• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    Drill bit, method for manufacturing a drill bit and method for directing a drill bit The present invention relates to a drill bit which is provided that in one embodiment may include a force application device on a drill bit body. drilling, wherein the force application device includes a coupled force application member hinged to the drill bit and configured to extend from the drill bit body to apply a force to a wellbore wall when the drill bit is used to drill a wellbore, and an actuator configured to actuate the force application member to apply force to the wellbore wall while drilling the wellbore.
    公开号:BR112012002520B1
    申请号:R112012002520-1
    申请日:2010-08-04
    公开日:2019-11-05
    发明作者:V Kulkarni Ajay；K Luce David；f bradford John
    申请人:Baker Hughes Inc；
    IPC主号:
    专利说明:

    CROSS REFERENCE [001] This application claims the benefit of the filing date of United States Patent Application Serial Number 12 / 535,326 filed on August 4, 2009, for DRILLING DRILL WITH ADJUSTABLE DRIVING DEVICE. FUNDAMENTAL INFORMATION
    1. FIELD OF DESCRIPTION [002] Oil wells (also referred to as well holes or wells) are drilled with a drill string that includes a tubular member that has a drill set (also referred to as a downhole set) or BHA) which includes a drill bit attached to its lower end. The drill bit is rotated to disintegrate the rock formation to drill the well hole. The BHA includes devices and sensors to provide information on a variety of parameters relating to drilling operations (drilling parameters), BHA behavior (BHA parameters) and the formation surrounding the well hole being drilled (drilling parameters ). A large number of well holes are drilled along a contoured path. For example, a single well hole can include one or more vertical sections, offset sections and horizontal sections. Some BHAs include adjustable pivot joints to form a deflected well hole. Such targeting devices are typically arranged over the BHA, that is, away from the drill bit, as described in US 2004/0089477. However, it is desirable to have a targeting device close to or over the drill bit for
    Petition 870190001552, of 01/07/2019, p. 3/32
    2/17 to make the drill bit change the drilling directions more quickly than can be obtained with the targeting devices that are inside the BHA, to drill more regular bypassed well holes, to improve the penetration rate of the drill bit and / or extend the life of the drill bit. US patent application number US 2009/0065262 discloses a drill bit that can be driven by retracting hinged fingers into the drill bit body, however, there is still scope for alternative drill targeting devices.
    [003] The description here provides drill bits with guiding devices, methods of making such bits and an apparatus for using such drill bits to drill well holes.
    SUMMARY [004] In one aspect, a drill bit is provided that in one embodiment may include a force application device on a drill bit stem, wherein the force application device includes a configured force application member for extending the stem to apply force on a well hole wall when the drill bit is used to drill a well hole, and an actuator configured to actuate the force member to apply force on a hole wall of well while drilling the well hole.
    [005] In another aspect, a method for making a drill bit is provided, the method of which may include: providing at least one force application device on a drill bit stem, wherein the force application device includes a member applying force attached to the rod and configured to extend the rod to apply force to a well hole wall when the drill bit is used to drill a well hole; and provide
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    3/17 an actuator configured to actuate the force member to apply force on a well hole wall during well hole drilling.
    [006] Examples of certain characteristics of the apparatus and method described herein are summarized quite generally so that the detailed description which follows can be better understood. These are, of course, additional features of the apparatus and of the method hereinafter described which will form the subject of the claims attached thereto.
