US20080190670A1 - Rotary drag bit with increased back rake angle gauge cutter - Google Patents
Rotary drag bit with increased back rake angle gauge cutter Download PDFInfo
- Publication number
- US20080190670A1 US20080190670A1 US12/029,197 US2919708A US2008190670A1 US 20080190670 A1 US20080190670 A1 US 20080190670A1 US 2919708 A US2919708 A US 2919708A US 2008190670 A1 US2008190670 A1 US 2008190670A1
- Authority
- US
- United States
- Prior art keywords
- cutting
- bit
- axis
- gauge
- back rake
- 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 claims abstract description 98
- 238000005553 drilling Methods 0.000 claims abstract description 6
- 229910003460 diamond Inorganic materials 0.000 claims description 12
- 239000010432 diamond Substances 0.000 claims description 12
- 230000015572 biosynthetic process Effects 0.000 description 7
- 239000000463 material Substances 0.000 description 6
- 230000008901 benefit Effects 0.000 description 3
- 238000000034 method Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- UONOETXJSWQNOL-UHFFFAOYSA-N tungsten carbide Chemical compound [W+]#[C-] UONOETXJSWQNOL-UHFFFAOYSA-N 0.000 description 2
- 230000001154 acute effect Effects 0.000 description 1
- 230000001627 detrimental effect Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 238000007790 scraping Methods 0.000 description 1
- 239000013598 vector Substances 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Definitions
- the present invention relates in general to rotary drag bits and, in particular, to an improved system, method, and apparatus for a rotary drag bit having gauge cutting elements configured at large back rake angles.
- Earth-boring bits of the fixed cutter variety commonly referred to as drag bits, have no moving parts and employ an array of hard inserts to scrape and shear formation material as the bit is rotated in the borehole.
- Inserts on prior art fixed cutter bits are typically aligned such that the inserts scrape the material from the borehole bottom.
- the longitudinal axis of the insert is typically at a small acute angle (e.g., 0° to 30°) relative to the bit face.
- Such an alignment places the cutting face of a cylindrically-shaped insert nearly perpendicular to the borehole bottom. The contact area between the cutting element and the formation starts out very small but increases rapidly as penetration or depth of cut becomes deeper.
- Embodiments of a system, method, and apparatus for a fixed cutter rotary drill bit having gauge cutting elements at large back rake angles are disclosed.
- the gauge is located at the outer diameter side wall portion of the bit that extends from the cutting end. The gauge and its cutting components contact the side wall of the bore hole during drilling operations.
- the gauge cutting elements may be configured at a back rake angle in a range of about 40° to 70°.
- a very high back rake angle helps ensure compressive cutter loading when side impact forces are higher.
- FIG. 1 is an isometric view of one embodiment of drill bit constructed in accordance with the present invention
- FIG. 2 is a schematic representation of half of a cutting profile of the drill bit of FIG. 1 and is constructed in accordance with the present invention
- FIG. 3 is an illustration of cutter element manipulation
- FIG. 4 is a side view of a cutting element showing a conventional back rake angle
- FIG. 5 is a side view of one embodiment of a cutting element showing a back rake angle constructed in accordance with the present invention.
- FIG. 6 is a side view of another embodiment of a cutting element showing a back rake angle constructed in accordance with the present invention.
- Bit 11 has a bit axis 12 and a threaded end 13 for connection into a drill string.
- a cutting end 15 at a generally opposite end of the bit 11 is provided with a plurality of hard cutting elements 17 (e.g., polycrystalline diamond cutters, etc.) arranged about cutting end 15 to effect efficient disintegration of formation material as bit 11 is rotated in a bore hole.
- hard cutting elements 17 e.g., polycrystalline diamond cutters, etc.
- each cutting element 17 has a cylindrical base 19 with an axis 20 , and is secured in a preformed pocket 21 provided on cutting end 15 and a cutting face 23 that engages the formation material.
