A cutting element may include a substrate; and an ultrahard layer on the substrate, the ultrahard layer including a non-planar working surface that is surrounded by a peripheral edge having a varying height around a circumference of the cutting element, the working surface also having: a plurality of cutting crests extending from an elevated portion of the peripheral edge across at least a portion of the working surface; at least one valley between the plurality of cutting crests; and a canted surface extending laterally from each of the outer plurality of cutting crests towards a depressed portion of the peripheral edge, a height between the depressed portion and the elevated portion being greater than a height between the elevated portion and the valley.
E21B 10/55 - 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
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
E21B 10/54 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
A cutting element for a drill bit includes an outer support element and an inner rotatable cutting element, a portion of which is disposed in the outer support element, where the inner rotatable cutting element has a body with a non-planar cutting face.
E21B 10/52 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of roller type with chisel- or button-type inserts
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
An underreamer for increasing a diameter of a wellbore. The underreamer may include a body having an axial bore extending at least partially therethrough. An electromagnetic activation system may be disposed at least partially within the bore of the body. A valve may be disposed within the bore of the body and coupled to the electromagnetic activation system. The valve may include a mobile element and a static element. The mobile element may be coupled to the electromagnetic activation system and move from a first position where the mobile element obstructs fluid flow through the valve to a second position where the mobile element permits fluid flow through the valve. A cutter block may be movably coupled to the body and move radially-outward as the mobile element moves from the first position to the second position.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 44/06 - Automatic control of the tool feed in response to the flow or pressure of the motive fluid of the drive
E21B 7/28 - Enlarging drilled holes, e.g. by counterboring
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
E21B 7/128 - Underwater drilling from floating support with independent underwater anchored guide base
A cutting element for a drill bit includes an outer support element and an inner rotatable cutting element, a portion of which is disposed in the outer support element, where the inner rotatable cutting element has a body with a non-planar cutting face.
E21B 10/52 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of roller type with chisel- or button-type inserts
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
E21B 10/62 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
A cutting element may include a substrate; and an ultrahard layer on the substrate, the ultrahard layer including a non-planar working surface that is surrounded by a peripheral edge having a varying height around a circumference of the cutting element, the working surface also having: a plurality of cutting crests extending from an elevated portion of the peripheral edge across at least a portion of the working surface; at least one valley between the plurality of cutting crests; and a canted surface extending laterally from each of the outer plurality of cutting crests towards a depressed portion of the peripheral edge, a height between the depressed portion and the elevated portion being greater than a height between the elevated portion and the valley.
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
E21B 10/54 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
E21B 10/55 - 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
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
A downhole cutting tool may include tool body; a first blade extending from the tool body; a plurality of cutting elements attached to the first blade, the plurality of cutting elements comprising at least two types of cutting elements, wherein the first blade extends from the tool body to a first height adjacent a first type of cutting element and a second height, different from the first height, adjacent a second type of cutting element.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 10/54 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
E21B 10/26 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
7.
Cutting elements, methods for manufacturing such cutting elements, and tools incorporating such cutting elements
The present disclosure relates to cutting elements incorporating polycrystalline diamond bodies used for subterranean drilling applications, and more particularly, to polycrystalline diamond bodies having a high diamond content which are configured to provide improved properties of thermal stability and wear resistance, while maintaining a desired degree of impact resistance, when compared to prior polycrystalline diamond bodies. In various embodiments disclosed herein, a cutting element with high diamond content includes a modified PCD structure and/or a modified interface (between the PCD body and a substrate), to provide superior performance.
E21B 10/55 - 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
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
B01J 3/06 - Processes using ultra-high pressure, e.g. for the formation of diamonds; Apparatus therefor, e.g. moulds or dies
B22F 5/00 - Manufacture of workpieces or articles from metallic powder characterised by the special shape of the product
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
B24D 3/10 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent and being essentially inorganic metallic for porous or cellular structure, e.g. for use with diamonds as abrasives
B22F 3/24 - After-treatment of workpieces or articles
8.
Drill bits with internally tapered blade and trimming cutting elements
A drill bit for obtaining core sample fragments from a subterranean formation includes a bit body having a bit centerline and a bit face, a plurality of blades extending radially along the bit face, including a coring blade, a plurality of cutting elements on the blades, and a non-planar insert embedded in the bit body proximate the bit centerline. One of the cutting elements is a first cutting element on the coring blade at a first radial position from the bit centerline, and at least a portion of the coring blade is radially outward from a most radially interior cutting part of the first cutting element.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 25/10 - Formed core retaining or severing means
9.
Polycrystalline diamond constructions with protective element
PCD constructions as disclosed comprise a ultra-hard body attached with a metallic substrate along a substrate extending between the body and the substrate. The construction includes a protective feature or element that is configured to protect a metal rich region or zone existing in the construction from unwanted effects of corrosion or erosion. The protective element extends from the body over the interface and along a portion of the substrate and may be integral with the.
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
10.
Cutting elements formed from combinations of materials and bits incorporating the same
A cutting element has an ultrahard layer on a substrate, the ultrahard layer having a non-planar working surface. The non-planar working surface is formed from a first region and a second region, where the first region encompasses at least a cutting edge or tip of the cutting element and has a differing composition than the second region.
E21B 10/55 - 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
A cutting assembly for use in a drill bit has an ovoid insert including an ultrahard material. The ovoid insert is cast in a matrix such that the matrix surrounds at least part of the ovoid insert, limiting movement of the ovoid insert. Material is removed from the top surface and sidewall of the cutting assembly to produce a cutting edge.
E21B 10/55 - 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
E21B 10/54 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
A downhole tool includes a tool body, at least one blade with a front face having an undulating geometry including a plurality of ridges and valleys, and a top face facing outwardly from the tool body and transitioning to the front face at a cutting edge. At least one cutting element is in a pocket at the cutting edge. The at least one cutting element has a non-planar cutting face facing in the same direction as the front face. The non-planar cutting face has at least two sloping surfaces meeting at an elongated crest, valley, or other feature. A portion of the elongated feature adjacent the front face may substantially align with, and have substantially corresponding geometry as, a ridge or valley of the front face.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
E21B 10/62 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
13.
Fixed cutter bits and other downhole tools having non-planar cutting elements thereon
A downhole cutting tool includes a body having a central axis extending therethrough, a plurality of blades extending outwardly from the body and converging towards a central region around the central axis, and at least one cutting element having a longitudinal axis, a non-cylindrical substrate, and an ultra-hard material body on the non-cylindrical substrate, the ultra-hard material body having a side surface extending around a cutting face and defining a cross-sectional shape of the ultra-hard material body, and the side surface comprising an edge having an inner angle of less than 180 degrees.
