WO2009135119A2 - Modular hybrid drill bit - Google Patents
Modular hybrid drill bit Download PDFInfo
- Publication number
- WO2009135119A2 WO2009135119A2 PCT/US2009/042514 US2009042514W WO2009135119A2 WO 2009135119 A2 WO2009135119 A2 WO 2009135119A2 US 2009042514 W US2009042514 W US 2009042514W WO 2009135119 A2 WO2009135119 A2 WO 2009135119A2
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- bit
- leg
- earth
- slot
- bit body
- Prior art date
Links
- 238000005096 rolling process Methods 0.000 claims abstract description 31
- 238000003466 welding Methods 0.000 claims abstract description 8
- 230000000717 retained effect Effects 0.000 claims abstract description 6
- 239000000314 lubricant Substances 0.000 claims description 13
- 239000012530 fluid Substances 0.000 claims description 7
- 230000001154 acute effect Effects 0.000 claims description 5
- 238000004891 communication Methods 0.000 claims description 4
- 238000005520 cutting process Methods 0.000 description 17
- 229910003460 diamond Inorganic materials 0.000 description 16
- 239000010432 diamond Substances 0.000 description 16
- 238000005553 drilling Methods 0.000 description 14
- 230000015572 biosynthetic process Effects 0.000 description 10
- 238000005755 formation reaction Methods 0.000 description 10
- 239000000463 material Substances 0.000 description 5
- 239000011435 rock Substances 0.000 description 5
- 238000010276 construction Methods 0.000 description 3
- UONOETXJSWQNOL-UHFFFAOYSA-N tungsten carbide Chemical compound [W+]#[C-] UONOETXJSWQNOL-UHFFFAOYSA-N 0.000 description 2
- 239000011324 bead Substances 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 230000013011 mating Effects 0.000 description 1
- 238000000034 method Methods 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 239000000758 substrate Substances 0.000 description 1
- 239000000725 suspension Substances 0.000 description 1
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
- E21B10/08—Roller bits
- E21B10/14—Roller bits combined with non-rolling cutters other than of leading-portion type
-
- 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
- E21B10/08—Roller bits
- E21B10/22—Roller bits characterised by bearing, lubrication or sealing details
- E21B10/24—Roller bits characterised by bearing, lubrication or sealing details characterised by lubricating details
-
- 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
- E21B10/62—Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
- Y10T29/00—Metal working
- Y10T29/49—Method of mechanical manufacture
- Y10T29/49826—Assembling or joining
- Y10T29/49947—Assembling or joining by applying separate fastener
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
- Y10T29/00—Metal working
- Y10T29/49—Method of mechanical manufacture
- Y10T29/49826—Assembling or joining
- Y10T29/49947—Assembling or joining by applying separate fastener
- Y10T29/49948—Multipart cooperating fastener [e.g., bolt and nut]
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
- Y10T29/00—Metal working
- Y10T29/49—Method of mechanical manufacture
- Y10T29/49826—Assembling or joining
- Y10T29/49947—Assembling or joining by applying separate fastener
- Y10T29/49963—Threaded fastener
Definitions
- Diamond or PDC bits carry cutting elements comprising polycrystalline diamond compact layers or "tables" formed on and bonded to a supporting substrate, conventionally of cemented tungsten carbide, the cutting elements being arranged in selected locations on blades or other structures on the bit body with the diamond tables facing generally in the direction of bit rotation.
- Diamond bits have an advantage over rolling-cutter bits in that they generally have no moving parts. The drilling mechanics and dynamics of diamond bits are different from those of rolling-cutter bits precisely because they have no moving parts. During drilling operation, diamond bits are used in a manner similar to that for rolling cutter bits, the diamond bits also being rotated against a formation being drilled under applied weight on bit to remove formation material.
- an earth-boring bit comprising a bit body configured at its upper end for connection into a drillstring. At least one fixed blade depends axially downwardly from the bit body. An axially extending slot is formed in the bit body adjacent the fixed blade. A bit leg is received and retained in the slot by engagement between the slot and correspondingly shaped bit leg. At least one rolling cutter is secured to the bit leg at its lower extent.
