US20060260845A1 - Stable Rotary Drill Bit - Google Patents

Stable Rotary Drill Bit Download PDF

Info

Publication number
US20060260845A1
US20060260845A1 US11382571 US38257106A US2006260845A1 US 20060260845 A1 US20060260845 A1 US 20060260845A1 US 11382571 US11382571 US 11382571 US 38257106 A US38257106 A US 38257106A US 2006260845 A1 US2006260845 A1 US 2006260845A1
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US
Grant status
Application
Patent type
Prior art keywords
bit
blades
cutting
drill
elements
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
Application number
US11382571
Inventor
Simon Johnson
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
ReedHycalog 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

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Classifications

    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B10/00Drill bits
    • E21B10/46Drill bits characterised by wear resisting parts, e.g. diamond inserts
    • E21B10/54Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B10/00Drill bits
    • E21B10/42Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B10/00Drill bits
    • E21B10/42Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
    • E21B10/43Rotary 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

Abstract

A drill bit comprises a bit body having a plurality of upstanding main blades formed thereon. The main blades have a plurality cutting elements mounted thereon, and they are shaped such that a cutting profile of the bit includes a nose portion, an inner cone region located radially inwards of the nose portion and an outer region located radially outwards of the nose portion. The bit further has at least one additional blade. The additional blade carrying cutting elements located radially inwards of the outer region of the cutting profile, but being substantially free of cutting elements located in the outer region of the cutting profile.

