4304results about "Cutting machines" patented technology

A drill bit that includes a bit body; and at least one cutting element for engaging the formation disposed on the bit body, the at least one cutting element comprising: a ductile phase; a plurality of carbide particles dispersed in the ductile phase; and a plurality of nanotubes integrated into the cutting element is disclosed.

A downhole tool that functions as an underreamer, or alternatively, as a stabilizer in an underreamed borehole. The tool includes one or more moveable arms disposed within a body having a flowbore therethrough in fluid communication with the wellbore annulus. The tool alternates between collapsed and expanded positions in response to differential fluid pressure between the flowbore and the wellbore annulus. In one embodiment, the tool moves automatically in response to differential pressure. In a second embodiment, the tool must be selectively actuated before it is moveable. When the tool expands, the arms are preferably translated axially upwardly, while simultaneously being extended radially outwardly from the body. The expanded tool diameter is adjustable at the surface without changing components. The arms may include borehole engaging pads that comprise cutting structures or wear structures or both, depending upon the function of the tool.

Cutting elements of this invention include an ultra hard body joined with a metallic substrate. The body includes an uppermost layer comprising a plurality of bonded ultra hard crystals and interstitial regions, and that defines a body working surface. The uppermost layer includes an outer region that is relatively more thermally stable than a remaining portion of the uppermost layer. The body further includes an intermediate layer joined to the uppermost layer, comprising a plurality of bonded ultra hard crystals, and having a wear resistance less than that of the uppermost layer remaining region. The body may additionally include a lowermost PCD layer that is interposed between and attached to the intermediate layer and the substrate.

Cutting elements of this invention include an ultra hard body joined with a metallic substrate. The body includes an uppermost layer comprising a plurality of bonded ultra hard crystals and interstitial regions, and that defines a body working surface. The uppermost layer includes an outer region that is relatively more thermally stable than a remaining portion of the uppermost layer. The body further includes an intermediate layer joined to the uppermost layer, comprising a plurality of bonded ultra hard crystals, and having a wear resistance less than that of the uppermost layer remaining region. The body may additionally include a lowermost PCD layer that is interposed between and attached to the intermediate layer and the substrate.

A round-shank bit for a coal cutting machine or the like, having a bit head and a bit shank, wherein the bit head has a bit tip, maintained by a base element in a receptacle of the bit head. Starting at the base element, the bit tip tapers in a direction toward the free end of the bit tip, wherein the base element forms a maximum diameter of the bit tip, and wherein the bit tip has recesses on its outer contour. In order to assure good rotational behavior over the entire length of the operating time, the base element has the recesses on an outer circumference forming the maximum diameter.

A method for simulating the drilling performance of a roller cone bit drilling an earth formation may be used to generate a visual representation of drilling, to design roller cone drill bits, and to optimize the drilling performance of a roller cone bit. The method for generating a visual representation of a roller cone bit drilling earth formations includes selecting bit design parameters, selecting drilling parameters, and selecting an earth formation to be drilled. The method further includes calculating, from the bit design parameters, drilling parameters and earth formation, parameters of a crater formed when one of a plurality of cutting elements contacts the earth formation. The method further includes calculating a bottomhole geometry, wherein the crater is removed from a bottomhole surface. The method also includes incrementally rotating the bit and repeating the calculating of crater parameters and bottomhole geometry based on calculated roller cone rotation speed and geometrical location with respect to rotation of said roller cone drill bit about its axis. The method also includes converting the crater and bottomhole geometry parameters into a visual representation.

Formation engaging elements are moveably mounted onto a drill bit. Such elements may be used to protect other rigidly mounted formation engaging elements from impacts that occur during use of the drill bit, or they may be used to alter the aggressiveness of the drill bit when used in directional drilling operations.

The present invention is an apparatus for use in drilling operations. It uses an under-reamer having a plurality of elongated arms with cutting elements at the ends of the arms for enlarging a previously drilled borehole drilled by a drill bit. One or more stabilizers in close proximity to the under-reamer provide stability to the under-reamer and the drill bit. The stabilizer could be rotating or non-rotating; and could be positioned between the under-reamer and the drill bit, or above the under reamer or above a directional device on the drillstring. The cutting arms are selectively operable to perform the enlargement. The stabilizer may be provided with members that closely fit the size of the borehole.

