CN214944011U - Composite drill bit - Google Patents
Composite drill bit Download PDFInfo
- Publication number
- CN214944011U CN214944011U CN202022978550.4U CN202022978550U CN214944011U CN 214944011 U CN214944011 U CN 214944011U CN 202022978550 U CN202022978550 U CN 202022978550U CN 214944011 U CN214944011 U CN 214944011U
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- rotary
- drill bit
- strip portion
- composite drill
- rotary cutting
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- 239000002131 composite material Substances 0.000 title claims abstract description 41
- 230000015572 biosynthetic process Effects 0.000 claims description 18
- 229910003460 diamond Inorganic materials 0.000 claims description 10
- 239000010432 diamond Substances 0.000 claims description 10
- 239000002245 particle Substances 0.000 claims description 10
- 239000000463 material Substances 0.000 claims description 8
- 229910000851 Alloy steel Inorganic materials 0.000 claims description 3
- 229910001315 Tool steel Inorganic materials 0.000 claims description 3
- 239000003921 oil Substances 0.000 abstract description 23
- 238000010276 construction Methods 0.000 abstract description 10
- 239000010730 cutting oil Substances 0.000 abstract 1
- 238000005553 drilling Methods 0.000 description 5
- 238000010586 diagram Methods 0.000 description 4
- 238000005516 engineering process Methods 0.000 description 4
- 238000009434 installation Methods 0.000 description 3
- 238000000034 method Methods 0.000 description 3
- 230000035515 penetration Effects 0.000 description 3
- 238000003466 welding Methods 0.000 description 3
- 150000001875 compounds Chemical class 0.000 description 2
- 239000000843 powder Substances 0.000 description 2
- 239000011435 rock Substances 0.000 description 2
- 230000000712 assembly Effects 0.000 description 1
- 238000000429 assembly Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 238000003801 milling Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- ORQBXQOJMQIAOY-UHFFFAOYSA-N nobelium Chemical compound [No] ORQBXQOJMQIAOY-UHFFFAOYSA-N 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 238000004080 punching Methods 0.000 description 1
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- Earth Drilling (AREA)
Abstract
The utility model provides a composite drill bit belongs to borehole operation technical field. The utility model discloses when the rotary cutting at composite bit, come the rotary cutting oil pipe sleeve by higher first rotary-cut piece earlier, drill out the punchhole back on oil pipe sleeve at first rotary-cut piece, first rotary-cut piece is wearing and tearing gradually when cutting the stratum, when highly equals a plurality of second rotary-cut pieces up to first rotary-cut piece, again by lower a plurality of second rotary-cut pieces come the rotary cutting stratum, and can conveniently fixed connection with other downhole tool based on the mounting, only need once only go into composite bit with tool string fixed connection down when the construction punchhole, need not to have repeated, tool string down, thereby the efficiency of construction of oil gas exploitation has been promoted, the cost of borehole operation has been reduced.
Description
Technical Field
The utility model relates to an operation technical field in the pit, in particular to compound drill bit.
Background
In the process of oil and gas exploration and development, after an oil layer is communicated with a shaft, oil and gas resources in the oil layer can be exploited. When an oil layer is communicated with a shaft, a traditional powder perforating mode can be adopted, but the powder perforating mode easily has the problems of short perforating depth, secondary pollution to the oil layer and the like, so that the deep penetration drilling technology is produced at the same time.
With the development of deep penetration drilling technology, the oil and gas exploitation process is more convenient from hydraulic jet rock breaking to hydraulic cutting rock breaking and to the current electric control drilling technology. When exploiting oil gas based on deep penetration drilling technology, two-stage construction is mostly adopted: firstly, drilling a casing extending into an oil-gas well by adopting sectional milling, punching and other modes; and then, lowering the tool string into the oil and gas well again, and penetrating through the drilled hole in the casing to drill the oil layer to form a crude oil drainage channel. That is, at present, each construction hole needs to be repeatedly started and stopped by a tool string, and the construction efficiency of oil and gas exploitation and the underground operation cost are seriously influenced.
