WO2020060668A1 - Ensembles trains de tiges de forage et systèmes et procédés d'utilisation associés - Google Patents

Ensembles trains de tiges de forage et systèmes et procédés d'utilisation associés Download PDF

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Publication number
WO2020060668A1
WO2020060668A1 PCT/US2019/043216 US2019043216W WO2020060668A1 WO 2020060668 A1 WO2020060668 A1 WO 2020060668A1 US 2019043216 W US2019043216 W US 2019043216W WO 2020060668 A1 WO2020060668 A1 WO 2020060668A1
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WO
WIPO (PCT)
Prior art keywords
drill
string assembly
drill string
drill bit
percussive
Prior art date
Application number
PCT/US2019/043216
Other languages
English (en)
Inventor
Jeffrey Hogan
Christopher L. Drenth
Tushar Matkar
Original Assignee
Bly Ip 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 Bly Ip Inc. filed Critical Bly Ip Inc.
Publication of WO2020060668A1 publication Critical patent/WO2020060668A1/fr

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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
    • 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
    • E21B17/042—Threaded
    • 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
    • E21B10/003—Drill bits with cutting edges facing in opposite axial directions
    • 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
    • E21B1/00—Percussion drilling
    • 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
    • E21B10/36—Percussion drill bits
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • 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
    • 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
    • E21B17/042—Threaded
    • E21B17/0426—Threaded with a threaded cylindrical portion, e.g. for percussion rods
    • 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
    • E21B10/42—Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
    • 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
    • E21B10/60—Drill bits characterised by conduits or nozzles for drilling fluids

Definitions

  • the disclosed invention relates to percussive drill string assemblies, and, in particular, to single-rod percussive drill string assemblies.
  • the percussive drill string assembly can include a drill bit and a drill rod.
  • the drill bit can have a body.
  • the body of the drill bit can have: a circumferential wall; a crown extending distally from the circumferential wall; and a threaded portion extending proximally from the circumferential wall.
  • the threaded portion can have an outer surface that defines at least one thread having a tapered thread profile.
  • the drill rod can have a box end portion having an inner surface.
  • the inner surface of the box end portion can define: a receptacle configured to receive the threaded portion of the body of the bit; and at least one thread having a tapered profile complementary to the tapered thread profile of the threaded portion of the body of the bit.
  • Figure 1A is a perspective view of an exemplary drill string assembly as disclosed herein.
  • Figure 1B is a cross-sectional view of the drill string assembly of Figure 1A.
  • Figure 2A is a perspective view of an exemplary drill string assembly having a drill rod with axial slots as disclosed herein.
  • Figure 2B is a perspective view of an exemplary drill string assembly having a drill rod formed of round steel and defining axial slots as disclosed herein.
  • Figure 3 is a perspective view of an exemplary drill string assembly having a crown with projecting buttons and a drill rod with axial slots as disclosed herein.
  • Figure 4A is a perspective view of an exemplary drill bit having a body 22 and a proximal threaded portion as disclosed herein.
  • Figure 4B is a perspective view of an exemplary drill bit having a water slot in an alternative location.
  • Figure 5 A is a side elevational view of an exemplary drill bit having a staged profile as disclosed herein.
  • Figure 5B is a top plan view of the drill bit of Figure 5 A.
  • Figure 6A is a perspective view of an exemplary drill rod having a cylindrical outer diameter and tapered axial slots as disclosed herein.
  • Figure 6B is a cross-sectional view of the drill rod of Figure 6A.
  • Figure 6C is a perspective view of another exemplary drill rod having a cylindrical outer diameter and tapered axial slots as disclosed herein.
  • Figure 7 is a perspective view of an exemplary drill rod having angled axial slots as disclosed herein.
  • Figure 8A is a perspective view of a portion of a drill rod, in accordance with embodiments disclosed herein, having cutting removal features.
  • Figure 8B is side view of the portion of the drill rod of Figure 8A.
  • Figure 8C is a bottom view of the portion of the drill rod of Figure 8A.
  • Figure 8D is a detail view of the side view of Figure 8A.