    BRIEF DESCRIPTION OF THE DRAWINGS [007] The description here will be better understood with reference to the accompanying figures in which equal numbers have generally been assigned to like elements and in which:
    [008] figure 1 is an isometric view of a drill bit with a targeting device over a stem section of a drill bit, according to one embodiment of the description;
    [009] figure 2 is a side view of components of an exemplary targeting device located on a drill bit, according to one embodiment of the description;
    [0010] figure 3 is a sectional view of a portion of an exemplary drill bit with two force members, which includes a profile of a single block in an extended position according to one embodiment of the description;
    [0011] figure 4 is a top view of an exemplary drill bit that includes a force applying member, according to an embodiment of the description;
    [0012] figure 5 is a side sectional view of an exemplary drill bit with two force members located on a floating sleeve, where the force members
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    4/17 articulate around a geometric axis perpendicular to a longitudinal drill geometric axis, according to a modality of the description;
    [0013] figure 6 is a side sectional view of an exemplary drill bit with two force members located on a floating sleeve, in which the force members articulate around a geometric axis parallel to a geometric axis longitudinal drill, according to a description mode;
    [0014] figure 7 is a top sectional view of the exemplary drill bit shown in figure 6.
    [0015] figure 8 is a side sectional view of an exemplary drill bit with two force members located on a floating sleeve, where the force members articulate around a geometric axis perpendicular to a geometric axis longitudinal drill, according to a description mode; and [0016] figure 9 is a schematic diagram of an exemplary drilling system that includes a drill bit that has a force application device made according to one embodiment of the description.
    DETAILED DESCRIPTION OF THE MODALITIES [0017] Figure 1 shows an isometric view of an exemplary drill bit 100 made according to one embodiment of the description. The drill bit 100 shown is a PDC bit that has a drill body 112 that includes a cone 112a, a stem 112b, and a pin 112c. The cone 112a is shown including a number of blade profiles 114a, 114b, ..., 114n (also referred to as the profiles). Each blade profile is shown to include a face or crown section, such as a section 118a and a gauge section, such as
    Petition 870190001552, of 01/07/2019, p. 6/32
    5/17 section 118b. A portion of the rod 112b is substantially parallel to the longitudinal geometric axis 122 of the drill bit 100. A number of spaced cutters are placed along each blade profile. For example, the blade profile 114n is shown to contain cutters 116a-116m. All blade profiles 114a-114n are shown ending near the lower center 115 of drill bit 100. Each cutter has a cutting face or cutting element, such as element 116a 'of cutter 116a, which engages the rock formation when the drill bit 100 is rotated while drilling the borehole. Each 116a-116m cutter has a rear scraping angle and a lateral scraping angle that defines the cut depth of the cutter within the rock formation. Each cutter also has a maximum cutting depth within the formation. In one aspect, a number of extensible force devices are placed around the stem 112b of the drill bit 100. Figure 1 shows the exemplary force devices 140a-140p placed around the stem 112b. Each force application device may further include a force application member and an actuation device or source for supplying energy to its associated force application member. For example, the force application device 140a may include a force application member 140af and a power source 140ap. In one aspect, the force applying member may be referred to as a block, block member, extensor or extensible member. Furthermore, the energy source can also be referred to as an actuator or an actuation device. The actuator can be any suitable device, which includes, but is not limited to, a hydraulic device, a screw device, a linear electrical device, and an electromechanical device, Shape Memory Alloy (SMA) or any other suitable device each member force application can be
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    6/17 independently acted to extend radially from the drill bit to apply a selected amount of force on the well hole wall during well hole drilling. Various modalities of the force application devices and their operations are described in more detail with reference to figures 2-9. Figure 1 shows a PDC drill bit as an example only. The force application devices described herein can be used with any other drill bit, which includes, but is not limited to, roller cone drill bits and diamond cutter drill bits.
