EP1006257B1 - Drehbohr-Fräsmeissel - Google Patents

Drehbohr-Fräsmeissel Download PDF

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Publication number
EP1006257B1
EP1006257B1 EP99309665A EP99309665A EP1006257B1 EP 1006257 B1 EP1006257 B1 EP 1006257B1 EP 99309665 A EP99309665 A EP 99309665A EP 99309665 A EP99309665 A EP 99309665A EP 1006257 B1 EP1006257 B1 EP 1006257B1
Authority
EP
European Patent Office
Prior art keywords
bit
pads
outer profile
drill bit
formation
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.)
Expired - Lifetime
Application number
EP99309665A
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English (en)
French (fr)
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EP1006257A3 (de
EP1006257A2 (de
Inventor
Douglas Caraway
Robin Macmillan
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
ReedHycalog UK Ltd
Original Assignee
Camco International UK Ltd
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Priority claimed from US09/447,059 external-priority patent/US6371226B1/en
Priority claimed from US09/444,072 external-priority patent/US6193000B1/en
Application filed by Camco International UK Ltd filed Critical Camco International UK Ltd
Publication of EP1006257A2 publication Critical patent/EP1006257A2/de
Publication of EP1006257A3 publication Critical patent/EP1006257A3/de
Application granted granted Critical
Publication of EP1006257B1 publication Critical patent/EP1006257B1/de
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

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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
    • E21B10/54—Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
    • 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