  • Ranges can be expressed herein as from“about” one particular value, and/or to “about” another particular value. When such a range is expressed, another aspect includes from the one particular value and/or to the other particular value. Similarly, when values are expressed as approximations, by use of the antecedent“about,” it will be understood that the particular value forms another aspect. It will be further understood that the endpoints of each of the ranges are significant both in relation to the other endpoint, and independently of the other endpoint.
  • the terms“optional” or“optionally” mean that the subsequently described event or circumstance may or may not occur, and that the description includes instances where said event or circumstance occurs and instances where it does not.
  • the word“or” as used herein means any one member of a particular list and also includes any combination of members of that list.
  • proximal refers to a direction toward the surface of a formation (where a drill rig can be located)
  • distal refers to a direction toward the bottom or end of a drill hole, moving away from the surface of the formation.
  • [metal] -based alloy (where [metal] is any metal) means commercially pure [metal] in addition to metal alloys wherein the weight percentage of [metal] in the alloy is greater than the weight percentage of any other component of the alloy. Where two or more metals are listed in this manner, the weight percentage of the listed metals in combination is greater than the weight percentage of any other component of the alloy.
  • tungsten carbide means any material composition that contains chemical compounds of tungsten and carbon in any stoichiometric or non- stoichiometric ratio or proportion, such as, for example, WC, W 2 C, and combinations of WC and W 2 C.
  • Tungsten carbide includes any morphological form of this material, for example, cast tungsten carbide, sintered tungsten carbide, monocrystalline tungsten carbide, and macrocrystalline tungsten carbide.
  • wear-resistant refers to a drilling tool that is not designed to erode or degrade to expose cutting material imbedded or otherwise positioned within the drilling tool.
  • wear-resistant tools are distinguishable from— and operate in a fundamentally different way than— impregnated drilling tools that are designed to wear away to continuously expose cutting media within the drilling tools.
  • the disclosed drill string assemblies can provide one or more improvements or advantages in comparison to existing tunneling drill string assemblies, leading to increases in rod life and straighter holes.
  • rod tip-off is a major problem for tunneling rods.
  • the rods are (incorrectly) used for scaling purposes, leading to dragging of the bit along rock as a hammering operation continues and resulting in undesirable loading problems that exacerbate the problem of rod failure.
  • the disclosed drill string assemblies can provide better flushing and tip-off resistance in comparison to conventional tunneling rod assemblies. It is further contemplated that the disclosed drill string assemblies can reduce or eliminate the misuse of rods for scaling purposes.
  • the drill string assembly 10 can have a drill bit 20 and a drill rod 50.
  • the drill bit 20 can have a body 22, which can include a circumferential (annular) wall 30 and a crown 24 extending distally from the circumferential wall.
  • the drill bit 20 can further comprise a threaded portion 40 extending proximally from the circumferential wall 30.
  • the threaded portion 40 can have an outer surface that defines at least one thread 42 having a tapered thread profile.
  • the drill rod 50 can have a box end portion 52 having an inner surface 56.
  • the inner surface 56 of the box end portion 52 can define a receptacle 58 configured to receive the threaded portion 42 of the bit 20.
  • the inner surface 56 of the box end portion 52 can define at least one thread 60 having a tapered profile complementary to the tapered thread profile of the threaded portion 42 of the bit 20.
  • the tapered thread profile of the threaded portion 42 of the bit can have a taper ranging from about 1 degree to about 10 degrees relative to the longitudinal axis 12.
  • the drill bit 20 can be a wear-resistant drill bit.
  • the drill bit 20 can be a percussive drill bit, such as a button drill bit, a blade drill bit, or a down-the-hole (DTH) hammer bit.
  • the drill bit 20 can be a button drill bit comprising buttons 25, such as, for example and without limitation, a rotary drag bit, a bi-cone bit, or a tri-cone bit.
  • buttons can be secured to the cutting face of the bit using conventional methods.
  • such buttons can comprise carbide (e.g., tungsten carbide) and/or polycrystalline diamond (PCD).
