Rotary drill bits with nozzles

Abstract: A rotary drill bit for connection to a drill string and for drilling boreholes in subsurface formations comprises a bit body having a leading face and a gauge region (191). Cutting elements 194 are mounted along blades (192) which extend outwardly on the leading face of the bit body so as to define fluid channels (200) between the blades. Nozzles (212) are mounted in the bit body for supplying drilling fluid to the channels for cleaning and cooling the cutting elements. There is an opening (206) in each circumferentially alternate channel (200), each of which openings leads into an enclosed passage (208) which passes internally through the bit body to a respective outlet. A bearing surface (210) is disposed at a portion of the gauge region radially outwardly from each opening, and each circumferentially alternate channel which is not provided with an opening leading to an internal passage has at its outer extremity a junk slot (202) extending through the gauge region.

Description: The invention relates generally to rotary drill bits and, more particularly, to rotary drill bits for use in drilling holes in subsurface formations. In the normal prior art construction, the gauge region of a drill bit is formed by a plurality of kickers which are spaced apart around the outer periphery of the bit body and are formed with bearing surfaces which, in use, bear against the wall of the borehole. The kickers generally form continuations of respective blades formed on the leading face of the bit and extending outwardly away from the axis of the bit towards the gauge region so as to define between the blades fluid channels leading towards the gauge region. The spaces between the kickers define junk slots with which the channels between the blades communicate. During drilling, drilling fluid pumped down the drill string to nozzles in the bit body flows outwardly along the channels, into the junk slots at the end of the channels, and passes upwardly through the junk slots into the annulus between the drill string and the wall of the borehole. While such PDC bits have been very successful in drilling relatively soft formations, they have been less successful in drilling harder formations, including soft formations which include harder occlusions or stringers. Although good rates of penetration are possible in harder formations, the PDC cutters may suffer accelerated wear. Thus, bit life may be too short to be commercially acceptable. Studies have suggested that the rapid wear of PCD of bits in harder formations may be due to chipping of the cutters as a result of impact leads caused by vibration of the drill bit. One of the most harmful types of vibration can be attributed to a phenomenon called "bit whirl", in which the drill bit begins to precess around the hole in the opposite direction to the direction of rotation of the drill bit. One result of bit whirl is that some cutters may temporarily move in the reverse direction relative to the formation and this can result in damage to the cutting elements. It is believed that the stability of such a drill bit, and its ability to resist vibration, may be enhanced by increasing the area of the bearing surfaces on the gauge region which engage the wall of the borehole. In the prior art designs, however, the area of engagement can only be increased by increasing the length and/or width of the bearing surfaces on the kickers. It may be undesirable to increase the length of the bearing surfaces since this may lead to difficulties in steering the bit in steerable drilling systems. Similarly, increasing the circumferential width of the bearing surfaces necessarily reduces the width of the junk slots between the bearing surfaces, and this may lead to less than optimum hydraulic flow of drilling fluid along the channels and over the cutters, or it may lead to blockage of the junk slots and channels by debris. US 5449048 describes a drill bit having a plurality of upstanding blades upon which cutting elements are mounted, the blades defining fluid channels therebetween. European Patent Specification EP 0707132 describes and claims arrangements for reducing or overcoming some of the above disadvantages. In particular the specification describes a rotary drill bit having a leading face and a gauge region, a plurality of blades formed on the leading face of the bit and extending outwardly away from the axis of the bit towards the gauge region so as to define between the blades a plurality of fluid channels leading towards the gauge region, a plurality of cutting elements mounted along each blade, and a plurality of nozzles in the bit body for supplying drilling fluid to the channels for cleaning and cooling the cutting elements. There is provided in at least one of the channels, adjacent the gauge region, an opening into an enclosed passage which passes internally through the bit body to an outlet which, in use, communicates with the annulus between the drill string and the wall of the borehole