US20180328116A1 - Drag bit with wear-resistant cylindrical cutting structure - Google Patents
Drag bit with wear-resistant cylindrical cutting structure Download PDFInfo
- Publication number
- US20180328116A1 US20180328116A1 US15/977,215 US201815977215A US2018328116A1 US 20180328116 A1 US20180328116 A1 US 20180328116A1 US 201815977215 A US201815977215 A US 201815977215A US 2018328116 A1 US2018328116 A1 US 2018328116A1
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- United States
- Prior art keywords
- pdc
- cutting
- drag bit
- bit
- face
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 238000005520 cutting process Methods 0.000 title claims abstract description 46
- 229910003460 diamond Inorganic materials 0.000 claims abstract description 20
- 239000010432 diamond Substances 0.000 claims abstract description 20
- 239000000956 alloy Substances 0.000 claims abstract description 6
- 229910045601 alloy Inorganic materials 0.000 claims abstract description 6
- 239000011248 coating agent Substances 0.000 claims abstract description 4
- 238000000576 coating method Methods 0.000 claims abstract description 4
- 239000011435 rock Substances 0.000 description 13
- 238000005553 drilling Methods 0.000 description 12
- 230000035515 penetration Effects 0.000 description 4
- 238000012360 testing method Methods 0.000 description 4
- 238000005299 abrasion Methods 0.000 description 3
- 230000015556 catabolic process Effects 0.000 description 3
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 239000000758 substrate Substances 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 1
- 230000000052 comparative effect Effects 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 238000005265 energy consumption Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 238000000034 method Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/46—Drill bits characterised by wear resisting parts, e.g. diamond inserts
- E21B10/56—Button-type inserts
- E21B10/567—Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
- E21B10/5673—Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts having a non planar or non circular cutting face
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/46—Drill bits characterised by wear resisting parts, e.g. diamond inserts
- E21B10/56—Button-type inserts
- E21B10/567—Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/42—Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/42—Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
- E21B10/43—Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/46—Drill bits characterised by wear resisting parts, e.g. diamond inserts
- E21B10/54—Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
- E21B10/55—Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits with preformed cutting elements
Definitions
- the invention relates to cutting and chipping drag drill bits used in drilling a rock formation to produce oil, natural gas or in other applications.
- a drill bit disclosed in U.S. Pat. No. 7,757,785 comprises a body with multiple blades, a conical part, a shoulder part and a gage part provided with wedge-shaped leached cutting elements mounted at a negative rake angle.
- the drill bit of U.S. Pat. No. 7,757,785 may not have a sufficient durability of cutting structure.
- a VTL test has shown that, when using a leached Polycrystalline Diamond Compact (PDC) cutter with a negative rake angle, a wear rate contingent on a drilled volume has an exponential relationship with three distinctive sections as shown in FIG. 1 .
- the first section is influenced by operation of a leached diamond layer of the PDC cutter, while wear of the diamond layer in this section is minimal.
- a non-leached diamond layer of the PDC cutter is engaged after the leached diamond layer is worn out, and the non-leached diamond layer is worn out faster.
- a hard alloy substrate of the PDC cutter diamond layer is engaged.
- a wear rate in the third section is higher compared to the first and second sections due to the fact that abrasion resistant of the hard alloy substrate is significantly less than that one of the PDC cutter diamond layer.
- a worn surface contact area of the PDC cutter diamond layer corresponds to each stage of the wear curve.
- a rapid increase in non-leached areas P 2 and P 3 actively generates heat leading to a rapid wear which causes an exponential increase in sections 2 and 3 of the wear curve.
- Such drill bit is worn quickly and loses its mechanical drilling speed.
- the main part of a rock is cut away by a first row of cutting elements mounted at a regular negative rake angle; therefore, energy consumption of the drag bit corresponds to that of a regular drag bit.