  • buttons 25 can be integrally formed with the matrix that forms the bit 20.
  • other wear-resistant drilling tools such as hole reamers, back reamers, hole openers, and drill string stabilizers, can be used in place of the disclosed drill bit, in combination with the drill rod 50.
  • the body 22 of the drill bit 20 can be an infiltrated body comprising a matrix and a binder.
  • the matrix can comprise a hard particulate material and a plurality of abrasive particles dispersed throughout the hard particulate material.
  • the binder can secure the hard particulate material and the abrasive particles together.
  • the plurality of abrasive particles can comprise a plurality of diamond particles.
  • any conventional abrasive cutting media can be used.
  • the box end portion 52 of the drill rod 50 can define a distal end 54 of the drill rod and have an outer surface 62.
  • the outer surface 62 of the box end portion 52 can be inwardly tapered (toward the longitudinal axis 12) moving proximally from the distal end 54. It is contemplated that the combination of a drill bit with a tapered thread and a drill rod having a box end portion with a tapered outer diameter can permit use of a standard (non- cylindrical) mid-body design in the drill rod.
  • this combination can provide for more efficient evacuation of cuttings and more drilling productivity in comparison to the use of straight couplings/rods.
  • at least a portion of the outer surface 62 of the box end portion 52 can be inwardly tapered at an angle ranging from about 2 degrees to about 10 degrees.
  • the entire outer surface 62 can have a consistent taper.
  • the box end portion 52 of the drill rod 50 can have an outer diameter that circumscribes a cylinder.
  • the box end portion 52 can comprise a plurality of axial slots 64 (further described below) that are inwardly recessed from the outer diameter and inwardly tapered moving proximally from the distal end 54. It is contemplated that these axial slots can be inwardly tapered at an angle ranging from about 2 degrees to about 10 degrees.
  • at least one axial slot 64 (optionally, each axial slot 64) of the plurality of axial slots can have a straight profile as shown in Figures 6A and 6C.
  • the outer diameter of the box end portion need not circumscribe a cylinder.
  • a plurality of axial slots 64 can be inwardly recessed from the outer diameter and inwardly tapered moving proximally from the distal end 54. As shown, it is contemplated that at least one axial slot 64 (optionally, each axial slot) of the plurality of axial slots can have a spiral or helical profile.
  • the plurality of axial slots 64 can be equally or substantially equally circumferentially spaced about the outer surface 62 of the box end portion 52. In one aspect, it is contemplated that the plurality of axial slots 64 can optionally be equally or substantially equally sized. Optionally, in further exemplary aspects, it is contemplated that the plurality of axial slots 64 can comprise from 2 to 16 axial slots or, more practically, from 2 to 6 axial slots, including, for example, 3, 4, or 5 axial slots.
  • the circumferential wall 30 and the threaded portion 42 of the drill bit 20 can cooperate to define an interior space 35 extending along the longitudinal axis 12 of the drill string assembly (e.g., percussive drill string assembly) 10.
  • the drill rod 50 can comprise a mid-body portion 66 that extends proximally from the box end portion 52.
  • the mid body portion 66 can have an inner surface 68 that cooperates with the circumferential wall 30 and the threaded portion 42 of the body 22 of the drill bit 20 to further define the interior space 35.
  • the interior space 35 can be configured to receive water or other drilling fluid during use of the drill bit 20.
  • the water or other drilling fluid can be supplied to the interior space 35 at a desired pressure.
  • the mid-body portion 66 of the drill rod 50 can be welded to the box end portion 52 of the drill rod 50.
  • the mid-body and box end portions 66, 52 of the drill rod 50 can be formed as a single piece using forging in accordance with conventional single-piece forging methods.
  • the threaded portion 42 of the drill bit 20 can define a proximal end 44 of the drill bit.
  • the proximal end 44 of the drill bit 20 can comprise a water slot 46a (optionally, a plurality of water slots) extending radially from the interior space 35 to the outer surface of the threaded portion 42.
