WO2005080742B1 - Casing and liner drilling bits, cutting elements therefor, and methods of use - Google Patents

Casing and liner drilling bits, cutting elements therefor, and methods of use

Info

Publication number
WO2005080742B1
WO2005080742B1 PCT/US2005/004106 US2005004106W WO2005080742B1 WO 2005080742 B1 WO2005080742 B1 WO 2005080742B1 US 2005004106 W US2005004106 W US 2005004106W WO 2005080742 B1 WO2005080742 B1 WO 2005080742B1
Authority
WO
WIPO (PCT)
Prior art keywords
casing bit
casing
bit
drilling
cutting elements
Prior art date
Application number
PCT/US2005/004106
Other languages
French (fr)
Other versions
WO2005080742A1 (en
Inventor
Jack T Oldham
L Allen Sinor
Eric E Mcclain
Robert A Laing
Evan C Turner
Mark W Dykstra
Eric C Sullivan
Original Assignee
Baker Hughes Inc
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
Application filed by Baker Hughes Inc filed Critical Baker Hughes Inc
Publication of WO2005080742A1 publication Critical patent/WO2005080742A1/en
Publication of WO2005080742B1 publication Critical patent/WO2005080742B1/en

Links

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
    • E21B10/08—Roller bits
    • 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
    • E21B10/26—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
    • 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
    • E21B10/56—Button-type inserts
    • E21B10/567—Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/02—Couplings; joints
    • E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
    • E21B17/07—Telescoping joints for varying drill string lengths; Shock absorbers
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/14—Casing shoes for the protection of the bottom of the casing
    • 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
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/20—Driving or forcing casings or pipes into boreholes, e.g. sinking; Simultaneously drilling and casing boreholes

Abstract

A casing bit, which may comprise a composite structure, for drilling a casing section into a subterranean formation, and which may include a portion configured to be drilled therethrough, is disclosed. Cutting elements and methods of use are disclosed. Adhesive, solder, electrically disbonding material, and braze affixation of a cutting element are disclosed. Differing abrasive material amount, characteristics, and size of cutting elements are disclosed. Telescoping casing sections and bits are disclosed. Aspects and embodiments are disclosed including: at least one gage section extending from the nose portion, at least one rotationally trailing groove formed in at least one of the plurality of blades, a movable blade, a leading face comprising superabrasive material, at least one of a drilling fluid nozzle and a sleeve, grooves for preferential failure, at least one rolling cone affixed to the nose portion, at least one sensor, discrete cutting element retention structures, and percussion inserts.

