Rotary drag-type drill bit with drilling fluid nozzles

Abstract: A drag-type drill bit for drilling holes in subsurface formations comprises a bit body (70) having an end face (71) and a shank (72) for connection to a drill string, a number of blades (73, 74) upstanding from the end face of the bit body and extending outwardly away from the axis of rotation of the bit, a number of cutters (76) mounted on each blade, and a number of nozzles (81) in the bit body for delivering drilling fluid for cooling and cleaning the cutters. The blades include primary blades (73) which, at their outer ends, are spaced apart around a peripheral gauge portion (75) of the bit, and secondary blades (74) which are spaced circumferentially between adjacent primary blades, each secondary blade having an outer end which terminates at a location inwardly of the gauge portion (75) of the bit. One of said nozzles (81) is located adjacent each blade (73, 74). Each primary blade (73) and associated secondary blade (74) may be equivalent, in terms of their combined contribution to the cutting profile, to a single blade which extends continuously from the centre of the bit body to the gauge, but the separation of the blades facilitates the flow of drilling fluid over and between the blades. Also, the increased number of blades may enhance the stability of the drill bit and reduce vibration.

Description: The invention relates to rotary drag-type drill bits, for use in drilling or coring holes in subsurface formations, and of the kind comprising a bit body having an end face and a shank for connection to a drill string, a plurality of blades upstanding from the end face of the bit body and extending outwardly away from the central axis of rotation of the bit, a plurality of cutters mounted on each blade, and a plurality of nozzles in the bit body for delivering fluid to the end face thereof for cooling and cleaning the cutters. Each cutter may include a preform cutting element of the kind comprising a front facing table of superhard material bonded to a less hard substrate. The cutting element may be mounted on a carrier, also of a material which is less hard than the superhard material, which is mounted on the body of the drill bit, for example, is secured within a socket on the bit body. Alternatively, the cutting element may be mounted directly on the bit body, for example the substrate may be of sufficient axial length that it may itself be secured within a socket on the bit body. In drag-type drill bits of this kind the bit body may be machined from metal, usually steel, and sockets to receive the carriers or the cutting elements themselves are machined in the bit body. Alternatively, the bit body may be moulded from tungsten carbide matrix material using a powder metallurgy process. In prior art drag-type drill bits where the cutters are mounted on blades extending outwardly away from the axis of rotation of the bit, it is usual for each blade, at its outer end, to join a respective kicker which, in use, engages the surrounding wall of the borehole being drilled. The kickers are spaced apart around a peripheral gauge portion of the bit so as to define between the kickers junk slots through which drilling fluid flows from the end face of the bit to the annulus between the drill string and the walls of the borehole. Since it is desirable for the cutters on the blades to define a cutting profile which extends over substantially the whole of the bottom surface of the borehole, it is necessary for at least some of the blades to extend substantially all the way from the central of the end face of the bit outwardly to the gauge of the bit. However, such arrangement inhibits the flow of drilling fluid across the blades in the circumferential direction. Also, if the total number of blades is reduced to improve cutting effectiveness, the stability of the bit may be compromised. The present invention therefore sets out to provide a novel arrangement of blades on a drag-type drill bit whereby these disadvantages of prior art constructions may be reduced or overcome. US 1914734 describes an arrangement having sharpened cutting blades, primary blades of which extend to a gauge, secondary blades of which terminate at positions short of gauge. US 5361859, GB 2294712 and US 4714120 similarly describe arrangements in which secondary blades terminate at locations short or long of gauge. According to the invention there is provided a drag-type drill bit for drilling holes in subsurface formations comprising a bit body having an end face and a shank for connection to a drill string, a plurality of blades upstanding from the end face of the bit body and extending outwardly away from the central axis of rotation of the bit, and a plurality of nozzles in the bit body for delivering fluid to the end face thereof, said blades include a plurality of primary blades the outer ends of which are spaced apart around a peripheral gauge portion of the bit, and a plurality of secondary blades spaced circumferentially between adjacent primary blades, each