    [0018] Figure 2 illustrates a side view of an exemplary force application member or block 200 and other components which may be included in the drill bit. In one aspect, a hinge member 202, shown as a pin, can work in combination with a wedge member 204, to move a block 200 away from the drill bit body. In addition, the movement of block 200 can be coordinated with one or more other blocks on the drill bit to direct the drill bit within a formation. The wedge member 204 can move in a linear direction 206, along a longitudinal geometric axis 208, to actuate the movement of the block 200 in a radial direction 210. The wedge member 204 can be actuated by any suitable mechanism to provide a force to move the block 200, pressing it in an outward direction 210 against a forming wall. Examples of mechanisms for moving the wedge member 204 may include a fluid based actuator (e.g., hydraulic), a screw based actuator, an electric actuator, shape memory alloys or any other suitable mechanism. In one aspect, a member composed in part of a shape memory alloy can be coupled to and act on the block movement. For example, a member
    Petition 870190001552, of 01/07/2019, p. 8/32
    7/17 composed of a Shape Memory Alloy, such as nickel titanium, copper-zinc-aluminum-nickel, copper-aluminum-nickel, or iron-based alloys, can be a component of the member, in which the shape of the metal changes when induced by a thermal change or by a voltage applied to the limb. As discussed below, block 200 may be positioned on a drill bit to provide relatively accurate control of drill bit direction when drilling a well hole.
    [0019] Still referring to figure 2, in one embodiment, block 200 may also include rollers 212 positioned on axial members 214, such as pins. Rollers 212 can reduce friction as block 200 contacts a forming wall. As such, rollers 212 can facilitate the movement of the drill bit and drill blocks 200 through a well hole as the drill bit moves through the formation below. Rollers 214 can also reduce wear on an outer surface 216 of block 200 as the bit moves through the formation below. As wedge member 204 moves axially in direction 206, a block surface 218 and a wedge surface 220 interface or cooperate to drive block movement 210. Surfaces 218 and 220 may include a reduced friction layer made of a material suitable, which includes, but is not limited to, a metallic or alloy coating, non-metallic materials, a combination of such materials, polymers or other materials suitable to allow sliding movement and shape transfer between the wedge member 204 and the block 200. The wedge member 204 and block 200 can be composed of any suitable wear-resistant material of sufficient strength, such as stainless acid, metal alloys, polymers or any combination thereof. Furthermore, the wedge member 204 can be of any suitable shape, such as a pie shape or a triangular shape
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    8/17 with an angular intersection of two sides, in which the shape allows a transfer of force from one direction to another. For example, wedge member 204 may have an angle of approximately 25 degrees between adjacent sides and allows a force applied generally perpendicular to a third side to be smoothly transferred to wedge surface 220 to trigger movement 210. In addition, rollers 212 can be of any suitable shape, such as substantially round wheels or a rounded polygon. In one aspect, roller wheels 212 may be made of any suitable material, which includes, but is not limited to, metallic elements, non-metallic elements and a combination thereof. Rollers 212 reduce rotational and tangential friction against a borehole wall and assist a block actuator 200 in transferring the driving force in an outward direction against the wall.
    [0020] Figure 3 shows a side sectional view of a profile of a drill bit 300, made according to one embodiment of the description. A profile of half the drill bit 300 is shown from a longitudinal axis 312 outwards. Drill bit 300 is shown including a plurality of blocks 302, which can be placed in one of several locations on drill bit 300 to direct the drill bit while drilling a well hole. In one aspect, three or more blocks 302 can be evenly spaced around an exterior of the drill bit 300, such as over the drill bit stem 300. For example, each of the blocks 302 can be 120 degrees from the others two blocks when three blocks are used or 90 degrees away from their adjacent block when four blocks are used, etc. In one aspect, the blocks 302 can be attached to the body of the drill bit 300 via a pivot mechanism 304, such as pivot pins, thereby allowing
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    9/17 gives the movement of blocks 302 to drive the drill 300. Any suitable hinge coupling mechanism can be used to allow movement of blocks 302, which includes, but is not limited to, bearing assemblies, pins and pin receivers stationary, connected hinged and hidden tabs, or any combination thereof. As will be discussed below, blocks 302 can also be directly attached to a linear actuator 306, where the linear actuator can linearly press the entire block 302 outwardly to drive the drill. As shown in figure 3, an actuator 306 can be coupled to each block and cause an angular movement of the block 302 to an extended position 308. Consequently, the actuator 306 is coupled to the block 302, through an articulated coupling, to translate the movement linear (actuation) for an angular or radial movement 310 of block 302. In another aspect, pivot pin 304 can be located closer to a crown portion 311 of the drill, thereby allowing block 302 to extend without grabbing over a forming wall as drill 300 and block 302 move in a direction 313. In one aspect, pivot pin 304 may be located within the portion of block 302 located furthest from crown 311. As such, the actuator may be located closer to the crown 311 to move the block 302. In aspects, in the embodiment of figure 3, the geometric axis of block 304 'in its recessed position is along the longitudinal geometric axis end of the drill bit.