Claims

97AMENDED CLAIMS [received by the International Bureau on 13 August 2005 (13.08.2005); original claims 1-188 replaced by amended claims 1-118 (18 pages)]What is claimed is:
1. A casing bit for drilling a casing section into a subterranean formation, comprising: a casing bit having an inner profile, an outer profile, and a nose portion; at least one aperture foπned in the nose portion of the casing bit and configured for delivering drilling fluid from an interior of the casing bit to an exterior thereof; a plurality of cutting elements affixed to the nose portion, configured for causing failure in the formation by contact therewith; and at least one gage section, the at least one gage section extending longitudinally from adjacent the nose portion of the casing bit.
2. The casing bit of claim 1 , further comprising a plurality of generally radially extending blades disposed on the nose portion, wherein at least one of the plurality of blades carries at least one cutting element affixed thereto.
3. The casing bit of claim 1 - wherein the casing bit comprises steel.
4. The casing bit of claim 1 , wherein at least a portion of the outer profile of the casing bit exhibits an inverted cone geometry.
5. The casing bit of claim 1 , wherein at least one of plurality of cutting elements are selected from the group consisting of a polycrystallinc diamond cutting element, a thermally stable diamond cutting element, a natural diamond cutting element, and a tungsten carbide cutting clement 98
6. The casing bit of claim 1 , wherein: the plurality of cutting elements comprises a first plurality of cutting elements and a second plurality of cutting elements; the first plurality of cutting elements is configured to initially engage and drill through a selected region; and the second plurality of cutting elements is configured to engage and drill through a region to be subsequently encountered by the casing bit.
7. The casing bit of claim 6, wherein each of the first plurality of cutting elements comprise a tungsten carbide cutting element and each of the second plurality of cutting elements comprise a polycrystalline diamond cutting element.
8. The casing bit of claim 7, wherein the first plurality of cutting elements exhibits greater exposure than the second plurality of cutting elements.
9. The casing bit of claim 1 , further comprising an integral stem section extending longitudinally from the nose portion of the casing bit.
10. The casing bit of claim 9, wherein the integral stem section comprises at least one of a frangible region, a float valve mechanism, a cementing stage tool, a float collar mechanism, or a landing collar structure.
11. The casing bit of claim 1 , wherein at least a portion of the casing bit is configured to be drilled therethrough by way of a drilling tool having a drilling profile defined by a drilled surface mat would be foπned by a full rotation of the drilling tool about a drilling axis,
12. The casing bit of claim 1 \, wherein at least a portion of at least one of the inner profile and the outer profile of the casing bit substantially corresponds to the drilling profile of the drilling tool. 99
13. The casing bit of claim 1 , wherein at least a portion of the casing bit is configured to fail in response to pressure acting on an interior surface thereof.
14. The casing bit of claim 13, wherein the at least a portion of the casing bit configured to fail is sized and configured to transmit cement therethrough.
15. The casing bit of claim 1 , wherein an average distance between the inner profile and the outer profile of the casing bit is selected in relation to a maximum predicted stress, the maximum predicted stress predicted in relation to expected forces of operating the casing bit to drill a casing section into a subterranean formation.
16. The casing bit of claim 15, wherein the casing bit comprises a material having a yield stress that is at least one and one half times the maximum predicted stress.
17. The casing bit of claim 11 , wherein the plurality of cutting elements includes a first portion of the plurality of cutting elements disposed generally within the at least a portion of the casing bit that is configured to be drilled through; and a second portion of the plurality of cutting elements disposed generally peripheral to the at least a portion of the casing bit that is configured to be drilled through; and wherein a majority of cutting elements of the first portion is configured differently than a majority of cutting elements of the second portion.
18. The casing bit of claim 17, wherein a size of the majority of the first portion of the plurality of cutting elements is smaller than a size of the majority of cutting elements of the second portion. 100
19. The casing bit of claim 11, wherein each of the plurality of cutting elements contains an amount of abrasive material; and wherein an average amount of the abrasive material contained by each of the cutting elements of the first portion is less than an average amount of the abrasive material contained by each of the plurality of cutting elements of the second portion.
20. The casing bit of claim 17, wherein a majority of the first portion of cutting elements is substantially carbide-free.
21. The casing bit of claim 17, wherein each of the plurality of cutting elements comprises a polycrystalline diamond cutting element
22. The casing bit of claim 17, wherein at least one of the plurality of cutting elements generally within the at least a portion of the casing bit that is configured to be drilled through comprises a first grade of cutting element relating to at least one inherent quality related to wear characteristics, and at least one of the plurality of cutting elements generally peripheral to the at least a portion of the casing bit that is configured to be drilled through comprises a second grade of cutting element relating to at least one inherent quality related to wear characteristics, wherein the at least one inherent quality of the second grade of cutting element is generally different than the at least one inherent quality of the first grade of cutting element.