being drilled, the portion of the gauge region outwardly of said opening comprising a bearing surface which, in use bears against the wall of the bore hole and extends across the width of said one channel. The present invention relates to modifications and developments of the invention referred to in EP 0707132. According to one aspect of the present invention there is provided a rotary drill bit for connection to a drill string and for drilling boreholes in subsurface formations comprising: a bit body having a leading face and a gauge region; a plurality of cutting elements mounted on the leading face of the bit body; a plurality of fluid channels formed in the leading face of the bit body; a plurality of nozzles in the bit body for supplying drilling fluid to the channels for cleaning and cooling the cutting elements; an opening in each circumferentially alternate channel, each of which openings leads into an enclosed passage which passes internally through the bit body to a respective outlet; a bearing surface disposed at a portion of said gauge region radially outwardly from each opening; and each circumferentially alternate channel which is not provided with an opening leading to an internal passage having at its outer extremity a junk slot extending through the gauge region. There may be provided in each said enclosed passage a nozzle for supplying drilling fluid, said nozzle being at least partly directed towards said opening so as to deliver drilling fluid through said opening to the leading face of the bit body. Alternatively or additionally there may be provided in said passage a nozzle for supplying drilling fluid, said nozzle being at least partly directed towards said outlet from the passage, so as to deliver drilling fluid through said outlet. In either case the nozzle may be mounted in a socket in a wall of said passage, the axis of the socket and of the nozzle being inclined with respect to the axis of the passage. Each said bearing surface preferably extends across said channel, thereby to inhibit flow of drilling fluid from said channel across the gauge region of the drill bit. The leading face of the bit body may be formed with a plurality of blades extending outwardly away from the axis of the bit towards the gauge region, said fluid channels being defined between said blades. Each enclosed passage passing internally through the bit body preferably extends generally parallel to the longitudinal axis of the drill bit, and said outlet from the enclosed passage preferably communicates, in use, with the annulus between the drill string and the wall of the borehole being drilled. The gauge region may have a peripheral chamfered edge remote from said leading face of the bit body. The bearing surface which is disposed at a portion of the gauge region radially outwardly from said opening may be free of said formation-engaging elements. 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: Fig. 1 is a perspective view of one embodiment of a prior art drill bit as described in EP 0707132; Fig. 2 is an end view of the drill bit shown in Fig. 1; Fig. 3 is a side elevation of the drill bit; Fig. 4 is a similar view to Fig. 2 showing diagrammatically the hydraulic flow over the surface of the drill bit; Fig. 5 is a similar view to Fig. 2 of an alternative form of prior art drill bit described in EP 0707132; Fig. 6 is a perspective view of a drill bit not in accordance with the invention. Fig. 7 is an end view of the drill bit as shown in Fig. 6; Fig. 8 is a side elevation of the drill 6; Fig. 9 is an end view of another drill bit not in accordance with the present invention; Fig. 10 is a side elevation of another drill bit not in accordance with the invention; Fig. 11 is a perspective view of a first embodiment of a drill bit in accordance with the invention; and Fig. 12 is an end view of the drill bit shown in Fig. 11. Turning to the drawings, and referring initially to Figs. 1-4, the prior art drill bit includes a bit body 10 and nine blades 12, 14, 16, 18, 20, 22, 24, 26, and 28 formed on the leading face of the bit and extending outwardly from the axis of the bit body 10 towards a gauge region 29. Between adjacent blades there are defined channels 30, 32, 34, 36, 38, 40, 42, 44, and 46. Extending side-by-side along each of the blades are a plurality of cutting elements or structures 48. The cutting structures 48 are of any appropriate type. For example, as shown, they may be circular pre-formed cutting elements brazed to cylindrical carriers which are embedded or otherwise mounted in the blades. The cutting elements each may include a pre-formed compact having a polycrystalline diamond front cutting layer bonded to a tungsten carbide substrate, the compact being brazed to a cylindrical tungsten carbide carrier. In another form, the cutting structure 48 may include the substrate of the pre-formed compact being of sufficient axial length to be mounted directly in the blade, so that the additional carrier may then be omitted. Back-up abrasion elements