Description

    BACKGROUND OF THE INVENTION
  • [0001]
    This invention relates to a rotary drill bit that is vibrationally stable, and in particular to a rotary drill bit suitable for use in the formation of subterranean well bores.
  • [0002]
    The cost of drilling a borehole in the subsurface formations of the Earth is dependent on the length of time taken to drill the borehole to the desired depth. The time spent drilling is in turn determined by the rate of penetration and the number of times the drill bit has to be changed in order to achieve the target depth.
  • [0003]
    A known form of drill bit for use in the formation of subterranean well bores comprises a bit body having formed thereon a series of upstanding blades. Each blade is provided with a series of cutting elements. The cutting elements each typically comprise a substrate of, for example, tungsten carbide to which is bonded a table of a superhard material, for example in the form of polycrystalline diamond. Between the blades are formed flow channels to which drilling fluid is supplied in use, the drilling fluid serving to clean and cool the cutting elements and to carry away material removed by the drill bit.
  • [0004]
    In use, the drill bit is rotated about its axis while an axially directed load is applied thereto. As a result, material is gouged, scraped or abraded from the formation in which the bore hole is being formed, the material being carried away, as hereinbefore described, by the drilling fluid.
  • [0005]
    The cutting elements naturally wear away in use due to the varying abrasive nature of the subsurface rock formations. In practice however, the expected economic life of the known drill bits is often degraded due to the cutters being chipped or broken.
  • [0006]
    In these cases, the known drill bits are known to suffer from literal and torsional vibrations, and these vibrations cause the known drill bit to deviate from its desired smooth path through the formation. This results in the application of large loadings to the cutting elements mounted on the bit which may cause damage thereto, which results in greatly accelerated degradation of the cutting elements. This is particularly apparent when drilling rock formations with bits of relatively large diameter. Obviously this is undesirable and it is an object of the invention to provide a drill bit of improved stability.
  • BRIEF SUMMARY OF THE INVENTION
  • [0007]
    According to the present invention there is provided a drill bit comprising a bit body having a plurality of upstanding main blades formed thereon, the blades having a plurality cutting elements mounted thereon, the blades being shaped such that a cutting profile of the bit includes a nose portion, an inner cone region located radially inwards of the nose portion and an outer region located radially outwards of the nose portion, the bit further comprising at least one additional blade, the additional blade carrying cutters located radially inwards of the outer region, but being substantially free of cutters located in the outer region.
  • [0008]
    Such an arrangement is advantageous in that the number of cutters located in the cone region, relative to the number of cutters on the outer region, can be increased, and these additional cutters create a restoring force to prevent the drill bit moving off its center of rotation while drilling. This can be used to achieve an improvement in bit stability, reducing lateral vibration thereof.
  • [0009]
    The outer regions of the additional blades are conveniently of increased blade height as compared to the outer regions of the main blades. As a result, during drilling, the outer regions of the additional blades can bear against the surface of the formation being drilled, thereby limiting the depth of cut achievable by the cutting elements, and this can be used to limit lateral and torsional vibration.
  • [0010]
    Although applicable to drill bits of relatively small diameter, the invention is particularly applicable to large diameter drill bits, for example bits of diameter falling within the range of approximately 12¼″ to 26″.
  • [0011]
    The cutting elements preferably comprise polycrystalline diamond compact cutters, but other arrangements are possible, for example the cutting elements could comprise diamond crystals, or polycrystalline diamonds, mounted upon or embedded in the blades.
  • [0012]
    The outer surface of the outer regions of the additional blades may be rendered of improved resistance to wear. This could be achieved for example by mounting suitably shaped and positioned, non-cutting, polycrystalline diamond compact elements thereon. Alternatively, or additionally, a hard facing material coating may be applied thereto.
  • BRIEF DESCRIPTION OF THE DRAWINGS
  • [0013]
    The invention will further be described, by way of example, with reference to the accompanying drawings.
  • [0014]
    FIG. 1 is a diagrammatic view of a typical known drill rig and a section through a portion of the Earth where a borehole is being drilled.
  • [0015]
    FIG. 2 is an end view of a drill bit in accordance with one embodiment of the invention.
  • [0016]
    FIG. 3 is a perspective view of the drill bit of FIG. 2.
  • [0017]
    FIG. 4 is a side view of the drill bit of FIG. 2.
  • [0018]
    FIG. 5 is a diagram illustrating the cutting profile of the bit of FIG. 2.
  • [0019]
    FIG. 6 is a view similar to FIG. 2 of an alternative embodiment of a drill bit of the invention.
  • [0020]
    FIG. 7 is a sectional view along the line 7-7 of FIG. 6.
  • DETAILED DESCRIPTION OF THE INVENTION AND THE PREFERRED EMBODIMENT
  • [0021]
    Referring first to FIG. 1, a drilling system 1, is shown and comprises a drill rig 2, with a drill string 3, and a drill bit 6, located within borehole 5. The drill bit 6 may be rotated from the surface by rotation of the drill string. Alternatively or additionally the drill bit 6, may be rotated by a downhole motor or turbine 4.
  • [0022]
    Referring to FIGS. 2 to 5 there is shown a drill bit comprising a bit body 10 having a front face 12 and a connection region 14 designed to allow the bit to be connected to other downhole components, in use, to allow the bit to be driven for rotation about its centerline 16 and to allow an axially directed load to be applied thereto.
  • [0023]
    Mounted on the bit body 10 are a number of upstanding main blades 18, the main blades 18 upstanding from the front face 12 of the bit body 10. The main blades 18 include a first plurality of blades 18a which extend from the center line 16, of the bit to the gauge region 20 thereof, and a second plurality of blades 18b which stop short of the center line 16, of the bit. These upstanding main blades 18 may be integrally formed on the bit body, or alternately, may be formed separately and later attached to the bit body 10. The gauge regions 20 of the main blades 18 are of substantially uniform gauge length, the gauge regions 20 all being located at the same axial position on the bit.