    [0021] Still referring to figure 3, the articulation pin mechanism 304 can be referred to as articulated with a geometry axis at an angle to the longitudinal geometry axis 312. As discussed below, the orientation of the articulation mechanism may vary, for this by changing the block configuration and the direction of block movement. Furthermore, the block actuation mechanism
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    10/17
    300 may vary, depending on application needs and other design and operating factors.
    [0022] Figure 4 is a top sectional view of a portion of an exemplary drill 400, drill 400 includes a block 402, which can be configured to direct and control a direction of drill 400 during a drilling process. Block 402 can pivot around a hinge 404 coupled to a drill body 412 and block 402. An actuation mechanism 406 can be used to move the block in a direction 408 to an extended position 410. When not extended, the block 402 can recede into the drill bit body 412, where it lies substantially in the plane with an outer surface 413 of the bit and the block. In addition, the outer surface 413 of the drill and block can include a wear resistant material to reduce wear as the drill 400 rotates against the rock to create a well hole, as previously described. As shown in Figure 4, pivot 404 pivots about a geometry axis that is parallel or substantially parallel to a longitudinal geometry axis 414. In addition, drill bit 400 rotates around longitudinal geometry axis 414 in a direction 415. The block 402 can extend or retract as drill 400 rotates. Block 402 thus directs drill 400 while drilling. Consequently, drill 400 may include sensors, processors, memory, and communication devices to allow drill 400 to extend block 402 at the appropriate time and duration to move drill 400 in a desired direction. Furthermore, by positioning the block 402 within the drill bit 400, the direction and drilling of the drill bit can be more precisely controlled. The drill bit 400 may contain a plurality of blocks 402 located on the outer portions of the bit. The drill can have blocks of the same configuration and orientation, such as those with geo axes
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    11/17 articulation metrics parallel or perpendicular to the longitudinal geometric axis or at any other suitable angle in relation to the longitudinal geometric axis of the drill bit. In one embodiment, a combination of block configurations can be used to drive a single drill set.
    [0023] Referring to figure 5, a side sectional view of an exemplary drill bit 500 is illustrated. The set includes one or more blocks 502 configured to direct the drill 500 during a drilling operation. Blocks 502 can be coupled to the drill bit via pivot pins 504. Blocks 502 can extend in an angled direction 506 to control the direction of the drill 500. A controller, memory, sensors, and a communication system can be coupled on drill 500, blocks 502, and other components to correlate block movements to the desired direction of drill bit 500. Blocks 502 can be substantially in the plane with a floating sleeve 508 when retracted. Floating sleeve 508 can be a hollow cylindrical member placed around a drill bit body 510. Floating sleeve 508 can be coupled to body 510 through bearings 512. Bearings 512 allow body 510 to rotate around the shaft longitudinal geometry 514 independent of floating sleeve 508. Consequently, drill bit body 510 can rotate at a high rate while floating sleeve 508 remains substantially stationary with respect to a drill column. By keeping the floating sleeve 508 in a substantially stationary position, processing and controlling drill direction by blocks 502 can be simplified. In addition, by positioning the blocks 502 on the floating sleeve 508 an operator can have more precise control over the direction of the drilling operation. In one aspect, the floating sleeve 508 can be substantially stationary
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    12/17 while the drill body 510 rotates. In another aspect, the floating sleeve 508 can rotate at a slower rate than the body 510. Bearings 512 can be any mechanism suitable for reducing friction between rotating components, including rollers, ball bearings, or any other suitable device. . In one aspect, the configuration of blocks 502 and pins 504 can be described as perpendicular or substantially perpendicular to the longitudinal geometric axis 514. In the embodiment shown, actuator mechanisms can be located within the floating sleeve 508 to control the movement of blocks 506.