- the bit body further comprises a shank that is configured for connection into the drillstring at its upper extent and has a generally cylindrical receptacle formed in its lower extent; and a bit body portion having a generally cylindrical upper extent, the receptacle being and dimensioned to receive the upper extent of the bit body, wherein the shank and bit body portions are secured together by welding.
- Figure 1 is a side elevation view of the embodiment of the hybrid earth-boring bit constructed in accordance with the present invention.
- the bit 1 1 comprises a bit body 13 having an axis 15 that defines an axial center of the bit body 13.
- a plurality (e.g., two shown) of bit legs or heads 17 extend from the bit body 13 in the axial direction.
- the bit body 13 also has a plurality (e.g., also two shown) of fixed blades 19 that extend in the axial direction.
- the number of each of legs 17 and fixed blades 19 is at least one but may be more than two (as in the case of the embodiment illustrated in Figure 3).
- the centers of the legs 17 and fixed blades 19 are symmetrically spaced apart from each other about the axis 15 in an alternating configuration.
- Rolling cutters 21 are mounted to respective ones of the bit legs ] 7. Each of the rolling cutters 21 is shaped and located such that every surface of the rolling cutters 21 is radially spaced apart from the axial center 15 ( Figure 2) by a minimal radial distance 23. A plurality of rolling-cutter cutting inserts or elements 25 are mounted to the rolling cutters 21 and radially spaced apart from the axial center 15 by a minimal radial distance 27.
- the minimal radial distances 23, 27 may vary according to the application, and may vary from cutter to cutter, and/or cutting element to cutting element.
- a plurality of fixed cutting elements 31 are mounted to the fixed blades 19. At least one of the fixed cutting elements 31 is located at the axial center 15 of the bit body 13 and adapted to cut a fo ⁇ nation at the axial center. In one embodiment, the at least one of the fixed cutting elements 31 is within approximately 0.040 inches of the axial center. Examples of rolling-cutter cutting elements 25 and fixed cutting elements 31 include tungsten carbide inserts, cutters made of super-hard material such as polycrystalline diamond, and others known to those skilled in the art. [0022] Figures 3 and 4 illustrate the modular aspect of the bit constructed according to the present invention. Figure 3 is an exploded view of the various parts of the bit 1 11 disassembled.
- FIG. 3 The illustrative embodiment of Figure 3 is a three-cutter, three-blade bit.
- the modular construction principles of the present invention are equally applicable to the two-cutter, two-blade bit 11 of Figures 1 and 2, and hybrid bits with any combination of fixed blades and rolling cutters.
- bit 111 comprises a shank portion or section 113, which is threaded or otherwise configured at its upper extent for connection into a drillstring.
- a generally cylindrical receptacle 115 is formed at the lower extent of shank portion 113.
- Receptacle 115 receives a correspondingly shaped and dimensioned cylindrical portion 117 at the upper extent of a bit body portion 119.
- Shank 113 and body 119 portions are joined together by inserting the cylindrical portion 117 at the upper extent of body portion 119 into the cylindrical receptacle 115 in the lower extent of shank 113.
- the receptacle is a Class 2 female thread that engages with a mating male thread at the upper extent of the body.
- Receptacle 115 and upper extent 1 17 need not be cylindrical, but could be other shapes that mate together, or could be a sliding or running fit relying on the weld for strength.
- the joint could be strengthened by a close interference fit between upper extent 119 and receptacle 115. Tack welding around the seam could also be used.
- a bit leg or head 121 (three are shown for the three-cutter embodiment of Figure 3) is received in an axially extending slot 123 (again, there is a slot 123 for each leg or head 121).
- slot 123 is dovetailed (and leg 121 correspondingly shaped) so that only axial sliding of leg 121 is permitted and leg 121 resists radial removal from slot 123.