  • [0024]
    As can be seen most clearly in FIGS. 4 and 5, the main blades 18 are shaped to define a bit profile 21 including a nose portion 22 of annular shape located at the axially most remote part of the bit from the connection region. Radially inward of the nose portion 22 is a cone region 24, and radially outward of the nose portion 22 is an outer region 26.
  • [0025]
    The main blades 18 each carry a series of cutting elements 28. Each cutting element 28 is in the form of a polycrystalline diamond compact comprising a table of polycrystalline diamond which is bonded to a substrate of less hard material, typically tungsten carbide. The cutting elements 28 are located on parts of the blades 18 in the cone region 24, at the nose portion 22 and in the outer region 26.
  • [0026]
    Back-up cutting elements 28a are provided immediately behind, and at the same general radial position as at least some of the cutting elements 28, in a known manner.
  • [0027]
    In addition to the main blades 18, the bit body 10 is further provided with a plurality of additional blades 30. As illustrated, each additional blade 30 is located immediately behind an associated one of the main blades 18 b, the additional blades 30 being substantially equally spaced apart around the bit body 10. Each additional blade 30 includes a part located in the cone region 24, a part located at the nose portion 22 and a part located in the outer region 26, and includes a gauge region aligned with the gauge regions 20 of the main blades 18.
  • [0028]
    Between the main blades 18 a, 18 b and the additional blades 30 are formed a series of flow channels 32 to which drilling fluid is supplied, in use, through passages (not shown) located internally of the bit and through nozzles 34. The fluid serves to clean and cool the cutting elements, and also serves to carry away from the bit formation material which, in use, is removed by the cutting elements.
  • [0029]
    Like the main blades 18, the additional blades 30 are also adapted to carry a series of cutting elements 28. The cutting elements 28 carried by the additional blades 30 are located radially inwards of the outer region 26, being located only in the cone region 24 and the nose portion 22, while the outer region 26 is free of cutting elements 28. The provision of the cutters 28 only in the cone region 24 and nose portion 22 of the additional blades 30 serves to enhance the stability of the bit. This is because, in order to reduce lateral vibrations, it is important for the lateral forces generated by the cutting elements to be balanced. Where the bit is of large diameter, as in the arrangement illustrated, this is usually difficult as the torque generated by the radially outer cutting elements is high compared to the torque generated by the inner cutting elements. The location of the cutting elements on the additional blades 30 only at relatively small radial distances from the axis enables this part of the bit to carry a disproportionately large number of cutting elements, and thereby allows such balancing to be achieved more easily.
  • [0030]
    The parts of the additional blades 30 in the outer regions 26 are, as mentioned hereinbefore, devoid of cutters, and will be referred to hereinafter as cutter devoid surfaces 36. In addition to being devoid of cutters, the cutter devoid surfaces are designed to be of larger blade height than the corresponding parts of the main blades 18 with the result that engagement of the cutter devoid surfaces 36 with the formation
  • [0031]
    being drilled, in use, limits the depth of cut achievable by the bit. In use, the bit is located downhole and is driven for rotation about its axis 16. An axially directed load sometimes referred to as weight-on-bit is applied to the bit. The combination of the rotary motion and the weight-on-bit causes the cutters 28 to gouge, scrape or abrade material from the formation, thereby extending the borehole. Changes in the applied weight-on-bit or changes in the formation being drilled can give rise to changes in the depth of cut and this, in turn, can cause torsional vibrations to occur. With the bit described hereinbefore, the maximum depth of cut is limited by the engagement of the cutter devoid surfaces 36 with the formation being drilled. As a result, variations in depth of cut are reduced and the severity of torsional vibrations can be limited, or the initiation of such vibrations can be avoided.
  • [0032]
    As the cutter devoid surfaces 36 wilt in use, bear against the formation being drilled, at least for some of the time, the surfaces 36 may be subject to wear. In order to limit such wear, a wear resistant coating may be applied thereto. Alternatively, a series of wear resistant inserts, for example in the form of suitably shaped polycrystalline diamond compacts, may be mounted upon the surfaces 36.
  • [0033]
    FIGS. 6 and 7 illustrate an alternative embodiment, which, in many respects, is the same as that illustrated in FIGS. 2 to 5. The biggest difference between the two embodiments is in the number of blades provided, the FIG. 6 embodiment includes four main blades 18 a, four main blades 18 b and four additional blades 30. FIG. 7 illustrates the profile of the additional blades 30, the profile of the corresponding parts of the main blades 18 being represented by the dotted line 38, thereby illustrating the difference in blade heights of the blades 18, 30. Specifically, the cutter devoid surfaces 36 of the additional blades 30 are at a greater blade height than the corresponding parts of the main blades 18.
  • [0034]
    It will be appreciated that a range of modifications and alterations may be made to the arrangements described hereinbefore without departing from the scope of the invention. For example, rather than using polycrystalline diamond compacts as the cutting elements, it may be possible to use diamond crystals or polycrystalline diamond mounted upon or embedded in the blades 18, 30. Further, alternative means may be used to render the cutter devoid surfaces of good wear resistance. A further possibility may be to shape the cutter devoid surfaces so as to match the actual shape of the bottom hole surface created by the cutter elements 28, at the desired rate of penetration. As a result, the full surface area of each cutter devoid surface can be arranged to engage the formation being drilled.
  • [0035]
    Whereas the present invention has been described in particular relation to the drawings attached hereto, it should be understood that other and further modifications apart from those shown or suggested herein, may be made within the scope and spirit of the present invention.