  • the body 22 of the drill bit 20 can have a distal end that defines a shoulder 27 that is configured to abut a distal end of the drill rod 50, with the shoulder defining a water slot 46b (optionally, a plurality of water slots) to provide a radial flow pathway between the drill bit 20 and the drill rod 50.
  • the water slot 46a can allow for the outward flow of a small volume of water (or other drilling fluid) from the interior space to cool and clean the threads of the bit 20.
  • the crown 24 of the body 22 of the drill bit 20 can be a full-face crown.
  • the crown 24 of the body 22 of the drill bit 20 can define a plurality of bores 28 in fluid communication with the interior space 35.
  • the circumferential wall 30 of the body 22 of the drill bit 20 can define at least one bore 36 in fluid communication with the interior space 35.
  • the plurality of bores 36 can be configured to direct water (or other drilling fluid) directly (or substantially directly) to the distal (cutting) face 26 from the interior space 25. It is further contemplated that the direct supply of pressurized water (or other drilling fluid) to the cutting face 26 can increase flow velocity across the cutting face, thereby permitting more rapid removal of cuttings and significantly increasing the convective cooling of the cutting face. It is further contemplated that the plurality of bores 36 can reduce the contact area of the cutting face 26 relative to conventional drill bits, thereby improving the penetration rate of the drill bit 10.
  • the plurality of bores 36 can permit novel distribution of water (or other drilling fluid) relative to the cutting face 26, thereby improving the wear resistance of the drill bit 10. It is still further contemplated that the plurality of bores 36 can provide flexibility in the distribution of water (or other drilling fluid) such that the center port of conventional drill bits is unnecessary (and can be eliminated from the drill bit).
  • the cutting face 26 can have a convex profile. In other aspects, it is contemplated that the cutting face 26 can optionally have a concave profile.
  • the plurality of bores 28 can optionally be equally (or substantially equally) distributed about the face 26.
  • the plurality of bores 28 can be randomly spaced from a center point of the drill bit 20.
  • the plurality of bores can optionally be uniformly (or substantially uniformly) spaced from the center point of the drill bit 20.
  • at least two concentric rows of bores can be provided, with the bores in each respective row being uniformly (or substantially uniformly) spaced from the center point of the drill bit 20.
  • the plurality of bores 28, 36 can be provided in any selected configuration. It is further contemplated that the plurality of bores 28, 36 can be distributed so as to optimize the wear characteristics of the drill bit 20 for a particular application.
  • each bore 28, 36 of the plurality of bores can be provided in a selected shape.
  • the plurality of bores 28, 36 can have a cylindrical shape (with a circular cross-sectional profile) or a substantially cylindrical shape (with a substantially circular cross-sectional profile).
  • the plurality of bores 28, 36 can have any shape, including, for example and without limitation, a conical or substantially conical (tapered) shape (with a circular or substantially circular cross- sectional profile), a shape having a rectangular or substantially rectangular cross-sectional profile, a shape having a square or substantially square cross-sectional profile, an S-shape, and the like.
  • an inner surface of the bit 20 (that defines the interior space 35) can define at least one flute extending parallel or substantially parallel to the longitudinal axis 12.
  • each flute of the at least one flute can optionally correspond to a rounded groove extending radially from the inner surface of the circumferential wall toward the outer surface 32 of the circumferential wall.
  • the at least one flute can optionally be positioned in fluid communication with at least one bore 28, 36 of the body 22 of the bit 20.
  • the circumferential wall 30 of the body 22 of the drill bit 20 can have an outer surface 32 that defines at least one axial channel 34 (optionally, a plurality of axial channels) that extends axially relative to the longitudinal axis 12 and is inwardly recessed from the outer surface 32 (toward the longitudinal axis).
  • the at least one axial channel 34 can be configured to permit delivery of cuttings from the cutting face of the bit to the annulus between the outer diameter of the drill bit and the drill hole.