    [0024] Figure 6 is a side sectional view of an exemplary 600 drill bit. The set includes a crown section 601 and a plurality of blocks 602 configured to drive the drill 600. The blocks 602 can be coupled hinged to the drill via hinge pins 604. The blocks 602 can extend in one direction 600 to change the direction the drill while drilling. Blocks 602 can be distributed across the entire drill 600 to provide optimal steering control for an operator. A controller, memory, sensors, and a communication system can be coupled to drill 600, blocks 602, and other components to correlate block movements to the desired direction of drill bit 600. When retracted, blocks 602 can be substantially in the plane with a floating sleeve 608. Floating sleeve 608 can be a hollow cylindrical member placed around a drill bit body 610. Floating sleeve 608 can be coupled to body 610 through bearings 612. Bearings 612 allow that the body 610 rotates about the longitudinal geometric axis 614 independent of the floating sleeve 608. In one aspect, the configuration of blocks 602 and pins 604 can be described as parallel or substantially parallel to the longitudinal geometric axis
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    13/17 tudinal 614. The orientation of blocks 602 can be changed based on a direction of drill rotation 616 to reduce wear on blocks 602. As shown, the illustration still includes a profile 618 of the extended blocks.
    [0025] Figure 7 is a top sectional view of the drill bit 600 shown in Figure 6. Floating sleeve 608 is shown as an annular member placed around the body 610 of the drill bit. Bearings 612 allow for rotational drill movement 616 while providing a reduced friction coupling between floating sleeve 608 and body 610. In one aspect, each of the three blocks 602 is located approximately 120 degrees from the other two blocks. The diagram also shows the extended profile 618 of a block, where the block articulates on a geometric axis parallel to the longitudinal geometric axis 614.
    [0026] Figure 8 is a side sectional view of an exemplary 600 drill bit. The set includes a crown section 801 and a plurality of blocks 802 configured to direct the drill bit 800. The blocks 802 can extend in a direction 808 to change the direction of the drill during drilling. In one aspect, the force application device may include a floating member 804 such as a floating sleeve, mounted on an external side of the drill bit body 810. The floating sleeve 804 can be a hollow cylindrical member placed around a drill bit body 810. Floating sleeve 804 can be coupled to drill bit body 810 via bearings 812. Bearings 812 allow drill bit body 810 to rotate around the longitudinal geometry axis 814 independent of the floating member 804. Floating member 804 may be placed within a recess around a suitable location on the drill bit body 810, such as the shank. In one aspect, the floating member 804 may be
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    14/17 configured to rotate more slowly than the drill bit 800 and in another aspect the floating member 804 can be stationary or substantially stationary with respect to the rotation of the drill bit body 810. In one aspect, the blocks 802 can move radially out of the floating sleeve 804 when actuated by an actuator (not shown). In addition, blocks 802 may be distributed in any number of suitable locations around drill bit 800 to provide optimum targeting of the drill bit within a borehole. As shown, the illustration includes a profile 806 of the extended blocks. A controller, memory, sensors, and a communication system can be coupled to the drill bit 800, blocks 802, and other components to correlate the block movements to the desired direction of the drill bit 800. When pushed back, the blocks 802 may be substantially in the plane with the floating sleeve 804.