- the drag drill bit comprises a plurality of PDC cutting elements, each having a cylindrical shape and arranged in such manner that an axis of the cutting element each forms an angle from 5 to 40 degrees with respect to an axis perpendicular to the cutting face in a contact point between the PDC cutting elements and a rock face.
- the cylindrical PDC cutting elements have conical cutting ends and are spaced from the drill bit center at a distance not exceeding half of the nominal drill bit diameter.
- the PDC cutter elements of U.S. Pat. No. 6,332,503 are arranged only in the central part within half diameter of the drag drill; therefore, the PDC cutter elements cannot significantly change the overall required torque on the drag drill bit.
- This is due to the fact that cutters in the central part of the drag drill bit require application of a smaller rotational torque thereto due to a small diameter of the apparatus. Therefore, the prior art drill bit has the same disadvantages as bits with a negative rake angle in their central part, i.e. a rotational torque required for rotation depends highly on applied axial load. In order to increase a mechanical drilling speed for such drill bit, a high specific energy for rock breakdown is required.
- Another disadvantage is that the prior art drill bit is prone to intensive wear due to exponential dependence wear of cutting elements arranged at a negative rake angle outside half of a nominal diameter.
- An object of the invention is to increase drilling speed while improving wear resistance of cutting elements.
- the present invention provides a decrease in a cutting force acting on bit cutters, thus increasing wear resistance and drilling speed thereof.
- a drag bit with a wear-resistant cylindrical cutting structure comprising a body with a connecting thread, a central channel and output openings, blades protected by a hard alloy coating and comprising a gage part, a main cutting profile with a plurality of PDC cutters, wherein some of the PDC cutters have an axis angled with respect to a cutting direction.
- the PDC cutters are mounted covering a surface between a central bit axis to a nominal diameter of the drag bit, wherein each PDC cutter has a diamond layer, a leached layer, a chamfer, an end face and a cylindrical face, wherein axes if the PDC cutters are arranged at an angle from 40 to 90 degrees to the cutting direction, and a cutting process is performed by the chamfer, the end face and the cylindrical face of the PDC cutter diamond layer.
- the PDC cutter generates a smaller cutting force and provides increased wear resistance due to the fact that the PDC cutter is arranged such that its axis forms an angle from 40 to 90 degrees with respect to a cutting direction at a rock face contact point.
- the diamond layer of each PDC cutter can have a thickness from 0.5 mm to 3 mm.
- the leached layer of each PDC cutter can have a thickness from 0.1 mm to 1 mm.
- the chamfer of each PDC cutter can have a size from 0.05 mm to 1.5 mm.
- the secondary elements have a different purpose comparing to that of the present invention.
- the secondary elements act as an auxiliary tool, limiting penetration of a primary structure and stabilizing the drag bit during drilling.
- the secondary cutting elements cut away a negligible rock volume or enter operation as the primary structure wears away, and the main part of the rock is cut away by the first row of cutting elements.
- FIG. 1 shows an exponential wear curve obtained by VTL testing
- FIG. 2 illustrates areas of PDC cutter wear
- FIG. 3 is a perspective view of a drag bit according to the present invention.
- FIG. 4 is a sectional view of a PDC cutter according to the present invention performed along the A-A line;
- FIG. 5 is a sectional view of a PDC cutter according to the present invention performed along the A-A line during rock drilling;
- FIGS. 6, 7 illustrate “torque/axial load” and “torque/penetration rate per revolution” power characteristics for drag bits according to the present invention and for a conventional drag bit;
- FIG. 8 shows comparison between VTL test results of PDC cutters with the apparatus according to the present invention and a conventional apparatus
- FIG. 9 shows comparative wear of PDC cutter with the apparatus according to the present invention and a conventional apparatus.
- a drag bit with a wear-resistant cylindrical cutting structure comprises a body 1 with a connecting thread 2 for a drill stem, a central channel 3 with output openings 4 for supplying washing fluid, and blades 5 protected by a hard alloy coating and comprising a gage part 6 and a main cutting profile.