23. The casing bit of claim 22, wherein the at least one inherent quality related to wear characteristics of the first grade of cutting element is generally inferior to the at least one inherent quality related to wear characteristics of the second grade of cutting element.
24. The casing bit of claim 17, wherein a majority of the first portion of cutting elements comprises an abrasive selected from the group consisting of 101
carbide, natural diamond, and synthetic diamond, wherein the abrasive is sized and configured to substantially wear away in response to drilling through a selected formation region.
25. The casing bit of claim 2, further comprising one or more wear knots disposed on at least one of the plurality of blades.
26. The casing bit of claim 25, wherein the one or more wear knots are sized and configured to mmimize at least one of torque fluctuations while drilling and rate-of-penetration fluctuations while drilling.
27. The casing bit of claim 1 , further comprising: a total bearing area and at least one cutting element secured to a selected portion of the casing bit, the at least one superabrasive cutter exhibiting a limited amount of cutter exposure perpendicular to the selected portion of the face of the casing bit to which the at least one superabrasive cutter is secured; wherein the total bearing area of the casing bit is configured to limit a maximum depth-of-cut of the at least one cutting clement into the formation during drilling.
28. The casing bit of claim 1 , wherein at least a portion of the casing bit comprises an abrasive dispersed within a metal binder.
29. The casing bit of claim 28, wherein the abrasive comprises at least one of carbide, natural diamond, and synthetic diamond.
30. The casing bit of claim 1 , further comprising a coating disposed on at least a portion of the exterior of the casing bit.
'31. The casing bit of claim 30, wherein the coating is formulated to inhibit adhesion between formation cuttings and the casing bit. 102
32. The casing bit of claim 31 , wherein the coating comprises a polymer.
33. The casing bit of claim 30, wherein the coating is formulated to inhibit at least one of erosion, abrasion, and wear to the casing bit
34. The casing bit of claim 33 , wherein the coating comprises diamond.
35 - The casing bit of claim 2, wherein each of the plurality of blades extends generally radially outwardly in a generally spiral fashion from a central axis of the casing bit to the radial outer extent thereof.
36. The casing bit of claim 2, wherein each of the at least one gage sections of each blade extend longitudinally from the nose portion of the casing bit in a generally helical fashion.
37. The casing bit of claim 2, further comprising at least one rotationally trailing groove formed in at least one of the plurality of blades.
38. The casing bit of claim 37, wherein the at least one rotationally trailing groove follows at least one of a tangential path and a circumferential path relative to the direction of rotation of the casing bit.
39. The casing bit of claim 37, wherein the at least one rotationally trailing groove exhibits at least one of a substantially constant width along a direction of rotation of the casing bit and a tapered geometry in which the width of the at least one rotationally trailing groove increases along a direction of rotation of the casing bit.
40. The casing bit of claim 1 , wherein the at least one aperture comprises a retention structure. 103
41. Th casingbi ofclai 40, further comprising at least one of a nozzle and a sleeve disposed within and affixed to the retention structure.
42. The casing bit of claim 41, wherein at least a portion of the at least one of a nozzle and a sleeve is configured to be removed in relation to an expected amount of erosion.
43. The casing bit of claim 41 , wherein the at least one of a nozzle and a sleeve is affixed to the retention structure via at least one of welding, brazing, and engagement of threaded surfaces,
44. The casing bit of claim 41 , wherein the at least one of the nozzle and the sleeve comprise one or more of tungsten carbide, ceramic, steel, aluminum, bronze, and brass.
45. The casing bit of claim 41 , wherein the at least one of a nozzle and a sleeve is replaceable.
46. The casing bit of claim 1 , further comprising at least one rolling cone affixed to the nose portion of the casing bit.
47. The casing bit of claim 10, wherein the plurality of cutting elements comprises: a first portion of the plurality of cutting elements disposed generally within the at least a portion of the casing bit that is configured to be drilled through; a second portion of the plurality of cutting elements disposed generally peripheral to the at least a portion of the casing bit that is configured to be drilled through; and wherein at least a majority of the first portion of cutting elements is affixed to the at least one blade of the casing bit differently than at least a majority of the second portion of plurality of cutting elements. 104
48. The casing bit of claim 47, wherein the at least a majority of the first portion of the plurality of cutting elements is affixed to the at least one blade of the casing bit by an adhesive.
49. The casing bit of claim 47, wherein the at least a majority of the first portion of the plurality of cutting elements is affixed to the at least one blade of the casing bit by a solder.
50. The casing bit of claim 1 , wherein the at least one cutting element is affixed to the at least one of the plurality of blades of the casing bit by an adhesive.