secondary blade having an outer end which terminates at a location inwardly of the gauge portion of the bit, and characterised in that the secondary blades each terminate at the outer periphery ofthe end face of the bit body as viewed axially of the drill bit, a plurality of cutters being mounted on each blade, one of the aforesaid nozzles being located adjacent each of said primary and secondary blades so as to deliver fluid to cool and clean the cutters thereon. The outer ends of the primary blades may join respective kickers which, in use, engage the surrounding wall of the borehole being drilled. There may be defined between the kickers junk slots through which drilling fluid flows from the end face of the bit. Thus each primary blade and an associated secondary blade, although spaced circumferentially apart, may be equivalent, in terms of their combined contribution to the cutting profile, to a single blade which extends continuously from the centre of the bit body to the gauge, but the separation of the blades facilitates the flow of drilling fluid over and between the blades. Also, cuttings washed from a secondary blade by the flow of drilling fluid are swept to a different region of the associated junk slot than the cuttings from the associated primary blade, thus facilitating a flow of cuttings up through the junk slot. Also, the increased number of blades may enhance the stability of the drill bit and reduce vibration. The number of secondary blades may equal the number of primary blades, secondary blades alternating with primary blades around the axis of rotation of the bit body. In preferred arrangements there are provided two or three primary blades and the same number of secondary blades. Each primary blade may have an inner end which is spaced outwardly from the axis of rotation of the bit, and the inner end of each primary blade is preferably closer to the axis of rotation of the bit than the outer end of an associated secondary blade. The inner end of each primary blade is also preferably further from the axis of rotation of the bit than the inner end of said associated secondary blade. Att least one of said secondary blades may have an inner end which is located at or adjacent the axis of rotation of the bit. At least two of said secondary blades may be joined at their inner ends. Said primary and secondary blades according to the invention may constitute the only blades on the bit body. Preferably the cutters on the blades are located at different distances from the axis of rotation of the bit body so as to define a substantially continuous cutting profile which extends over substantially the whole of the bottom surface of the borehole being drilled. In any of the above arrangements according to the invention, each cutting element may be a preform cutting element comprising a front facing table of superhard material bonded to a less hard substrate. The cutting element may be substantially cylindrical, the substrate being of sufficient axial length to be received and secured within a cylindrical socket in the bit body. Each cutting element may be of generally circular cross-section and may have a substantially straight cutting edge formed by a substantially flat bevel in the facing table and substrate which is inclined to the front surface of the facing table as it extends rearwardly therefrom. In any of the arrangements according to the invention said cutters may include cutters of different size and/or shape. For example, the cutters on at least one blade may be ofa different size and/or shape to the cutters on at least one other blade. The cutters on at least one blade may also project from the bit body to a greater extend than the cutters on at least one other blade. The following is a more detailed description of embodiments of the invention, by way of example, reference being made to the accompanying drawings in which: Figure 1 is a diagrammatic perspective view of a drag-type drill bit incorporating the invention, Figure 2 is an end view of the drill bit of Figure 1, Figure 3 is a side view of the drill bit of Figure 1, Figure 4 is a diagrammatic section through a cutting structure of the drill bit shown in Figures 1-3, Figures 5 and 6 are similar views to Figure 2 of alternative forms of drill bit, only the drill bit of Figure 6 incorporating the invention. Referring to Figures 1-4: the drag-type drill bit comprises a bit body 70 having an end face 71 and formed with a tapered threaded pin 72 for connecting the drill bit to a drill string in known manner. The end face 71 of the bit body is formed with four upstanding blades 73, 74 which extend outwardly away from the central longitudinal axis of rotation of the drill bit. The inner two blades 74 are joined at the centre of the bit whereas the outer two blades 73 are widely separated and are connected to respective kickers 75 which engage the walls of the borehole being drilled, in use, so as to stabilise the bit within the borehole. Each inner blade 74 is formed with two spaced cutters 76 and each outer blade 73 is