  • the plurality of axial channels 34 can be equally or substantially equally circumferentially spaced about the outer surface 32 of the body 22 of the drill bit 20. In one aspect, it is contemplated that the plurality of axial channels 34 can optionally be equally or substantially equally sized. Optionally, in further exemplary aspects, it is contemplated that the plurality of axial channels 34 can comprise from 2 to 16 axial channels or, more practically, from 2 to 6 axial channels, including, for example, 2, 3, 4, or 5 axial channels. [0042] In further exemplary aspects, the circumferential wall 30 of the body 22 of the drill bit 20 can completely circumferentially enclose the interior space 35. In still further exemplary aspects, the circumferential wall 30 does not comprise a waterway extending radially between the outer surface of the circumferential wall and the interior space.
  • the outer surface 62 of the box end portion 52 of the drill rod 50 can define a plurality of axial slots 64.
  • the outer surface 32 of the circumferential wall 30 of the body 22 of the drill bit 20 defines at least one axial channel 34 as shown in Figures 2A-3
  • at least one axial slot 64 of the plurality of axial slots can be axially aligned with a corresponding axial channel of the body of the drill bit.
  • the axial slots 64 can be proximally tapered (with a width that decreases moving in a proximal direction) as shown in Figures 2A-2B.
  • the axial slots 64 can be distally tapered (with a width that decreases moving in a distal direction) as shown in Figure 3.
  • the box end portion 52 of the drill rod 50 can have an axial length.
  • at least one axial slot (optionally, each axial slot) 64 of the plurality of axial slots can have an axial length that is greater than 60 percent of the axial length of the box end portion 52. It is further contemplated that at least one axial slot (optionally, each axial slot) 64 of the plurality of axial slots can have an axial length that ranges from about 60 to about 90 percent, from about 70 to about 90 percent, from about 70 to about 80 percent, or from about 80 to about 90 percent of the axial length of the box end portion 52.
  • the drill bit 20 can have a gauge diameter, and the circumferential wall 30 and the crown 24 of the body 22 of the drill bit can have a combined axial length (measured relative to the longitudinal axis 12). In these aspects, it is
  • a ratio between the combined axial length of the crown 24 and the circumferential wall 30 of the body 22 of the drill bit and the gauge diameter of the drill bit can be less than 0.7 or can range from about 0.5 to about 0.8 or from about 0.6 to about 0.7.
  • the combined axial length of the circumferential wall and the crown of the body of the drill bit can be less than 2 inches.
  • the crown 24 of the body 22 of the drill bit 20 can have a staged profile.
  • the staged profile can include a center platform 38 that projects upwardly from the remainder (i.e., a base portion) of the body 22 of the bit 20.
  • the outer surface 32 of the base portion of the body 22 of the bit can further comprise at least one flute 37 (optionally, a plurality of flutes) that are positioned in fluid communication with (optionally, in contact with) a corresponding channel 34.
  • At least one flute 37 can be angularly oriented relative to the longitudinal axis 12 of the drill string assembly 10. Additionally, or alternatively, in further aspects, at least one flute 37 (optionally, each flute) can be angularly oriented relative to (i.e., not parallel or aligned with) the channel 34 that is in fluid communication with the flute 37.
  • the center platform 38 can define the crown 24 of the bit 20. It is further contemplated that buttons 25 can be secured to (or integrally formed with) the center platform and extend from the crown 24. As shown in Figures 5A-5B, it is still further contemplated that buttons 25 can be secured to (or integrally formed with) the outer surface of the base portion of the body of the bit (from which the center platform 38 projects).
  • the center platform 38 can define at least one bore extending to the face 26 of the crown 24 and in fluid communication with the interior space 35 as further disclosed herein.
  • the base portion of the body 22 of the bit can define a bore 36 that is in fluid communication with the interior space 35 as further disclosed herein.
  • the total length of the body 22 of the staged drill bit (including the center platform) as shown in Figures 5A-5B can range from about 5 inches to about 6.5 inches.
  • the maximum outer diameter of the body 22 of the staged drill bit i.e., measured at the base portion
  • the drill string assembly 10 can be provided as a portion of a drilling system.
  • the drilling system can comprise a drill or drill rig as is known in the art.
  • a drill can be operatively secured or coupled to the disclosed drill string assembly 10 such that the drill can effect movement of the drill string assembly.