or cutters 49 may be spaced rearwardly of some of the cutting structures, as shown. Inner nozzles 50, 52, and 54 are mounted in the surface of the bit body 10 and are located fairly close to the central axis of rotation of the bit. Each inner nozzle 50, 52, and 54 is so located that it can deliver drilling fluid to two or more channels. In addition, peripheral nozzles 56, 58, and 60 are located in the channels 34, 40, and 44, respectively, and are oriented to direct drilling fluid inwardly along their respective channels towards the center of the drill bit. All of the nozzles communicate with a central axial passage (not shown) in the shank of the bit, to which drilling fluid is supplied under pressure downwardly through the drill string in known manner. The outer extremities of the blades 12, 14, 16, 18, 20, 22, 24, 26, and 28 are formed with axially extending kickers 62, 64, 66, 68, 70, 72, 74, 76, and 78, respectively, which provide part-cylindrical bearing surfaces 79 which, in use, bear against the surrounding wall of the borehole and stabilize the bit in the borehole. Abrasion-resistant bearing elements 81, of any suitable known form, may be embedded in the bearing surfaces 79. Each of the channels 32, 34, 36, 38, 40, 41, 44, and 46 leads to a respective junk slot 80, 82, 84, 86, 88, 90, 92, and 94. The junk slots extend upwardly between the kickers, generally parallel to the central longitudinal axis of the drill bit, so that drilling fluid flowing outwardly along each channel passes into the associated junk slot and flows upwardly, between the bit body and the surrounding formation, into the annulus between the drill string and the wall of the borehole. However, the channel 30 between the blades 12 and 14 does not lead to a conventional junk slot, but continues right up to the gauge region 79 of the drill bit. Formed in the channel 30 adjacent the gauge region 79 is a circular opening 96 into an enclosed cylindrical passage 98 which extends through the bit body 10 to an outlet 100 (see Figure 3) which communicates with the annulus. The kickers 78 and 62 at the outer extremities of the blades 12 and 14 are connected by an intermediate bearing member 101 that has a bearing surface 102 which extends across the width of the channel 30 so as to form, with the kickers 78 and 62, a large continuous part-cylindrical bearing surface 104. As best seen in Fig. 1, a cylindrical socket 106 is formed in the side wall of the passage 98 and is included at an angle to the longitudinal axis of the passage 98. A nozzle 108 is mounted in the socket 106 and is angled to direct drilling fluid along the passage 98 towards the opening 96, so that the drilling fluid emerges from the opening 96 and flows inwardly along the channel 30. Thus, in the case ofthe channel 30, the conventional junk slot is replaced by the enclosed passage 98 which passes internally through the bit body 10. This enables the provision on the adjacent part of the gauge region 29 of a bearing surface 104 of extended peripheral extent. This increased bearing surface 104 may enhance the stability of the drill bit in the borehole. Fig. 4 shows diagrammatically a typical pattern of flow of drilling fluid over the face of the bit. It will be seen that drilling fluid flows inwardly, as indicated by the arrows, from the peripheral nozzles 108, 56, 58, and 60 towards the centre of the bit and then across the face of the bit to flow outwardly along other channels. The outward flow is reinforced by the flow from the inner nozzles 50, 52, and 54. However, other flow patterns are possible and may be achieved by appropriate location and orientation of the nozzles. For example, the nozzle 108 in the passage 98 may be oriented so as to direct a flow of drilling fluid upwardly through the passage 98 towards the outlet 100, in which case the flow along the channel 30 will be in an outward direction towards the opening 96. Alternatively, the nozzle 108 may be omitted altogether, and in this case also drilling fluid will flow outwardly along the channel 30, such flow being derived, for example, from the nozzles 50 and 56. Fig. 5 shows an alternative prior art arrangement where the opening 110 into the passage 112 is irregularly shaped so as to extend over almost all of the entire area of the channel 30 between the blades 12 and 14. In this case, a nozzle is not provided in the passage 112 and the flow of drilling fluid along the channel 30 and through the passage 112 is derived from the peripheral nozzle 56, as indicated by the arrows in Fig. 5. One form of drill bit not according to the present invention is illustrated in Figs. 6-8. Similar to the drill bit illustrated in Figs. 1-5, the drill bit includes a bit body 120 and eight blades 122 formed on the leading face of the bit and extending outwardly from the axis of the bit body towards the gauge region. Between adjacent blades 122 there are defined channels 124. Extending side-by-side along each of the blades 122 is a plurality of cutting structures 126. Each cutting