A bi-center drill bit includes pilot and reaming blades affixed to a body at azimuthally spaced locations. The blades have PDC cutters attached at selected positions. In one aspect, the pilot blades form a section having length along the bit axis less than about 80 percent of a diameter of the section. In another aspect, selected pilot blades and corresponding reaming blades are formed into single spiral structures. In another aspect, shapes and positions of the blades and inserts are selected so that lateral forces exerted by the reaming and the pilot sections are balanced as a single structure. Lateral forces are preferably balanced to within 10 percent of the total axial force on the bit. In another aspect, the center of mass of the bit is located less than about 2.5 percent of the diameter of the bit from the axis of rotation. In another aspect, jets are disposed in the reaming section oriented so that their axes are within about 30 degrees of normal to the axis of the bit. In another aspect, the reaming blades are shaped to conform to the radially least extensive, from the longitudinal axis, of a pass-through circle or a drill circle, so the cutters on the reaming blades drill at the drill diameter, without contact to the cutters on the reaming blades when the bit passes through an opening having about the pass-through diameter.

An expandable reamer apparatus and methods for reaming a borehole, wherein a laterally movable blade carried by a tubular body may be selectively positioned at an inward position and an expanded position. The laterally movable blade, held inwardly by blade-biasing elements, may be forced outwardly by drilling fluid selectively allowed to communicate therewith by way of an actuation sleeve disposed within the tubular body. Alternatively, a separation element may transmit force or pressure from the drilling fluid to the movable blade. Further, a chamber in communication with the movable blade may be pressurized by way of a downhole turbine or pump. A ridged seal wiper, compensator, movable bearing pad, fixed bearing pad preceding the movable blade, or an adjustable spacer element to alter expanded blade position may be included within the expandable reamer. In addition, a drilling fluid pressure response indicating an operational characteristic of the expandable reamer may be generated.

Cutting elements are provided having substrates including end surfaces. TSP material layers extend over only a portion of the end surfaces or extend into the substrates below the end surfaces. Bits incorporating such cutting elements are also provided.

Thermally-stable polycrystalline diamond materials of this invention comprise a first phase including a plurality of bonded together diamond crystals, and a second phase including a reaction product formed between a binder / catalyst material and a material reactive with the binder / catalyst material. The reaction product is disposed within interstitial regions of the polycrystalline diamond material that exists between the bonded diamond crystals. The first and second phases are formed during a single high pressure / high temperature process condition. The reaction product has a coefficient of thermal expansion that is relatively closer to that of the bonded together diamond crystals than that of the binder / catalyst material, thereby providing an improved degree of thermal stability to the polycrystalline diamond material.

PCD materials comprise a diamond body having bonded diamond crystals and interstitial regions disposed among the crystals. The diamond body is formed from diamond grains and a catalyst material at high pressure / high temperature conditions. The diamond grains have an average particle size of about 0.03 mm or greater. At least a portion of the diamond body has a high diamond volume content of greater than about 93 percent by volume. The entire diamond body can comprise high volume content diamond or a region of the diamond body can comprise the high volume content diamond. The diamond body includes a working surface, a first region substantially free of the catalyst material, and a second region that includes the catalyst material. At least a portion of the first region extends from the working surface to depth of from about 0.01 to about 0.1 mm.

The present invention is a bi-center drill bit designed to drill out the cement and other material in the casing and then proceed to drill out the full gauge drilling diameter borehole with a diameter greater than the inside of the casing. The bi-center drill bit is configured with non-drilling bearing elements that contact with the casing when the bit is drilling the cement without allowing the gauge cutting elements of the bi-center drill bit to contact the casing. The bi-center drill bit also has a cutting element configuration which prevents reverse scraping of the cutting elements when drilling both the cement and the formation.

A cutting element is provided including a substrate and a TSP material layer over the substrate. The TSP material layer includes at least a property having a value that varies through the layer.