SUMMERY OF THE UTILITY MODEL
The embodiment of the application provides a composite drill bit, can promote the efficiency of construction of oil gas exploitation, reduce borehole operation cost. The composite drill bit comprises the following components:
a composite drill bit, comprising: the drill bit comprises a drill bit main body, a first rotary cutting piece, a plurality of second rotary cutting pieces and a fixing piece;
the drill bit main body comprises a cylindrical part and a conical part, the bottom end of the conical part is connected with the top end of the cylindrical part, and the radius of the bottom surface of the conical part is matched with that of the bottom surface of the cylindrical part;
the first rotary cutting piece is used for rotatably cutting an oil pipe sleeve and comprises a first strip-shaped part and a second strip-shaped part, the first strip-shaped part is connected with the second strip-shaped part, and the first strip-shaped part and the second strip-shaped part are both connected with the outer surface of the conical part;
the second rotary cutting pieces are used for rotatably cutting the stratum and connected with the outer surface of the conical part, and the heights of the second rotary cutting pieces are lower than that of the first rotary cutting piece;
the fastener is used to connect the bit body and a downhole tool, the fastener being connected to the bottom end of the cylindrical portion.
In a possible embodiment, the angle between the first strip and the second strip is equal to the cone angle of the cone.
In a possible embodiment, the length of each of the first and second strip portions is equal to the generatrix length of the conical portion.
In one possible embodiment, the fastener is threadably engaged with the downhole tool.
In one possible embodiment, the fastener is flanged to the downhole tool.
In one possible embodiment, the plurality of second rotational cutting members has a hardness greater than a hardness of the first rotational cutting member.
In one possible embodiment, the plurality of second rotary cut pieces is a plurality of diamond particles.
In one possible embodiment, the plurality of diamond particles are uniformly distributed on the outer surface of the tapered portion.
In one possible embodiment, the first rotational cutting member is a cutting edge.
In one possible embodiment, the material of the cutting edge comprises tool steel or hard alloy steel.
The beneficial effect of the compound drill bit that this application embodiment provided includes at least:
the first rotary cutting piece and the second rotary cutting pieces are arranged on the outer surface of the conical part of the drill bit main body, and the heights of the second rotary cutting pieces are lower than that of the first rotary cutting piece, so that the whole composite drill bit is firstly used for rotatably cutting an oil pipe sleeve by the first rotary cutting piece which is higher when the composite drill bit is used for rotatably cutting the oil pipe sleeve, after a hole is drilled on the oil pipe sleeve by the first rotary cutting piece, the first rotary cutting piece is gradually worn when cutting a stratum until the height of the first rotary cutting piece is equal to that of the second rotary cutting pieces, then the lower second rotary cutting pieces are used for rotatably cutting the stratum, and the composite drill bit fixedly connected with a tool string is only required to be put down once based on a fixing piece when the hole is constructed without repeatedly starting and putting down the tool string, so that the construction efficiency of oil and gas exploitation is improved, and the cost of downhole operation is reduced.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings needed to be used in the description of the embodiments are briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings without creative efforts.
FIG. 1 is a schematic diagram of a composite drill bit according to an embodiment of the present disclosure;
fig. 2 is a schematic diagram of a composite drill bit according to an embodiment of the present disclosure.
Wherein the reference numerals in the drawings are explained as follows:
101 a drill body, 102 a first rotary cutting member, 103 a plurality of second rotary cutting members, 104 a retaining member,
1011 cylindrical portion, 1012 conical portion, 1021 first strip portion, 1022 second strip portion,
201 rotationally cutting the casing, 202 rotationally cutting the formation, 203 rotationally cutting the formation.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention clearer, embodiments of the present invention will be described in further detail below with reference to the accompanying drawings.