- the main cutting profile comprises PDC cutters 9 mounted in the range from the central bit axis 7 to the nominal bit diameter 8 , each PDC cutter 9 has a diamond layer with thickness D from 0.5 mm to 3 mm, having a leached layer L from 0.05 mm to 1.5 mm, a flat end face T, a cylindrical face C and a chamfer F from 0.05 mm to 1.5 mm, as shown in section A-A in FIG.
- the PDC cutter 9 is mounted such that a cutter axis O forms an angle A° from 40 to 90 degrees with respect to a cutting direction. Due to this arrangement, cutting process is performed by a combined working area 10 consisting of the chamfer F, the flat end face T, and the cylindrical face C of the PDC cutter 9 .
- the present invention is operated as follows.
- the drag bit is attached to the end of a drilling string (not shown) and lowered into a borehole bottom where drilling occurs.
- the PDC cutter 9 cuts away the rock with the combined working area 10 during rotation of the drag bit.
- An axial force appearing on the PDC cutters for supporting preset penetration rate per bit revolution and a cutting force will be lower compared to the conventional cutting with a negative rake angle. Therefore, as shown in FIG. 6 , a cutting force on the PDC cutters 9 mounted as described above creates a lower required rotational torque on the drag bit according to the present invention compared to a grad bit having conventionally mounted PDC cutters with a negative rake angle at equal axial loads on the drag bits. Further, as shown in FIG.
- a lower required rotational torque is formed on the drag bit according to the present invention compared to a drag bit with conventionally mounted PDC cutters at equal penetration rates per bit revolution.
- the disclosed drag bit requires less specific energy for rock breakdown compared to a drag bit with negative rake angles, thus providing high drilling speeds.
- the advantages of the lower rotational torque of the disclosed drag bit can be implemented by increasing bit rotation speed, thus increasing mechanical drilling speed.
- the disclosed arrangement of the PDC cutters 9 is more efficient in terms of impact resistance of the structure.
- the entire impact is taken, as illustrated in FIG. 5 , by the combined working area 10 of the diamond layer D, the combined working area 10 consisting of the flat end face T, the chamfer F, and the cylindrical face C.
- the combined working area 10 is significantly larger than that in the conventional arrangement with a negative rake angle, therefore breaking stress on the cutter will be significantly lower, thus preventing its breakdown.
- Abrasion resistance according to the VTL test in the first wear area (that is the operating area of the leached layer) of the leached PDC cutter 9 mounted according to the above method is more effective compared to a conventional arrangement with a negative rake angle ( FIG. 8 ).
- reserve of the diamond layer of the PDC cutter 9 is up to 10 times higher compared to a conventional arrangement of a PDC cutter with a negative rake angle, thus increasing operating life.
- the present invention provides decrease in cutting force on drag bit cutters decreasing torque capacity and increasing structural resistance of the drag bit during rock drilling.
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- Engineering & Computer Science (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Mechanical Engineering (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Crystallography & Structural Chemistry (AREA)
- Earth Drilling (AREA)
Abstract
The drag bit with a wear-resistant cylindrical cutting structure comprises a body with a connecting thread, a central channel and output openings, blades protected by a hard alloy coating and comprising a gage part, a main cutting profile with a plurality of PDC cutters, wherein some of the PDC cutters have an axis angled with respect to a cutting direction, wherein the PDC cutters are mounted in the range from the central bit axis to a nominal diameter of the drag bit, wherein each PDC cutter has a diamond layer, a leached layer, a chamfer, an end face and a cylindrical face, wherein axes of the PDC cutters are arranged at an angle of 40 to 90 degrees to the cutting direction, and cutting process is performed by the chamfer, the end face and the cylindrical face of the PDC cutter diamond layer.
Description
- The invention relates to cutting and chipping drag drill bits used in drilling a rock formation to produce oil, natural gas or in other applications.