Claims (12)

  1. 1. A drill bit comprising a bit body having a plurality of upstanding main blades formed thereon, the main blades having a plurality cutting elements mounted thereon, the main blades being shaped such that a cutting profile of the bit includes a nose portion, an inner cone region located radially inwards of the nose portion and an outer region located radially outwards of the nose portion, the bit further comprising at least one additional blade, the additional blade carrying cutting elements located radially inwards of the outer region of the cutting profile, but being substantially free of cutting elements located in the outer region of the cutting profile, wherein the cutting elements provided on the main blades and on the additional blades are located such that the lateral forces generated by the cutting elements, in use, are substantially balanced.
  2. 2. A drill bit according to claim 1, wherein a part of the additional blade located in the outer region of the cutting profile is of increased blade height as compared to parts of the main blades located in the outer region of the cutting profile.
  3. 3. A drill bit according to claim 1, wherein the bit has a diameter falling within the range of about 12¼″ to 26″.
  4. 4. A drill bit according to claim 1, wherein the cutting elements comprise polycrystalline diamond compact cutters.
  5. 5. A drill bit according to claim 1, wherein the cutting elements comprise diamond crystals mounted upon or embedded in the main and additional blades.
  6. 6. A drill bit according to claim 1, wherein the cutting elements comprise polycrystalline diamond crystals mounted upon or embedded in the main and additional blades.
  7. 7. A drill bit according to claim 1, wherein an outer surface of a part of the additional blade located in the outer region of the cutting profile is rendered of improved resistance to wear.
  8. 8. A drill bit according to claim 7, wherein the said part of the additional blade located in the outer region is rendered of improved resistance to wear by having suitably shaped and positioned, non-cutting, polycrystalline diamond elements mounted thereon.
  9. 9. A drill bit according to claim 7, wherein the said part of the additional blade located in the outer region is rendered of improved resistance to wear by having a hard facing material coating applied thereto.
  10. 10. A drill bit according to claim 1, wherein the plurality of main blades comprise a first plurality of blades which extend inwardly to a centerline of the bit body, and a second plurality of blades which stop short of the centerline of the bit body.
  11. 11. A drill bit according to claim 1, wherein a plurality of the additional blades are provided, the additional blades being substantially equally spaced around the bit body.
  12. 12. A drill bit according to claim 1, wherein the main blades and the additional blades each have a gauge region, the gauge regions being of substantially uniform length and being aligned with one another.
US11382571 2005-05-17 2006-05-10 Stable Rotary Drill Bit Abandoned US20060260845A1 (en)

Priority Applications (2)

Application Number Priority Date Filing Date Title
GB0510010A GB0510010D0 (en) 2005-05-17 2005-05-17 Rotary drill bit
GB0510010.2 2005-05-17

Publications (1)

Publication Number Publication Date
US20060260845A1 true true US20060260845A1 (en) 2006-11-23

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GB (2) GB0510010D0 (en)