structure 126 includes a preformed cutting element brazed to a cylindrical carrier which is embedded or otherwise mounted in one of the blades 122. Each cutting element may include a preformed compact having a polycrystalline diamond front cutting table which is bonded, by brazing for instance, to a tungsten carbide substrate. Alternatively, the substrate of the preformed compact may be of sufficient axially length to be mounted directly in the blade, so that the additional carrier may then be omitted. The cutting elements are set with a high back rake of 25 on the nose ofthe drill bit increasing to 40 on the shoulder adjacent the gauge section to reduce the reactive torque. The outer region of the drill bit also has increased protection provided by the addition of back-up cutters 130 or abrasion elements 132 disposed rearwardly of the outer three or four cutters on each blade. The back-up cutters 130 may have the same exposure as the primary cutters 126, i.e., they may project to the same distance from the surface of the blade on which they are mounted. Alternatively, they may have a higher or a lower exposure. Similarly, the back rake of the back-up cutters 130 may be the same as the primary cutters 126, or they may have a greater or smaller back rake angle. The location of the back-up cutters 130 may vary. For instance, each back-up cutter 130 may be located at the same radial position as a corresponding primary cutter 126 so as to follow the groove in the formation cut by its associated primary cutter 126. Alternatively, the back-up cutters 130 may be located at radial positions which are intermediate the radial positions of the associated primary cutters, so that each back-up cutter 130 removes from the formation the upstanding kerf left between the two grooves cut by adjacent primary cutters and, thus, provides a smoother surface to the borehole. Furthermore, each back-up cutter 130 may be located on the same blade as its associated primary cutter 126, or it may be on a different blade. The gauge region 128 of the bit body includes a continuous bearing surface 134 which extends around the whole of the gauge region. Gauge protection is provided by inserts 136 which may be a mixture of polycrystalline diamond compacts and diamond inserts. Alternatively, the inserts may be made of tungsten carbide. As may be seen from Figs. 6 and 8, the gauge inserts 136 may be located on those parts ofthe bearing surface 134 which are located at the outer ends of the blades 122, i.e., in areas where the gauge region 29 is fully supported by the bit body 10 radially inwardly of the gauge region 29. The gauge inserts 136 act on the formation more aggressively than the intermediate portions of the bearing surface 134 where no inserts are provided. These greater forces are more easily accommodated by the full support of the inserts 136 by the bit body 10, as compared with the relatively unsupported portions of the bearing surface 134 adjacent the openings 140. Inner nozzles 138 are mounted in the surface of the bit body and are located fairly close to the central axis of rotation of the bit. The inner nozzles 138 are positioned to give efficient cleaning in the central region of the bit and are also directed to deliver drilling fluid along a channel 124 on the leading side of one of the four longer blades 122 on the bit body, so as to clean and cool the cutting elements 126 mounted on that blade. The channels 124 between the blades 122 do not lead to conventional junk slots which extend upwardly through the gauge region 128. Rather, the channels 124 continue right up to the continuous bearing surface 134 of the gauge region 128. A shaped opening 140 is formed in each channel 124 adjacent the gauge region 128. The opening 140 leads to an enclosed passage 142 which extends through the bit body 12 0 to an outlet 144, as illustrated in Fig. 8. The passage 142 communicates, in use, with the annulus between the drill string and the surrounding formation forming the walls of the borehole. As best seen in Fig. 7 and 8, outer nozzles 146 are located in those passages 142 which are disposed on the leading sides of the shorter blades 122. These four outer nozzles 146 are directed to the outer shoulder of the drill bit where a higher proportion of hydraulic energy is required to clean the increased cutter count in this region provided by the back-up cutters 130. Fluid flow from the inner nozzles 138 creates a pressure difference such that fluid from the outer nozzles 146 also flows inwardly towards the inner nozzles 138, across the inner cutters on the shorter blades, before flowing outwardly again with the outward flow from the inner cutters 138. Flow from both the inner nozzles 138 and outer nozzles 146 flows to the annulus through the openings 140 and passages 142 through the bit body. All of the nozzles 138 and 146 communicate with a central axial passage (not shown) in the shank of the bit, to which drilling fluid is supplied under pressure downwardly through the drill string