Fig. 1 is a schematic structural diagram of a composite drill bit provided in an embodiment of the present application. Referring to fig. 1, the embodiment provides the composite drill bit including: drill body 101, first rotary cutting member 102, a plurality of second rotary cutting members 103, and securing members 104, each of which is described in detail below:
This drill bit main body 101 includes: a cylindrical part 1011 and a tapered part 1012, the bottom end of the tapered part 1012 being connected to the top end of the cylindrical part 1011, the radius of the bottom surface of the tapered part 1012 matching the radius of the bottom surface of the cylindrical part 1011.
Wherein the cylindrical portion 1011 is a cylinder and the tapered portion 1012 is a cone.
In some embodiments, the connection of the bottom end of the tapered portion 1012 to the top end of the cylindrical portion 1011 means: the rounded bottom surface of the tapered portion 1012 is connected to the rounded top surface of the cylindrical portion 1011.
In some embodiments, the tapered portion 1012 and the cylindrical portion 1011 are integrally formed, wherein the tapered portion 1012 and the cylindrical portion 1011 structurally form an integral assembly, or the tapered portion 1012 and the cylindrical portion 1011 are fixedly attached, wherein the tapered portion 1012 and the cylindrical portion 1011 structurally belong to different assemblies.
Optionally, when the tapered portion 1012 is fixedly connected with the cylindrical portion 1011, the manner of fixedly connecting includes: welding, screwing or flange connection, and the embodiment of the present application does not specifically limit the manner of the fixed connection between the tapered portion 1012 and the cylindrical portion 1011.
For example, the tapered portion 1012 is welded to the cylindrical portion 1011 to ensure the tightness of the fixed connection, or the tapered portion 1012 is screwed to the cylindrical portion 1011 to facilitate the mounting and dismounting, or the tapered portion 1012 is flanged to the cylindrical portion 1011 to facilitate the mounting and dismounting.
In some embodiments, matching the radius of the bottom surface of the tapered portion 1012 to the radius of the bottom surface of the cylindrical portion 1011 means: the radius of the bottom surface of the tapered portion 1012 is greater than or equal to the radius of the bottom surface of the cylindrical portion 1011. For example, the radius of the bottom surface of the tapered portion 1012 is equal to the radius of the bottom surface of the cylindrical portion 1011.
(II) first rotary cutter 102
The first rotary cutting member 102 is adapted to rotatably cut a tubing sleeve, the first rotary cutting member 102 includes a first strip portion 1021 and a second strip portion 1022, the first strip portion 1021 and the second strip portion 1022 are connected, and the first strip portion 1021 and the second strip portion 1022 are both connected to an outer surface of the tapered portion 1012.
In some embodiments, the angle between the first bar 1021 and the second bar 1022 is equal to the taper angle of the tapered portion 1012. Since the first strip portion 1021 and the second strip portion 1022 are connected and the included angle between the first strip portion 1021 and the second strip portion 1022 is equal to the conical angle of the tapered portion 1012, that is, the first strip portion 1021 and the second strip portion 1022 intersect at the vertex of the tapered portion 1012, the first strip portion 1021 is parallel to one generatrix of the tapered portion 1012, the second strip portion 1022 is parallel to the other generatrix of the tapered portion 1012, and the two generatrixes are symmetrically distributed on the outer surface of the tapered portion 1012.
In some embodiments, the length of the first strip portion 1021 and the second strip portion 1022 are both equal to the length of the generatrix of the tapered portion 1012. That is, the first and second bar portions 1021 and 1022 do not extend beyond the rounded bottom surface of the tapered portion 1012.
In other embodiments, the length of the first strip 1021 and the second strip 1022 may be greater than the generatrix length of the tapered portion 1012, which is because the first strip 1021 and the second strip 1022 extend beyond the rounded bottom surface of the tapered portion 1012 to ensure that the first rotary cutting member 102 does not wear down the bit body 101 during rotational cutting of the tubing sleeve.
In some embodiments, the first strip portion 1021 and the second strip portion 1022 are integrally formed, in which case the first strip portion 1021 and the second strip portion 1022 are structurally integrated into a single component, or the first strip portion 1021 and the second strip portion 1022 are fixedly connected, in which case the first strip portion 1021 and the second strip portion 1022 are structurally different components.