- cutting element 17 may comprise a frustoconical cutting end that forms a beveled edge adjacent the face 23 .
- Cutting element 17 acts somewhat like a plow that generally directs a high percentage of the material of the formation up its flat face.
- profile 25 (approximately half of which is shown in FIG. 2 ) about bit axis 12 .
- profile 25 comprises various areas, including a cone 27 , a nose 29 , a shoulder 31 , and a gauge or gauge pad or surface 33 .
- the gauge 33 is on a radially outermost portion of the bit body relative to the bit axis 12 .
- the gauge 33 essentially defines the flat, outer diameter side wall portion of bit 11 that extends from cutting end 15 ( FIG. 1 ).
- the gauge 33 and its cutting components are proximal to and contact the side wall 34 (see FIG. 3 ) of the bore hole during drilling operations with bit 11 .
- a plurality of channels or grooves 35 extend from cutting end 15 through gauge 33 to provide a clearance area for the removal of cuttings and chips formed by cutting elements 17 .
- a plurality of cutting elements 17 are provided on gauge 33 of bit 11 .
- Active, gauge cutting elements 17 on gauge 33 provide the ability to actively cut formation material at the side wall 34 ( FIG. 3 ) of the bore hole to provide dynamic stability and improved gauge-holding ability in earth-boring bits of the fixed cutter variety.
- at least some of the gauge cutting elements 17 on gauge 33 may be ground flat at the outer diameter of bit 11 for some types of applications.
- Bit 11 is illustrated as a polycrystalline diamond cutter (PDC) bit, but cutting elements 17 are equally useful in other fixed cutter or drag bits that include a gauge or gauge surface for engagement with the side wall of the bore hole. Examples include impregnated and natural diamond bit cutting elements.
- Cutting element 117 is a conventional PDC cutting element and is cylindrical in shape.
- Cutting element 117 has an axis 120 and a diamond table on its face 123 with an essentially circular cross-section.
- Cutting element 117 has a cutter back rake angle 140 of 20°.
- conventional cutter back rake angles of 5° to 30° also are known.
- the circle 23 represents the face of cutting element 17 on the gauge 33 .
- a back rake axis 42 is shown as vertical in the drawing, and parallel to the gauge 33 , bit axis 12 , and the bore side wall 34 .
- a side rake axis 44 is perpendicular to axis 42 , gauge 33 , the bit axis 12 , and the bore side wall 34 .
- both the back rake angle and the side rake angle of element 17 are zero.
- face 23 extends in the plane defined by axes 42 , 44 , such that it is perpendicular to the gauge 33 and bore sidewall, and face 23 is parallel to axes 12 , 42 and 44 .
- Rotating the face 23 about axis 42 results in a modification to the back rake angle.
- a positive back rake angle inclines the cutting face 23 away from the bit axis 12 and toward the borehole 34 .
- Rotating the face 23 about axis 44 results in a modification to the side rake angle.
- a positive side rake angle includes the cutting face 23 away from the drill string and toward the bottom of the bore hole.
- one embodiment of cutting element 17 in accordance with the invention is shown with a relatively large positive back rake angle 42 of 40°, and a 0° side rake angle.
- another embodiment of cutting element 17 is shown at a 65° back rake angle 42 , and a 0° side rake angle.
- the invention may comprise back rake angles of approximately 40° to 70°.
- a very high back rake angle help ensures compressive cutter loading when side impact forces are higher. This is accomplished by lowering the y-component force (see, e.g., FIGS. 5 and 6 ) that results from side loads.
Abstract
Description
- This application claims priority to and the benefit of U.S. Provisional Patent Application No. 60/889,403, which was filed on Feb. 12, 2007, incorporated herein by reference in its entirety.
- 1. Technical Field
- The present invention relates in general to rotary drag bits and, in particular, to an improved system, method, and apparatus for a rotary drag bit having gauge cutting elements configured at large back rake angles.