Definitions

  • the invention relates to rotary drag-type drill bits for drilling in subsurface formations.
  • the invention is a rotary drag-type drill bit with wearable pads formed of an impregnated diamond/matrix material.
  • Diamond impreg bits may be generally described as being of the kind comprising a bit body having a leading surface comprising a plurality of pads separated by channels for drilling fluid, at least some of the pads each having an abrasive surface including particles of superhard material.
  • the particles of superhard material may be natural or synthetic diamonds, or small bodies of polycrystalline diamond, set in the outer surface of a pad, or the pad may include an outer layer impregnated with superhard particles which, again, may be natural or synthetic diamonds or particles of polycrystalline diamond. It is also possible to combine the two arrangements.
  • Such bits are particularly suitable for drilling through harder subsurface formations.
  • a lighter set bit i.e. a bit having fewer superhard particles disposed over the surface of the bit
  • a heavier set bit is actually used since such a bit will be required in order to drill through the harder formations likely to be met deeper in the borehole.
  • the rate of penetration (ROP) of the bit may be lower than that could be achieved by using a lighter set bit.
  • EP 0554568 and EP 0314 953 describes a drill bit having areas upon which a number of preformed cutting elements are mounted.
  • the present invention therefore sets out to provide a rotary drill bit of the above-mentioned type where the same bit can act as a lighter set bit during initial drilling but can act as a more heavily set bit as drilling proceeds.
  • a rotary drag-type drill bit comprising a bit body having a central longitudinal axis a leading surface, and a plurality of continuous wearable pads separated by a plurality of flow channels for a drilling fluid, the continuous wearable pads being impregnated with particles of superhard material and having an abrasive surface, a first set of the continuous wearable pads forming a first outer profile the first outer profile forming the leading surface of the drill bit, a second set of the continuous wearable pads forming a second outer profile distinct from the leading surface of the bit, at least a portion of the second outer profile being disposed inwardly with respect to the bit body along the central longitudinal axis from the leading surface of the bit.
  • inwardly and outwardly or “inner” and “outer” refer to positions relative to the centre of the bit body, i.e. a point lying on the central longitudinal axis of rotation of the bit.
  • the overall profile of a set of inner pads may be generally similar to the overall profile of a set of outer pads, the profiles merely being displaced relatively to one another, for example relatively displaced in the direction of the longitudinal axis of the drill bit.
  • the abrasive surface of any of the pads may be smoothly and continuously curved so that the outer profile defined by the pad surface follows the contour of the surface itself.
  • the abrasive surface of a pad may comprise higher and lower regions, in which case the outer profile is defined by the higher regions of the pad surface, the lower regions lying inwardly of the outer profile.
  • the drill bit includes a plurality of pads having outer profiles which are disposed inwardly or outwardly of the outer profiles of the other pads, so that under all conditions a plurality of pads engage the formation.
  • some pads may have outer profiles which together define a reference profile, the bit including pads having outer profiles lying inwardly of the reference profile as well as pads having outer profiles lying outwardly of the reference profile.
  • the pads may extend outwardly away from the central longitudinal axis of the bit towards the outer periphery thereof.
  • the outer profile of each pad may be displaced inwardly or outwards with respect to the profile of the pad on the leading and/or trailing side thereof with respect to the normal direction of rotation of the drill bit.
  • Each pad may extend generally radially outwards from the central longitudinal axis of the bit or may be offset forwardly or rearwardly of a radius of the bit, with respect to the direction of normal rotation of the bit.
  • each pad may extend away from the axis in a spiral.
  • the outer profiles of the pads, at the outer periphery of the bit are preferably equidistant from the central longitudinal axis of rotation of the bit so that all of the pads engage the side walls of the borehole.
  • the particles of superhard material may be set in the outer surface of a pad or the pad may include an outer layer impregnated with superhard particles. Such arrangements may be combined by some pads having particles set in their outer surface while other pads include an outer layer impregnated with superhard particles. Arrangements are also possible where the pad includes both an outer layer impregnated with superhard particles and additional superhard particles set in the outer surface of the impregnated layer.
  • the superhard particles may be, but are not limited to, natural diamonds, synthetic diamonds, or bodies of polycrystalline diamond material. Where the particles are of polycrystalline diamond they preferably comprise but are not limited to thermally stable polycrystalline diamond material.
  • bit body or at least the part thereof forming the pads, may be formed from solid infiltrated matrix material.
  • the rotary drag-type drill bit 6 of the present invention has a longitudinal axis 9, a bit body 8 with a first end 5 which is adapted to be secured to a drill string (not shown). Typically, threads 4 are used for attachment to the drill string, but other forms of attachment may also be utilized.
  • leading surface 10 of the drill bit 6 is formed with a plurality of wearable, outwardly extending pads 11 separated by flow channels 12 for drilling fluid which lead to junk slots 13 at the outer periphery of the bit.
  • the junk slots 13 extend generally axially upwardly across the gauge portion 14 of the drill bit.
  • the bit body 8 is rotated by some external means while the drill bit 6 is forced into the material being drilled.
  • the rotation under load causes the leading surface 10 to engage the drilled material and remove the material in a scraping and/or gouging action.
  • the bit body 8 has internal passaging (not shown) with allows pressurized drilling fluid to be supplied from the surface to a plurality of orifices 3. These orifices 3 discharge the drilling fluid to clean and cool the leading surface 10 as it engages the material being drilled. The drilling fluid also transports the drilled material to the surface for disposal
  • each pad 11 is impregnated in known manner with a large number of abrasive particles of superhard material (not shown) which may be natural or synthetic diamond.
  • the diamond particles may be of a size in the range of from 2-1000 particles/carat.
  • the diamond impregnated layer may for example have a thickness in the range of 3-25mm.
  • the bit body 8 is molded, using a powder metallurgy process, and the diamond particles are impregnated into the surface of the bit body by applying a layer of tungsten carbide paste, or premolded parts in which the particles are suspended, to the interior surface of the mold along surfaces corresponding to the lands 11.