Optionally, when the first strip portion 1021 and the second strip portion 1022 are fixedly connected, the manner of fixedly connecting includes: welding, screwing or flange connection, and the embodiment of the present application does not specifically limit the manner of the fixed connection between the first strip portion 1021 and the second strip portion 1022.
For example, the first bar-shaped portion 1021 and the second bar-shaped portion 1022 are welded, so that the tightness of the fixed connection can be ensured, or the first bar-shaped portion 1021 and the second bar-shaped portion 1022 are in threaded connection, so that the installation and the disassembly can be facilitated, or the first bar-shaped portion 1021 and the second bar-shaped portion 1022 are in flange connection, so that the installation and the disassembly can be facilitated.
In some embodiments, the first rotary cutting member 102 and the tapered portion 1012 are integrally formed, i.e., the first strip portion 1021 and the second strip portion 1022 are integrally formed with the tapered portion 1012, and the first rotary cutting member 102 and the drill body 101 structurally form an integrated component, or the first rotary cutting member 102 and the tapered portion 1012 are fixedly connected, i.e., the first strip portion 1021 and the second strip portion 1022 are fixedly connected with the tapered portion 1012, and the first rotary cutting member 102 and the drill body 101 structurally belong to different components.
Optionally, for any one of the first strip portion 1021 or the second strip portion 1022, the manner of fixedly connecting with the tapered portion 1012 includes: a welding or a screw connection, and the embodiment of the present application does not specifically limit the manner of the fixed connection between any one of the first strip portion 1021 or the second strip portion 1022 and the tapered portion 1012.
It should be noted that the manner of the fixed connection between the first strip portion 1021 and the tapered portion 1012 may be the same as or different from the manner of the fixed connection between the second strip portion 1022 and the tapered portion 1012, and the embodiment of the present invention is not limited thereto.
For example, the first strip portion 1021 and the second strip portion 1022 are both welded to the tapered portion 1012, so that the tightness of the fixed connection can be ensured, or the first strip portion 1021 and the second strip portion 1022 are both in threaded connection with the tapered portion 1012, so that the installation and the disassembly are convenient, at this time, fixing holes can be respectively formed in the first strip portion 1021 and the second strip portion 1022, fixing holes are formed in the outer surface of the tapered portion 1012, and bolts are respectively used to penetrate through the fixing holes formed in the first strip portion 1021 and the second strip portion 1022, and are fastened and connected with the fixing holes formed in the outer surface of the tapered portion 1012.
In some embodiments, the first rotational cutting member 102 is a cutting edge, thereby enabling cutting of the tubing sleeve as the composite drill bit is rotated. Optionally, the material of the cutting edge includes tool steel or hard alloy steel, or the cutting edge may also adopt other materials capable of cutting the oil pipe sleeve, and the material of the cutting edge is not specifically limited in this embodiment of the application.
(III) a plurality of second rotary cutters 103
The plurality of second cutting members 103 are configured to rotationally cut the earth formation, the plurality of second cutting members 103 are coupled to an outer surface of the tapered portion 1012, and a height of the plurality of second cutting members 103 is less than a height of the first cutting member 102.
In some embodiments, the hardness of the second plurality of rotary cut members 103 is greater than the hardness of the first plurality of rotary cut members 102. Because the height of the second cutting members 103 is lower than the height of the first cutting member 102 and the hardness of the second cutting members 103 is greater than the hardness of the first cutting member 102, the composite drill bit is first rotated by the first cutting member 102 to cut the tubing casing, and the composite drill bit is drilled into the formation through the perforations as the composite drill bit cuts the perforations through the tubing casing, and the first cutting member 102, which is less hard, gradually wears in the formation until the second cutting members 103, which are harder, continue to rotate to cut the formation when the height of the first cutting member 102 is equal to the height of the second cutting members 103.
In some embodiments, the second cutting members 103 are diamond particles, or other materials capable of cutting the formation may be used for the second cutting members 103, and the material of the second cutting members 103 is not particularly limited in this embodiment.