- 2. Description of the Related Art
- Earth-boring bits of the fixed cutter variety, commonly referred to as drag bits, have no moving parts and employ an array of hard inserts to scrape and shear formation material as the bit is rotated in the borehole. Inserts on prior art fixed cutter bits are typically aligned such that the inserts scrape the material from the borehole bottom. For scraping to take place, the longitudinal axis of the insert is typically at a small acute angle (e.g., 0° to 30°) relative to the bit face. Such an alignment places the cutting face of a cylindrically-shaped insert nearly perpendicular to the borehole bottom. The contact area between the cutting element and the formation starts out very small but increases rapidly as penetration or depth of cut becomes deeper.
- High impact side-loading of drill bits during operation results in non-compressive loading of the interface between the diamond and tungsten carbide components on PDC cutters. This leads to broken and/or chipped cutters in the upper shoulder and gauge areas of the bit profile. High residual stresses are inherent in this interface area as a result of varying planar and non-planar geometries and the cutter manufacturing process. An improved solution that overcomes these problems would be desirable.
- Embodiments of a system, method, and apparatus for a fixed cutter rotary drill bit having gauge cutting elements at large back rake angles are disclosed. The gauge is located at the outer diameter side wall portion of the bit that extends from the cutting end. The gauge and its cutting components contact the side wall of the bore hole during drilling operations.
- In accordance with the invention, the gauge cutting elements may be configured at a back rake angle in a range of about 40° to 70°. For applications where cutter damage is a concern and side-cutting aggressiveness is a low priority, a very high back rake angle helps ensure compressive cutter loading when side impact forces are higher.
- The foregoing and other objects and advantages of the present invention will be apparent to those skilled in the art, in view of the following detailed description of the present invention, taken in conjunction with the appended claims and the accompanying drawings.
- So that the manner in which the features and advantages of the present invention are attained and can be understood in more detail, a more particular description of the invention briefly summarized above may be had by reference to the embodiments thereof that are illustrated in the appended drawings. However, the drawings illustrate only some embodiments of the invention and therefore are not to be considered limiting of its scope as the invention may admit to other equally effective embodiments.
-
FIG. 1 is an isometric view of one embodiment of drill bit constructed in accordance with the present invention; -
FIG. 2 is a schematic representation of half of a cutting profile of the drill bit ofFIG. 1 and is constructed in accordance with the present invention; -
FIG. 3 is an illustration of cutter element manipulation; -
FIG. 4 is a side view of a cutting element showing a conventional back rake angle; -
FIG. 5 is a side view of one embodiment of a cutting element showing a back rake angle constructed in accordance with the present invention; and -
FIG. 6 is a side view of another embodiment of a cutting element showing a back rake angle constructed in accordance with the present invention. - Referring to
FIG. 1 , one embodiment of a fixed cutterrotary drill bit 11 is shown.Bit 11 has abit axis 12 and a threadedend 13 for connection into a drill string. Acutting end 15 at a generally opposite end of thebit 11 is provided with a plurality of hard cutting elements 17 (e.g., polycrystalline diamond cutters, etc.) arranged about cuttingend 15 to effect efficient disintegration of formation material asbit 11 is rotated in a bore hole. - As shown in the embodiment of
FIG. 5 , eachcutting element 17 has acylindrical base 19 with anaxis 20, and is secured in apreformed pocket 21 provided on cuttingend 15 and acutting face 23 that engages the formation material. As illustrated,cutting element 17 may comprise a frustoconical cutting end that forms a beveled edge adjacent theface 23. Cuttingelement 17 acts somewhat like a plow that generally directs a high percentage of the material of the formation up its flat face. - Referring now to