  • the paste may be formed with the tungsten carbide, the particles and other materials mixed with an organic binder or other form of binder material. strips of clay or other suitable mold material are also applied to the interior surface of the mold to define the waterways 10. The mold is then packed with dry particulate tungsten carbide or equivalent material.
  • the mold is then placed in a furnace where a suitable copper or other alloy is infiltrated downwardly though the carbide particles so as to form, upon cooling, a body of solid infiltrated matrix material in the shape of the mold, and having diamond particles embedded in its outer surface.
  • a suitable copper or other alloy is infiltrated downwardly though the carbide particles so as to form, upon cooling, a body of solid infiltrated matrix material in the shape of the mold, and having diamond particles embedded in its outer surface.
  • the invention is particularly applicable to impregnated drill bits, it may also be applicable to drill bits where larger natural or synthetic diamonds are set in the outer surface of the pads on the bit body.
  • the outer surfaces of all of the abrasive pads 11 lie on the same overall common cutting profile of the drill bit so that, during drilling, all of the pads act on the formation simultaneously.
  • pads 11 have outer profiles which are at different locations with respect to the bit body, and one such arrangement is shown diagrammatically in Figure 2, where the reference 9 indicates the central longitudinal axis of rotation of the drill bit.
  • the outermost of the abrasive pads 11 with respect to the bit body define a leading surface 17, 21, 22, 30 of the bit 6 as it rotates about its central longitudinal axis 9.
  • a set of four of the pads 11, indicated at C in Figures 1 and 2 have an outer cutting profile 15.
  • a set of two of the pads, indicated at B in Figures 1 and 2 have an outer cutting profile 16 which is disposed outwardly of the cutting profile 15 of the pads C, and is distinct from the cutting profile 15 of pass C.
  • a further pair of pads, indicated at A, in Figures 1 and 2 have an outer cutting profile 17 which is disposed outwardly of both the cutting profiles 15 and 16, and is distinct from both.
  • the outer cutting profile 17 of the pads 11 in set A form the leading surface of the bit.
  • a useful feature of the abrasive impregnated pads 11 is that the pads 11 are wearable. As the cutting surface wears, new abrasive cutting elements are exposed. The result is that, even though worn, the cutting surface continues to remove formation at the same cutting rate as an unworn cutting surface.
  • the pads A begin to wear while remaining equally effective in formation removal as when new, as new abrasive particles are continuously exposed at the surface of the pads A.
  • the pads A have a substantially constant abrasive area as they wear.
  • each set of pads A, B, C each have a substantially constant abrasive area as they wear. However, the total abrasive area of the bit increases incrementally, first as set B of the pads, and later as set C of pads, begin to remove formation.
  • any number of different sets of pads having cutting profiles at different positions may be provided, although two to five such sets are preferred.
  • the different cutting profiles maybe distributed in any manner between the pads on the drill bit, although symmetrical distributions are preferred, such as shown in Figure 1, to ensure that stability of the bit as it rotates is maintained, regardless of how many pads are actually acting on the formation. Assymetric distributions may be used for some applications. Although a total of eight generally radially extending pads are shown in Figure 1, it will be appreciated that any number and configuration of pads may be employed, for example the pads may be of any of the configurations used in the prior art, but with the difference that, according to the invention, the outer profiles of different sets of pads are at different positions relative to the bit body.
  • Figure 3 shows a modified version of the arrangement of Figure 2 where the profiles of the three sets of pads, instead of converging gradually towards the outer periphery of the drill bit, are stepped, as indicated at 19 in Figure 3, again to ensure that the cutting profiles of the sets of pads are equidistant from the central longitudinal axis 9 at the periphery of the bit, thereby ensuring that the diameter of the borehole does not vary significantly with differential wear of the pads.
  • the outer abrasive surfaces of the pads are smoothly curved as they extend outwardly away from the central longitudinal axis of the bit and consequently the outer cutting profiles of the pads follow and are close to the surface contours of the pads themselves.
  • the outer surfaces of the pads may not be smoothly and continuously curved but may comprise higher and lower regions, in which case the outer profile is defined by the higher regions of the surface, the lower regions lying inwardly of the outer profile.
  • Such an arrangement is shown diagrammatically in Figure 4 where the pads C having the innermost cutting profile 20 have a surface profile which undulates as it extends outwardly away from the central longitudinal axis 9 of the drill bit. The cutting profile 20 extends thus across the tops of the undulations.
  • the intermediate pads B are smoothly and continuously curved so that their cutting profile follows the actual surface of the pads.
  • the pads A, having the outermost cutting profile 21, have a generally saw tooth configuration along their length.
  • the operation of the drill bit 8 of Figures 2 and 3 is shown by an example of an 8-3/8 inch (213 mm) 642 type diamond impregnated bits made by Reed-Hycalog.
  • the bit 8 has a total of fifteen pads 11 arranged in a configuration similar to Figure 2.
  • the 642 type bit there are five pads in set A, five pads in set B and five pads 11 in set C.
  • the pads 11 of set A in this bit are disposed outwardly by 2 mm from the pads 11 of set B.
  • the pads 11 of set C in this bit are disposed outwardly by 2 mm from the pads 11 of set C.
  • This bit is designed to run in the Naricual formation, in Venezuela.
  • a 642 type bit of the present invention is typically run in this formation at 1200 RPM with an applied drilling weight of 8000 pounds (3629 kg).
  • the bit initially drills the upper part of this formation with only the five pads in set A. In this operating condition, the bit can drill about .05mm of the formation per bit revolution. As the bit drills, the pads 11 continually wear at a known rate.
  • the wear rate of the bit is determined by the size and type of diamond grit, and the concentration of the diamond grit in the matrix. The bit designer adjusts these to cause the bit to wear in a known manner. Oftentimes, the adjustments are so precise, bits run in adjacent boreholes will have differing diamond grit constituencies. Although not a requirement, all the pads 11 of the matrix on the bit in this example have the same diamond constituencies.
  • the diamonds particles are a relatively coarse .5 mm average diameter with a concentration of 50%-55%.
  • the pads A wear about 2mm in 500 feet (152 meters) of drilling.
  • the five pads in set B join the five pads in set A for a total of ten pads removing formation.
  • the bit now drills only about .03 mm/revolution.