A cutting element includes a cutting end extending a depth from a cutting face to an interface surface opposite from the cutting face, and a spindle, the spindle axially separated from the cutting end by a transition region. The spindle has a spindle diameter measured between a spindle side surface, which is less than a cutting end diameter. A guide length, measured from a point of transition to the transition region to a retention feature, is longer than 75% of a total length of the spindle.
Cutting elements and hardfacing materials are in the form of a milled tooth having an uppermost first surface or crest and remaining surfaces such as flank surfaces and end surfaces extending downwardly away from crest. The crest has a hardfaced layer disposed thereon formed from a premium hardfacing material, and one or more of the remaining cutting element surfaces has a hardfaced layer formed from a hardfacing material different than the premium hardfacing material, wherein the hardfaced layer on the crest has a wear resistance at least 10% greater than that of the remaining cutting element hardfaced surfaces. The hardfaced layer on the crest may extend along a partial portion of one or more of the adjacent remaining cutting element surfaces.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
C22C 29/08 - Alloys based on carbides, oxides, borides, nitrides or silicides, e.g. cermets, or other metal compounds, e. g. oxynitrides, sulfides based on carbides or carbonitrides based on carbides, but not containing other metal compounds based on tungsten carbide
B22F 1/02 - Special treatment of metallic powder, e.g. to facilitate working, to improve properties; Metallic powders per se, e.g. mixtures of particles of different composition comprising coating of the powder
C22C 1/05 - Mixtures of metal powder with non-metallic powder
E21B 10/52 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of roller type with chisel- or button-type inserts
B22F 5/00 - Manufacture of workpieces or articles from metallic powder characterised by the special shape of the product
B22F 7/06 - Manufacture of composite layers, workpieces, or articles, comprising metallic powder, by sintering the powder, with or without compacting of composite workpieces or articles from parts, e.g. to form tipped tools
E21B 10/55 - 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
16.
Rotating cutting structures and structures for retaining the same
A downhole cutting tool includes a tool body defining a cutter pocket and a rolling cutter having an inner rotatable cutting element and a sleeve in the cutter pocket, where axial movement of the inner rotatable cutting element is limited by an external retention element disposed outside of the sleeve.
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
E21B 10/55 - 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
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/62 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
A cutting element includes a sleeve, a rotatable cutting element, and at least one retaining ring. The sleeve has a first inner diameter and a second inner diameter, wherein the second inner diameter is larger than the first inner diameter and located at a lower axial position than the first inner diameter. The rotatable cutting element has an axis of rotation extending therethrough, a cutting face, a body extending axially downward from the cutting face, wherein the body has a shaft that is disposed within the sleeve, and a circumferential groove formed around an outer surface of the shaft. The at least one retaining ring is disposed in the circumferential groove and extends at least around the entire circumference of the shaft, wherein the at least one retaining ring protrudes from the circumferential groove, thereby retaining the rotatable cutting element within the sleeve.
E21B 10/62 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/50 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of roller type
E21B 10/627 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements
E21B 10/633 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements independently detachable
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
18.
Kerfing hybrid drill bit and other downhole cutting tools
A drill bit for drilling a borehole in earth formations may include a bit body having a bit axis and a bit face; a plurality of blades extending radially along the bit face; and a plurality of cutting elements disposed on the plurality of blades, the plurality of cutting elements comprising: at least one cutter comprising a substrate and a diamond table having a substantially planar cutting face; and at least two non-planar cutting elements comprising a substrate and a diamond layer having a non-planar cutting end, wherein in a rotated view of the plurality of cutting elements into a single plane, the at least one cutter is located a radial position from the bit axis that is intermediate the radial positions of the at least two non-planar cutting elements.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/55 - 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
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 10/62 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
E21B 10/46 - Drill bits characterised by wear resisting parts, e.g. diamond inserts
E21B 10/54 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
E21B 10/26 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
E21B 10/627 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements
E21B 10/633 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements independently detachable
19.
Thermal insulation layer and pressure transfer medium for high-pressure high-temperature cell
HPHT press system includes a thermal insulation layer. The thermal insulation layer includes CsCl, CsBr, CsI, or a combination thereof, and the thermal insulation layer is electrically insulating. The thermal insulation layer may include a thermal insulation sleeve and/or a thermal insulation button for an HPHT cell.
B30B 11/00 - Presses specially adapted for forming shaped articles from material in particulate or plastic state, e.g. briquetting presses or tabletting presses
B30B 15/00 - PRESSES IN GENERAL; PRESSES NOT OTHERWISE PROVIDED FOR - Details of, or accessories for, presses; Auxiliary measures in connection with pressing
B01J 3/06 - Processes using ultra-high pressure, e.g. for the formation of diamonds; Apparatus therefor, e.g. moulds or dies
20.
Roller cone drill bit with evenly loaded cutting elements
A drill bit is used for drilling through earthen formations and forming a wellbore. The drill bit includes a bit body having a bit axis, and at least a first cone and a second cone coupled to the bit body. Each of the first and the second cones has a backface, a nose opposite the backface, and a cone axis of rotation. An array of cutting elements coupled to the first or second cones is in a band that lies between the backface and the nose. The cutting elements in the band are arranged at radial positions with respect to the bit axis and at least two adjacent cutting elements are at a same radial position within the array, and the remaining cutting elements are at different radial positions within the array.
A method of forming a polycrystalline diamond cutting element includes assembling a diamond material, a substrate, and a source of catalyst material or infiltrant material distinct from the substrate, the source of catalyst material or infiltrant material being adjacent to the diamond material to form an assembly. The substrate includes an attachment material including a refractory metal. The assembly is subjected to a first high-pressure/high temperature condition to cause the catalyst material or infiltrant material to melt and infiltrate into the diamond material and subjected to a second high-pressure/high temperature condition to cause the attachment material to melt and infiltrate a portion of the infiltrated diamond material to bond the infiltrated diamond material to the substrate.
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
B22F 5/00 - Manufacture of workpieces or articles from metallic powder characterised by the special shape of the product
22.
