mechanical movement.
    [0031] In an embodiment of the invention shown in figure 3, a sensor platform 303 provided with an array of detection elements 305 is shown. The detection elements can include pressure sensors, temperature sensors, voltage sensors and / or request sensors. When using the sensor array, it is possible to measure the variations of the fence parameter across the face of the PDC element 301. The electrical connections 307 to the detection array are shown. The platform 303 can be glued to the PDC element 301 as indicated by the arrow 309.
    [0032] In an embodiment of the invention shown in figure 4, a sensor 419 is shown in cutter 34. The sensor can be a chemical field effect (FET) transistor. The 413 PDC element is provided with grooves to allow fluid and particles to flow into the sensor
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    9/14 sor 419. In another embodiment of the invention, sensor 419 may comprise an acoustic transducer configured to measure the acoustic velocity of fluids and particles in the grooves. The acoustic sensors can be made of thin films or they can be made of piezoelectric elements. The detection layer can be built on top of the diamond table or below the diamond table or on the substrate surface, (any of the interfaces with the diamond table or the drill bit matrix). In another embodiment of the invention, sensor 419 may include an array of sensors of the type discussed above with reference to figure 3.
    [0033] With reference to figure 5a, a drill body 12 is shown with cutters 34. A sensor 501 is shown arranged in a cavity 503 in the drill body 12. A communication channel (input flow) 505 is provided for the flow of fluids and / or particles to the sensor 503. The cavity is also provided with an output channel 507. The sensor 501 is similar to the sensor shown in figure 2 , but does not have the cutting elements 213 but includes the circuit layer 215, and the sensor layer 217. The sensor may include a chemical analysis sensor, an inertial sensor; an electrical potential sensor; a magnetic flow sensor and / or an acoustic sensor. The sensor is configured to measure a property of the fluid transported to the cavity and / or solid material in the fluid.
    [0034] Figure 5 (b) shows the sensor arrangement 217 discussed in figure 2. In figure 5 (c), sensor 217 is on the cutting element 213. Figure 5 (d) shows sensor 217 on the substrate and in figure 5 (e) shows a sensor in the matrix 30 and a sensor in the substrate 211. Figure 5f shows an arrangement in which the nanotube sensors 501 are embedded in the matrix. These nanotubes can be used to measure the force of pressure and / or temperature.
    [0035] Figure 6 shows an antenna 601 on cutter 34. One
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    10/14 electromagnetic transceiver (EM) 603 is located in the matrix of the drill body 12. The transceiver is used to interrogate the 601 antenna and retrieve data about the measurements made by the 219 sensor in figure 2. The transceiver is provided with electrically protected cables to allow communication with the devices on the drill stem or on a replacement tool attached to the drill drilling.
    [0036] With reference to figures 7 (a) - (e), the sequence of operations used to assemble the cutter 34 shown in figure 2 is discussed. As shown in figure 7 (a), the PDC 213 elements are mounted in a lever insert 701 to form a diamond table. The loading material 703 is added to flatten the upper surface of the subset shown in figure 7 (a).
    [0037] As shown in more detail of figure 7a in figure
    7b, a passivation layer 705 comprising Si3N4 can be deposited on top of cutter elements 213 and load 703. The purpose of the thin layer is to improve the adhesion between cutter elements 213 and the layer (discussed with reference to figure 7a ). As suggested by the term passivation, this layer also prevents damage to the above layer by the PDC 213 cutting element. Chemical mechanical polishing (CMP) may be required to form the passivation layer. It should be noted that the use of Si3N4 is for example purposes and should not be interpreted as a limitation. The equipment for the deposition of chemical vapor (CVD), the deposition of physical vapor / plasma (PVD), the deposition of low-pressure chemical vapor (LPCVD), the deposition of atomic layer (ALD), and the rotation of sol- gel, it may be necessary at this stage.