    [0027] Figure 9 is a schematic diagram of an exemplary drilling system 900 that can use drill bits made according to one or more of the description. Figure 9 shows a well hole 910 that has an upper section 911 with a liner 912 installed therein and a lower section 914 being drilled with a drill column 918. Drill column 918 is shown including a tubular member 916 with a BHA 930 (also referred to as the drilling set or downhole assembly (BHA)) attached to its lower end. Tubular member 916 can be a series of joined drill pipe sections or it can be a spiral pipe. A drill bit 950 is shown attached to the lower end of the BHA 930 to disintegrate the rock formation to drill well hole 910 of a diameter selected in formation 919. The drill bit includes one or more force application devices 960 made from wake up
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    15/17 with one or more modalities of this description.
    [0028] The drilling column 918 is shown driven into the well hole 910 of a platform 980 on surface 967. The exemplary platform 980 is a land platform for ease of explanation. The apparatus and methods described here can also be used with offshore platforms. A rotary table 969 or an upper drive (not shown) coupled to drill column 918 can be used to rotate drill column 918 to rotate BHA 930 and drill bit 950 to drill well hole 910. An engine Drill 955 (also referred to as the mud motor) can be provided on BHA 930 to turn drill bit 950. Drill motor 955 can be used alone to turn drill bit or superimpose drill column 918 rotation. A 990 control unit (or controller), which can be a computer-based unit, can be placed on the surface to receive and process the data transmitted by the sensors on the drill bit 950 and BHA 930 and to control the selected operations of the various devices and sensors in drilling set 930. The surface controller 990, in one embodiment, can include a 992 processor, a storage device (or a computer-readable medium 994 for storing data and computer programs 996. The data storage device 994 can be any suitable device, which includes, but is not limited to, a read-only memory (ROM) a random access memory (RAM), an instant memory, a magnetic tape, a hard disk and an optical disk. During drilling, a drilling fluid 979 from its source is pumped under pressure into the tubular member 916. The drilling fluid discharges to the bottom of the drill bit 950 and returns to the surface through the annular space (also referred to as the
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    16/17 ring) between the drilling column 918 and the inner wall 942 of well hole 910.
    [0029] BHA 930 may further include one or more downhole sensors, which include, but are not limited to, sensors commonly known as measurement sensors during drilling (MWD) or profiling sensors during drilling (LWD ), and sensors that provide information on the behavior of the BHA 930, such as drill bit rotation, vibration, swirling, and grip - slip (collectively referred to in figure 9 by number 975) and at least one control unit (or controller) 970 to control the operation of the force application members 962 and to at least partially process the data received from the sensors 975 and the drill bit 950. The controller 970 may include, among other things, a processor 972, such as such as a microprocessor, a 974 data storage device, such as a solid state memory, and a program 976 for use by the 972 processor to control the operation to the force application members 960, processing the data downhole, and also communicate with the controller 970 via a telemetry unit 988 two-way.
    [0030] The 950 drill bit can include one or more 955 sensors, which include, but are not limited to, accelerometers, magnetometers, torque sensors, weight sensors, resistivity sensors, and acoustic sensors to provide information on various parameters of interest. The drill bit 950 may also include a processor and a communication connection to provide two-way communication between the drill bit 950 and the BHA 930. While drilling the well hole 910, one or more force application devices 960 are activated to apply a force to the borehole wall. The use of three application devices
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    17/17 force application typically provides force vectors suitable for causing the 950 drill bit to move in any desired direction. The 950 drill bit may also include more than three or less than three force application devices. Each force applying member can be independently operated by its associated actuator, which can be located inside the drill bit or in the BHA. The processor in the BHA and / or the drill bit can cause each force application device to apply a selected force to the borehole wall in accordance with the instruction programs and instructions available to the processor inside the drill bit. drilling, BHA and / or the surface to drill the well hole along a desired path or trajectory.
    [0031] Although the description above is directed to certain modalities, several changes and modifications of such modalities will be apparent to those versed in the technique. The scope of the present invention is intended to include all changes and modifications that are within the scope of the claims.