Assemblies for making superhard products by high pressure/high temperature processing
Assemblies as disclosed herein for making superhard products by HPHT process comprise a first can portion for accommodating a mixture of materials therein and a second can mated with the first can portion. A leak-tight seal is provided between the first can portion and second can portion in a manner that accommodates the manufacture of relatively longer superhard products without having to change other elements or members used for HPHT processing to thereby provide improved manufacturing flexibility and cost efficiency.
B29C 43/02 - Compression moulding, i.e. applying external pressure to flow the moulding material; Apparatus therefor of articles of definite length, i.e. discrete articles
B01J 3/06 - Processes using ultra-high pressure, e.g. for the formation of diamonds; Apparatus therefor, e.g. moulds or dies
B29C 43/00 - Compression moulding, i.e. applying external pressure to flow the moulding material; Apparatus therefor
A bit includes a bit body having at least one blade coupled to the bit body. The blade has a plurality of cutting elements at a nose region and a shoulder region of the blade. A plurality of fluid outlets are positioned on the blade such that at least 30% of the cutting elements have a fluid outlet within a distance that is two or three times a cutting element diameter away from a cutting face of the cutting element.
E21B 10/60 - Drill bits characterised by conduits or nozzles for drilling fluids
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 10/50 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of roller type
Roller cutters comprise a diamond-bonded body joined to an infiltration substrate. An extension is joined to the substrate and includes first section having a diameter sized the same as the substrate, and an integral second section having a diameter smaller than the substrate. The extension is joined to the substrate during an HPHT process. The first section has a thickness greater than that of the infiltration substrate. The second section has an axial length greater than the combined thickness of the substrate and the first section. The extension has a strength and/or toughness greater than the substrate as a result of its material composition, e.g., the amount of binder phase material and/or the size of hard phase material. The roller cutter is rotatably disposed within a pocket internal cavity, wherein the pocket is attached to a drill bit.
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
E21B 10/633 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements independently detachable
E21B 10/55 - 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
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
B01J 3/06 - Processes using ultra-high pressure, e.g. for the formation of diamonds; Apparatus therefor, e.g. moulds or dies
B23P 15/28 - Making specific metal objects by operations not covered by a single other subclass or a group in this subclass cutting tools
A cutting element includes a table coupled to a substrate at an interface. The table includes a working surface opposite the interface and defined by a perimeter, a table thickness measured between the interface and the working surface, and a torque transmittable depression formed in the working surface of the table a distance away from the perimeter. The torque transmittable depression extends a depth into the table and has a cross-sectional profile with a torque transmittable shape. The depth of the depression may be greater than the thickness of the table, or an optional sensor may be placed in the depression.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/54 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
E21B 10/633 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements independently detachable
Embodiments disclosed herein relate to a composition useful for forming a stator or a portion thereof. The composition may include: a curable elastomer; a fiber or fibrous compound; a fiber dispersion compound; and optionally carbon black.
F04C 13/00 - Adaptations of machines or pumps for special use, e.g. for extremely high pressures
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
H02K 1/12 - Stationary parts of the magnetic circuit
H02K 15/02 - Methods or apparatus specially adapted for manufacturing, assembling, maintaining or repairing of dynamo-electric machines of stator or rotor bodies
B29C 45/00 - Injection moulding, i.e. forcing the required volume of moulding material through a nozzle into a closed mould; Apparatus therefor
A cutting tool has a tool body, a plurality of blades extending radially from the tool body, at least one pocket in the plurality of blades, and at least one rolling element in the at least one pocket. The cutting tool may be a drill bit, with at least one rolling element in a pocket in a blade of the drill bit and at least partially exposed to the formation to be drilled.
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
E21B 10/46 - Drill bits characterised by wear resisting parts, e.g. diamond inserts
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
B23P 15/28 - Making specific metal objects by operations not covered by a single other subclass or a group in this subclass cutting tools
A cutting element includes a sleeve, a rotatable cutting element, and at least one retaining ring. The sleeve has a first inner diameter and a second inner diameter, wherein the second inner diameter is larger than the first inner diameter and located at a lower axial position than the first inner diameter. The rotatable cutting element has an axis of rotation extending therethrough, a cutting face, a body extending axially downward from the cutting face, wherein the body has a shaft that is disposed within the sleeve, and a circumferential groove formed around an outer surface of the shaft. The at least one retaining ring is disposed in the circumferential groove and extends at least around the entire circumference of the shaft, wherein the at least one retaining ring protrudes from the circumferential groove, thereby retaining the rotatable cutting element within the sleeve.
Techniques relate to a moving cavity motor or pump, such as a mud motor, including a rotor, a stator, and one or more apparatus for constraining (i.e., controlling or limiting) the movement of the rotor relative to the stator, where the apparatus for constraining is operable with the rotor catch. The motor may include a top sub, power section having a progressive cavity motor with a stator and rotor, a rotor catch, and an apparatus between a proximal and distal end of the rotor catch shaft. The apparatus may constrain the radial and/or tangential movement of the rotor catch shaft and the rotor.
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
F03C 2/08 - Rotary-piston engines of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing
F04C 13/00 - Adaptations of machines or pumps for special use, e.g. for extremely high pressures
F04C 15/00 - Component parts, details or accessories of machines, pumps or pumping installations, not provided for in groups
F01C 1/10 - Rotary-piston machines or engines of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member
A method for making a carbonate polycrystalline diamond body includes combining a first quantity of diamond with a first quantity of magnesium carbonate to form a first layer for forming a working surface, and combining a second quantity of magnesium carbonate to form a second layer adjacent to the first layer, forming an assembly. The method includes placing a quantity of silicon or aluminum in or adjacent to at least a portion of the assembly and sintering the assembly including the silicon or aluminum at high pressure and high temperature, causing the silicon or aluminum to infiltrate at least one layer of the assembly.
B24D 3/00 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents
B24D 18/00 - Manufacture of grinding tools, e.g. wheels, not otherwise provided for
B24D 99/00 - Subject matter not provided for in other groups of this subclass
E21B 10/55 - 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
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
B24D 3/02 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent
B24D 11/00 - Constructional features of flexible abrasive materials; Special features in the manufacture of such materials
A container assembly for use in a high-pressure press having a central pressure cell and a method of sealing a central pressure cell. The container assembly includes a container that receives a sample to be pressed, and a gasket distinct from the container, the gasket meeting the container at an interface. The container and the gasket are dimensioned to locate the interface within the central pressure cell.