in known manner. The provision of a continuous bearing surface 134 around the whole of the gauge region of the drill bit substantially enhances the stability of the bit in operation. It reduces the bits susceptibility to vibration, due to the absence of edges, cutting elements or other protrusions in the gauge region which otherwise might act on the surrounding formation to cause vibration and, under some circumstances, to initiate "bit whirl". Furthermore, the provision of a continuous bearing surface around the whole periphery of the drill bit allows the axial length of the gauge section to be reduced while maintaining a suitable overall area of the bearing surface. As may be seen from Fig. 8, the gauge length of the drill bit is considerably less than is normally the case with a conventional PDC drill bit. For instance, a conventional 12.25 inch drill bit will normally have a gauge of3 to 4 inches in axial length and will normally have an overall length of 12 to 16 inches. In contrast, a 12 inch drill bit of the kind shown in Figs. 6-8 may have a gauge of only 2 inches in axial length and an overall bit length of only 9 inches, thereby not only reducing the axial length of the gauge section but also reducing the distance from the motor to the bit, in a steerable motor-driven system, and thereby improving the directional response of the drill bit when steering is taking place. Although the passage 98 is described as being a cylindrical passage parallel to the longitudinal axis of the drill bit, other arrangements are possible. For example, the passage may vary in cross-sectional shape and/or diameter along its length. Two or more openings may be provided in the channel, the openings leading to separate passages through the bit body, or two or more openings may lead into a single passage. In the arrangement shown in Figs. 6-8, where the bit is provided with eight blades, there is provided a single opening 140 in each channel 124. However, when drilling some types of formation, particularly softer formations, it may be preferred to use a lighter set drill bit having fewer blades and cutters, since this may reduce the problem of bit balling. Fig. 9 shows such a lighter set drill bit, not according to the invention, where only four blades 148 are provided, separated by channels 150 which are almost 90 in angular extent. In such a construction, the provision of a single large opening and passage in the bit body, in order to deliver drilling fluid from each channel 150 past the continuous gauge section 152 to the annulus, may result in substantial structural weakening of the drill bit and, in particular, the gauge section. According to the arrangement shown in Fig. 9, therefore, each channel is formed with two openings 154 and 156 which communicate with separate passages leading through the bit body to the annulus. The larger of the two openings 154 is disposed adjacent the gauge section 152 and on the leading side of a respective blade 148, and the smaller opening 156 is disposed adjacent the trailing side of the preceding blade. In this case the inner nozzles 158 direct drilling fluid outwardly along the leading edges of the blades 148 respectively. The portion 160 of the bit body between each pair of openings 154, 156 may thus be regarded as a support strut which provides radial strength to the gauge section 152 between the widely angularly spaced blades 148. Another drill bit not according to the invention is illustrated in Fig. 10. This drill bit includes a bit body 162. Eight blades 164 are formed on the leading face of the bit. These blades 164 extend generally outwardly from the central axis of the bit body 162 towards a gauge region 165 and, thus, define channels 166 therebetween. A plurality of cutting structures 168, which may be similar to the cutting structures described in reference to previous embodiments, extend side- by-side along each of the blades 164. The gauge region 165 of the bit body 162 includes a continuous bearing surface that extends continuously around the whole of the gauge region 165. In similar fashion to the previously described embodiments, inner nozzles (not shown) may be mounted in the surface of the bit body, close to the central axis of rotation for instance, to deliver drilling fluid along the channels 166. An opening (not shown), similar to the previously described openings, may be formed in each channel 166 adjacent the gauge region 165. Each opening leads to an internal passage that extends through the bit body 162 to an outlet 172. The outlet 172 advantageously communicates with the annulus between the drill string and the surrounding formation of the borehole when the drill bit is in use. The drill bit of Fig. 10 may also include a portion 174 of the bit body 162 that is relieved. As illustrated, the relieved portion 174 includes four breaker slots 176 that are equally spaced about the circumference of the relieved portion 174. Each breaker slot 176 may be thought of as a flat-bottomed recess cut int the cylindrical