- a plurality (four) of bolts 127 and washers secure each leg 121 in slot 123 so that leg 121 is secured against axial motion in and removal from slot 123.
- a rolling cutter 125 is secured on a bearing associated with each leg 121 by a ball lock and seal assembly 129.
- the apertures in leg 121 through which bolts 127 extend are oblong, which permits the axial positioning of leg 121 within slot 123, which in turn permits selection of the relative projection of the cutting elements on each rolling cutter.
- a lubricant compensator assembly 131 is also carried in each leg 121 and supplies lubricant to the bearing assembly and compensates for pressure variations in the lubricant during drilling operations.
- a preferred compensator is disclosed in commonly assigned U.S. Patent No. 4,727,942 to Galle and Zahradnik.
- At least one nozzle 133 is received and retained in the bit body portion 1 19 to direct a stream of drilling fluid from the interior of bit 11 1 to selected locations proximate the cutters and blades of the bit.
- Figure 4 is a fragmentary section view of bit body 119 illustrating the configuration of slot 123.
- slot 123 has a pair of adjacent opposing sides 135 that are inclined toward one another at an acute included angle (from vertical) to define a dovetail.
- a third side which may be curved or flat, connects the two opposing sides 135.
- a rectilinear 137 recess is formed within the third side for additional engagement between the bit leg and bit body.
- bit leg 121 is provided with a corresponding shape so that once assembled together, bit leg 121 resists removal from slot 123 except by axial force.
- slot 123 is approximately 3.880 inches wide at its widest point, opposing sides 135 are inclined at an angle of approximately 15 degrees and converge to define an included angle of approximately 30 degrees.
- Recess 137 is approximately 1.880 inches wide and approximately 0.385 inches deep.
- the corresponding surfaces of bit leg 121 are similarly dimensioned, but between 0.005 and 0.010 inch smaller to provide a sliding or running fit within the slot. A close interference fit could also be used to enhance strength, at the cost of ease of assembly.
- a blind threaded hole or aperture 139 is formed in bit body 119 to receive each of the fasteners or bolts 127 ( Figure 3).
- the opposed sides 135 of slot 123 could be "straight," but such a construction will not be as strong as the "dovetailed” construction and may unduly strain bolts 127.
- the threaded shank is separable from the bit body and each bit leg and associated rolling cutter is also separable from the bit body (along with the associated lubricant compensator, bearing and seal assembly).
- the bearing associated with a cutter loses lubricant and fails, the entire bit leg assembly can be replaced as needed. If the bit body wears to the degree that it will no longer support fixed cutters (or other parts of the bit assembly), it can be replaced.
- the shank is damaged, it can be replaced.
- the welded joint is not typically considered a replaceable joint, in this instance, the weld can be removed, a new shank or body portion fitted, and there will be ample material remaining to permit re-welding of the two together.
Landscapes
- 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)
- Earth Drilling (AREA)
Abstract
Description
Claims
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
MX2010012023A MX2010012023A (en) | 2008-05-02 | 2009-05-01 | Modular hybrid drill bit. |
EP09739921A EP2310612B1 (en) | 2008-05-02 | 2009-05-01 | Modular hybrid drill bit |