  • the pads of set A and set B have worn an additional 2mm so that now all 15 pads of sets A, B and C join to drill the borehole to its final depth. With all 15 pads in contact the bit drills only about .01mm/revolution.
  • a single 642 type bit of the present example is expected to drill this interval in 100-150 hours.
  • the wearable pads 11 allow the bit to drill relative quickly in the less tough, upper section of the interval. As the formation becomes progressively denser, tougher and more abrasive in the middle and lower sections, more of the pads 11 come in contact with the formation as the pads wear.
  • a characteristic of the bit is that the drilling rate does not significantly change as the sets of pads in contact with the formation wear. Instead, the drilling rate changes only when the wear causes additional pads to contact the formation.
  • an 8-1/2 inch (216 mm) 672 type diamond impregnated bits made by Reed-Hycalog has a total of twenty-four pads 11 arranged in a configuration similar to Figures 1 and 2.
  • the 642 type bit there are eight pads in set A, eight pads in set B and eight pads 11 in set C.
  • the pads 11 of set A in this bit are disposed outwardly by 1.0 mm from the pads 11 of set B.
  • the pads 11 of set B in this bit are disposed outwardly by 1.0 mm from the pads 11 of set C.
  • This bit is designed to run in the Mirador formation, in Columbia.
  • a 642 type bit of the present invention is typically run in this formation at 600 RPM with an applied drilling weight of 8000 pounds (3629 kg).
  • the bit initially drills the upper part of this formation with only the five pads in set A. In this operating condition, the bit can drill about .04 mm of the formation per bit revolution. As the bit drills, the pads 11 continually wear at a known rate.
  • the diamonds particles are a relatively coarse 0.4mm average diameter with a concentration of 50%-55%.
  • the pads A wear about 1 mm in 100 feet (30 meters) of drilling.
  • the eight pads in set B join the eight pads in set A for a total of sixteen pads removing formation.
  • sixteen pads in contact the bit now drills only about .03mm/revolution.
  • the pads of set A and set B have worn an additional 1mm so that now all twenty-four pads of sets A, B and C join to drill the borehole to its final depth. With all twenty-four pads in contact the bit drills only about .01 mm/revolution.
  • a single 672 type bit of the present example is expected to drill this interval in 40-80 hours.
  • the wearable pads 11 allow the bit to drill relative quickly in the less tough, upper section of the interval. As the formation becomes progressively denser, tougher and more abrasive in the middle and lower sections, more of the pads 11 come in contact with the formation as the pads wear. Again, the drilling rate changes only when the wear of the pads cause additional pads to contact the formation.
  • Figure 4 shows only diagrammatically the principle that the actual surfaces of the pads do not require to be smoothly and continuously curved.
  • Figure 5 shows diagrammatically a circumferential cross-section through a radial pad of a conventional prior art impregnated drill bit.
  • the outer surface of the pad, which abrades the formation, is indicated at 22 and the channels or waterways along each side of the pad are indicated at 23.
  • impregnated drill bits can be made to cut a wider variety of different formations efficiently by configuring the circumferential cross-sectional shape of the pads 11 so that not all of the pad 11 acts on the formation at the same time.
  • Typical configurations in accordance with the invention are shown diagrammatically in Figures 6-12.
  • the outer surface of the pad 11 is shaped to provide two inclined surfaces 25 facing respectively forwardly and rearwardly with reference to the normal direction of rotation of the drill bit during drilling, as indicated by the arrow 26.
  • the wearable pads 11 have a surface acting on the formation which forms the leading surface of the bit 6. Other surfaces of the pads 11 are disposed inwardly with respect to the bit body along the longitudinal axis from the leading surface of the bit 6.
  • the outer surface 29 of the pad 11 is convexly curved in cross-section but the radius of curvature of the pad is significantly smaller than the radius of curvature of the overall cutting profile 30A of the drill bit so that not all of the surface 29 acts on the formation simultaneously. Only the section of the surface indicated by numeral 44 initially acts on the formation. In operation, the surface 29 wears to a new cutting profile 40A. This causes the initial area of the abrasive surface 44 on the pad 11 to increase to that indicated by 42A as the bit 6 drills.
  • the outer surface of the pad 11 is formed with two longitudinal convexly curved ribs 31 separated by a groove 32.
  • the initial radius of curvature of the overall cutting profile is indicated as 30B, and each rib 31 will only have a limited area acting on the formation.
  • the ribs 31 wear to a new cutting profile 40B. This causes the initial area of the abrasive surface on each rib 31 of the pad 11 to increase as indicated by 42B as the bit 6 drills.
  • FIG 11 three generally triangular ribs 33 on the pad 18 are separated by triangular grooves 34.
  • the initial radius of curvature of the overall cutting profile is indicated as 30C, and each groove 34 will only have a limited area acting on the formation.
  • the ribs 33 wear to a new cutting profile 40C. This causes the initial area of the abrasive surface on each rib 33 of the pad 11 to increase as indicated by 42C as the bit 6 drills.
  • each rib 35 will only have a limited area acting on the formation.
  • the ribs 35 wear to a new cutting profile 40B. This also causes the initial area of the abrasive surface on each rib 35 of the pad 11 to increase as the bit 6 drills.
  • a first portion of surface of the wearable pads 11 form the outer profile of the bit 6, and a second portion of the surface of the wearable pads 11 is disposed inwardly with respect to the bit body 8 along the longitudinal axis 9 from the leading surface of the bit 6.
  • the second portion of the surface disposed inwardly with respect to the bit body 8 along the longitudinal axis 9 from the leading surface of the bit 6 continuously increases in surface area. The result is that the wearable pads 11 will effectively become heavier set as wear occurs, which is desirable for the reasons previously explained.
  • the wearable pads 11 before they begin to wear, the wearable pads 11 form a first outer profile 30A, 30B, 30C, 30D.
  • the set of wearable pads 11 which form the first outer profile 30A, 30B, 30C, 30D combine to form a first contact area acting on the formation.
  • the wearable pads 11 Once the bit 6 has been in operation for a period of time the wearable pads 11 will form a secondary outer profile 40A, 40B, 40C, 40D.
  • the set of wearable pads 11 which form the secondary outer profile 40A, 40B, 40C, 40D combine to form a second contact area acting on the formation that is greater than the first contact area. The result is that the wearable pads 11 will effectively become heavier set as wear occurs, which is desirable for the reasons previously explained.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Mechanical Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Processing Of Stones Or Stones Resemblance Materials (AREA)
  • Earth Drilling (AREA)