- A drill bit disclosed in U.S. Pat. No. 7,757,785 comprises a body with multiple blades, a conical part, a shoulder part and a gage part provided with wedge-shaped leached cutting elements mounted at a negative rake angle.
- The drill bit of U.S. Pat. No. 7,757,785 may not have a sufficient durability of cutting structure.
- A VTL test has shown that, when using a leached Polycrystalline Diamond Compact (PDC) cutter with a negative rake angle, a wear rate contingent on a drilled volume has an exponential relationship with three distinctive sections as shown in
FIG. 1 . The first section is influenced by operation of a leached diamond layer of the PDC cutter, while wear of the diamond layer in this section is minimal. In the second section, a non-leached diamond layer of the PDC cutter is engaged after the leached diamond layer is worn out, and the non-leached diamond layer is worn out faster. In the third section, a hard alloy substrate of the PDC cutter diamond layer is engaged. A wear rate in the third section is higher compared to the first and second sections due to the fact that abrasion resistant of the hard alloy substrate is significantly less than that one of the PDC cutter diamond layer. As seen inFIG. 2 , a worn surface contact area of the PDC cutter diamond layer (P1, P2, P3, respectively) corresponds to each stage of the wear curve. A rapid increase in non-leached areas P2 and P3 actively generates heat leading to a rapid wear which causes an exponential increase insections - Also, known is a drag bit of U.S. Pat. No. 6,408,958, where primary cutting elements are mounted at a negative rake angle, and secondary cutting elements are mounted behind the primary elements and arranged on a blade in such manner that their axes form an angle of 3 to 5 degrees with respect to a cutting face.
- The secondary elements cut away a negligible rock volume or are engaged as a primary structure wears out. The main part of a rock is cut away by a first row of cutting elements mounted at a regular negative rake angle; therefore, energy consumption of the drag bit corresponds to that of a regular drag bit.
- The closest prior art for the present invention is a drag drill bit disclosed in U.S. Pat. No. 6,332,503, the drag drill bit comprises a plurality of PDC cutting elements, each having a cylindrical shape and arranged in such manner that an axis of the cutting element each forms an angle from 5 to 40 degrees with respect to an axis perpendicular to the cutting face in a contact point between the PDC cutting elements and a rock face. The cylindrical PDC cutting elements have conical cutting ends and are spaced from the drill bit center at a distance not exceeding half of the nominal drill bit diameter.
- Disadvantageously, the PDC cutter elements of U.S. Pat. No. 6,332,503 are arranged only in the central part within half diameter of the drag drill; therefore, the PDC cutter elements cannot significantly change the overall required torque on the drag drill bit. This is due to the fact that cutters in the central part of the drag drill bit require application of a smaller rotational torque thereto due to a small diameter of the apparatus. Therefore, the prior art drill bit has the same disadvantages as bits with a negative rake angle in their central part, i.e. a rotational torque required for rotation depends highly on applied axial load. In order to increase a mechanical drilling speed for such drill bit, a high specific energy for rock breakdown is required.
- Another disadvantage is that the prior art drill bit is prone to intensive wear due to exponential dependence wear of cutting elements arranged at a negative rake angle outside half of a nominal diameter.
- An object of the invention is to increase drilling speed while improving wear resistance of cutting elements.
- The present invention provides a decrease in a cutting force acting on bit cutters, thus increasing wear resistance and drilling speed thereof.
- This is achieved by a drag bit with a wear-resistant cylindrical cutting structure, the drag bit comprising a body with a connecting thread, a central channel and output openings, blades protected by a hard alloy coating and comprising a gage part, a main cutting profile with a plurality of PDC cutters, wherein some of the PDC cutters have an axis angled with respect to a cutting direction. The PDC cutters are mounted covering a surface between a central bit axis to a nominal diameter of the drag bit, wherein each PDC cutter has a diamond layer, a leached layer, a chamfer, an end face and a cylindrical face, wherein axes if the PDC cutters are arranged at an angle from 40 to 90 degrees to the cutting direction, and a cutting process is performed by the chamfer, the end face and the cylindrical face of the PDC cutter diamond layer.