BRPI0912183-8A BRPI0912183B1 (en) | 2008-05-02 | 2009-05-01 | ground drill bit |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/114,537 | 2008-05-02 | ||
US12/114,537 US20090272582A1 (en) | 2008-05-02 | 2008-05-02 | Modular hybrid drill bit |
Publications (3)
Publication Number | Publication Date |
---|---|
WO2009135119A2 true WO2009135119A2 (en) | 2009-11-05 |
WO2009135119A3 WO2009135119A3 (en) | 2010-02-25 |
WO2009135119A4 WO2009135119A4 (en) | 2010-04-29 |
Family
ID=41255854
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2009/042514 WO2009135119A2 (en) | 2008-05-02 | 2009-05-01 | Modular hybrid drill bit |
Country Status (5)
Country | Link |
---|---|
US (2) | US20090272582A1 (en) |
EP (1) | EP2310612B1 (en) |
BR (1) | BRPI0912183B1 (en) |
MX (1) | MX2010012023A (en) |
WO (1) | WO2009135119A2 (en) |
Cited By (11)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2015179792A3 (en) * | 2014-05-23 | 2016-01-14 | Baker Hughes Incorporated | Hybrid bit with mechanically attached rolling cutter assembly |
WO2016014080A1 (en) * | 2014-07-25 | 2016-01-28 | Halliburton Energy Services, Inc. | Nanofiber strain gauge sensors in downhole tools |
US9353575B2 (en) | 2011-11-15 | 2016-05-31 | Baker Hughes Incorporated | Hybrid drill bits having increased drilling efficiency |
US9476259B2 (en) | 2008-05-02 | 2016-10-25 | Baker Hughes Incorporated | System and method for leg retention on hybrid bits |
US9556681B2 (en) | 2009-09-16 | 2017-01-31 | Baker Hughes Incorporated | External, divorced PDC bearing assemblies for hybrid drill bits |
CN106414890A (en) * | 2014-05-23 | 2017-02-15 | 贝克休斯公司 | Hybrid bit with mechanically attached rolling cutter assembly |
US9657527B2 (en) | 2010-06-29 | 2017-05-23 | Baker Hughes Incorporated | Drill bits with anti-tracking features |
US9670736B2 (en) | 2009-05-13 | 2017-06-06 | Baker Hughes Incorporated | Hybrid drill bit |
US9782857B2 (en) | 2011-02-11 | 2017-10-10 | Baker Hughes Incorporated | Hybrid drill bit having increased service life |
US10316589B2 (en) | 2007-11-16 | 2019-06-11 | Baker Hughes, A Ge Company, Llc | Hybrid drill bit and design method |
US11428050B2 (en) | 2014-10-20 | 2022-08-30 | Baker Hughes Holdings Llc | Reverse circulation hybrid bit |
Families Citing this family (25)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9574405B2 (en) | 2005-09-21 | 2017-02-21 | Smith International, Inc. | Hybrid disc bit with optimized PDC cutter placement |
US20090272582A1 (en) * | 2008-05-02 | 2009-11-05 | Baker Hughes Incorporated | Modular hybrid drill bit |
US8141664B2 (en) * | 2009-03-03 | 2012-03-27 | Baker Hughes Incorporated | Hybrid drill bit with high bearing pin angles |
US8157026B2 (en) * | 2009-06-18 | 2012-04-17 | Baker Hughes Incorporated | Hybrid bit with variable exposure |
US8672060B2 (en) | 2009-07-31 | 2014-03-18 | Smith International, Inc. | High shear roller cone drill bits |
US8955413B2 (en) * | 2009-07-31 | 2015-02-17 | Smith International, Inc. | Manufacturing methods for high shear roller cone bits |
US20110079442A1 (en) | 2009-10-06 | 2011-04-07 | Baker Hughes Incorporated | Hole opener with hybrid reaming section |
WO2011084944A2 (en) * | 2010-01-05 | 2011-07-14 | Smith International, Inc. | High-shear roller cone and pdc hybrid bit |
US8978786B2 (en) | 2010-11-04 | 2015-03-17 | Baker Hughes Incorporated | System and method for adjusting roller cone profile on hybrid bit |
US8881848B2 (en) | 2012-05-07 | 2014-11-11 | Ulterra Drilling Technologies, L.P. | Fixed cutter drill bit with rotating cutter disc |