B29C 43/22 - Compression moulding, i.e. applying external pressure to flow the moulding material; Apparatus therefor of articles of indefinite length
B30B 11/00 - Presses specially adapted for forming shaped articles from material in particulate or plastic state, e.g. briquetting presses or tabletting presses
B01J 3/06 - Processes using ultra-high pressure, e.g. for the formation of diamonds; Apparatus therefor, e.g. moulds or dies
A method for selecting a bottomhole assembly (BHA) includes inputting BHA parameters, wellbore parameters, and drilling operating parameters, performing a dynamic simulation of a first BHA based on the BHA parameters, wellbore parameters, and drilling operating parameters, and presenting a wellbore quality factor of the first BHA calculated from the dynamic simulation.
G06G 7/48 - Analogue computers for specific processes, systems, or devices, e.g. simulators
E21B 41/00 - Equipment or details not covered by groups
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 47/022 - Determining slope or direction of the borehole, e.g. using geomagnetism
E21B 47/08 - Measuring diameters or related dimensions at the borehole
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
33.
Sintering of thick solid carbonate-based PCD for drilling application
A method of making a polycrystalline diamond compact includes forming multiple layers of premixed diamond particles and carbonate material, where the carbonate material includes an alkaline earth metal carbonate, and where each layer has a weight percent ratio of diamond to carbonate that is different from adjacent layers. The layers are subjected to high pressure high temperature conditions to form polycrystalline diamond.
B24D 3/00 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents
B24D 18/00 - Manufacture of grinding tools, e.g. wheels, not otherwise provided for
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/46 - Drill bits characterised by wear resisting parts, e.g. diamond inserts
B24D 3/04 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent and being essentially inorganic
B24D 3/02 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent
B24D 11/00 - Constructional features of flexible abrasive materials; Special features in the manufacture of such materials
An underreamer for increasing a diameter of a wellbore. The underreamer may include a body having an axial bore extending at least partially therethrough. An electromagnetic activation system may be disposed at least partially within the bore of the body. A valve may be disposed within the bore of the body and coupled to the electromagnetic activation system. The valve may include a mobile element and a static element. The mobile element may be coupled to the electromagnetic activation system and move from a first position where the mobile element obstructs fluid flow through the valve to a second position where the mobile element permits fluid flow through the valve. A cutter block may be movably coupled to the body and move radially-outward as the mobile element moves from the first position to the second position.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 7/28 - Enlarging drilled holes, e.g. by counterboring
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
E21B 44/06 - Automatic control of the tool feed in response to the flow or pressure of the motive fluid of the drive
A polycrystalline diamond body, and a method for making a carbonate polycrystalline diamond body includes combining a first quantity of diamond particles with a first quantity of magnesium carbonate to form a first layer in an enclosure, the first layer having a working surface, and placing a second quantity of magnesium carbonate in the enclosure forming a second layer, the first layer and the second layer forming an assembly. A quantity of at least one of silicon or aluminum is mixed in with or placed adjacent to at least one of the first layer or the second layer. The assembly, including the at least one of silicon or aluminum, is sintered at high pressure and high temperature, causing the at least one of silicon or aluminum to infiltrate at least one layer of the assembly, forming a polycrystalline diamond body.
B24D 3/00 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents
B24D 18/00 - Manufacture of grinding tools, e.g. wheels, not otherwise provided for
B24D 99/00 - Subject matter not provided for in other groups of this subclass
B24D 3/04 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent and being essentially inorganic
B24D 11/00 - Constructional features of flexible abrasive materials; Special features in the manufacture of such materials
E21B 10/55 - 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
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
36.
Pressure pumping valves and methods of making such valves
A method for joining a valve member for use within a valve, the method including brazing a body portion having a head and a base, the base having a bore extending a depth therein, to a leg portion having a shaft, the shaft having a distal end, a proximal end opposite the distal end, and a plurality of legs extending radially and axially therefrom and away from the proximal end, the brazing including placing a braze material between the bore and the proximal end, inserting the proximal end into the bore such that a portion of an outer surface of the proximal end is adjacent to an inner surface of the bore, and heating at least the adjacent surfaces to a braze temperature.
A cutting tool may include a tool body. At least one blade extends radially from the tool body, and cutters are coupled to the at least one blade. At least one retention component contributes to the retention of at least two of the plurality of cutters.
A hammer bit includes a bit body having a bit axis and a bit face, a first circumferential row of cutting elements mounted to the bit face, the first circumferential row located at an outermost radius of the bit face and extending around the bit axis, and a second circumferential row of cutting elements mounted to the bit face, the second circumferential row located radially inwardly adjacent the first circumferential row, wherein each of the cutting elements of the second circumferential row is a semi-round top insert. The ratio of the radial overlap distance to the radial span distance between the cutting profiles of cutting elements of the first and second circumferential rows is between 0.1 and 0.5. The ratio of the radial overlap distance to the radial span distance between the cutting profiles of the first and second circumferential rows is greater than 0.25.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
Techniques involve a motor assembly including a rotor and a stator. The stator includes a contact surface for contacting an outer surface of the rotor. The contact surface includes a rigid material. The motor assembly also includes at least one constraint disposed along a length of the motor assembly, where the constraint constrains a radial and/or tangential movement of the rotor relative to the stator. The at least one constraint may be disposed at one or more proximate ends of the motor assembly, and/or along the length of the motor assembly. The contact surface of the stator may have a profile including peaks and valleys, and in some embodiments, the contact surface may be treated to reduce friction and/or wear.
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
Repeated percussive forces may be provided using various devices, systems, assemblies, and methods. Example rotary percussive devices may be used in a downhole environment, including within a drilling system that includes a percussive hammer drill bit. The rotary percussive device may include a rotational translator to convert drilling fluid pressure into a rotational force. An axial translator coupled to the rotational translator may convert the rotational force into an axial percussive force. This conversion may be done using magnets arranged in arrays of alternating polarities. The rotational translator may longitudinally overlap the axial translator. The rotational translator may include a rotational stator rotationally fixed within a bottomhole assembly. The rotational stator may include a shaft of a positive displacement motor.
A cutting element assembly includes a sleeve, a lining extending a distance axially from an end of the sleeve, and an inner cutter. The inner cutter has a cutting end, wherein the cutting end extends a depth from a cutting face, a side surface, and a body, wherein the body is at least partially disposed within the sleeve, and wherein the side surface of the cutting end interfaces with an interfacing surface of the lining.
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
E21B 10/55 - 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
E21B 10/54 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
E21B 10/633 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements independently detachable
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/52 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of roller type with chisel- or button-type inserts
42.