In some embodiments, for any of the plurality of second rotary cutting members 103, the any second rotary cutting member is configured to be integral with the conical portion 1012, wherein the any second rotary cutting member is configured to be structurally integrated with the drill body 101, or wherein the any second rotary cutting member is fixedly coupled to the conical portion 1012, wherein the any second rotary cutting member and the drill body 101 are structurally distinct components.
Optionally, the means for fixedly attaching any of the second rotary cutting members to the tapered portion 1012 comprises: a welded or threaded connection, and the embodiments of the present application are not limited to any particular manner of securing the second rotary cutting member to the tapered portion 1012. It should be noted that the manner of securing the second cutting member to the tapered portion 1012 may be the same or different, and the embodiments of the present invention are not limited thereto.
For example, the second rotary cutting member is welded to the tapered portion 1012 to ensure the tightness of the fixed connection, or the second rotary cutting member is screwed to the tapered portion 1012 to facilitate the mounting and dismounting.
In some embodiments, the plurality of diamond particles are uniformly distributed on the outer surface of the tapered portion 1012, or the plurality of diamond particles are randomly distributed on the outer surface of the tapered portion 1012, which is not particularly limited in the embodiments.
In one example, the plurality of diamond particles are symmetrically distributed along a plurality of generatrices of the conical portion 1012, and the diamond particles on each generatrix are equally spaced, which ensures that the plurality of diamond particles are evenly forced in all directions when rotationally cutting the formation.
Composition structure of (IV) fixing piece 104
The fastener 104 is used to connect the bit body 101 to a downhole tool, and the fastener 104 is connected to the bottom end of the cylindrical portion 1011. Wherein the dimension of the fixing member 104 is smaller than or equal to the radius of the bottom surface of the cylindrical portion 1011.
In some embodiments, the fastener 104 is threadably coupled to the downhole tool; in other embodiments, the fastener 104 is flanged to the downhole tool, and the embodiment of the present application does not specifically limit the manner of connection between the fastener 104 and the downhole tool.
Fig. 2 is a schematic diagram of the operation of a composite drill bit according to an embodiment of the present disclosure, referring to fig. 2, the composite drill bit is connected to a downhole tool via a fastener 104 and is lowered into a tubular casing, and under the weight and torque applied by the downhole tool, the composite drill bit extends from the downhole tool and contacts the inner wall of the tubular casing, as shown at 201, to illustrate the rotary cutting casing state of the composite drill bit, wherein the first rotary cutting member 102 first contacts the tubular casing and rotatably cuts the tubular casing, and the plurality of second rotary cutting members 103 are not in contact with the tubular casing because the height of the plurality of second rotary cutting members 103 is lower than the initial height of the first rotary cutting member 102. As the cut progresses, the composite drill bit eventually drills through the tubing casing and into the formation, as shown at 202, illustrating the rotary cut formation condition of the composite drill bit, where the first rotary cutting element 102 has just entered the formation and continues to cut the formation under the torque and weight on bit. Because the material selected for the first rotary cutting member 102 is used to cut the casing of the tubing, it generally does not have the ability to cut the formation, and therefore the first rotary cutting member 102 will quickly wear and wear away in the formation until the height of the first rotary cutting member 102 is lower than the height of the second rotary cutting members 103, as shown at 203, another rotary cutting casing state of the composite drill bit is shown, at which time the second rotary cutting members 103 just begin to contact the formation and cut the formation to drill a hole until the target length is reached, and a hole construction in the formation can be completed. The technician may then remove the tool and composite bit from the well, replace the other composite bit, and continue to construct the next hole, repeating the process.