FIGS. 1 and 2 , the arrangement ofcutting elements 17 onbit 11 is configured in an overall cutting profile 25 (approximately half of which is shown inFIG. 2 ) aboutbit axis 12. Starting ataxis 12 at the inner diameter ofbit 11 and moving toward the outer diameter of bit 11 (right to left inFIG. 2 ),profile 25 comprises various areas, including acone 27, anose 29, ashoulder 31, and a gauge or gauge pad orsurface 33. Thegauge 33 is on a radially outermost portion of the bit body relative to thebit axis 12. - The
gauge 33 essentially defines the flat, outer diameter side wall portion ofbit 11 that extends from cutting end 15 (FIG. 1 ). Thegauge 33 and its cutting components are proximal to and contact the side wall 34 (seeFIG. 3 ) of the bore hole during drilling operations withbit 11. As shown inFIG. 1 , a plurality of channels or grooves 35 (e.g., junk slots) extend from cuttingend 15 throughgauge 33 to provide a clearance area for the removal of cuttings and chips formed by cuttingelements 17. - As shown in
FIG. 1 , a plurality ofcutting elements 17 are provided ongauge 33 ofbit 11. Active,gauge cutting elements 17 ongauge 33 provide the ability to actively cut formation material at the side wall 34 (FIG. 3 ) of the bore hole to provide dynamic stability and improved gauge-holding ability in earth-boring bits of the fixed cutter variety. AsFIG. 1 illustrates, at least some of thegauge cutting elements 17 ongauge 33 may be ground flat at the outer diameter ofbit 11 for some types of applications.Bit 11 is illustrated as a polycrystalline diamond cutter (PDC) bit, butcutting elements 17 are equally useful in other fixed cutter or drag bits that include a gauge or gauge surface for engagement with the side wall of the bore hole. Examples include impregnated and natural diamond bit cutting elements. - Referring now to
FIG. 4 , one type of priorart cutting element 117 for cutting formation is shown.Cutting element 117 is a conventional PDC cutting element and is cylindrical in shape.Cutting element 117 has anaxis 120 and a diamond table on itsface 123 with an essentially circular cross-section.Cutting element 117 has a cutterback rake angle 140 of 20°. However, conventional cutter back rake angles of 5° to 30° also are known. - As shown in
FIG. 3 , thecircle 23 represents the face ofcutting element 17 on thegauge 33. Aback rake axis 42 is shown as vertical in the drawing, and parallel to thegauge 33,bit axis 12, and thebore side wall 34. Aside rake axis 44 is perpendicular toaxis 42,gauge 33, thebit axis 12, and thebore side wall 34. - In a “nominal” position on the
gauge 33, both the back rake angle and the side rake angle ofelement 17 are zero. Thus, in one embodiment of the nominal position,face 23 extends in the plane defined byaxes gauge 33 and bore sidewall, andface 23 is parallel toaxes face 23 aboutaxis 42 results in a modification to the back rake angle. In thegauge area 33, a positive back rake angle inclines thecutting face 23 away from thebit axis 12 and toward theborehole 34. Rotating theface 23 aboutaxis 44 results in a modification to the side rake angle. A positive side rake angle includes thecutting face 23 away from the drill string and toward the bottom of the bore hole. - Referring again to
FIG. 5 , one embodiment ofcutting element 17 in accordance with the invention is shown with a relatively large positiveback rake angle 42 of 40°, and a 0° side rake angle. InFIG. 6 , another embodiment of cuttingelement 17 is shown at a 65°back rake angle 42, and a 0° side rake angle. The invention may comprise back rake angles of approximately 40° to 70°. - For applications where cutter damage is a concern and side-cutting (e.g., cutting with the
gauge 33 of the cutting profile 25) aggressiveness is a low priority, a very high back rake angle help ensures compressive cutter loading when side impact forces are higher. This is accomplished by lowering the y-component force (see, e.g.,FIGS. 5 and 6 ) that results from side loads. - For example, comparing
FIGS. 4 and 5 , lower back rake angles result in higher loading in the y-direction, as depicted by the vectors Fy. This is detrimental to cutter integrity with respect to the diamond/tungsten carbide interface where residual stresses are high. Although the direction of overall force, Ff (which is normal to the bore side wall 34), will vary slightly with dynamic events, the invention enhances the cutter integrity and dynamic stability of fixed cutter drill bits. - While the invention has been shown or described in only some of its forms, it should be apparent to those skilled in the art that it is not so limited, but is susceptible to various changes without departing from the scope of the invention.