A drilling bit for use in conjunction with a holder that has a bore wherein the drilling bit has a drilling bit body that has an axial forward end and an axial rearward end. The drilling bit body further includes a reduced diameter portion adjacent to the axial rearward end thereof so as to define a reduced diameter surface. A hard insert is affixed to the drilling bit body at the axial forward end thereof. A resilient retainer sleeve has a first thickness and presents an interior surface. The retainer sleeve is carried by the drilling bit body within the reduced diameter portion. The resilient retainer sleeve is in an expanded condition when the drilling bit is not within the bore of the holder and the resilient retainer sleeve is in a compressed condition when the drilling bit being within the bore of the holder. The clearance between the reduced diameter surface of the drilling bit body and the interior surface of the resilient retainer sleeve when the resilient retainer sleeve is in its compressed condition is at least as great as the thickness of the resilient retainer sleeve.

A rotary drill bit for drilling subterranean formations configured with at least one protective structure proximate to the rotationally leading and trailing edges of a gage trimmer, wherein the at least one protective structure is positioned at substantially the same exposure as its associated gage trimmer. Particularly, the apparatus of the present invention may provide protection for gage trimmers during drilling, tripping, and / or rotation within a casing; i.e., when changing a drilling fluid. Protective structures may be configured and located according to anticipated drilling conditions including helix angles. In addition, a protective structure may be proximate to more than one gage trimmer while having a substantially equal exposure to each associated gage trimmer. Methods of use and a method of rotary bit design are also disclosed.

A drill bit nozzle providing a through bore for the passage of drilling fluid through a drill bit. The nozzle is made of a material or materials which can be drilled through by standard well bore drilling equipment. The material(s) are selected to provide a surface to the through bore which has a relatively high resistance to erosion to withstand the abrasive and corrosive impact of jetted drilling fluid. Embodiments are described using a hard chrome / copper combination and a single rubber material.

Diamond-bonded constructions include a diamond-bonded body having a thermally stable region extending a distance below a diamond-bonded body surface. The thermally stable region comprises a matrix phase of bonded-together diamond crystals, and interstitial regions comprising a reaction product. The reaction product is formed by reaction between the diamond crystals and a reactive material. The reactant is a carbide former and the reaction product is a carbide. The diamond-bonded body includes a further diamond region extending from the thermally stable region that comprises the matrix phase and a Group VIII metal disposed within interstitial regions of the matrix phase. The thermally stable region is substantially free of a catalyst material used to initially form the diamond-bonded body. The diamond-bonded body may include a material layer formed from the reaction product that is disposed on a surface of the diamond-bonded body thermally stable region.

The invention provides an excavation bit, which is constructed from either a single or double carrier. If two carriers are present the carriers are contra-rotating. By the off setting of the axes of rotation of single or dual carriers from a longitudinal axis of the bit, and by driving to carriers to rotate, a ground engaging thrust is produced, as well as the rotation of the excavation bit in the ground as a consequence of the rotation of the carriers, and not vice versa as is the case with prior art. By the invention, there can result sufficient thrust on the bit, by the rotation of the carriers, so that the need to apply thrust down the bore via the drill rod is reduced or eliminated. As a result of the invention the number and or size of the ground engaging tools are not a function of the bore diameter to be drilled. Thus as the excavation bit is scaled up for larger diameter bores more ground engaging tools and or an increase in their size is not required. By the invention, thrust applied (either via the drill rod or from the rotation of the carriers) is thought to be, through a quasi lever system, multiplied at some of the ground engaging tools in the radial direction. That is the total thrust in the longitudinal axis direction (whether externally applied or resultant from the contra-rotation of the carriers), is multiplied so that the outward forces exerted (by the cutters onto the rock surface in the region approaching perpendicular to the longitudinal axis of the bore) is thought to be significantly higher than the magnitude of the total thrust.

The present invention generally relates to a method and an apparatus for drilling with casing. In one aspect, a method of drilling a wellbore with casing is provided, including placing a string of casing with a drill bit at the lower end thereof into a previously formed wellbore and urging the string of casing axially downward to form a new section of wellbore. The method further includes pumping fluid through the string of casing into an annulus formed between the casing string and the new section of wellbore. The method also includes diverting a portion of the fluid into an upper annulus in the previously formed wellbore. In another aspect, a method of drilling with casing to form a wellbore is provided. In yet another aspect, an apparatus for forming a wellbore is provided. In still another aspect, a method of casing a wellbore while drilling the wellbore is provided.