    权利要求:
    Claims (19)
    [1]
    1. Drill bit (100; 200; 300; 400; 950), characterized by the fact that it comprises:
    a drill body (112; 412) comprising a cone (112a) and a shank (112b) wherein the cone (112a) includes a plurality of blade profiles (114a-114n) including a crown section (118a; 311) and a gauge section (118b);
    a plurality of force application devices (140a-140p; 960) on the body (112; 412), wherein the force application devices (140a-140p; 960) each include a force application member ( 140af; 962) pivotally coupled to the body (112; 412) configured to extend from the body (112; 412) radially outwards beyond the crown section (118a; 311), in order to apply a force to a well wall to direct the drill bit (100; 200; 300; 400; 950) towards a desired path when the drill bit (100; 200; 300; 400; 950) is used to drill a well; and an actuator (306) configured to actuate the force members (140af; 962) to apply the force to the well hole wall during well drilling.
    [2]
    Drill bit according to claim 1, characterized by the fact that the force application members (140af; 962) comprise an outer surface of a wear-resistant material.
    [3]
    Drill bit according to claim 1, characterized in that the force application devices (140a-140p; 960) are positioned on a rod (112b) of the body (112; 412) and are substantially flush with a drill bit surface (100; 200; 300; 400; 950) when not extended.
    [4]
    4. Drill bit according to claim 1, characterized by the fact that the devices for applying force
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    2/5 (140a-140p; 960) comprise a pivoting coupling (202; 304; 404) between the force application members (140af; 962) and the body (112; 412), in which an axis of the pivoting coupling ( 202; 304; 404) is one of: substantially parallel to a longitudinal drill bit axis (122; 208; 312; 414); substantially perpendicular to a longitudinal drill bit axis (122; 208; 312; 414); and at an angle selected for a longitudinal drill bit axis (122; 208; 312; 414).
    [5]
    Drill bit according to claim 1, characterized in that the actuator (306) comprises a wedge member (204).
    [6]
    6. Drill bit according to claim 1, characterized by the fact that the actuator (306) comprises one of: a hydraulic actuator; a screw-based actuator, a linear electrical device; a shape memory alloy; and an electromechanical actuator.
    [7]
    Drill bit according to claim 1, characterized in that the force member (140af; 962) comprises rollers (212) located on an external surface to reduce friction against the well hole wall.
    [8]
    Drill bit according to claim 1, characterized in that a portion of the rod is substantially parallel to a longitudinal axis (112; 208; 312; 414) of the drill bit.
    [9]
    Drill bit according to claim 8, characterized by the fact that the plurality of force application devices are in the part of the rod that is substantially parallel to the longitudinal axis (122; 208; 312; 414) of the drill bit .
    [10]
    10. Method for making a drill bit (100; 200; 300; 400; 950), characterized by the fact that it comprises:
    Petition 870190001552, of 01/07/2019, p. 21/32
    3/5 providing a drill body (112; 412) comprising a cone (112a) and a shank (112b) in which the cone (112a) includes a plurality of blade profiles (114a-114n) including a crown section ( 118a; 311) and a gauge section (118b);
    providing a plurality of force application devices (140a-140p; 960) on the body (112; 412), wherein the force application devices (140a-140p; 960) each include a force application member (140af; 962) pivotally coupled to the body (112; 412) configured to extend from the body (112; 412) radially outwards beyond the crown section (118a; 311), in order to apply a force to a well wall to direct the drill bit (100; 200; 300; 400; 950) toward a desired path when the drill bit (100; 200; 300; 400; 950) is used to drill a well; and providing an actuator (306) configured to actuate the force applying member (140af; 962) to apply force to the well bore wall during well drilling.
    [11]
    11. Method according to claim 10, characterized by the fact that providing the force application devices (140a140p; 960) comprises providing a pivoting coupling (202; 304; 404) between the force application members (140af; 962) ) and the body (112; 412), in which an axis of the pivoting coupling (202; 304; 404) is one of: substantially parallel to a longitudinal drill bit axis (122; 208; 312; 414); substantially perpendicular to a longitudinal drill bit axis (122; 208; 312; 414); and at an angle selected for a longitudinal drill bit axis (122; 208; 312; 414).