Managed pressure drilling with rig heave compensation
A method for maintaining pressure in a wellbore drilled from a drilling platform floating on a body of water includes the steps of pumping fluid at a determined flow rate into a drill string disposed in a wellbore and measuring fluid pressure within a fluid discharge line of fluid returning from the wellbore. The fluid discharge line has a variable length corresponding to an elevation of the floating platform above the bottom of the body of water. The wellbore pressure is determined at a selected depth in the wellbore or at a selected position along a drilling riser or variable length portion of the fluid discharge line using known parameters/methods. The determined wellbore pressure is adjusted for changes in length of the fluid discharge line corresponding to changes in the elevation of the floating platform relative to the bottom of the body of water. A backpressure system may be operated to maintain the adjusted determined wellbore pressure at a selected (or set point) value by applying backpressure to the wellbore.
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 19/09 - Apparatus for feeding the rods or cables; Apparatus for increasing or decreasing the pressure on the drilling tool; Apparatus for counterbalancing the weight of the rods specially adapted for drilling underwater formations from a floating support using heave compensators supporting the drill string
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
The present invention relates to tungsten-rhenium coated compounds, materials formed from tungsten-rhenium coated compounds, and to methods of forming the same. In embodiments, tungsten and rhenium are coated on ultra hard material particles to form coated ultra hard material particles, and the coated ultra hard material particles are sintered at high temperature and high pressure.
B32B 15/04 - Layered products essentially comprising metal comprising metal as the main or only constituent of a layer, next to another layer of a specific substance
C22C 29/16 - Alloys based on carbides, oxides, borides, nitrides or silicides, e.g. cermets, or other metal compounds, e. g. oxynitrides, sulfides based on nitrides
A fluid control system has a body with the inlet passage in fluid communication with a discharge passage. The position of a choke piston in the body controls flow of the fluid from the inlet passage to the discharge passage. A controller connected to the body has an actuator connected to a linkage that is connected to the choke piston. The controller positions the choke piston in the body using the actuator and the linkage to control the flow of a fluid from the inlet passage to the outlet passage.
A carbide composite for a downhole tool may be formed by depositing a first layer on a substrate, and a second layer at least partially adjacent to the first layer. The first and second layers may each include carbides, metal binders, organic binders, or a combination thereof. The first and second carbide layers may have a different particle size, particle shape, carbide concentration, metal binder concentration, or organic binder concentration from one another.
Polycrystalline diamond constructions comprises a diamond body attached to a metallic substrate, and having an engineered metal content. The body comprises bonded together diamond crystals with a metal material disposed interstitially between the crystals. A body working surface has metal content of 2 to 8 percent that increases moving away therefrom. A transition region between the body and substrate includes metal rich and metal depleted regions having controlled metal content that provides improved thermal expansion matching/reduced residual stress. A point in the body adjacent the metal rich zone has a metal content that is at least about 3 percent by weight greater than that at a body/substrate interface. The metal depleted zone metal content increases gradually moving from the body, and has a thickness greater than 1.25 mm. Metal depleted zone metal content changes less about 4 percent per millimeter moving along the substrate.
B22F 7/06 - Manufacture of composite layers, workpieces, or articles, comprising metallic powder, by sintering the powder, with or without compacting of composite workpieces or articles from parts, e.g. to form tipped tools
B24D 3/10 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent and being essentially inorganic metallic for porous or cellular structure, e.g. for use with diamonds as abrasives
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
B22F 5/00 - Manufacture of workpieces or articles from metallic powder characterised by the special shape of the product
B24D 18/00 - Manufacture of grinding tools, e.g. wheels, not otherwise provided for
Passive load balancing in a fluid bearing for a rotational device is provided using disclosed devices, systems, and methods. In particular, fluid bearing apparatus may include an outer member with an inner member disposed concentrically within the outer member. A fluid inlet may provide fluid communication with a surrounding space between the inner and outer members. A bearing may be connected to the inner member and may extend into the surrounding space. The apparatus may also include a piston located in the surrounding space between the bearing and the fluid inlet. A supporting fluid is located between the piston and a surface of the bearing to transmit force from the piston to the bearing.
An assembly to restrict fluid flow through the bearing section of a positive displacement or progressive cavity pump or motor. The assembly fits within the bearing chamber and includes an upper ring member, a lower ring member, an outer ring member and a floating member. The floating ring member is axially disposed between the upper and lower ring members. The floating ring member is also disposed at least partially around a drive shaft and is radially movable and constrained inwardly of the outer ring member. The floating ring member has a radial clearance between the drive shaft and a floating ring member inner surface with the radial clearance varying depending on the relative position of the floating ring member to the outer ring member.
F01D 25/16 - Arrangement of bearings; Supporting or mounting bearings in casings
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
F16C 17/26 - Systems consisting of a plurality of sliding-contact bearings
F04C 15/00 - Component parts, details or accessories of machines, pumps or pumping installations, not provided for in groups
B23Q 1/28 - Means for securing sliding members in any desired position
B23Q 1/26 - Movable or adjustable work or tool supports characterised by constructional features relating to the co-operation of relatively movable members; Means for preventing relative movement of such members
F16C 35/02 - Rigid support of bearing units; Housings, e.g. caps, covers in the case of sliding-contact bearings
49.
Method and apparatus to manufacture a progressive cavity motor or pump
A stator and a method of manufacturing at least a portion of a progressive cavity motor or pump include disposing a cylindrical shell within a cylindrical housing, disposing a stator mold within the cylindrical shell, disposing an elastomeric material between the stator mold and the cylindrical shell, removing the stator mold from within the elastomeric material, thereby forming an elastomeric material layer having a stator profile within the cylindrical shell, and removing the cylindrical shell from within the cylindrical housing, thereby forming a cartridge having the elastomeric material layer disposed within the cylindrical shell.
F01C 1/10 - Rotary-piston machines or engines of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
A drill bit for obtaining core sample fragments from a subterranean formation includes a bit body having a bit centerline and a bit face, a plurality of blades extending radially along the bit face, including a coring blade, a plurality of cutting elements on the blades, and a non-planar insert embedded in the bit body proximate the bit centerline. One of the cutting elements is a first cutting element on the coring blade at a first radial position from the bit centerline, and at least a portion of the coring blade is radially outward from a most radially interior cutting part of the first cutting element.
E21B 25/10 - Formed core retaining or severing means
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
51.