- The PDC cutter generates a smaller cutting force and provides increased wear resistance due to the fact that the PDC cutter is arranged such that its axis forms an angle from 40 to 90 degrees with respect to a cutting direction at a rock face contact point.
- The diamond layer of each PDC cutter can have a thickness from 0.5 mm to 3 mm.
- The leached layer of each PDC cutter can have a thickness from 0.1 mm to 1 mm.
- The chamfer of each PDC cutter can have a size from 0.05 mm to 1.5 mm.
- It is important to note that in the drag bit disclosed in U.S. Pat. No. 6,408,958, the secondary elements have a different purpose comparing to that of the present invention. In particular, the secondary elements act as an auxiliary tool, limiting penetration of a primary structure and stabilizing the drag bit during drilling. As mentioned above, the secondary cutting elements cut away a negligible rock volume or enter operation as the primary structure wears away, and the main part of the rock is cut away by the first row of cutting elements.
- The present invention is further described with reference to the accompanying drawings, wherein:
-
FIG. 1 shows an exponential wear curve obtained by VTL testing; -
FIG. 2 illustrates areas of PDC cutter wear; -
FIG. 3 is a perspective view of a drag bit according to the present invention; -
FIG. 4 is a sectional view of a PDC cutter according to the present invention performed along the A-A line; -
FIG. 5 is a sectional view of a PDC cutter according to the present invention performed along the A-A line during rock drilling; -
FIGS. 6, 7 illustrate “torque/axial load” and “torque/penetration rate per revolution” power characteristics for drag bits according to the present invention and for a conventional drag bit; -
FIG. 8 shows comparison between VTL test results of PDC cutters with the apparatus according to the present invention and a conventional apparatus; -
FIG. 9 shows comparative wear of PDC cutter with the apparatus according to the present invention and a conventional apparatus. - As suggested by the present invention, a drag bit with a wear-resistant cylindrical cutting structure comprises a
body 1 with a connectingthread 2 for a drill stem, acentral channel 3 withoutput openings 4 for supplying washing fluid, andblades 5 protected by a hard alloy coating and comprising agage part 6 and a main cutting profile. The main cutting profile comprisesPDC cutters 9 mounted in the range from thecentral bit axis 7 to thenominal bit diameter 8, eachPDC cutter 9 has a diamond layer with thickness D from 0.5 mm to 3 mm, having a leached layer L from 0.05 mm to 1.5 mm, a flat end face T, a cylindrical face C and a chamfer F from 0.05 mm to 1.5 mm, as shown in section A-A inFIG. 4 . As seen inFIG. 5 , thePDC cutter 9 is mounted such that a cutter axis O forms an angle A° from 40 to 90 degrees with respect to a cutting direction. Due to this arrangement, cutting process is performed by a combinedworking area 10 consisting of the chamfer F, the flat end face T, and the cylindrical face C of thePDC cutter 9. - The present invention is operated as follows.