Claims (19)
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/029,197 US20080190670A1 (en) | 2007-02-12 | 2008-02-11 | Rotary drag bit with increased back rake angle gauge cutter |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US88940307P | 2007-02-12 | 2007-02-12 | |
US12/029,197 US20080190670A1 (en) | 2007-02-12 | 2008-02-11 | Rotary drag bit with increased back rake angle gauge cutter |
Publications (1)
Publication Number | Publication Date |
---|---|
US20080190670A1 true US20080190670A1 (en) | 2008-08-14 |
Family
ID=39530646
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/029,197 Abandoned US20080190670A1 (en) | 2007-02-12 | 2008-02-11 | Rotary drag bit with increased back rake angle gauge cutter |
Country Status (7)
Country | Link |
---|---|
US (1) | US20080190670A1 (en) |
EP (1) | EP2118431B1 (en) |
CN (1) | CN101605962A (en) |
AT (1) | ATE534797T1 (en) |
MX (1) | MX2009008257A (en) |
RU (1) | RU2009133697A (en) |
WO (1) | WO2008100455A1 (en) |
Cited By (12)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP2419595A1 (en) * | 2009-04-13 | 2012-02-22 | Baker Hughes Incorporated | A drill bit with a hybrid cutter profile |
CN103362444A (en) * | 2013-07-24 | 2013-10-23 | 中国地质大学(武汉) | Drill for cutting-grinding wing type oil and gas drilling |
US20130292186A1 (en) * | 2012-05-03 | 2013-11-07 | Smith International, Inc. | Gage cutter protection for drilling bits |
US20170211334A1 (en) * | 2014-07-21 | 2017-07-27 | Schlumberger Technology Corporation | Reamer |
US20170211333A1 (en) * | 2014-07-21 | 2017-07-27 | Schlumberger Technology Corporation | Downhole rotary cutting tool |
US20170211335A1 (en) * | 2014-07-21 | 2017-07-27 | Schlumberger Technology Corporation | Reamer |
US20170218707A1 (en) * | 2014-07-21 | 2017-08-03 | Schlumberger Technology Corporation | Reamer |
US9739094B2 (en) | 2013-09-06 | 2017-08-22 | Baker Hughes Incorporated | Reamer blades exhibiting at least one of enhanced gage cutting element backrakes and exposures and reamers so equipped |
JP2018204202A (en) * | 2017-05-31 | 2018-12-27 | 独立行政法人石油天然ガス・金属鉱物資源機構 | PDC bit |
US10415318B2 (en) | 2013-12-06 | 2019-09-17 | Schlumberger Technology Corporation | Expandable reamer |
US10508499B2 (en) * | 2014-07-21 | 2019-12-17 | Schlumberger Technology Corporation | Reamer |
US10519722B2 (en) | 2014-07-21 | 2019-12-31 | Schlumberger Technology Corporation | Reamer |
Families Citing this family (7)
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MX369559B (en) | 2012-12-03 | 2019-11-12 | Ulterra Drilling Tech Lp | Earth boring tool with improved arrangment of cutter side rakes. |
EP2865843B1 (en) * | 2013-10-28 | 2016-01-20 | Sandvik Intellectual Property AB | Percussive rock drill bit with optimised gauge buttons |
EP3140384B1 (en) * | 2014-05-06 | 2024-02-14 | Milliken & Company | Laundry care compositions |
CN104074465A (en) * | 2014-07-09 | 2014-10-01 | 江苏长城石油装备制造有限公司 | Drill bit for scraper cutting roller cone |
CN106761424B (en) * | 2017-01-21 | 2019-04-12 | 四川川石·克锐达金刚石钻头有限公司 | A kind of PDC drill bit that cutting element is arranged in pairs |