Ultra-hard material cutting elements and methods of manufacturing the same with a metal-rich intermediate layer
Methods for joining an ultra-hard body, such as a thermally stable polycrystalline diamond (TSP) body, to a substrate and mitigating the formation of high stress concentration regions between the ultra-hard body and the substrate. One method includes covering at least a portion of the ultra-hard body with an intermediate layer, placing the ultra-hard body and the intermediate layer in a mold, filling a remaining portion of mold with a substrate material including a matrix material and a binder material such that the intermediate layer is disposed between the ultra-hard body and the substrate material, and heating the mold to an infiltration temperature configured to melt the binder material and form the substrate.
B24D 3/06 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent and being essentially inorganic metallic
52.
Diamond enhanced insert with controlled diamond frame strength
A Diamond Enhanced Insert (DEI) includes a working layer of a polycrystalline diamond material (PCD). The PCD material includes a first phase that includes a number of particles of a first material. The PCD material also includes a second phase that is adapted as a catalyst. The PCD material has a fracture toughness greater than 12.5 MPa·√m, a flexural strength of greater than 800 MPa, and a diamond frame strength of less than 400 MPa.
B24D 3/10 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent and being essentially inorganic metallic for porous or cellular structure, e.g. for use with diamonds as abrasives
E21B 10/46 - Drill bits characterised by wear resisting parts, e.g. diamond inserts
E21B 10/55 - 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
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
B24D 18/00 - Manufacture of grinding tools, e.g. wheels, not otherwise provided for
B24D 99/00 - Subject matter not provided for in other groups of this subclass
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
53.
Graphite heater with tailored resistance characteristics for HPHT presses and products made therein
A method for sintering includes loading a tool material into a resistance heating element within a HPHT press and heating the resistance heating element at a first axial portion to a control temperature, where a temperature difference is measured between the control temperature and a second temperature measured at a distal axial portion along the resistance heating element, wherein a difference between the control temperature and the second temperature ranges between about 5 percent to about 11 percent of the control temperature.
A cutting element may be formed by sintering together a plurality of metal carbide grains and a metal binder to form a substrate, forming at least one binder gradient in the substrate, and mounting an abrasive layer to the substrate at an interface. The concentration of metal binder material may decrease along at least one direction to form the at least one binder gradient.
E21B 10/46 - Drill bits characterised by wear resisting parts, e.g. diamond inserts
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
B24D 99/00 - Subject matter not provided for in other groups of this subclass
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
B24D 18/00 - Manufacture of grinding tools, e.g. wheels, not otherwise provided for
B24D 3/06 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent and being essentially inorganic metallic
A bearing assembly for a drilling tool. A thrust bearing assembly for use in a drilling tool may include a first thrust frame having a generally cylindrical hollow body with a first inner surface, where the first thrust frame includes: (i) first flow diverters protruding laterally from the first inner surface toward a longitudinal axis of the thrust bearing assembly and (ii) first flow ports formed along the first inner surface between adjacent first flow diverters. The thrust bearing assembly may also include a stationary thrust bearing having a generally cylindrical base with legs extending in an axial direction from the base, where the legs may be generally positioned within the first flow ports.
An underreamer for increasing a diameter of a wellbore. The underreamer includes a body having an axial bore extending at least partially therethrough. A sleeve is arranged and designed to move a first axial distance within the body. A cutter block is movably coupled to the body. The cutter block is arranged and designed to move at least the first axial distance with respect to the body to contact the sleeve in response to hydraulic pressure in the bore. The cutter block moves from a first outer diameter to a second outer diameter as the cutter block moves the first axial distance.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 7/28 - Enlarging drilled holes, e.g. by counterboring
A downhole cutting tool may include tool body; a first blade extending from the tool body; a plurality of cutting elements attached to the first blade, the plurality of cutting elements comprising at least two types of cutting elements, wherein the first blade extends from the tool body to a first height adjacent a first type of cutting element and a second height, different from the first height, adjacent a second type of cutting element.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 10/54 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
E21B 10/26 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
A cutting tool has a tool body and at least one non-planar cutting element oriented at a forward rake angle on the top surface of the cutting tool. The at least one non-planar cutting element of the cutting tool has a grip region and a non-planar cutting end. A support of the cutting tool extends around at least a portion of a circumference of the grip region.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
A downhole motor drive shaft assembly includes a drive shaft having a longitudinal rotational axis, a plurality of drive key sockets, an end housing having a longitudinal rotational axis, a plurality of circumferentially spaced axial keyways, and a concave spherical thrust bearing surface, and a drive key operatively connecting each drive key socket with a respective axial keyway for transferring torque from the drive shaft to the end housing. The drive key includes a substantially planar drive face slidably engaging the axial keyway, and a radiused, cylindrical back portion rotatably engaging the drive key socket, the substantially planar drive face and radiused, cylindrical back portion forming a nominal half-circle.
F16D 3/20 - Universal joints in which flexibility is produced by means of pivots or sliding or rolling connecting parts one coupling part entering a sleeve of the other coupling part and connected thereto by sliding or rolling members
F16C 33/12 - Structural composition; Use of special materials or surface treatments, e.g. for rust-proofing
F16D 3/34 - Hooke's joints or other joints with an equivalent intermediate member to which each coupling part is pivotally or slideably connected in which the coupling is specially adapted to constant velocity-ratio parts being connected by ridges, pins, balls, or the like guided in grooves or between cogs
A downhole motor may include a power section, a connecting rod assembly, and a drive shaft. The power section may include a stator and a rotor with the rotor configured to rotate eccentrically when a drilling fluid is passed through the stator. The connecting rod assembly operatively connects the rotor of the power section and the drive shaft of the bearing section. The connecting rod assembly may include a housing and a connecting rod. The housing may have a proximal end and a distal end with the proximal end connected to the stator. The connecting rod may include a proximal end including a rigid connection operatively connected to the rotor, a mid flexible rod, and a distal end terminating at or proximate an articulating joint. The drive shaft may be operatively connected to the articulating joint.
Elastomeric compositions containing a combination of selected carbon blacks. The resultant elastomers have improved durability and/or power generation. Such elastomers may be used in oilfield products, for example, as seals or stator liners. Methods of producing these elastomeric compositions are also disclosed.