The composite drill bit provided by the embodiment of the application has the advantages that the first rotary cutting member 102 and the plurality of second rotary cutting members 103 are arranged on the outer surface of the conical part 1012 of the drill bit body 101, and because the heights of the plurality of second rotary cutting members 103 are lower than the height of the first rotary cutting member 102, when the whole composite drill bit is used for rotary cutting, the first rotary cutting member 102 with a higher height is used for rotary cutting of an oil pipe sleeve, after a hole is drilled on the oil pipe sleeve by the first rotary cutting member 102, the first rotary cutting member 102 is gradually worn when cutting a stratum until the height of the first rotary cutting member 102 is equal to the heights of the plurality of second rotary cutting members 103, the stratum is rotationally cut by the plurality of second rotary cutting members 103 with a lower height, and the composite drill bit fixedly connected with a tool string can be conveniently and fixedly connected with other downhole tools based on the fixing member 104, only needs to be put in once during hole construction, and the tool string does not need to be repeatedly lifted and put down, so that the oil and gas extraction construction efficiency is improved, the cost of downhole operations is reduced.
All the above optional technical solutions may be combined arbitrarily to form the optional embodiments of the present disclosure, and are not described herein again.
The above description is only an optional embodiment of the present invention, and is not intended to limit the present invention, and any modifications, equivalent replacements, improvements, etc. made within the spirit and principle of the present invention should be included in the protection scope of the present invention.
Claims (10)
1. A composite drill bit, comprising: a bit body (101), a first rotary cutter (102), a plurality of second rotary cutters (103), and a fixture (104);
the drill bit body (101) comprises a cylindrical part (1011) and a conical part (1012), the bottom end of the conical part (1012) is connected with the top end of the cylindrical part (1011), and the radius of the bottom surface of the conical part (1012) is matched with that of the bottom surface of the cylindrical part (1011);
the first rotary cutter (102) is configured to rotationally cut an oil tube sleeve, the first rotary cutter (102) includes a first strip portion (1021) and a second strip portion (1022), the first strip portion (1021) and the second strip portion (1022) are connected, and the first strip portion (1021) and the second strip portion (1022) are both connected to an outer surface of the tapered portion (1012);
the second plurality of rotary cutting members (103) being adapted to rotatably cut the subterranean formation, the second plurality of rotary cutting members (103) being attached to the outer surface of the tapered portion (1012), the second plurality of rotary cutting members (103) having a height less than a height of the first plurality of rotary cutting members (102);
the fixing member (104) is used for connecting the drill bit main body (101) and a downhole tool, and the fixing member (104) is connected with the bottom end of the cylindrical part (1011).
2. The composite drill bit of claim 1, wherein an included angle between the first strip portion (1021) and the second strip portion (1022) is equal to a cone angle of the tapered portion (1012).
3. The composite drill bit of claim 1, wherein the first strip portion (1021) and the second strip portion (1022) each have a length equal to a generatrix length of the cone portion (1012).
4. The composite drill bit of claim 1, wherein the fastener (104) is threadably coupled to the downhole tool.
5. The composite drill bit of claim 1, wherein the fastener (104) is flanged to the downhole tool.
6. The composite drill bit of claim 1, wherein the hardness of the second plurality of rotary cut pieces (103) is greater than the hardness of the first rotary cut piece (102).
7. The composite drill bit of claim 1, wherein the second plurality of rotary cut pieces (103) is a plurality of diamond particles.
8. The composite drill bit of claim 7, wherein the plurality of diamond particles are uniformly distributed on the outer surface of the cone portion (1012).
9. The composite drill bit of claim 1, wherein the first rotational cutting member (102) is a cutting edge.
10. The composite drill bit of claim 9, wherein the material of the cutting edge comprises tool steel or hard alloy steel.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202022978550.4U CN214944011U (en) | 2020-12-08 | 2020-12-08 | Composite drill bit |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202022978550.4U CN214944011U (en) | 2020-12-08 | 2020-12-08 | Composite drill bit |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN214944011U true CN214944011U (en) | 2021-11-30 |
Family
ID=79113907
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202022978550.4U Active CN214944011U (en) | 2020-12-08 | 2020-12-08 | Composite drill bit |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN214944011U (en) |
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2020
- 2020-12-08 CN CN202022978550.4U patent/CN214944011U/en active Active
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