US9714544B2 (en) * | 2013-05-20 | 2017-07-25 | The Charles Machine Works, Inc. | Reamer with replaceable rolling cutters |
US10619420B2 (en) | 2013-05-20 | 2020-04-14 | The Charles Machine Works, Inc. | Reamer with replaceable rolling cutters |
US20160319602A1 (en) * | 2013-12-31 | 2016-11-03 | Smith International, Inc. | Multi-Piece Body Manufacturing Method Of Hybrid Bit |
RU2681750C2 (en) * | 2014-01-31 | 2019-03-12 | Бейкер Хьюз Инкорпорейтед | Hybrid drill bit with increased service life |
US10156102B2 (en) | 2014-05-08 | 2018-12-18 | Evolution Engineering Inc. | Gap assembly for EM data telemetry |
WO2015168804A1 (en) | 2014-05-08 | 2015-11-12 | Evolution Engineering Inc. | Drill string sections with interchangeable couplings |
CA3193759A1 (en) | 2014-05-08 | 2015-11-12 | Evolution Engineering Inc. | Jig for coupling or uncoupling drill string sections with detachable couplings and related methods |
WO2015168806A1 (en) | 2014-05-09 | 2015-11-12 | Evolution Engineering Inc. | Downhole electronics carrier |
CN107709693A (en) | 2015-07-17 | 2018-02-16 | 哈里伯顿能源服务公司 | Center has the Mixed drilling bit for reversely rotating cutter |
WO2017014748A1 (en) * | 2015-07-21 | 2017-01-26 | Halliburton Energy Services, Inc. | Roller cone drill bit journal with asymmetric ball race and extended friction race |
US10428586B2 (en) | 2015-12-15 | 2019-10-01 | Inrock Drilling Systems, Inc. | Reamer assembly |
GB2561317A (en) | 2016-02-26 | 2018-10-10 | Halliburton Energy Services Inc | Hybrid drill bit with axially adjustable counter-rotation cutters in center |
US10995557B2 (en) | 2017-11-08 | 2021-05-04 | Halliburton Energy Services, Inc. | Method of manufacturing and designing a hybrid drill bit |
AU2019279892A1 (en) | 2018-05-29 | 2020-12-17 | Quanta Associates, L.P. | Horizontal directional reaming |
US11732531B2 (en) * | 2021-06-04 | 2023-08-22 | Baker Hughes Oilfield Operations Llc | Modular earth boring tools having fixed blades and removable blade assemblies and related methods |
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US9353575B2 (en) | 2011-11-15 | 2016-05-31 | Baker Hughes Incorporated | Hybrid drill bits having increased drilling efficiency |
WO2015179792A3 (en) * | 2014-05-23 | 2016-01-14 | Baker Hughes Incorporated | Hybrid bit with mechanically attached rolling cutter assembly |
CN106414890A (en) * | 2014-05-23 | 2017-02-15 | 贝克休斯公司 | Hybrid bit with mechanically attached rolling cutter assembly |
US10107039B2 (en) | 2014-05-23 | 2018-10-23 | Baker Hughes Incorporated | Hybrid bit with mechanically attached roller cone elements |
EP3521548A1 (en) * | 2014-05-23 | 2019-08-07 | Baker Hughes, A Ge Company, Llc | Hybrid bit with mechanically attached roller cone elements |
US9869171B2 (en) | 2014-07-25 | 2018-01-16 | Halliburton Energy Services, Inc. | Nanofiber strain gauge sensors in downhole tools |
WO2016014080A1 (en) * | 2014-07-25 | 2016-01-28 | Halliburton Energy Services, Inc. | Nanofiber strain gauge sensors in downhole tools |
US11428050B2 (en) | 2014-10-20 | 2022-08-30 | Baker Hughes Holdings Llc | Reverse circulation hybrid bit |
Also Published As
Publication number | Publication date |
---|---|
EP2310612B1 (en) | 2012-10-03 |
MX2010012023A (en) | 2011-02-18 |
BRPI0912183A2 (en) | 2017-06-13 |
EP2310612A4 (en) | 2011-07-20 |
WO2009135119A3 (en) | 2010-02-25 |
WO2009135119A4 (en) | 2010-04-29 |
US20090272582A1 (en) | 2009-11-05 |
BRPI0912183B1 (en) | 2019-10-29 |
EP2310612A2 (en) | 2011-04-20 |
US20110120269A1 (en) | 2011-05-26 |
US8356398B2 (en) | 2013-01-22 |
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