US11480016B2 (en) | 2018-11-12 | 2022-10-25 | Ulterra Drilling Technologies, L.P. | Drill bit |
RU2769009C1 (en) * | 2021-08-23 | 2022-03-28 | Алексей Викторович Чихоткин | Drill bit |
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US4440247A (en) * | 1982-04-29 | 1984-04-03 | Sartor Raymond W | Rotary earth drilling bit |
US5287936A (en) * | 1992-01-31 | 1994-02-22 | Baker Hughes Incorporated | Rolling cone bit with shear cutting gage |
US5346026A (en) * | 1992-01-31 | 1994-09-13 | Baker Hughes Incorporated | Rolling cone bit with shear cutting gage |
US5443565A (en) * | 1994-07-11 | 1995-08-22 | Strange, Jr.; William S. | Drill bit with forward sweep cutting elements |
US5467836A (en) * | 1992-01-31 | 1995-11-21 | Baker Hughes Incorporated | Fixed cutter bit with shear cutting gage |
US6050354A (en) * | 1992-01-31 | 2000-04-18 | Baker Hughes Incorporated | Rolling cutter bit with shear cutting gage |
US6332503B1 (en) * | 1992-01-31 | 2001-12-25 | Baker Hughes Incorporated | Fixed cutter bit with chisel or vertical cutting elements |
US20060185901A1 (en) * | 2005-02-22 | 2006-08-24 | Sinor L A | Drilling tool equipped with improved cutting element layout to reduce cutter damage through formation changes, methods of design and operation thereof |
Family Cites Families (3)
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GB9420839D0 (en) | 1994-10-15 | 1994-11-30 | Camco Drilling Group Ltd | Improvements in or relating to rotary drill bits |
US6340064B2 (en) | 1999-02-03 | 2002-01-22 | Diamond Products International, Inc. | Bi-center bit adapted to drill casing shoe |
WO2003031763A1 (en) | 2001-10-03 | 2003-04-17 | Shell Internationale Research Maatschappij B.V. | System for rotary-percussion drilling in an earth formation |
-
2008
- 2008-02-11 EP EP08725403A patent/EP2118431B1/en not_active Not-in-force
- 2008-02-11 CN CNA200880004759XA patent/CN101605962A/en active Pending
- 2008-02-11 RU RU2009133697/03A patent/RU2009133697A/en unknown
- 2008-02-11 AT AT08725403T patent/ATE534797T1/en active
- 2008-02-11 MX MX2009008257A patent/MX2009008257A/en active IP Right Grant
- 2008-02-11 US US12/029,197 patent/US20080190670A1/en not_active Abandoned
- 2008-02-11 WO PCT/US2008/001764 patent/WO2008100455A1/en active Application Filing
Patent Citations (9)
Publication number | Priority date | Publication date | Assignee | Title |
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US4440247A (en) * | 1982-04-29 | 1984-04-03 | Sartor Raymond W | Rotary earth drilling bit |
US5287936A (en) * | 1992-01-31 | 1994-02-22 | Baker Hughes Incorporated | Rolling cone bit with shear cutting gage |
US5346026A (en) * | 1992-01-31 | 1994-09-13 | Baker Hughes Incorporated | Rolling cone bit with shear cutting gage |
US5467836A (en) * | 1992-01-31 | 1995-11-21 | Baker Hughes Incorporated | Fixed cutter bit with shear cutting gage |
US5655612A (en) * | 1992-01-31 | 1997-08-12 | Baker Hughes Inc. | Earth-boring bit with shear cutting gage |
US6050354A (en) * | 1992-01-31 | 2000-04-18 | Baker Hughes Incorporated | Rolling cutter bit with shear cutting gage |
