Source: http://www.google.com/patents/US7497281?dq=6,578,054
Timestamp: 2016-08-28 12:16:04
Document Index: 513115397

Matched Legal Cases: ['Application No. 60', 'Application No. 0503934', 'Application No. 0504304', 'Application No. 99945376', 'application No. 04025232', 'application No. 04025233', 'application No. 04025234']

Patent US7497281 - Roller cone drill bits with enhanced cutting elements and cutting structures - Google PatentsSearch Images Maps Play YouTube News Gmail Drive More »Sign inPatentsRoller cone drill bits are provided with cutting elements and cutting structures optimized for efficient drilling of soft and medium formations interspersed with hard stringers. The cutting elements and cutting structures may be satisfactorily used to drill downhole formations with varying amounts of...http://www.google.com/patents/US7497281?utm_source=gb-gplus-sharePatent US7497281 - Roller cone drill bits with enhanced cutting elements and cutting structuresAdvanced Patent SearchPublication numberUS7497281 B2Publication typeGrantApplication numberUS 11/671,649Publication dateMar 3, 2009Filing dateFeb 6, 2007Priority dateAug 31, 1998Fee statusPaidAlso published asCN1664301A, CN100595416C, US7334652, US20050133273, US20070125579Publication number11671649, 671649, US 7497281 B2, US 7497281B2, US-B2-7497281, US7497281 B2, US7497281B2InventorsShilin Chen, James S. DahlemOriginal AssigneeHalliburton Energy Services, Inc.Export CitationBiBTeX, EndNote, RefManPatent Citations (99), Non-Patent Citations (79), Classifications (12), Legal Events (3) External Links: USPTO, USPTO Assignment, EspacenetRoller cone drill bits with enhanced cutting elements and cutting structures
US 7497281 B2Abstract
Roller cone drill bits are provided with cutting elements and cutting structures optimized for efficient drilling of soft and medium formations interspersed with hard stringers. The cutting elements and cutting structures may be satisfactorily used to drill downhole formations with varying amounts of hardness. The cutting elements and cutting structures may also be optimized to reduce tracking and increase wear resistance.
This application is a divisional application of U.S. patent application Ser. No. 11/054,395 filed on Feb. 9, 2005 now U.S. Pat. No. 7,334,652; which is a continuation-in-part application of U.S. patent application Ser. No. 10/189,305 filed Jul. 2, 2002, now abandoned, and claims the benefit of U.S. Provisional Patent Application Ser. No. 60/549,354 filed Mar. 2, 2004; which is a continuation application of U.S. patent application Ser. No. 09/629,344 filed Aug. 1, 2000, now U.S. Pat. No. 6,412,577; which is a continuation of U.S. patent application Ser. No. 09/387,304 filed Aug. 31, 1999, now U.S. Pat. No. 6,095,262; which claims the benefit of U.S. Provisional Application No. 60/098,442 filed Aug. 31, 1998.
The present invention is related to roller cone drill bits used to form wellbores in subterranean formations and more particularly to arrangement and design of cutting elements and cutting structures for optimum performance of an associated drill bit.
A wide variety of roller cone drill bits have previously been used to form wellbores in downhole formations. Such drill bits may also be referred to as “rotary” cone drill bits. Roller cone drill bits frequently include a bit body with three support arms extending therefrom. A respective cone is generally rotatably mounted on each support arm opposite from the bit body. Such drill bits may also be referred to as “tricone drill bits” or “rock bits”.
In accordance with teachings of the present disclosure, a roller cone drill bit may be formed with at least one cone having at least one row of cutting elements oriented such that the crest of one element extends generally perpendicular to an associated scraping direction and the crest of an adjacent cutting element extends generally parallel with the associated scraping direction. The remaining cutting elements in the one row are preferably arranged with alternating crests extending generally perpendicular to the associated scraping direction and parallel with the associated scraping direction.
Preferred embodiments of the invention and its advantages are best understood by reference to FIGS. 1-16 wherein like number refer to same and like parts.
The terms “crest” and “longitudinal crest” may be used in this application to describe portions of a cutting element or cutting structure that makes initial contact with a downhole formation during drilling of a wellbore. The crest of a cutting element will typically engage and disengage the bottom of a wellbore during rotation of a roller cone drill bit and associated cone assemblies. The geometric configuration and dimensions of a crest may vary substantially depending upon specific design and dimensions of an associated cutting element or cutting structure.
For purposes of describing various features of the present invention cone assemblies 30 may be identified as 30 a, 30 b and 30 c. Cone assemblies 330 may be identified as 330 a, 330 b and 330 c. Cone assemblies 30 and 330 may sometimes be referred to as “rotary cone cutters”, “roller cone cutters” or “cutter cone assemblies”.
For embodiments of the present invention as represented by drill bit 20, bit body 24 may have three (3) substantially identical support arms 32 extending therefrom. The lower portion of each support arm 32 opposite from bit body 24 preferably includes respective shaft or spindle 34. Spindle 34 may also be referred to as a “bearing pin”. Each cone assembly 30 a, 30 b and 30 c preferably includes respective cavity 48 extending from backface 42. The dimensions and configuration of each cavity 48 are preferably selected to receive associated spindle 34. Portions of cavity 48 are shown in FIG. 2.
Cone assemblies 30 a, 30 b and 30 c may be rotatably attached to respective spindles 34 extending from support arms 32. Each cone assembly 30 a, 30 b and 30 c includes a respective axis of rotation 36 (sometimes referred to as “cone rotational axis”) extending at an angle corresponding with the relationship between spindle 34 and associated support arm 32. Axis of rotation 36 often corresponds with the longitudinal center line of associated spindle 34.