H02K 15/02 - Methods or apparatus specially adapted for manufacturing, assembling, maintaining or repairing of dynamo-electric machines of stator or rotor bodies
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
F04C 13/00 - Adaptations of machines or pumps for special use, e.g. for extremely high pressures
A jar includes the following: a mandrel; an outer housing slidably disposed about the mandrel; a low pressure chamber having a first port and formed between the mandrel and the outer housing; a high pressure chamber having a second port and formed between the mandrel and the outer housing; a fluid passage between the first and second port; and a valve disposed in the fluid passage.
A rolling cone drill bit for drilling in earthen formations. In an embodiment, the drill bit comprises a plurality of rolling cone cutters. Each cone cutter includes a plurality of gage cutting elements, a first plurality of bottomhole cutting elements, and a second plurality of bottomhole cutter elements. Each of the first plurality of bottomhole cutting elements is staggered relative to the gage cutting elements on each cone cutter, and the profiles of the gage cutting elements and the first plurality of bottomhole cutting elements on each cone cutter overlap in rotated profile view. Each of the second plurality of bottomhole cutting elements is staggered relative to the first plurality of bottomhole cutting elements on at least one cone cutter, and the profiles of the first plurality of bottomhole cutting elements and the second plurality of bottomhole cutting elements on at least one cone cutter overlap in rotated profile view.
It is desirable to secure a lower end of a down hole assembly in the event of a down hole failure, such as a fractured drive shaft, enabling recovery of the bottom hole assembly and drill bit. To secure the lower end of the down hole assembly, a catch apparatus according to embodiments herein may be used, the catch apparatus including a rotating bearing having a distal end threadably coupled to a distal portion of a drive shaft. The apparatus may also include a stationary bearing having a proximal end threadably coupled to a distal end of an outer housing. A catch ring may be threadably coupled to a proximal end of the rotating bearing, the catch ring having a shoulder radially overlapping a shoulder of the stationary bearing.
Polycrystalline ultra-hard constructions comprise a polycrystalline ultra-hard material body and two or more support members attached to the body by braze material. The support members include a backside support member and a side support member. The side support member is a one- or two-piece construction, and is positioned circumferentially around and extends axially along the body or both the body and the backside support member such that a working surface of the body remains exposed. The support members can be configured to provide a mechanical attachment or interlocking attachment with the body or another support member. The braze materials used in the construction can be different and selected to enhance the attachment and/or reduce the creation of thermal stress within the construction during assembly. The support members can be selected having different thermal expansion characteristics that also operate to reduce the thermal stress during construction assembly.
B24D 3/00 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents
B24D 3/10 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent and being essentially inorganic metallic for porous or cellular structure, e.g. for use with diamonds as abrasives
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
C09G 1/02 - Polishing compositions containing abrasives or grinding agents
A cutting element includes a polycrystalline diamond layer having a cutting face and a diamond layer side surface, a substrate attached to the polycrystalline diamond layer, the substrate having a bottom surface and a substrate side surface, an interface between the diamond layer and the substrate, and a mask covering at least the bottom surface and the substrate side surface of the cutting element.
A cutter for a fixed cutter drill bit including a substrate and an ultrahard material layer disposed on an end surface of the substrate, the ultra hard material layer having an upper surface opposite the substrate end surface and a peripheral surface such that the upper surface intersects the peripheral surface along a peripheral edge. The peripheral edge continuously increases and decreases in height as measured from a plane perpendicular to a longitudinal axis of the cutter.
E21B 10/55 - 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
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
68.
Apparatuses and methods for stabilizing downhole tools
A secondary cutting structure for use in a drilling assembly includes a tubular body, and a block, extendable from the tubular body, the block including a first arrangement of cutting elements disposed on a first blade, a first stabilization section disposed proximate the first arrangement of cutting elements, a second arrangement of cutting elements disposed on the first blade, and a second stabilization section disposed proximate the second arrangement of cutting elements. A method of drilling includes disposing a drilling assembly in a wellbore, the drilling assembly including a secondary cutting structure having a tubular body and a block, extendable from the body, the block including at least three blades, actuating the secondary cutting structure, wherein the actuating includes extending the block from the tubular body, and drilling formation with the extended block.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
A downhole cutting tool may include a tool body; a plurality of blades extending from the tool body; a first blade comprising at least one pointed cutting element thereon, the at least one pointed cutting element comprising a first polycrystalline diamond material on a first carbide substrate, the first polycrystalline diamond material extending away from the first carbide substrate to terminate in a substantially pointed geometry opposite the first carbide substrate; a second blade comprising at least one shear cutting element, the at least one shear cutting element comprising a second polycrystalline diamond material on a second carbide substrate, the second polycrystalline diamond material forming a planar cutting surface opposite the substrate; wherein, when the first blade and the second blade are superimposed on each other, a central axis of the at least one pointed cutting element is offset from a central axis of the at least one shear cutting element.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 10/55 - 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
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
E21B 10/54 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits
70.
Computing systems, tools, and methods for simulating wellbore departure
Specialized computing systems, devices, interfaces and methods facilitate the simulation of downhole milling procedures such as wellbore departure milling procedures. Computing systems, devices, interfaces and methods enable a user to design and select milling components and procedures to be compared and simulated. Various milling parameters, such as milling tool parameters, whipstock parameters, and wellbore casing parameters may be accessed and selectably modified with milling and simulation interfaces to define and control the simulated milling procedures. Different types of output are selectably rendered to reflect various aspects of the simulated milling procedures.
A method for treating a polycrystalline diamond material includes subjecting the polycrystalline diamond material to a leaching process and to a thermal decomposition process.
B24D 18/00 - Manufacture of grinding tools, e.g. wheels, not otherwise provided for
B01J 3/06 - Processes using ultra-high pressure, e.g. for the formation of diamonds; Apparatus therefor, e.g. moulds or dies
C04B 35/52 - Shaped ceramic products characterised by their composition; Ceramic compositions; Processing powders of inorganic compounds preparatory to the manufacturing of ceramic products based on non-oxides based on carbon, e.g. graphite
A method of forming a cutting element may include subjecting a first press containing at least a diamond powder-containing container and a volume of a high melting temperature non-reactive material to a first high pressure high temperature sintering condition to form a sintered polycrystalline diamond wafer including a diamond matrix of diamond grains bonded together and a plurality of interstitial spaces between the bonded together diamond grains; and subjecting a second press containing the sintered polycrystalline diamond wafer and a substrate to a second high temperature high pressure condition, thereby attaching the wafer to the substrate to form a cutting element having a polycrystalline diamond layer on the substrate.