Cited By (16)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20070261890A1 (en) * 2006-05-10 2007-11-15 Smith International, Inc. Fixed Cutter Bit With Centrally Positioned Backup Cutter Elements
US20080302575A1 (en) * 2007-06-11 2008-12-11 Smith International, Inc. Fixed Cutter Bit With Backup Cutter Elements on Primary Blades
US20090025984A1 (en) * 2007-07-27 2009-01-29 Varel International, Ind., L.P. Single mold milling process for fabrication of rotary bits to include necessary features utilized for fabrication in said process
US20090065263A1 (en) * 2007-09-06 2009-03-12 Smith International, Inc. Drag bit with utility blades
US7621348B2 (en) 2006-10-02 2009-11-24 Smith International, Inc. Drag bits with dropping tendencies and methods for making the same
US20100252332A1 (en) * 2009-04-02 2010-10-07 Jones Mark L Drill bit for earth boring
US20110073369A1 (en) * 2009-09-28 2011-03-31 Baker Hughes Incorporated Earth-boring tools, methods of making earth-boring tools and methods of drilling with earth-boring tools
US8100202B2 (en) 2008-04-01 2012-01-24 Smith International, Inc. Fixed cutter bit with backup cutter elements on secondary blades
CN102959175A (en) * 2010-06-24 2013-03-06 贝克休斯公司 Downhole cutting tool having center beveled mill blade
US20130292186A1 (en) * 2012-05-03 2013-11-07 Smith International, Inc. Gage cutter protection for drilling bits
US8869919B2 (en) 2007-09-06 2014-10-28 Smith International, Inc. Drag bit with utility blades
US9016407B2 (en) 2007-12-07 2015-04-28 Smith International, Inc. Drill bit cutting structure and methods to maximize depth-of-cut for weight on bit applied
CN105683484A (en) * 2013-09-11 2016-06-15 史密斯国际有限公司 Orientation of cutting element at first radial position to cut core
US9885234B2 (en) 2012-08-31 2018-02-06 Halliburton Energy Services, Inc. System and method for measuring temperature using an opto-analytical device
US9945181B2 (en) 2012-08-31 2018-04-17 Halliburton Energy Services, Inc. System and method for detecting drilling events using an opto-analytical device
US9957792B2 (en) 2012-08-31 2018-05-01 Halliburton Energy Services, Inc. System and method for analyzing cuttings using an opto-analytical device

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8851207B2 (en) * 2011-05-05 2014-10-07 Baker Hughes Incorporated Earth-boring tools and methods of forming such earth-boring tools

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US4602691A (en) * 1984-06-07 1986-07-29 Hughes Tool Company Diamond drill bit with varied cutting elements
US4982802A (en) * 1989-11-22 1991-01-08 Amoco Corporation Method for stabilizing a rotary drill string and drill bit
US5010789A (en) * 1989-02-21 1991-04-30 Amoco Corporation Method of making imbalanced compensated drill bit
US5042596A (en) * 1989-02-21 1991-08-27 Amoco Corporation Imbalance compensated drill bit
US5163524A (en) * 1991-10-31 1992-11-17 Camco Drilling Group Ltd. Rotary drill bits
US5178222A (en) * 1991-07-11 1993-01-12 Baker Hughes Incorporated Drill bit having enhanced stability
US5655614A (en) * 1994-12-20 1997-08-12 Smith International, Inc. Self-centering polycrystalline diamond cutting rock bit
US5967245A (en) * 1996-06-21 1999-10-19 Smith International, Inc. Rolling cone bit having gage and nestled gage cutter elements having enhancements in materials and geometry to optimize borehole corner cutting duty
US6349780B1 (en) * 2000-08-11 2002-02-26 Baker Hughes Incorporated Drill bit with selectively-aggressive gage pads
US6575256B1 (en) * 2000-01-11 2003-06-10 Baker Hughes Incorporated Drill bit with lateral movement mitigation and method of subterranean drilling

Patent Citations (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4602691A (en) * 1984-06-07 1986-07-29 Hughes Tool Company Diamond drill bit with varied cutting elements
US5010789A (en) * 1989-02-21 1991-04-30 Amoco Corporation Method of making imbalanced compensated drill bit
US5042596A (en) * 1989-02-21 1991-08-27 Amoco Corporation Imbalance compensated drill bit
US4982802A (en) * 1989-11-22 1991-01-08 Amoco Corporation Method for stabilizing a rotary drill string and drill bit
US5178222A (en) * 1991-07-11 1993-01-12 Baker Hughes Incorporated Drill bit having enhanced stability
US5163524A (en) * 1991-10-31 1992-11-17 Camco Drilling Group Ltd. Rotary drill bits
US5655614A (en) * 1994-12-20 1997-08-12 Smith International, Inc. Self-centering polycrystalline diamond cutting rock bit
US5967245A (en) * 1996-06-21 1999-10-19 Smith International, Inc. Rolling cone bit having gage and nestled gage cutter elements having enhancements in materials and geometry to optimize borehole corner cutting duty
US6575256B1 (en) * 2000-01-11 2003-06-10 Baker Hughes Incorporated Drill bit with lateral movement mitigation and method of subterranean drilling
US6349780B1 (en) * 2000-08-11 2002-02-26 Baker Hughes Incorporated Drill bit with selectively-aggressive gage pads