    [12]
    12. Method according to claim 10, characterized in that providing an actuator (306) comprises providing a wedge member (204).
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    4/5
    [13]
    13. Method according to claim 10, characterized by the fact that the actuator (306) comprises one of: a hydraulic actuator; a screw-based actuator, a linear electrical device; a shape memory alloy; and an electromechanical actuator.
    [14]
    14. Method for directing a drill bit (100; 200; 300; 400; 950) into a well bore, characterized by the fact that it comprises:
    drive a tool that has a drill bit (100; 200; 300; 400; 950) at one of its ends, into a well hole, the drill bit (100; 200; 300; 400; 950) including :
    a drill body (112; 412) comprising a cone (112a) and a shank (112b) wherein the cone (112a) includes a plurality of blade profiles (114a-114n) including a crown section (118a; 311) and a gauge section (118b) and a plurality of force application devices (140a-140p; 960) each having a force application member (140af; 962) pivotally coupled to the body (112; 412) and configured to extend from the body (112; 412) radially outward beyond the crown section (118a; 311), so as to apply force to a well wall to direct the drill (100; 200; 300; 400; 950) in direction to a desired route;
    determine the desired path for the drill bit (100; 200; 300; 400; 950); and actuating the force applying member (140af; 962) to extend the body (112; 412) radially outwardly beyond the crown section (118a; 311) so as to apply a force on the well bore wall to drive the drill along the desired path.
    [15]
    15. Method according to claim 14, characterized by the fact that the force application device (140a
    Petition 870190001552, of 01/07/2019, p. 23/32
    5/5
    140p; 960) comprises extending the force application members (140af; 962) pivotally along a geometry axis which is one of: substantially parallel to a longitudinal geometry axis (122; 208; 312; 414) of drill bit; substantially perpendicular to a longitudinal geometric axis (122; 208; 312; 414) of drill bit; and at a selected angle with respect to a longitudinal geometric axis (122; 208; 312; 414) of drill bit.
    [16]
    16. Method according to claim 14, characterized in that the actuation of the force application devices (140a140p; 960) comprises causing the movement of the force application members (140af; 962) through a wedge member; or through one of: a fluid-based actuator; a screw actuator; a linear fixture; a material with shape memory; and an electromechanical actuator.
    [17]
    17. Method according to claim 14, characterized in that the force applying member (140af; 962) comprises rollers (212) located on an external surface to reduce friction against the borehole wall.
    [18]
    18. Method according to claim 10 or 14, characterized in that a portion of the shank is substantially parallel to a longitudinal axis (112; 208; 312; 414) of the drill bit.
    [19]
    19. Method according to claim 18, characterized in that the plurality of force application devices are in the part of the shank that is substantially parallel to the longitudinal axis (122; 208; 312; 414) of the drill bit.
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    同族专利:
    公开号 | 公开日
    WO2011017411A2|2011-02-10|
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    US20110147089A1|2011-06-23|
    BR112012002520A2|2016-03-15|
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    法律状态:
    2018-11-06| B06T| Formal requirements before examination [chapter 6.20 patent gazette]|
    2019-01-15| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|
    2019-05-07| B06A| Notification to applicant to reply to the report for non-patentability or inadequacy of the application [chapter 6.1 patent gazette]|
    2019-09-10| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|
    2019-11-05| B16A| Patent or certificate of addition of invention granted|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 04/08/2010, OBSERVADAS AS CONDICOES LEGAIS. |
    优先权:
    申请号 | 申请日 | 专利标题
    US12/535,326|US8087479B2|2009-08-04|2009-08-04|Drill bit with an adjustable steering device|
    PCT/US2010/044374|WO2011017411A2|2009-08-04|2010-08-04|Drill bit with an adjustable steering device|
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