  • the drilling system can comprise a production drill, such as a hydraulic production drill as is known in the art.
  • An example of a suitable hydraulic production drill is the STOPEMASTERTM hydraulic production drill manufactured by Boart Longyear (Salt Lake City, Utah).
  • the drilling system can be a single-pass system that does not comprise an extension or an additional drill rod. That is, in these aspects, it is contemplated that the drilling system can comprise only a single drill rod (that is a component of the drill string assembly 10).
  • the drill rod 50 can comprise a back face 80 that is provided with a cutting profile 82 that comprises at least one cutting edge 84.
  • the cutting edge 84 can be a surface oriented so that vectors extending
  • the perpendicularly to the surface’s face extend at least partially in a direction of travel of the cutting edge 84 as it rotates about the drill rod’s longitudinal axis 12 ( Figure 1A).
  • the drill string can rotate counter-clockwise.
  • the at least one cutting edge 84 can be disposed to engage cuttings as the drill rod 50 rotates counter clockwise.
  • the at least one cutting edge 84 defined on the back face 80 can have a substantially saw-tooth cutting profile. It is contemplated that the at least one cutting edge 84 of the back face 80 can be configured to cut and/or agitate cuttings, thereby promoting removal of the drill rod 50 from the hole and increasing the productivity of drilling operations.
  • the cutting profile 82 can cooperate with flutes 37 to provide increased efficiency in chip evacuation.
  • the cutting profile 82 can comprise a plurality of back cutting teeth 86.
  • the teeth 86 can be circumferentially spaced about the back face 80.
  • the plurality of teeth 86 can be substantially equally circumferentially spaced about the back face 80.
  • each tooth 86 of the plurality of teeth can define a respective cutting edge 84 of the back face 80.
  • the plurality of back cutting teeth 86 can comprise five back cutting teeth.
  • the cutting profile 82 can comprise a plurality of recessed portions 88 positioned between adjacent teeth 86 of the plurality of back cutting teeth.
  • the plurality of recessed portions 88 can comprise five recessed portions.
  • the recessed portions 88 can be defined by corresponding sloped portions 83 of the cutting profile 82.
  • the sloped portions 83 of the cutting profile 82 can be oriented at a selected angle 89a relative to a plane 85 positioned perpendicular to the longitudinal axis 12 ( Figure 1A) of the drill rod 50.
  • the selected angle 89a can range from about 5° to about 45°. In one exemplary aspect, it is contemplated that the selected angle 89a can range from about 10° to about 30°. In another exemplary aspect, it is contemplated that the selected angle 89a can range from about 15° to about 20°.
  • the back surface 80 can be a step that, at least in certain portions, defines a shoulder surface that is perpendicular to the longitudinal axis.
  • the sloped portions 83 can transition to a surface of increasing concavity in a clockwise direction 90 that ultimately defines the cutting edge 84.
  • the cutting edge 84 can engage the cuttings as the bit rotates in the counterclockwise direction 91.
  • the sloped portions 83 can have an end 92 that is opposite the back cutting teeth 86.
  • the back cutting teeth 86 can extend to a proximal edge 93 (moving away from the cutting face of the bit) that is on the same transverse plane as the end 92 of the sloped portions 83.
  • Methods of using the described percussive drill string assembly 10 are also disclosed.
  • the drill string assembly can be used in a horizontal or near-horizontal drilling operation, such as in conventional tunneling or drifting processes.
  • the drill string assembly can be used in a bolting process (e.g., a rock bolting process for stabilizing a rock excavation) as is known in the art.
  • the binder materials disclosed herein can include, for example, cobalt-based, iron-based, nickel-based, silver-based, iron and nickel-based, cobalt and nickel-based, iron and cobalt-based, aluminum-based, copper-based, magnesium-based, molybdenum based, and titanium-based alloys.
  • the alloying elements can include, but are not limited to, one or more of the following elements— manganese (Mn), nickel (Ni), silver (Ag), tin (Sn), zinc (Zn), silicon (Si), molybdenum (Mo), tungsten (W), boron (B) and phosphorous (P).