    [0038] With reference to figure 7c, traces of metal and a pattern 709 for contacts and electronic circuits are deposited. The equipment for coating with ion bombardment, evaporation, ALD, electroplating, and caustication (plasma and moisture) can
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    11/14 to be used. As shown in figure 7d, a piezoelectric material and a semiconductor layer p-n-p 709 are deposited. The piezoelectric material output can be used as an indication of stress when the underlying pattern in layer 707 includes a Wheatstone bridge. It should be noted that the use of a piezoelectric material is for exemplification purposes only and other types of sensor materials can be used. The equipment needed for this can include LPCVD, CVD, plasma, ALD, and RF ion bombardment.
    [0039] A protective passivation layer that is conformable is added 711. The conformation term is used to mean the ability to form a layer on top of a variable topology layer. This can be made of diamond-type carbon (DLC). The necessary processing equipment may include CVD, sintering, and RF ion bombardment. Removing the handle 701 and the load material results in the PDC cutter 34 shown in figure 2 which can be attached to the wing 30 in figure 1.
    [0040] Figure 8a shows the main operational units needed to provide the assembled PDC unit of figure 7b. This includes starting with elements 213 at step 801 and lever lever PDC 701 at 803 to form the mounted and planarized unit 805. [0041] The mounted PDC unit is transferred to an 811 PDC loading unit and proceeds to a unit PDC 813 chip transfer units. The units are then transferred to the units identified as 815, 817 and 819. 815 is the metal processing chamber that can include CVD, ion bombardment and evaporation. The 819 thin film deposition chamber may include LPCVD, CVD, and plasma enhanced CVD. The 817 DLC deposition chamber may include CVD and ALD. Next, the fabrication of the arrangement in figure 3 is discussed.
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    [0042] With reference now to figure 9, the base 905 of tungsten carbide is shown with sensors 903 and a PDC table. One manufacturing method comprises depositing detection layer 903 directly on top of base 905 and then forming the tungsten carbide on the diamond table table on top of the tungsten carbide base. Temperatures from 1500 ° C to 1700 ° C can be used, and pressures of about 106 pounds per square inch can be used.
    [0043] Such a set can be manufactured by building a detection layer 903 on the substrate 905 and executing the traces 904 as shown in figure 10 (a). The diamond table 901 is then deposited on the substrate. Alternatively, the diamond table 901 can be preformed, based on substrate 905, and scraped.
    [0044] The manufacture of the set shown in figure 5f is discussed below with reference to figures 11 (a) - (b). Nanotubes 1103 are inserted into substrate 905. The diamond table 901 is then deposited on substrate 905.
    [0045] The integration of temperature sensors in the sets of figures 10-11 is relatively straightforward. The possible materials to be used are high temperature thermocouple materials. The connection can be provided through the PDC side or through the PDC bottom. [0046] Pressure sensors made of quartz crystals can be embedded in the substrate. Piezoelectric materials can be used. Resistivity and capacitive measurements can be performed through the diamond table by placing electrodes on the tungsten carbide substrate. Magnetic sensors can be integrated for magnetic failure scans. Those skilled in the art and having the benefit of the present invention must recognize that the magnetic material must have to be remagnetized after integration into the sensor assembly. Chemical sensors can also be used
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    13/14 in the configuration of figure 11. Specifically, a small source of radioactive materials is used in or instead of one of the nanotubes and a gamma-ray sensor or a neutron sensor can be used in the position of another of the nanotubes.