- The drag bit is attached to the end of a drilling string (not shown) and lowered into a borehole bottom where drilling occurs. As shown in
FIG. 5 , thePDC cutter 9 cuts away the rock with the combinedworking area 10 during rotation of the drag bit. An axial force appearing on the PDC cutters for supporting preset penetration rate per bit revolution and a cutting force will be lower compared to the conventional cutting with a negative rake angle. Therefore, as shown inFIG. 6 , a cutting force on thePDC cutters 9 mounted as described above creates a lower required rotational torque on the drag bit according to the present invention compared to a grad bit having conventionally mounted PDC cutters with a negative rake angle at equal axial loads on the drag bits. Further, as shown inFIG. 7 , a lower required rotational torque is formed on the drag bit according to the present invention compared to a drag bit with conventionally mounted PDC cutters at equal penetration rates per bit revolution. As a result, the disclosed drag bit requires less specific energy for rock breakdown compared to a drag bit with negative rake angles, thus providing high drilling speeds. The advantages of the lower rotational torque of the disclosed drag bit can be implemented by increasing bit rotation speed, thus increasing mechanical drilling speed. - The disclosed arrangement of the
PDC cutters 9 is more efficient in terms of impact resistance of the structure. During rock cutting, when unstable operation modes occur, the entire impact is taken, as illustrated inFIG. 5 , by the combinedworking area 10 of the diamond layer D, the combinedworking area 10 consisting of the flat end face T, the chamfer F, and the cylindrical face C. In the disclosed arrangement of thePDC cutters 9, the combinedworking area 10 is significantly larger than that in the conventional arrangement with a negative rake angle, therefore breaking stress on the cutter will be significantly lower, thus preventing its breakdown. - Abrasion resistance according to the VTL test in the first wear area (that is the operating area of the leached layer) of the leached
PDC cutter 9 mounted according to the above method is more effective compared to a conventional arrangement with a negative rake angle (FIG. 8 ). As shown inFIG. 9 , at equal wear height W of leached layers, reserve of the diamond layer of thePDC cutter 9 is up to 10 times higher compared to a conventional arrangement of a PDC cutter with a negative rake angle, thus increasing operating life. - Therefore, the above advantages increase abrasion resistance of the PDC cutter.
- The present invention provides decrease in cutting force on drag bit cutters decreasing torque capacity and increasing structural resistance of the drag bit during rock drilling.
Claims (4)
1. A drag bit with a wear-resistant cylindrical cutting structure, the drag bit comprising a body with a connecting thread, a central channel and output openings, blades protected by a hard alloy coating and comprising a gage part, a main cutting profile with a plurality of PDC cutters,
wherein some of the PDC cutters have an axis angled with respect to a cutting direction,
wherein the PDC cutters are mounted covering a surface between a central bit axis to a nominal diameter of the drag bit,
wherein each PDC cutter has a diamond layer, a leached layer, a chamfer, an end face and a cylindrical face,
wherein axes of the PDC cutters are arranged at an angle of 40 to 90 degrees to the cutting direction, and cutting process is performed by the chamfer, the end face and the cylindrical face of the PDC cutter diamond layer.