formed with three spaced cutters 76. Each cutter 76 is generally cylindrical and is a preform cutter comprising a front facing table 77 (see Figure 4) of polycrystalline diamond bonded to a cylindrical substrate 78 of cemented tungsten carbide. The substrate is received and secured in a socket in the respective blade 73 or 74. Each cutter 76 is formed with an inclined bevel 79 which is inclined to the front face of the facing table 77 so as to form a generally straight cutting edge 80. The purpose of the inclined bevel 79 on the cutter 76 is to limit the depth of cut of the cutters. This feature reduces the rate of penetration of the drill bit and hence reduces the volume of cuttings (chips or shavings) produced with respect to time and hydraulic flow. This therefore facilitates the removal of the cuttings as they are formed. The cutters 76 are arranged at different distances from the axis of rotation of the drill bit so that, as the bit rotates, the cutters between them sweep over the whole of the bottom surface of the borehole so as to define a substantially continuous cutting profile. On the leading side of each blade 73, 74, there is mounted in the leading surface 71 of the drill bit a nozzle 81 for delivering drilling fluid to the surface of the drill bit. As is well known, drilling fluid under pressure is delivered downhole through the drill string and through a central passage in the bit body and subsidiary passages leading to the nozzles 81. The purpose of the drilling fluid is to cool and clean the cutters and to carry back to the surface cuttings or chips removed from the formation by the cutters. Drilling fluid emerging from the nozzles normally flows outwardly across the leading surface of the bit body so as to be returned to the surface through the annulus between the drill string and the surrounding formation of the borehole. In a common prior art arrangement the cutters on the blades face into channels defined between the blades, which cutters extend outwardly from the axis of the drill bit to junk slots at the periphery. The nozzles are located and orientated to cause fluid to flow outwardly along these channels and, in so doing, to wash over the cutters so as to clean and cool them. According to the present invention, however, means are provided for directing the flow of drilling fluid more specifically on to individual cutters. As best seen in Figure 1 and Figure 4, each nozzle 81 is located adjacent the downstream ends oftwo or three grooves 82 which are formed in the leading surface of the associated blade 73 or 74 and are orientated to direct fluid from the nozzle 81 to the respective cutters 76 on the blade. As best seen in Figure 4, fluid discharged from the nozzle 81 is directed along each of the grooves 82, as indicated by the arrows 83, so as to impinge on a cutting 84 being raised from the formation 85 by the cutter 76. The hydraulic pressure of the jet of fluid serves to break up the cutting 84 into smaller chips so that it is more easily detached from the surface of the formation and entrained in the flow of drilling fluid. The arrangement of Figures 1-4 is particularly advantageous in drill bits for drilling soft and sticky formations such as plastic shales. The provision of the grooves 82 concentrates the hydraulic energy in the drilling fluid emerging from each nozzle directly on to the individual cutters. The grooves split up the flow from each nozzle and form discrete jets of fluid to impact on the cuttings of formation being removed by the cutter. Although the arrangement shows a separate groove 82 for each cutter, arrangements are possible where a groove may serve two or more closely adjacent cutters, although the described arrangement is preferred. Although the cutter arrangement shown in Figures 1-3 is preferred, the number and type of cutter on each blade may be varied. Figure 5 is a diagrammatic end view of a form of drag-type drill bit which does not incorporate the invention. The drill bit comprises a bit body 100 having an end face 101 on which are formed three upstanding blades 102 which are joined in the vicinity of the axis of the bit and extend outwardly away from the central longitudinal axis to join, at the gauge region of the bit, with respective kickers 103 which are spaced apart around the gauge of the bit to define between them junk slots 104. Mounted on each blade are four spaced cutters 105, which may be preform cutters of the kind previously described. As in the previous arrangement the cutters 105 are arranged at different distances from the axis of rotation of the drill bit so that, as the bit rotates, the cutters between them sweep over the whole of the bottom surface of the borehole so as to define a substantially continuous cutting profile. There may be mounted in the leading surface 101 of the bit body a nozzle 106 for delivering fluid to the cutters on the associated blade. In order to direct fluid from each nozzle 106 to the associated cutters 105 the leading surface of each blade 102 may be formed with a group of grooves for directing