outer surface of the portion 174. The breaker slots 176 facilitate tool engagement with the drill bit during attachment or detachment of the tapered threaded pin 178 into an internally threaded collar (not shown) at the lower end of a drill string. Furthermore, the breaker slots 176 are advantageously in register with one or more outlets 172 to facilitate the flow of drilling fluid as it emerges from the outlets 172 after passing through the internal passages of the drill bit. Specifically, this registration permits the size of the outlets 172 to be maximized to provide a greater flow potential. Also, in the embodiment of Fig. 10, it should be noticed that gauge cutters 180 are disposed at the peripheral bearing surface 170 of the gauge region 165. The gauge cutters 180 may be mounted in recesses 182 in the bearing surface 170 so that the cutting edges of the gauge cutters 180 project only a short distance from the bearing surface 170. In the illustrated embodiment, two gauge cutters 180 are provided on each portion of the bearing surface 170 which lies at the outer end of a blade 164 on the leading face of the drill bit. Instead of, or in addition to, the gauge cutters 180, gauge protection inserts (not shown), similar to the inserts 136 discussed previously, may be disposed in the bearing surface 170. Since the bearing surface 170 of the gauge region 165 extends continuously about the whole periphery of the drill bit, it is possible that occasional difficulty may be experienced when withdrawing the drill bit from the borehole. Accordingly, to facilitate withdrawal of the drill bit, a chamfer, such as a frusto-conical peripheral chamfer 184, may be formed in the upper edge of the gauge region 165. In addition, back-reaming cutters 186 may be mounted in a peripherally spaced apart relationship on the upper edge of the gauge region 165. Under particularly difficult conditions, the back-reaming cutters 186 may facilitate removal of the drill bit from the borehole by reaming out the walls of the borehole as the rotating drill bit is withdrawn. In this case, the combination of the back-reaming cutters 186 with the chamfer 184 may increase the exposure of the cutters 186 and, thus, increase their efficiency. To this point, drill bits have been disclosed as having a passage disposed in only one channel where the gauge region includes a bearing surface extending across the outer end ofthat one channel, or as having a passage disposed in each channel where a bearing surface extends continuously around the entire periphery of the bit. However, many other arrangements may be possible. As one example, Figs 11 and 12 illustrate a drill bit having a passage disposed in a first plurality of channels which terminate with a bearing member in the gauge region, and where a second plurality of channels lead to a conventional junk slot. Specifically, channels leading to an internal passage and bearing member are alternated with channels leading to a conventional junk slot. As illustrated in Figs. 11 and 12, the drill bit includes a bit body 188. Eight blades 189 are formed on the leading face of the bit and extend generally outwardly from the axis of the bit towards the gauge region 191. The blades 189 include four longer blades 190 alternating with four shorter blades 192. A plurality of cutting structures 194 extend side-by-side along each of the blades 189. Back-up cutters 196 may be provided rearwardly of the primary cutting structures 194 on the shorter blades 192, whereas abrasion elements 198 may be disposed rearwardly of the primary cutting structures 194 on the longer blades 190. A channel 200 is defined between the leading edge of each longer blade 190 and the trailing edge of the preceding shorter blade 192. Each channel 200 leads outwardly to a junk slot 202 which extends upwardly through the gauge region 191 to the annulus between the drill string and the borehole. Similarly, a channel 204 is defined between the leading edge of each shorter blade 192 and the trailing edge of the preceding longer blade 190. In this case, however, an opening 206 is formed in each channel 204 adjacent the gauge region 191. Each opening 206 leads to a passage 208 that passes internally through the bit body 188 to an outlet which passes fluid into the annulus between the drill string and the surrounding borehole. A bearing member 209 is formed outwardly of each opening 206 between the outer ends of the respective adjacent blades 190 and 192. Each bearing member 209 includes a substantially continuous peripheral bearing surface 210 at the gauge region 191. The bearing surfaces 210 may also incorporate any of the features previously described with reference to the bearing surfaces of Figs. 1-10. Inner nozzles 212 are mounted in the surface of the bit body 188 and are located fairly close to the central axis of the bit. The inner nozzles 212 are positioned to provide efficient cleaning in the central region of the bit. The inner nozzles 212 may also be directed to deliver drilling fluid