2. The drag bit of claim 1 , wherein the diamond layer of each PDC cutter has a thickness from 0.5 mm to 3 mm.
3. The drag bit of claim 1 , wherein the leached layer of each PDC cutter has a thickness from 0.1 mm to 1 mm.
4. The drag bit of claim 1 , wherein the chamfer of each PDC cutter has a size from 0.05 mm to 1.5 mm.
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
RU2017116580A RU2652726C1 (en) | 2017-05-11 | 2017-05-11 | Blade chisel with wear-resistant cylindrical cutting structure |
RU2017116580 | 2017-05-11 |
Publications (1)
Publication Number | Publication Date |
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US20180328116A1 true US20180328116A1 (en) | 2018-11-15 |
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Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US15/977,215 Abandoned US20180328116A1 (en) | 2017-05-11 | 2018-05-11 | Drag bit with wear-resistant cylindrical cutting structure |
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US (1) | US20180328116A1 (en) |
RU (1) | RU2652726C1 (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN109356600A (en) * | 2018-11-18 | 2019-02-19 | 中国电建集团铁路建设有限公司 | A kind of shield multi-layer diamond composite sheet bite |
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US5437343A (en) * | 1992-06-05 | 1995-08-01 | Baker Hughes Incorporated | Diamond cutters having modified cutting edge geometry and drill bit mounting arrangement therefor |
US20060086540A1 (en) * | 2004-10-23 | 2006-04-27 | Griffin Nigel D | Dual-Edge Working Surfaces for Polycrystalline Diamond Cutting Elements |
US7441612B2 (en) * | 2005-01-24 | 2008-10-28 | Smith International, Inc. | PDC drill bit using optimized side rake angle |
US7814998B2 (en) * | 2006-12-18 | 2010-10-19 | Baker Hughes Incorporated | Superabrasive cutting elements with enhanced durability and increased wear life, and drilling apparatus so equipped |
US20140151133A1 (en) * | 2012-12-03 | 2014-06-05 | Ulterra Drilling Technologies, L.P. | Earth boring tool with improved arrangement of cutter side rakes |
US8978789B1 (en) * | 2010-07-28 | 2015-03-17 | Us Synthetic Corporation | Polycrystalline diamond compact including an at least bi-layer polycrystalline diamond table, methods of manufacturing same, and applications therefor |
US20150209745A1 (en) * | 2013-11-21 | 2015-07-30 | Us Synthetic Corporation | Methods of fabricating polycrystalline diamond and polycrystalline diamond compacts |
US9316059B1 (en) * | 2012-08-21 | 2016-04-19 | Us Synthetic Corporation | Polycrystalline diamond compact and applications therefor |
US9394747B2 (en) * | 2012-06-13 | 2016-07-19 | Varel International Ind., L.P. | PCD cutters with improved strength and thermal stability |
US20170029338A1 (en) * | 2015-07-31 | 2017-02-02 | Baker Hughes Incorporated | Polycrystalline diamond compacts having leach depths selected to control physical properties and methods of forming such compacts |
US20170037686A1 (en) * | 2015-08-03 | 2017-02-09 | Baker Hughes Incorporated | Methods of forming and methods of repairing earth boring-tools |
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US6332503B1 (en) * | 1992-01-31 | 2001-12-25 | Baker Hughes Incorporated | Fixed cutter bit with chisel or vertical cutting elements |
US6408958B1 (en) * | 2000-10-23 | 2002-06-25 | Baker Hughes Incorporated | Superabrasive cutting assemblies including cutters of varying orientations and drill bits so equipped |
RU2377111C1 (en) * | 2008-05-26 | 2009-12-27 | Открытое акционерное общество "Волгабурмаш" (ОАО "Волгабурмаш") | Method of manufacture of diamont drill bit |
US9464490B2 (en) * | 2012-05-03 | 2016-10-11 | Smith International, Inc. | Gage cutter protection for drilling bits |
RU2549653C1 (en) * | 2014-01-15 | 2015-04-27 | Общество с ограниченной ответственностью Научно-производственное предприятие "БУРИНТЕХ" (ООО НПП "БУРИНТЕХ") | Blade drilling bit (versions) |
-
2017
- 2017-05-11 RU RU2017116580A patent/RU2652726C1/en active
-
2018
- 2018-05-11 US US15/977,215 patent/US20180328116A1/en not_active Abandoned
Patent Citations (11)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5437343A (en) * | 1992-06-05 | 1995-08-01 | Baker Hughes Incorporated | Diamond cutters having modified cutting edge geometry and drill bit mounting arrangement therefor |
US20060086540A1 (en) * | 2004-10-23 | 2006-04-27 | Griffin Nigel D | Dual-Edge Working Surfaces for Polycrystalline Diamond Cutting Elements |
US7441612B2 (en) * | 2005-01-24 | 2008-10-28 | Smith International, Inc. | PDC drill bit using optimized side rake angle |
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US20170029338A1 (en) * | 2015-07-31 | 2017-02-02 | Baker Hughes Incorporated | Polycrystalline diamond compacts having leach depths selected to control physical properties and methods of forming such compacts |
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CN109356600A (en) * | 2018-11-18 | 2019-02-19 | 中国电建集团铁路建设有限公司 | A kind of shield multi-layer diamond composite sheet bite |
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