  • the binder material can also be selected from commercially pure elements such as cobalt, aluminum, silver, copper, magnesium, titanium, iron, and nickel.
  • the binder composite material can include carbon steel, alloy steel, stainless steel, tool steel, Hadfield manganese steel, nickel or cobalt superalloy material, and low thermal expansion iron or nickel based alloys.
  • the abrasive particles of the matrix compositions disclosed herein can comprise diamond, synthetic diamond, metal or semi-metal carbides, nitrides, oxides, or borides.
  • the abrasive particles can comprise diamond or ceramic materials such as carbides, nitrides, oxides, and borides (including boron carbide (EUC)) and combinations of them, such as carbonitrides.
  • the abrasive particles can comprise carbides and borides made from elements such as W, Ti, Mo, Nb, V, Hf, Ta, Cr, Zr, Al, and Si.
  • materials that may be used to form abrasive particles include tungsten carbide (WC, W 2 C), titanium carbide (TiC), tantalum carbide (TaC), titanium diboride (T1B2), chromium carbides, titanium nitride (TiN), vanadium carbide (VC), aluminium oxide (AI 2 O 3 ), aluminium nitride (A1N), boron nitride (BN), and silicon carbide (SiC).
  • tungsten carbide WC, W 2 C
  • TiC titanium carbide
  • TaC tantalum carbide
  • chromium carbides titanium nitride (TiN), vanadium carbide (VC), aluminium oxide (AI 2 O 3 ), aluminium nitride (A1N), boron nitride (BN), and silicon carbide (SiC).
  • combinations of different abrasive particles may be used to tailor the physical properties and characteristics of the matrix material.
  • the hard particulate material of the matrix can comprise a tungsten-based alloy.
  • the hard particulate material of the matrix can comprise a tungsten carbide-based alloy.
  • other conventional hard particulate materials can be used.
  • a percussive drill string assembly having a longitudinal axis and comprising: a drill bit having: a body having: a circumferential wall; and a crown extending distally from the circumferential wall; and a threaded portion extending proximally from the circumferential wall, wherein the threaded portion has an outer surface that defines at least one thread having a tapered thread profile; and a drill rod having: a box end portion having an inner surface that defines: a receptacle configured to receive the threaded portion of the bit; and at least one thread having a tapered profile complementary to the tapered thread profile of the threaded portion of the bit.
  • Aspect 2 The percussive drill string assembly of aspect 1, wherein the box end portion of the drill rod defines a distal end of the drill rod and has an outer surface, wherein at least a portion of the outer surface of the box end portion is inwardly tapered moving proximally from the distal end.
  • Aspect 3 The percussive drill string assembly of aspect 1 or aspect 2, wherein the circumferential wall and the threaded portion of the drill bit cooperate to define an interior space extending along the longitudinal axis of the percussive drill string assembly.
  • Aspect 4 The percussive drill string assembly of aspect 3, wherein the drill rod comprises a mid-body portion that extends proximally from the box end portion, and wherein the mid-body portion has an inner surface that cooperates with the circumferential wall and the threaded portion of the drill bit to further define the interior space.
  • Aspect 5 The percussive drill string assembly of aspect 3 or aspect 4, wherein the threaded portion of the drill bit defines a proximal end of the drill bit and wherein the body of the drill bit defines a shoulder that is configured to abut a distal end of the drill rod, and wherein the drill bit comprises: a water slot defined by the proximal end of the drill bit and extending radially from the interior space to the outer surface of the threaded portion; and/or a water slot defined by the shoulder and extending radially outwardly to an exterior surface of the drill bit.
  • Aspect 6 The percussive drill string assembly of any one of aspects 3-5, wherein the crown of the body of the drill bit is a full-face crown.
  • Aspect 7 The percussive drill string assembly of aspect 6, wherein the crown of the body of the drill bit defines a plurality of bores in fluid communication with the interior space.
  • Aspect 8 The percussive drill string assembly of any one of aspects 3-7, wherein the circumferential wall of the body of the drill bit defines at least one bore in fluid communication with the interior space.