outwardly along each channel 200 along the leading side of one of the four longer blades 190 to clean and cool the cutting elements 194 mounted on that blade. An outer nozzle 214 is mounted in a socket in the wall of each internal passage 208 and is directed to cool and clean the outer cutters 194 on the adjacent shorter blade 192. Fluid from each outer nozzle 214 flows both upwardly through the internal passage 206 and also inwardly towards the adjacent inner nozzle 212 to cool and clean the inner cutters on the shorter blades 192. This inwardly directed fluid then becomes entrained with the fluid flowing outwardly from the adjacent inner nozzle 212 so that it flows outwardly through the rearwardly adjacent channel 200 leading to a junk slot 202. The flow of drilling fluid is illustrated by arrows in Fig. 12. The provision of four continuous stretches of peripheral bearing surfaces 210 in this embodiment increases the bearing surface area and, thus, provides some or all of the advantages mentioned previously. At the same time, the provision of the internal passages alternating with junk slots, combined with the fluid flow described above, may enhance the clearing of cuttings from the face of the bit and may reduce the risk of balling up cuttings in the internal passages 206. In the arrangement shown in Figs. 11 and 12, the junk slots 202 extend substantially parallel to the longitudinal axis of the bit body 188. However, in an alternate arrangement, the junk slots may extend helically with respect to the longitudinal axis so that the upper extremity of the bearing surface 210 on one side of the junk slot 202 approaches or overlaps the circumferential position of the lower extremity of the bearing surface 210 on the other side of the junk slot. Such arrangement may then provide that there is a portion of the bearing surface 210 around substantially the whole 360 degree periphery of the gauge region 191.

Claims: A rotary drill bit for connection to a drill string and for drilling boreholes in subsurface formations comprising: a bit body (188) having a leading face and a gauge region (191); a plurality of cutting elements (194) mounted on the leading face of the bit body (188); a plurality of fluid channels (203, 204) formed in the leading face of the bit body (188); a plurality of nozzles (212, 214) in the bit body for supplying drilling fluid to the channels (200, 204) for cleaning and cooling the cutting elements (194); characterised by an opening (206) in each circumferentially alternate channel, each of which openings (206) leads into an enclosed passage (208) which passes internally through the bit body to a respective outlet; a bearing surface (209) disposed at a portion of said gauge region (191) radially outwardly from each opening (206); and each circumferentially alternate channel which is not provided with an opening (206) leading to an internal passage having at its outer extremity a junk slot (202) extending through the gauge region. A drill bit according to Claim 1, wherein there is provided in each said enclosed passage (205) a nozzle (214) for supplying drilling fluid, said nozzle (214) being at least partly directed towards said openings (206) so as to deliver drilling fluid through said opening (206) to the leading face of the bit body. A drill bit according to Claim 1 or Claim 2, wherein there is provided in said passage (208) a nozzle (214) for supplying drilling fluid, said nozzle (214) being at least partly directed towards said outlet from the passage (208), so as to deliver drilling fluid through said outlet. A drill bit according to Claim 2 or Claim 3, wherein said nozzle (214) is mounted in a socket in a wall of said passage, the axis of the socket and of the nozzle being inclined with respect to the axis of the passage. A drill bit according to any of the preceding claims, wherein each said bearing surface extends across said channel (204) thereby to inhibit flow of drilling fluid from said channel across the gauge region of the drill bit. A drill bit according to any ofthe preceding claims, wherein the leading face of the bit body is formed with a plurality of blades (190, 192) extending outwardly away from the axis of the bit towards the gauge region, said fluid channels (200, 204) being defined between said blades. A drill bit according to any of the preceding claims, wherein each enclosed passage (208) passing internally through the bit body extends generally parallel to the longitudinal central axis of the drill bit. A drill bit according to any of the preceding claims, wherein said outlet from the enclosed passage (208) communicates, in use, with the annulus between the drill string and the wall of the borehole being drilled.

Inventors: CLEGG JOHN MARTIN, MURDOCK ANDREW, NEWTON ALEX, TAYLOR STEVEN, TOMCZAK MICHAEL, CLEGG, JOHN MARTIN, MURDOCK, ANDREW, NEWTON, ALEX, TAYLOR, STEVEN, TOMCZAK, MICHAEL
Applicants: CAMCO INT UK LTD, CAMCO INTERNATIONAL (UK) LIMITED
Application year: 1998
Main classification: E21B10
IPC codes: E21B10