51. The casing bit of claim 1 , wherein the at least one cutting element is affixed to the at least one of the plurality of blades of the casing bit by a solder.
52. The casing bit of claim 47, wherein the at least a majority of the first portion of the plurality of cutting elements is affixed to the at least one of the plurality of blades of the casing bit by electrically disbonding material.
53. The casing bit of claim 52, further comprising: a conductor extending to and in electrical communication with each of the at least a majority of the first portion of cutting elements affixed to the at least one of the plurality of blades of the casing bit by electrically disbonding material; and wherein each conductor is electrically insulated from the casing bit.
54. The casing bit of claim 1 , wherein the at least one cuttmg element is affixed to the at least one of the plurality of blades of the casing bit by electrically disbonding material. 105
55. The casing bit of claim 54, further comprising: a conductor extending to and in electrical communication with the at least one cutting element affixed to the at least one of the plurality of blades of the casing bit by electrically disbonding material; wherein the conductor is electrically insulated from the casing bit.
56. The casing bit of claim 47, wherein the at least a majority of the first portion of the plurality of cutting elements is affixed to the at least one of the plurality of blades of the casing bit by a fastening element extending therethrough.
57. The casing bit of claim 2, wherein the at least one element is affixed to the at least one of the plurality of blades of the casing bit by a fastening element extending therethrough.
58. The casing bit of claim 47, wherein each of the at least a majority of the first portion of cutting elements comprises an elongated body having an upper end comprising a cutting element and a lower end configured to extend through a recess formed in the at least one of the plurality of blades of the casing bit, the elongated body being affixed to the at least one of the plurality of blades of the casing bit by way of the lower end thereof.
59. The casing bit of claim 58, wherein the lower ends of the elongated bodies of the at least a majority of the first portion of cutting elements are affixed to the at least one of the plurality of blades of the casing bit by at least one of a threaded clement, a weld, a braze joint, and a pin.
60. The casing bit of claim 2, wherein the at least one cutting element comprises an elongated body having an upper end comprising a cutting element and a lower end configured to extend through a recess formed in the at least one of the plurality of blades of the casing bit, the elongated body of the at least one cutting element being affixed to the at least one of the plurality of blades of the casing bit by way of the lower end thereof.
61. The casing bit of claim 60, wherein the lower end of the elongated body of the at least one cutting element is affixed to the at least one of the plurality of blades of the casing bit by at least one of a threaded element, a weld, a braze joint, and a pin.
62. The casing bit of claim 47, wherein the at least a majority of the first portion of cutting elements is affixed to the at least one of the plurality of blades of the casing bit by a braze material exhibiting a liquidus temperature of, at most, about 1305° Fahrenheit.
63. The casing bit of cl aim 2, wherein the at least one cutting elements is affixed to the at least one of the plurality of blades of the casing bit by a braze material exhibiting a liquidus temperature of, at most, about 1305° Fahrenheit,
64. The casing bit of claim 1 , further comprising at least one groove that is sized and configured to preferentially facilitate failure of at least a portion of the casing bit.
65. The casing bit of claim 64, wherein the at least one groove comprises a plurality of grooves sized and configured to preferentially facilitate failure of at least a portion of the casing bit into sections.
66. The casing bit of claim 1 , wherein the casing bit comprises one or more fibers disposed within a matrix material.
67. The casing bit of claim 65, wherein the one or more fibers is circu ferentially oriented.
68. The casing bit of claim 66, wherein the one or more fibers is oriented concentrically or spirally. 107
69. The casing bit of claim 1 , further comprising at least one sensox for measuring at least one of a condition of drilling, a condition of the casing bit, or a formation characteristic.
70. The casing bit of claim 1 , wherein the casing bit comprises an outer shell and at least one inner core.
71. The casing bit of claim 70, wherein the outer shell comprises at: least one of steel, iron alloys, tungsten carbide powder infiltrated with a copper bas«d binder, and nickel alloys and the at least one inner core comprises at least one of aluminum, brass, bronze, or phenolic.
72. The casing bit of claim 70, wherein the outer shell and the at least one inner core are affixed to one another by at least one of fasteners, welding, and brazing.
73. The casing bit of claim 2, wherein at least a portion of a leading face of at least one blade of the plurality of blades of the casing bit is formed from a superabrasive material.
74. The casing bit of claim 1 , further comprising: at least one of an incendiary agent, an explosive agent, a reactive chemical, aa«d an abrasive material; wherein the at least one of an incendiary agent, an explosive agent, a reactive chemical, and an abrasive material is configured to render the casing bit more drillable.
75. The casing bit of claim 1 , further comprising an integral stem section including at least one of a float valve mechanism, a frangible region, a cementing stage tool, a float collar mechanism, and a landing collar structure. 108