fluid from a single nozzle to a plurality of cutters. Figure 6 shows a modified and improved form of blade arrangement for a drag-type drill bit which provides the advantages of the arrangement of Figure 5 while reducing or eliminating the disadvantages of such a bit, as previously described. In accordance with the present invention the leading face 108 of the bit body 107 in Figure 6 is formed with six upstanding blades comprising three primary blades 109 circumferentially spaced between which are three secondary blades 110, each of which is associated with a particular primary blade. Each blade carries two cutters 111 and a nozzle (not shown) is associated with each blade to direct drilling fluid to the two cutters on the blade using an arrangement of grooves in the leading surface of the blade to direct the fluid to the cutters, as in the previously described arrangements. The primary blades 109 join with kickers 112 which engage the walls of the borehole and are spaced apart around the gauge section of the bit to define between them junk slots 113 through which drilling fluid is delivered to the annulus between the drill string and the walls of the borehole. Each primary blade 109 extends only a short distance inwardly from its associated kicker towards the axis of the drill bit. In the drill bit shown in Figure 6 each secondary blade 110 is associated with that primary blade which is disposed rearwardly of it with respect to the normal direction of rotation of the drill bit. Other arrangements are possible, however, and the primary blade could be disposed forwardly of its associated secondary blade or, indeed, in any other relative circumferential position on the face of the drill bit. Each secondary blade is in a radial position which overlaps the radial position of its associated primary blade, and each cutter on the secondary blade is disposed nearer the axis of rotation of the bit than the corresponding cutter on the associated primary blade. Each secondary blade terminates at the outer periphery of the bit body 107 and inwardly of the outer formation-engaging surfaces of the kickers 112. Thus, each primary blade 109, in combination with its associated secondary blade 110, is equivalent, as far as its contribution to the cutting profile is concerned, to one of the blades 102 of the arrangement of Figure 5. However, the drill bit of Figure 6 is in other respects a six-bladed bit giving advantages in stability and lack of vibration. Also, since the secondary blades are displaced both circumferentially and radially with respect to their associated primary blades, drilling fluid can more easily flow over and between the blades in the circumferential direction, thus enhancing the cleaning and cooling of the cutters. In the arrangement of Figure 5, cuttings swept from each of the blades 102 will tend to pass through the same region of the associated junk slot 104. However, in the arrangement of Figure 6, since the primary and secondary blades are circumferentially spaced, the cuttings swept from those blades will pass through different regions of the associated junk slot 113 again enhancing the removal of cuttings from the bit. Similar remarks apply to the blade arrangement of the drill bit shown in Figures 1-3 where the outer blades 73 are primary blades and the inner blades 74 are secondary blades, so that the four-bladed bit is in some respects equivalent to a two-bladed bit where each blade extends continuously from a kicker 75 inwardly towards the axis of rotation of the bit. In the arrangements described above the cutters on all of the blades are of the same type, size and shape. However, arrangements are possible where the cutters vary in size, type and/or shape. Thus circular cutters, as shown in Figure 6, may be combined with part-circular bevelled cutters of the kind employed in the arrangement of Figures 1-3. Also, cutters of different diameters may be employed. Cutters of different shapes, other than circular or part-circular, may also be employed. Cutters may also be used in the invention which are not preform cutters of the kind described in relation to Figures 1-6. For example, some cutters may be of the known kind comprising particles or small bodies of natural or synthetic diamond impregnated into bodies of less hard material, such as tungsten carbide. Drill bits according to the invention may have cutters of different type, size and/or shape on different blades. For example, the cutters on the primary blades may be of one type, size or shape, the cutters on the secondary blades being of a different type, size or shape. Also, in arrangements according to the invention, some of the cutters may project from the bit body to a greater extent than other cutters. That is to say, some of the cutters may be set lower than others so that their cutting edges lie inwardly of the cutting profile defined by the cutting edges of the other cutters. For example, the cutters on the primary blades may project from the bit body to a greater extent than the cutters on the secondary blades.