  • Aspect 9 The percussive drill string assembly of any one of the preceding aspects, wherein the circumferential wall of the body of the drill bit has an outer surface that defines at least one axial channel.
  • Aspect 10 The percussive drill string assembly of any one of aspects 2-9, wherein the outer surface of the box end portion of the drill rod defines a plurality of axial slots.
  • Aspect 11 The percussive drill string assembly of aspect 10, wherein the circumferential wall of the body of the drill bit has an outer surface that defines at least one axial channel, and wherein at least one axial slot of the plurality of axial slots is axially aligned with a corresponding axial channel of the body of the drill bit.
  • Aspect 12 The percussive drill string assembly of aspect 10 or aspect 11, wherein the axial slots are proximally tapered.
  • Aspect 13 The percussive drill string assembly of any one of aspects 10-12, wherein the box end portion of the drill rod has an axial length, and wherein at least one axial slot of the plurality of axial slots has an axial length that is greater than 60% of the axial length of the box end portion.
  • Aspect 14 The percussive drill string assembly of any one of aspects 4-13, wherein the mid-body portion of the drill rod is welded to the box end portion of the drill rod.
  • Aspect 15 The percussive drill string assembly of any one of aspects 4-14, wherein the mid-body and box end portions of the drill rod are forged as a single piece.
  • Aspect 16 The percussive drill string assembly of any one of the preceding aspects, wherein the drill bit has a gauge diameter, wherein the circumferential wall and the crown of the body of the drill bit have a combined axial length, and wherein a ratio between the combined axial length of the crown and the body of the drill bit and the gauge diameter of the drill bit is less than 0.7.
  • Aspect 17 The percussive drill string assembly of any one of the preceding aspects, wherein the crown of the body of the drill bit has a staged profile.
  • Aspect 18 The percussive drill string assembly of any one of aspects 10-17, wherein the box end portion of the drill rod has an outer diameter that circumscribes a cylinder, and wherein the plurality of axial slots that are inwardly recessed from the outer diameter and inwardly tapered moving proximally from the distal end.
  • a drilling system comprising the percussive drill string assembly of any one of the preceding aspects.
  • Aspect 20 The drilling system of aspect 19, wherein the drilling system is a single-pass system that does not comprise an extension or an additional drill rod.
  • Aspect 21 A method of using the percussive drill string assembly of any one of aspects 1-18.
  • Aspect 22 The method of aspect 21, wherein the percussive drill string assembly is used in a tunneling or bolting process.
  • Aspect 23 The percussive drill string assembly of any one of aspects 1-18, wherein the drill rod comprises at least one back face defining a cutting profile.

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  • 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

L'invention concerne un ensemble train de tiges de forage à percussion qui comprend un trépan et une tige de forage. Le trépan a un corps qui a : une paroi circonférentielle ; une couronne qui s'étend de façon distale à partir de la paroi circonférentielle ; et une partie filetée qui s'étend de façon proximale à partir de la paroi circonférentielle. La partie filetée a une surface extérieure qui définit au moins un filet qui a un profil de filet effilé. La tige de forage a une partie d'extrémité de joint à filetage femelle qui a une surface intérieure qui définit : un réceptacle configuré pour recevoir la partie filetée du trépan ; et au moins un filet qui a un profil effilé complémentaire du profil de filet effilé de la partie filetée du trépan.
PCT/US2019/043216 2018-09-17 2019-07-24 Ensembles trains de tiges de forage et systèmes et procédés d'utilisation associés WO2020060668A1 (fr)

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US201862732209P 2018-09-17 2018-09-17
US62/732,209 2018-09-17

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EP4179176A1 (fr) * 2020-07-08 2023-05-17 Robit Plc Ensemble foret pour un forage par percussion, trépan et élément de train de tiges de forage
CA3183779A1 (fr) 2021-12-09 2023-06-09 Precise Drilling Components Ltd Elargisseur
FI130985B1 (en) * 2022-02-14 2024-07-05 Tri Mach Global Oue Drill bit

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