76. The casing bit of claim 1 - wherein the casing bit comprises a casing bit reamer for drilling a casing section into a subterranean formation by enlarging a borehole, the casing bit reamer comprising: a pilot section comprising the inner profile, the outer profile, and the nose portion, the pilot section having a first cutting structure thereon; wherein the first cutting structure comprises: a plurality of generally radially extending blades disposed on the nose portion, wherein at least one of the plurality of blades carries at least one cutting element of the plurality of cutting elements; and. at least one gage section, the at least one gage section defining a pilot gage diameter; a reamer section longitudinally adjacent the pilot section comprising a tubular body including a second cutting structure thereon; wherein the second cutting structure comprises: a plurality of generally radially extending blades disposed on the tubmlar body, wherein at least one of the plurality of blades of the second cutting structure carries at least one cutting element of the plurality of cutting elements; and at least one gage section, the at least one gage section of the second cutting structure extending longitudinally from the reamer section and defining a reaming diameter that is larger than the pilot gage diameter.
77. The casing bit of claim 76, wherein the casing bit reamer is configured as a bicenter reamer.
78. The casing bit of claim 77, wherein at least one blade of the reamer section is expandable.
79. The casing bit of claim 76, wherein the casing bit reamer is configured with the reamer section that is generally centered with respect to the pilot 109
section and the plurality of blades of the reamer section are spaced about a substantial portion of the circumference of the casing bit reamer.
80. The casing bit of claim 79, wherein at least one fclade of the reamer section is expandable.
81. The casing bit of claim 76, wherein at least one "blade of the reamer section is expandable.
82. The casing bit of claim 76, wherein at least a portion of the outer profile of the pilot section exhibits an inverted cone geometry.
83. A cutting element for use in a casing bit configured to drill a casing section into a subterranean formation comprising: a substrate; and an abrasive volume forming at least a portion of a cutting face; wherein the abrasive volume is configured to be substantially removed from the cutting element in response to drilling subterranean foπriation material.
84. The cutting element of claim 83 : wherein at least a portion of a side surface of the abrasive volume is bonded to the substrate.
85. The cutting clement of claim 83, wherein the abrasive volume comprises at least one of diamond, ceramic, boron nitride, impregnated material, hardfacing material, and carbide.
86. The cutting clement of claim 83, wherein the abrasive volume has a geometry of one of a circular sector, a generally circular shape, and a partially rectangular shape.
87. The cutting element of claim 84, wherein the substrate surrounds the entire side surface of the abrasive volume. 110
88. The cutting element of claim 83, wherein the abrasive volume comprises a portion of the substrate.
89. The cutting element of claim 83, wherein the abrasϊ ve volume is configured to be substantially removed by wearing away in response to drilling a selected region of subterranean formation.
90. The cutting element of claim 83, wherein the abrasive volume is configured to be removed by one or more of mechanical, thermal, or chemical degradation.
91. A cutting clement for use in a casing bit configured to drill a casing section into a subterranean formation comprising: an abrasive volume forming at least a portion of a cutting face; and a substrate that is substantially free of carbide.
92. The cutting element of claim 91 , wherein the substrate comprises at least one of steel, tungsten, TZM, molybdenum, bronze, brass, aluminum, or ceramic.
93. A method of forming a borehole, comprising: providing a casing bit configured for drilling a subterranean formation and having an inner region that is configured for drilling therethrough; selecting at least one superabrasive cutting element within the inner region; affixing the at least one superabrasive cutting element within the inner region containing at least one of carbide or diamond; affixing the casing bit to a casing section; forming a borehole by rotating the casing section affixed to the casing bit and engaging a subterranean formation with the casing bit; substantially removing the at least one of diamond and carbide; and drilling through the casing bit with a drilling tool. 111
94. The method of claim 93, wherein substantially removing the at least one of diamond and carbide comprises wearing away the at L east one of diamond and carbide in response to drilling a selected region of subterranean formation.
95. The method of claim 93, wherein substantially removing the at least one of diamond and carbide comprises degrading the at least one of diamond and carbide by one or more of mechanical, thermal, or chemical interaction.
96. A method of cementing a casing within a borehole, comprising: providing a casing bit affixed to a casing section; forming a borehole by rotating the casing section affixed to t ie casing bit; causing a portion of at least one of the casing bit and the casi-ng section to fail to create an aperture therethrough; and flowing cement through the aperture.
97. A drilling assembly for drilling two or more casing sections into a subterranean formation comprising: at least two casing bits of different diameter affixed to respective casing sections of different diameter; wherein radially adjacent casing sections are selectively rclαasably affixed to one another; and wherein the at least two casing bits and the casing sections atre arranged in a telescoping relationship.