    [0047] Those skilled in the art and who have the benefit of the present invention must recognize that the piezoelectric transducer can also be used to generate acoustic vibrations. Such ultrasonic transducers can be used to keep the PDC element face clean and increase drilling efficiency. Such a transducer can be indicated as a vibrator. In addition, the ability to generate elastic waves in formation can provide a lot of useful information. This is illustrated schematically in figure 12 showing acoustic transducers in two different PDC 34 elements. One of them, for example, 1201 can be used to generate a shear wave in the formation. The shear wave that propagates through the formation is detected by the transducer 1203 at a known distance from the original transducer 1201. By measuring the travel time for the shear wave to propagate through the formation, the shear speed of the formation can be estimated. This is a good diagnosis of the rock type. Measuring the deterioration of the shear wave over a plurality of distances provides an additional indication of the type of rock. In an embodiment of the invention, measurements of the speed of the compression wave are also made. The relationship between the speed of the compression wave and the speed of the shear wave (VP / Vs ratio) helps to distinguish between carbonate rocks and siliciclastic rocks. The presence of gas can also be detected when using VP / Vs ratio measurements. In an alternative embodiment, the condition of the cutting element can be determined from the speed of propagation of surface waves in the cutting element. This is an example of determining the opePetition condition 870200027979, of 03/02/2020, p. 17/32
    14/14 rational drill bit.
    [0048] Shear waves can be generated when using an electromagnetic acoustic transducer (EMAT). US Patent 7697375 to Reiderman et al., Which having the same content as that of the present invention and whose content is incorporated herein by reference, presents a combined EMAT adapted to generate SH and Lamb waves. Teachings such as those by Reiderman can be used in the present invention.
    [0049] The acquisition and processing of measurements made by the transducer can be controlled at least in part by the hole-below electronics (not shown). In the control and processing of data, the use of a computer program in an environment that can be read by an appropriate machine is implicit, allowing processors to perform control and processing. Machine-readable media can include ROMs, EPROMs, EEPROMs, flash memories and optical discs. The term processor lends itself to include devices such as a programmable field gate arrangement (FPGA).
    权利要求:
    Claims (28)
    [1]
    1. Rotary drill bit (10) configured to be driven into a well hole and drill a formation of the earth, the rotary drill bit (10) characterized by the fact that it comprises:
    at least one compact polycrystalline diamond cutter (PDC) including:
    (i) at least one cutting element (213);
    (ii) at least one transducer (219) configured to provide a signal indicative of at least one of: (I) a drill bit operating condition, and (ii) a fluid property in the well bore, and ( iii) a property of the surrounding formation; and (iii) a protective layer (221) on one side of the at least one transducer opposite at least one cutting element (213), the protective layer (221) being configured to protect a detection layer including the transducer ( 219) against abrasive elements.
    [2]
    2. Rotary drill bit (10) according to claim 1, characterized by the fact that at least one transducer (219) further comprises an array of transducers arranged on a platform.
    [3]
    3. Rotary drill bit (10) according to claim 1, characterized by the fact that at least one transducer (219) is selected from the group consisting of: (i) a voltage sensor, (ii) a accelerometer, (iii) an inclinometer, (iv) a magnetometer, (v) a temperature sensor, (vi) a carbon nanotube sensor, (vii) an electropotential sensor, (viii) a carbon analysis sensor / oxygen, (ix) an acoustic sensor, (x) a chemical field effect sensor, (xi) an ion sensitive sensor, (xii) an angular ratio sensor, (xiii) a nuclear sensor, (xiv) an pressure sensor
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    2/7 are, (xv) a vibrator and (xvi) an electromechanical acoustic transducer.
    [4]
    Rotary drill bit (10) according to claim 1, characterized in that the at least one cutter (34) PDC further comprises a passivation layer disposed between at least one cutting element (213) and the least one transducer (219).
    [5]
    5. Rotary drill bit (10), according to claim 1, characterized by the fact that it also comprises electronic circuits arranged between the passivation layer and the at least one transducer (219).
    [6]
    6. Rotary drill bit (10) according to claim 1, characterized in that the at least one cutting element (213) is provided with a channel configured to allow the flow of a fluid to the at least one transducer (219).
    [7]
    7. Rotary drill bit (10) according to claim 1, characterized by the fact that at least one transducer (219) is arranged in at least one of: (i) a cavity in the drill body (12) provided with a fluid flow channel, (ii) at least one cutting element (213), (iii) a substrate of at least one cutting element (213), and (iv) a drill body matrix ( 12).