Claims: A drag-type drill bit for drilling holes in subsurface formations comprising a bit body (70) having an end face (71) and a shank (72) for connection to a drill string, a plurality of blades (73, 74) upstanding from the end face of the bit body and extending outwardly away from the central axis of rotation of the bit, and a plurality of nozzles (81) in the bit body for delivering fluid to the end face thereof, said blades include a plurality of primary blades (73) the outer ends of which are spaced apart around a peripheral gauge portion of the bit, and a plurality of secondary blades (74) spaced circumferentially between adjacent primary blades, a plurality of cutters being mounted on each blade, one of the aforesaid nozzles (81) being located adjacent each of said primary and secondary blades so as to deliver fluid to cool and clean the cutters thereon, and characterised in that the secondary blades each terminate at the outer periphery of the end face (107) of the bit body as viewed axially of the drill bit. A drill bit according to Claim 1, wherein the outer ends of the primary blades (73) join respective kickers (75) which, in use, engage the surrounding wall of the borehole being drilled. A drill bit according to Claim 2, wherein there are defined between the kickers (75) junk slots through which drilling fluid flows from the end face of the bit. A drill bit according to any of the preceding claims, wherein the number of secondary blades (74) equals the number of primary blades (73), secondary blades alternating with primary blades around the axis of rotation of the bit body. A drill bit according to Claim 4, wherein there are two primary blades (73) and two secondary blades (74). A drill bit according to Claim 4, wherein there are three primary blades (109) and three secondary blades (110). A drill bit according to any of the preceding claims, wherein each primary blade (109) has an inner end which is spaced outwardly from the axis of rotation of the bit. A drill bit according to Claim 7, wherein the inner end of each primary blade (109) is closer to the axis of rotation of the bit than the outer end of an associated secondary blade (110). A drill bit according to Claim 9, wherein the inner end of each primary blade (109) is further from the axis of rotation of the bit than the inner end of said associated secondary blade (110). A drill bit according to any of the preceding claims, wherein at least one of said secondary blades (74) has an inner end which is located at or adjacent the axis of rotation of the bit. A drill bit according to Claim 10, wherein at least two of said secondary blades (74) are joined at their inner ends. A drill bit according to any of Claims 7 to 11, wherein said primary and secondary blades (73, 74) constitute the only blades on the bit body. A drill bit according to any of the preceding claims, wherein the cutters (76) on the blades are located at different distances from the axis of rotation of the bit body so as to define a substantially continuous cutting profile which extends over substantially the whole of the bottom surface of the borehole being drilled. A drill bit according to any of the preceding claims, wherein at least one of said cutting elements (76) is a preform cutting element comprising a front facing table of superhard material bonded to a less hard substrate. A drill bit according to any of the preceding claims, wherein at least one of said cutting elements (111) is substantially cylindrical, the substrate being of sufficient axial length to be received and secured within a cylindrical socket in the bit body. A drill bit according to any of the preceding claims, wherein at least one of said cutting elements (111) is of generally circular cross-section. A drill bit according to any of the preceding claims, wherein at least one of said cutting elements (76) has a substantially straight cutting edge (80) formed by a substantially flat bevel (79) in the facing table and substrate which is inclined to the front surface of the facing table as it extends rearwardly therefrom. A drill bit according to any of the preceding claims, wherein said cutters include cutters of different size and/or shape. A drill bit according to Claim 18, wherein the cutters on at least one blade are of a different size and/or shape to the cutters on at least one other blade. A drill bit according to any of the preceding claims, wherein the cutters on at least one blade project from the bit body to a greater extent than the cutters on at least one other blade.

Inventors: TAYLOR STEVEN, TAYLOR, STEVEN
Applicants: CAMCO INT UK LTD, CAMCO INTERNATIONAL (UK) LIMITED
Application year: 1998
Main classification: E21B10
IPC codes: E21B10