US6332503B1 (en) * | 1992-01-31 | 2001-12-25 | Baker Hughes Incorporated | Fixed cutter bit with chisel or vertical cutting elements |
US5443565A (en) * | 1994-07-11 | 1995-08-22 | Strange, Jr.; William S. | Drill bit with forward sweep cutting elements |
US20060185901A1 (en) * | 2005-02-22 | 2006-08-24 | Sinor L A | Drilling tool equipped with improved cutting element layout to reduce cutter damage through formation changes, methods of design and operation thereof |
Cited By (18)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP2419595A1 (en) * | 2009-04-13 | 2012-02-22 | Baker Hughes Incorporated | A drill bit with a hybrid cutter profile |
EP2419595A4 (en) * | 2009-04-13 | 2014-01-22 | Baker Hughes Inc | A drill bit with a hybrid cutter profile |
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 |
CN103362444A (en) * | 2013-07-24 | 2013-10-23 | 中国地质大学(武汉) | Drill for cutting-grinding wing type oil and gas drilling |
US9739094B2 (en) | 2013-09-06 | 2017-08-22 | Baker Hughes Incorporated | Reamer blades exhibiting at least one of enhanced gage cutting element backrakes and exposures and reamers so equipped |
US10415318B2 (en) | 2013-12-06 | 2019-09-17 | Schlumberger Technology Corporation | Expandable reamer |
US20170218707A1 (en) * | 2014-07-21 | 2017-08-03 | Schlumberger Technology Corporation | Reamer |
US20170211335A1 (en) * | 2014-07-21 | 2017-07-27 | Schlumberger Technology Corporation | Reamer |
US20170211333A1 (en) * | 2014-07-21 | 2017-07-27 | Schlumberger Technology Corporation | Downhole rotary cutting tool |
US20170211334A1 (en) * | 2014-07-21 | 2017-07-27 | Schlumberger Technology Corporation | Reamer |
US10501995B2 (en) * | 2014-07-21 | 2019-12-10 | Schlumberger Technology Corporation | Reamer |
US10508499B2 (en) * | 2014-07-21 | 2019-12-17 | Schlumberger Technology Corporation | Reamer |
US10519722B2 (en) | 2014-07-21 | 2019-12-31 | Schlumberger Technology Corporation | Reamer |
US10584538B2 (en) * | 2014-07-21 | 2020-03-10 | Schlumberger Technology Corporation | Reamer |
US10612309B2 (en) * | 2014-07-21 | 2020-04-07 | Schlumberger Technology Corporation | Reamer |
US10704332B2 (en) * | 2014-07-21 | 2020-07-07 | Schlumberger Technology Corporation | Downhole rotary cutting tool |
JP2018204202A (en) * | 2017-05-31 | 2018-12-27 | 独立行政法人石油天然ガス・金属鉱物資源機構 | PDC bit |
Also Published As
Publication number | Publication date |
---|---|
CN101605962A (en) | 2009-12-16 |
EP2118431A1 (en) | 2009-11-18 |
RU2009133697A (en) | 2011-03-20 |
MX2009008257A (en) | 2009-08-12 |
EP2118431B1 (en) | 2011-11-23 |
ATE534797T1 (en) | 2011-12-15 |
WO2008100455A1 (en) | 2008-08-21 |
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Owner name: BAKER HUGHES INCORPORATED, TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:WELCH, ROBERT W., MR.;FELDERHOFF, FLOYD C., MR.;DOSTER, MICHAEL L., MR.;REEL/FRAME:020756/0302;SIGNING DATES FROM 20080401 TO 20080403 Owner name: BAKER HUGHES INCORPORATED, TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:WELCH, ROBERT W., MR.;FELDERHOFF, FLOYD C., MR.;DOSTER, MICHAEL L., MR.;SIGNING DATES FROM 20080401 TO 20080403;REEL/FRAME:020756/0302 |
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