    [8]
    8. Rotary drill bit (10), according to claim 1, characterized by the fact that it also comprises:
    an electromagnetic transceiver, EM, (603) in the drill body (12); and an antenna on at least one PDC cutter (34);
    wherein the EM transceiver is configured to interrogate the antenna and receive data that is related to the signal.
    [9]
    9. Rotary drill bit (10), according to claim 1, characterized by the fact that the at least one he
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    3/7 cutting element (213) further comprises a first cutting element having a first transducer and a second cutting element having a second transducer responsive to a signal produced by the first transducer.
    [10]
    10. Method of performing drilling operations, the method characterized by the fact that it comprises:
    driving a rotary drill bit (10) into a well and drilling an earth formation; and the use of at least one transducer (219) in a compact polycrystalline diamond cutter (PDC) coupled to a rotary drill bit (12) body (10) to provide a signal indicative of at least one of:
    (i) a drill bit operating condition, and (ii) a fluid property in the well, and (iii) a formation property;
    further comprising the use of a drill bit having a protective layer (221) on one side of at least one transducer opposite at least one cutting element, and the use of the protective layer (221) to protect a detection layer including at least one transducer against external abrasion.
    [11]
    11. Method, according to claim 10, characterized by the fact that it also comprises the use, for at least one transducer (219), of a transducer (219) selected from the group consisting of: (i) a sensor of voltage, (ii) an accelerometer, (iii) an inclinometer, (iv) a magnetometer, (v) a temperature sensor, (vi) a carbon nanotube sensor, (vii) an electropotential sensor, (viii) a sensor for carbon / oxygen analysis, (ix) an acoustic sensor, (x) a chemical field effect sensor, (xi) an ion sensitive sensor, (xii) an angular ratio sensor, (xiii) a sensor nuclear, and (xiv) a pressure sensor.
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    4/7
    [12]
    12. Method according to claim 10, characterized in that it further comprises the use, for at least one PDC cutter (34), a PDC cutter (34) including a passivation layer disposed between at least one element of section (213) and at least one transducer (219).
    [13]
    13. Method, according to claim 12, characterized by the fact that it also comprises the conduction of the signal to the electronic circuits arranged between the protective layer (221) and at least one transducer (219).
    [14]
    14. Method according to claim 10, characterized in that it further comprises the provision of a channel for conducting the well-bore fluid to at least one transducer (219).
    [15]
    15. Method, according to claim 10, characterized by the fact that it also comprises the positioning of at least one transducer (219) in a position selected from: (i) a cavity in the drill body (12) provided with a channel fluid flow, (ii) at least one cutting element (213), (iii) a substrate of at least one cutting element, (iv) a drill body matrix (12).
    [16]
    16. Method, according to claim 10, characterized by the fact that it further comprises:
    the provision of an electromagnetic transceiver (EM) in the drill body (12);
    providing an antenna on at least one PDC cutter (34); and the use of the EM transceiver to interrogate the antenna and receive data that is related to the signal.
    [17]
    17. Method, according to claim 10, characterized by the fact that it also comprises the generation of a signal when using a transducer in a first cutting element of the drill bit.
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    5/7 rotating motion (10) and receiving a signal indicative of a land formation property when using a transducer on a second cutting element of the rotary drilling bit (10).
    [18]
    18. Method of forming a rotary drill bit (10), the method characterized by the fact that it comprises:
    producing at least one compact polycrystalline diamond cutter (PDC) including at least one cutting element (213);
    coupling a detection layer including at least one transducer (219) to the cutting element (213); and coupling at least one PDC cutter (34) to a drill body (12); and depositing the protective layer (221) to protect the abrasion detection layer during the drilling operation.
    [19]
    19. Method according to claim 18, characterized in that coupling a detection layer further comprises the deposition of a detection layer.