Claims (9)

  1. Rotary-Blattbohrmeißel, der einen Meißelkörper (8) mit einer Längsmittelachse (9), einer vorderen Fläche (10) und einer Vielzahl von durchgehenden abnutzbaren Blöcken (11), getrennt durch eine Vielzahl von Strömungskanälen (12) für einen Spülschlamm, umfaßt, wobei die durchgehenden abnutzbaren Blöcke (11) mit Teilchen aus einem superharten Material imprägniert werden und eine abschleifende Oberfläche haben, wobei ein erster Satz (A) der durchgehenden abnutzbaren Blöcke (11) ein erstes äußeres Profil (17) bildet, wobei das erste äußere Profil (17) die vordere Fläche (10) des Bohrmeißels bildet, ein zweiter Satz (C) der durchgehenden abnutzbaren Blöcke (11) ein zweites äußeres Profil (15) bildet, getrennt von der vorderen Fläche des Meißels, wobei wenigstens ein Abschnitt des zweiten äußeren Profils (15) im Verhältnis zum Meißelkörper (8) längs der Längsmittelachse (9) von der vorderen Fläche des Meißels nach innen angeordnet wird.
  2. Rotary-Blaftbohrmeißelw nach Anspruch 1, bei dem das superharte Material Diamant ist.
  3. Rotary-Blattbohrmeißel nach Anspruch 2, bei dem der Diamant natürlichen Diamanten mit einer Größe von etwa 2 bis 1000 Diamanten pro Karat umfaßt.
  4. Rotary-Blattbohrmeißel nach Anspruch 2, bei dem der Diamant polykristallinen Diamanten umfaßt.
  5. Rotary-Blattbohrmeißel nach einem der vorhergehenden Ansprüche, bei dem ein dritter Satz (B) der abnutzbaren Blöcke (11) ein drittes äußeres Profil (16) zwischen dem zweiten äußeren Profil (15) und der vorderen Fläche (10) des Meißels bildet.
  6. Rotary-Blattbohrmeißel nach einem der vorhergehenden Ansprüche, bei dem das zweite äußere Profil (15) um wenigstens etwa 2 mm von der vorderen Fläche (10) des Meißels versetzt wird.
  7. Rotary-Blattbohrmeißel nach Anspruch 5, bei dem das dritte äußere Profil (16) um wenigstens etwa 1 mm vom zweiten äußeren Profil (15) versetzt wird.
  8. Rotary-Blattbohrmeißel nach einem der vorhergehenden Ansprüche, bei dem das zweite äußere Profil (15) und die vordere Fläche (10) des Meißels an einem äußeren Umfang des Meißels zusammenlaufen.
  9. Rotary-Blattbohrmeißel nach Anspruch 8, bei dem ein dritter Satz der abnutzbaren Blöcke (11) ein drittes äußeres Profil zwischen dem zweiten äußeren Profil und der vorderen Fläche des Meißels bildet, wobei das dritte äußere Profil, das zweite äußere Profil und die vordere Fläche des Meißels alle am äußeren Umfang des Meißels zusammenlaufen.
EP99309665A 1998-12-04 1999-12-01 Drehbohr-Fräsmeissel Expired - Lifetime EP1006257B1 (de)