98. The drilling assembly of claim 97, wherein the radially adjacent casing sections are affixed to one another by way of shear puns.
99. The drilling assembly of claim 97, wherein one or more casing bits of the at least two casing bits are disposed at least partially with-in one or more other casing bits of the at least two casing bits in a telescoping relationship. 112
100. The drilling assembly of claim 97, wherein one or more smaller casing bits of the at least two casing bits are configured to drill through at least another larger casing bit of the at least two casing bits.
101. A drilling assembly for drilling two* or more casing sections into a subterranean formation comprising: at least two casing sections of different diameter disposed in a telescoping relationship; wherein radially adjacent casing sections are selectively releasably affixed to one another; a drilling tool disposed at a longitudinally preceding end of the at least two casing sections, in relation to an intended direction of drilling; wherein the drilling tool is sized and configured to drill a diameter exceeding a largest diameter of the at least two casing sections of different diameter.
1 2. The drilling assembly of claim 101, wherein the radially adjacent casing sections are affixed to one another by way of shear pins.
103. The drilling assembly of claim 101, wherein the drilling tool comprises at least one of a rotary drill bit, a reamer, and a reaming assembly operably coupled to the innermost of the at least two casing sections.
104. The drilling assembly of claim 101, further comprising a motor disposed longitudinally between and coupled to the drilling tool and the innermost of the at least two casing sections.
105. The drilling assembly of claim 101, wherein the drilling tool comprises a casing bit operably coupled to the innermost of the at least two casing sections.
106. A dπlling assembly for drilling a casing section into a subterranean formation comprising: 113
a casing bit affixed to a casing section; a chamber configured to selectively deliver a substance in proximity to the casing bit; and wherein the substance is configured to render the casing bit more drillable.
107. The drilling assembly of claim 106, wherein the substance comprises at least one of an incendiary agent, an explosive agent-, an acid, and an abrasive material.
108. The drilling assembly of claim 106, wherein the chamber is configured to be punctured to selectively deliver the substance in proximity to the casing bit,
109. The drilling assembly of claim 106, further comprising a piston element that is configured to reduce a size of the chamber to expel the substance therefrom.
110. The drilling assembly of claim 109, wherein the piston element is configured to reduce the size of the chamber by failing one or more frangible elements responsive to force developed by drilling fluid flow through an orifice in excess of a selected drilling fluid flow magnitude.
111. The drilling assembly of claim 109, wbierein the piston element is configured to reduce the size of the chamber in response to an actuation element interacting with the piston element.
112. The drilling assembly of claim 111, wherein the actuation element is a ball disposed within the interior of the casing section configured to move downwardly therein and to cause the size of the chamber to be reduced.
113. A drilling assembly for drilling a casing section into a subterranean formation comprising: 114
a casing bit affixed to a casing section; at least one destructive element configured to render the casing bit more drillable,
114. The drilling assembly of claim 113, wherein the at least one destructive element comprises at least one of an incendiary agent and an explosive agent.
115. The drilling assembly of claim 113, further comprising an ignition device configured to ignite the at least one of an incendiary agent and an explosive agent.
116. The drilling assembly of claim 113, wherein the ignition device is configured to ignite the at least one of an incendiary agent and an explosive agent in response to mud pulse telemetry.
117. A method for removing cutting elements from a casing bit, the method comprising: drilling a casing bit having a plurality of cutting elements affixed thereto by way of braze material into a subterranean fb-rmation to form a borehole; and heating the braze material to a sufficient temperature, while the casing bit is within the borehole, to substantially weaken the affixation of the plurality of cutting elements affixed therewith.
118. A method for removing cutting elements from a casing bit, the method comprising: drilling a casing bit having a plurality of cutting elements affixed thereto by way of an electrically disbonding material into a subterranean formation; and causing electric current to flow through the electrically disbonding material to substantially weaken the affixation of the plurality of cutting elements affixed therewith.
PCT/US2005/004106 2004-02-19 2005-02-10 Casing and liner drilling bits, cutting elements therefor, and methods of use WO2005080742A1 (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US10/783,720 2004-02-19
US10/783,720 US7395882B2 (en) 2004-02-19 2004-02-19 Casing and liner drilling bits

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WO2005080742A1 WO2005080742A1 (en) 2005-09-01
WO2005080742B1 true WO2005080742B1 (en) 2005-10-27

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US20080223575A1 (en) 2008-09-18
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US20110259608A1 (en) 2011-10-27
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US8205693B2 (en) 2012-06-26
US20110259605A1 (en) 2011-10-27
US20110259606A1 (en) 2011-10-27
US8225888B2 (en) 2012-07-24
US20110259643A1 (en) 2011-10-27
US7395882B2 (en) 2008-07-08
US20110259604A1 (en) 2011-10-27
US20050183892A1 (en) 2005-08-25

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