    [20]
    20. Method according to claim 18, characterized in that the at least one transducer (219) is configured to provide a signal indicative of at least one of: (i) a drill bit operating condition, ( ii) a property of a fluid in the well bore, and (iii) a property of the formation.
    [21]
    21. Method according to claim 18, characterized in that the production of at least one compact polycrystalline diamond cutter (PDC) further comprises:
    mounting a plurality of cutting elements on a lever insert;
    adding a material from the load to the openings between the plurality of cutting elements;
    deposition of a passivation layer on top of the
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    6/7 loading material and the plurality of cutting elements;
    the deposition of electronic circuits on top of the passivation layer;
    the positioning of a transducer (219) above the electronic circuits and the coupling of a transducer output to the electronic circuits;
    forming a protective layer (221) above the transducer (219);
    removing the lever insert; and removing the loading material.
    [22]
    22. Method, according to claim 21, characterized by the fact that the deposition of the passivation layer further comprises the use of Si3N4.
    [23]
    23. Method according to claim 21, characterized by the fact that the deposition of the passivation layer also comprises at least one of: (i) chemical vapor deposition (CVD), (ii) low pressure chemical vapor deposition (LPCVD), (iii) atomic layer deposition (ALD), and (iv) use of a sol-gel.
    [24]
    24. Method, according to claim 21, characterized by the fact that the deposition of electronic circuits on top of the passivation layer also comprises at least one of: (i) coating with ion bombardment, (ii) evaporation, (ii) deposition of the atomic layer (ALD), (iii) electroplating, (iv) caustication of plasma, and (iv) caustication with moisture.
    [25]
    25. Method, according to claim 21, characterized by the fact that the positioning of a transducer (219) above the electronic circuits also comprises at least one of: (i) chemical vapor deposition (CVD), (ii) CVD low pressure, (iii) plasma etching, (iv) atomic layer deposition, and (v) radio frequency (RF) ion bombardment.
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    7/7
    [26]
    26. Method, according to claim 21, characterized by the fact that the formation of the protective layer (221) above the transducer (219) further comprises the use of at least one of: (i) deposition of chemical vapor, ( ii) sintering, (iii) ion bombardment, (iv) evaporation, and (v) screen printing and curing.
    [27]
    27. Method according to claim 21, characterized by the fact that the formation of the protective layer (221) above the transducer (219) further comprises hard materials such as diamond-type carbon (DLC).
    [28]
    28. Method according to claim 21, characterized by the fact that it further comprises the use of a forming material.
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    同族专利:
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    CA2797673A1|2011-11-10|
    CA2797673C|2016-02-02|
    BR112012027697A2|2016-08-16|
    WO2011139697A3|2011-12-29|
    MX2012012471A|2013-04-03|
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    RU2012150740A|2014-06-10|
    CA2848298C|2017-11-28|
    US20140224539A1|2014-08-14|
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    法律状态:
    2018-12-26| B06F| Objections, documents and/or translations needed after an examination request according art. 34 industrial property law|
    2019-06-25| B06T| Formal requirements before examination|
    2019-12-03| B06A| Notification to applicant to reply to the report for non-patentability or inadequacy of the application according art. 36 industrial patent law|
    2020-03-24| B09A| Decision: intention to grant|
    2020-05-26| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 26/04/2011, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US32878210P| true| 2010-04-28|2010-04-28|
    US61/328,782|2010-04-28|
    US40810610P| true| 2010-10-29|2010-10-29|
    US40811910P| true| 2010-10-29|2010-10-29|
    US40814410P| true| 2010-10-29|2010-10-29|
    US61/408,106|2010-10-29|
    US61/408,144|2010-10-29|
    US61/408,119|2010-10-29|
    US13/093,326|2011-04-25|
    US13/093,326|US8695729B2|2010-04-28|2011-04-25|PDC sensing element fabrication process and tool|
    PCT/US2011/033959|WO2011139697A2|2010-04-28|2011-04-26|Pdc sensing element fabrication process and tool|
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