For embodiments shown in FIGS. 1 and 2 a plurality of compacts 40 may be disposed in backface 42 of each cone assembly 30 a, 30 b and 30 c. Compacts 40 may be used to “trim” the inside diameter of a borehole and prevent other portions of backface 42 from contacting the adjacent formation. For some applications compacts 40 may be formed from polycrystalline diamond type materials or other suitable hard materials. Each cone assembly 30 a, 30 b and 30 c includes a plurality of cutting elements 60 arranged in respective rows. A gauge row of cutting elements 60 may be disposed adjacent to backface 42 of each cone assembly 30 a, 30 b and 30 c. The gauge row may sometimes be referred to as the “first row” of inserts.
Compacts 40 and cutting elements 60 may be formed from a wide variety of hard materials such as tungsten carbide. The term “tungsten carbide” includes monotungsten carbide (WC), ditungsten carbide (W2C), macrocrystalline tungsten carbide and cemented or sintered tungsten carbide. Examples of hard materials which may be satisfactorily used to form compacts 40 and cutting elements 60 include various metal alloys and cermets such as metal borides, metal carbides, metal oxides and metal nitrides. An important feature of the present invention includes the ability to select the type of hard material which provides desired abrasion, wear and erosion resistance in a cost effective, reliable manner and provides optimum downhole drilling performance.
For embodiments shown in FIGS. 1-3 extension 64 may be described as having a “chisel shaped” configuration defined in part by crest 68. Cylindrical body 62 may be modified to have an oblong or oval cross section. Also, extension 64 may have various configurations.
FIGS. 4A and 4B are graphical representations showing relative movement of cutting elements 60 a and 60 b during rotation of roller cone drill bit 20 at the bottom of a wellbore. The graphs shown in FIGS. 4A and 4B are based on a bit coordinate system in which the Z axis corresponds generally with the axis of rotation of an associated roller cone drill bit (sometimes referred to as “drill bit rotational axis”). Axes Xh and Yh coordinates are for the borehole.
Various techniques may be used to determine optimum orientation of cutting elements and associated scraping for removal of material from a downhole formation using roller cone drill bits. U.S. Pat. No. 6,095,262 entitled “Roller-Cone Bits, Systems, Drilling Methods, And Design Methods With Optimization Of Tooth Orientation” discloses examples of some techniques for optimizations based in part on determining radial and tangential scraping motion of inserts or teeth during engagement of a roller cone bit with a downhole formation. For some applications equivalent tangent scraping distance and equivalent radial scraping distance along with calculations of ratios between drill bit rotation speed and cone rotation speed may be used to determine optimum orientation of cutting elements and associated scraping direction for removal of material from a downhole formation. Depending upon specific design characteristic of each cutting element such as size and configuration of an associated crest, the orientation of the crest of a cutting element for optimum penetration of a formation may be approximately perpendicular to the optimum orientation of the crest of the same cutting element for removal of material from the same formation.
FIGS. 12A, 12B and 12C are schematic drawings showing examples of craters which may be formed at the bottom 80 of a wellbore by a roller cone drill bit incorporating teachings of the present invention. FIG. 12A shows an example of crater 82 formed by a cutting element oriented in a direction for optimum removal of formation materials. Crater 84 may be formed by a cutting element oriented for enhanced penetration of a formation in accordance with teachings of the present invention. Crater 82 and crater 84 may be formed by cutting elements of different roller cones of the bit or may be formed by cutting elements that are disposed on the same roller cone. The combined craters 82 and 84 produce generally “T shaped” crater 86. FIG. 12B shows the results of orienting cutting elements in accordance with teachings of the present invention such that craters 82 and 84 may form general “cross shaped” crater 88. FIG. 12C shows the results of multiple impacts of cutting elements to produce a series of connected craters 82 and 84 which produce row 90 of “H shaped” craters.
Technical benefits of the present invention include forming craters 82 and 84 in a wellbore to optimize fracturing and splitting of adjacent formation materials. Cutting elements may also be oriented to increase fracturing or splitting of any formation materials extending between or “bridging” adjacent craters 82 and 84. The size and configuration of the cutting elements may be varied to minimize the presence of bridging materials.
Cutting structures may be formed on each cone assembly 330 a, 330 b and 330 c in accordance with teachings of the present invention. For example, cutting elements or teeth 360 may be formed in rows on each cone assembly 330 a, 330 b and 330 c with orientations similar to previously described cutting elements 60. Cutting element 360 may be disposed with crests 368 oriented for optimum penetration of a formation or for optimum removal of formation material as previously described with respect to cutting elements 60. Cutting elements 360 are typically formed using milling techniques. The resulting cutting elements 360 may sometimes be referred to as “milled teeth”.
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Chin, Wave Propagation in Petroleum Engineering, 1994.Classifications U.S. Classification175/374, 175/376, 175/378International ClassificationE21B10/16, E21B10/08, E21B41/00Cooperative ClassificationE21B10/16, E21B10/08, E21B10/50European ClassificationE21B10/08, E21B10/16, E21B10/50Legal EventsDateCodeEventDescriptionApr 2, 2007ASAssignmentOwner name: HALLIBURTON ENERGY SERVICES, INC., TEXASFree format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:CHEN, SHILIN;DAHLEM, JAMES S.;REEL/FRAME:019100/0695;SIGNING DATES FROM 20070112 TO 20070123Aug 28, 2012FPAYFee paymentYear of fee payment: 4May 4, 2016FPAYFee paymentYear of fee payment: 8RotateOriginal ImageGoogle Home - Sitemap - USPTO Bulk Downloads - Privacy Policy - Terms of Service - About Google Patents - Send FeedbackData provided by IFI CLAIMS Patent Services