Applications Claiming Priority (6)

Application Number Priority Date Filing Date Title
US447059 1982-12-06
US11085398P 1998-12-04 1998-12-04
US110853P 1998-12-04
US444072 1999-11-22
US09/447,059 US6371226B1 (en) 1998-12-04 1999-11-22 Drag-type rotary drill bit
US09/444,072 US6193000B1 (en) 1999-11-22 1999-11-22 Drag-type rotary drill bit

Publications (3)

Publication Number Publication Date
EP1006257A2 EP1006257A2 (de) 2000-06-07
EP1006257A3 EP1006257A3 (de) 2000-09-13
EP1006257B1 true EP1006257B1 (de) 2004-02-25

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EP99309665A Expired - Lifetime EP1006257B1 (de) 1998-12-04 1999-12-01 Drehbohr-Fräsmeissel

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EP (1) EP1006257B1 (de)
DE (1) DE69915009T2 (de)

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8573330B2 (en) 2009-08-07 2013-11-05 Smith International, Inc. Highly wear resistant diamond insert with improved transition structure
US8579053B2 (en) 2009-08-07 2013-11-12 Smith International, Inc. Polycrystalline diamond material with high toughness and high wear resistance
US8695733B2 (en) 2009-08-07 2014-04-15 Smith International, Inc. Functionally graded polycrystalline diamond insert
US8758463B2 (en) 2009-08-07 2014-06-24 Smith International, Inc. Method of forming a thermally stable diamond cutting element
US8857541B2 (en) 2009-08-07 2014-10-14 Smith International, Inc. Diamond transition layer construction with improved thickness ratio
US9482056B2 (en) 2011-12-30 2016-11-01 Smith International, Inc. Solid PCD cutter

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR1555163A (de) * 1968-02-23 1969-01-24
US4128136A (en) * 1977-12-09 1978-12-05 Lamage Limited Drill bit
GB8418481D0 (en) * 1984-07-19 1984-08-22 Nl Petroleum Prod Rotary drill bits
US5238074A (en) * 1992-01-06 1993-08-24 Baker Hughes Incorporated Mosaic diamond drag bit cutter having a nonuniform wear pattern

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8573330B2 (en) 2009-08-07 2013-11-05 Smith International, Inc. Highly wear resistant diamond insert with improved transition structure
US8579053B2 (en) 2009-08-07 2013-11-12 Smith International, Inc. Polycrystalline diamond material with high toughness and high wear resistance
US8695733B2 (en) 2009-08-07 2014-04-15 Smith International, Inc. Functionally graded polycrystalline diamond insert
US8758463B2 (en) 2009-08-07 2014-06-24 Smith International, Inc. Method of forming a thermally stable diamond cutting element
US8857541B2 (en) 2009-08-07 2014-10-14 Smith International, Inc. Diamond transition layer construction with improved thickness ratio
US9482056B2 (en) 2011-12-30 2016-11-01 Smith International, Inc. Solid PCD cutter

Also Published As

Publication number Publication date
DE69915009D1 (de) 2004-04-01
EP1006257A3 (de) 2000-09-13
EP1006257A2 (de) 2000-06-07
DE69915009T2 (de) 2004-12-30

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