Cited By (26)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20070261890A1 (en) * 2006-05-10 2007-11-15 Smith International, Inc. Fixed Cutter Bit With Centrally Positioned Backup Cutter Elements
US7621348B2 (en) 2006-10-02 2009-11-24 Smith International, Inc. Drag bits with dropping tendencies and methods for making the same
US7703557B2 (en) 2007-06-11 2010-04-27 Smith International, Inc. Fixed cutter bit with backup cutter elements on primary blades
GB2471020A (en) * 2007-06-11 2010-12-15 Smith International Drill bit for drilling a borehole
GB2471020B (en) * 2007-06-11 2011-05-11 Smith International Drill bit for drilling a borehole
GB2462206A (en) * 2007-06-11 2010-02-03 Smith International Drill Bit For Drilling A Borehole
US20080302575A1 (en) * 2007-06-11 2008-12-11 Smith International, Inc. Fixed Cutter Bit With Backup Cutter Elements on Primary Blades
GB2462206B (en) * 2007-06-11 2011-01-12 Smith International Drill bit for drilling a borehole
US8915166B2 (en) * 2007-07-27 2014-12-23 Varel International Ind., L.P. Single mold milling process
US20090025984A1 (en) * 2007-07-27 2009-01-29 Varel International, Ind., L.P. Single mold milling process for fabrication of rotary bits to include necessary features utilized for fabrication in said process
US8869919B2 (en) 2007-09-06 2014-10-28 Smith International, Inc. Drag bit with utility blades
US7926596B2 (en) 2007-09-06 2011-04-19 Smith International, Inc. Drag bit with utility blades
US20090065263A1 (en) * 2007-09-06 2009-03-12 Smith International, Inc. Drag bit with utility blades
US9016407B2 (en) 2007-12-07 2015-04-28 Smith International, Inc. Drill bit cutting structure and methods to maximize depth-of-cut for weight on bit applied
US8100202B2 (en) 2008-04-01 2012-01-24 Smith International, Inc. Fixed cutter bit with backup cutter elements on secondary blades
US8439136B2 (en) * 2009-04-02 2013-05-14 Atlas Copco Secoroc Llc Drill bit for earth boring
US20100252332A1 (en) * 2009-04-02 2010-10-07 Jones Mark L Drill bit for earth boring
US8127869B2 (en) 2009-09-28 2012-03-06 Baker Hughes Incorporated Earth-boring tools, methods of making earth-boring tools and methods of drilling with earth-boring tools
US20110073369A1 (en) * 2009-09-28 2011-03-31 Baker Hughes Incorporated Earth-boring tools, methods of making earth-boring tools and methods of drilling with earth-boring tools
CN102959175A (en) * 2010-06-24 2013-03-06 贝克休斯公司 Downhole cutting tool having center beveled mill blade
US20130292186A1 (en) * 2012-05-03 2013-11-07 Smith International, Inc. Gage cutter protection for drilling bits
US9464490B2 (en) * 2012-05-03 2016-10-11 Smith International, Inc. Gage cutter protection for drilling bits
US9885234B2 (en) 2012-08-31 2018-02-06 Halliburton Energy Services, Inc. System and method for measuring temperature using an opto-analytical device
US9945181B2 (en) 2012-08-31 2018-04-17 Halliburton Energy Services, Inc. System and method for detecting drilling events using an opto-analytical device
US9957792B2 (en) 2012-08-31 2018-05-01 Halliburton Energy Services, Inc. System and method for analyzing cuttings using an opto-analytical device
CN105683484A (en) * 2013-09-11 2016-06-15 史密斯国际有限公司 Orientation of cutting element at first radial position to cut core

Also Published As

Publication number Publication date Type
GB0609742D0 (en) 2006-06-28 grant
GB2426533A (en) 2006-11-29 application
GB0510010D0 (en) 2005-06-22 grant
GB2426533B (en) 2010-07-21 grant

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AS Assignment

Owner name: REEDHYCALOG UK LIMITED, UNITED KINGDOM

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:JOHNSON, SIMON;REEL/FRAME:017780/0430

Effective date: 20060609