E21B 10/55 - 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
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
Methods for manufacturing a matrix tool body comprising placing a first matrix material within a first region of a mold cavity proximate a surface of the mold. A second matrix material may be placed within a second region of the mold cavity positioned inwardly of the first matrix material. The first matrix material and the second matrix material comprise a plurality of hard particles. The plurality of hard particles of the second matrix material have a median particle size that is less than the median particle size of the first matrix material. The plurality of hard particles of the first matrix material and the second matrix material are infiltrated with an infiltration binder to form the tool body. Also included are tool bodies having one or more regions proximate a surface of the tool body comprising an erosion resistant matrix material and/or a wear resistant matrix material.
C22C 29/06 - Alloys based on carbides, oxides, borides, nitrides or silicides, e.g. cermets, or other metal compounds, e. g. oxynitrides, sulfides based on carbides or carbonitrides based on carbides, but not containing other metal compounds
B24D 3/06 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent and being essentially inorganic metallic
B22D 19/14 - Casting in, on, or around, objects which form part of the product the objects being filamentary or particulate in form
E21B 10/55 - 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
B24D 99/00 - Subject matter not provided for in other groups of this subclass
74.
Wellbore annular pressure control system and method using gas lift in drilling fluid return line
A system and method include pumping drilling fluid through a drill string extended into a wellbore extending below the bottom of a body of water, out the bottom of the drill string and into the wellbore annulus. Fluid is discharged from the annulus into a riser and a discharge conduit. The riser is disposed above the top of the wellbore and extends to the water surface. The discharge conduit couples to the riser and includes a controllable fluid choke. A fluid return line is coupled to an outlet of the choke and extends to the water surface. Gas under pressure is pumped into the return line at a selected depth below the water surface. The controllable fluid choke may be operated to maintain a selected drilling fluid level in the riser, the selected fluid level being a selected distance below the water surface.
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
E21B 21/16 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using gaseous fluids
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
A system for field selecting drill bit includes a server having a computing processor with functionality to perform: receiving a first simulation request, executing a first simulation to generate a first set of performance data, receiving a second simulation request, and executing a second simulation to generate a second set of performance data. A computing device coupled to the server having a graphical user interface with functionality to perform: selecting a baseline bit, inputting a plurality of drilling data, sending the first simulation request, receiving the first set of performance data, presenting the first set of performance data for review, modifying a parameter of a drill bit, sending the second simulation request with the modified parameter, receiving the second set of performance data from the second simulation, and presenting the first set of performance data and the second set of performance data for review.
A system and method for locating a bottom hole assembly during liner drilling. The system and method employ a liner and a drill string. The liner may include a stop sub. The drill string may include a bottom hole assembly position indicator. In one or more embodiments, the bottom hole assembly position indicator is configured to engage the stop sub and arrest further advancement of the drill string.
A fixed cutter drill bit may include a bit body having a bit centerline and a plurality of blades that extend radially from the bit body and are separated by a plurality of flow courses therebetween. Each of the plurality of blades is spaced a radial distance from the bit centerline to define a core-forming region. A plurality of cutting elements is disposed on the plurality of blades. The plurality of cutting elements comprises at least two coring cutting elements that are disposed on the plurality of blades and the at least two coring cutting elements are the radially innermost cutting elements on the plurality of blades.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
A downhole tool for increasing a diameter of a wellbore disposed within a subterranean formation. The downhole tool includes an underreamer having a plurality of cutter blocks moveably coupled thereto that move radially-outward from a refracted state to an expanded state. The cutter blocks cut the subterranean formation to increase the diameter of the wellbore from a first diameter to a second diameter when in the expanded state. A formation weakening tool may be coupled to the underreamer. The formation weakening tool weakens a portion of the subterranean formation positioned radially-outward therefrom.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 7/15 - Drilling by use of heat, e.g. flame drilling of electrically generated heat
E21B 7/124 - Underwater drilling with underwater tool drive prime mover, e.g. portable drilling rigs for use on underwater floors
A fixed cutter drill bit may include a bit body having a bit centerline a plurality of blades extending radially from the bit body, and a plurality of flow courses between the plurality of blades. Each of the plurality of blades is spaced a radial distance from the bit centerline to define a core-forming region. A plurality of cutting elements is disposed on the plurality of blades, and the plurality of cutting elements include at least one coring cutting element disposed on at least one of the plurality of blades. The at least one coring cutting element is the radially innermost cutting element on the plurality of blades, and a coring angle of the at least one coring cutting element is less than an inner cone angle thereof.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
A downhole tool includes a body having a bore extending at least partially therethrough. A component is disposed within the bore and arranged and designed to move axially from a first position to a second position within the bore. An axial end portion of the component has a first contact surface that is oriented at an angle from about 1° to about 45° with respect to a longitudinal axis extending through the component.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
81.
Cutting structures and structures for retaining the same
A downhole cutting tool may include a tool body having at least one cutting element support structure formed thereon, wherein the at least one cutting element support structure comprises at least one cutter pocket formed therein; at least one cutter having at least substantially unobstructed cutting face retained within the at least one cutter pocket, the cutter pocket preventing substantial lateral movement of the at least one cutter; and at least one retention element interfacing a portion of a circumferential surface of the at least one cutter.
E21B 10/633 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements independently detachable
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
A downhole cutting tool may include a cutting element support, structure having a plurality of cutter pockets formed therein; and a plurality of rotatable cutters disposed in the plurality of cutter pockets, wherein at least one rotatable cutter is spaced from another rotatable cutter on the cutting element support structure by at least one-quarter of the diameter of the at least one rotatable cutter.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
E21B 10/14 - Roller bits combined with non-rolling cutters other than of leading-portion type
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
83.
Systems and methods for managed pressured drilling
Stable back pressure control devices are used to control fluid pressure in a wellbore to provide constant downhole pressure. Back pressure may be estimated from a correlation between the speed of a mud pump and the pressure exerted from the pump. Drilling plans disclosed herein provide for the continued operation of one or more back pressure control devices for providing constant bottomhole pressure when casing connections are being made.
A cutting element for a drill bit includes an outer support element and an inner rotatable cutting element, a portion of which is disposed in the outer support element, where the inner rotatable cutting element has a body with a non-planar cutting face.
E21B 10/62 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
E21B 10/52 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of roller type with chisel- or button-type inserts
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
85.
Axially stable retention mechanism for picks and cutting elements
A cutting element assembly includes a cutting element partially disposed within a support and a retention mechanism disposed between the cutting element and the support, both the axial and radial dimensions of the retention mechanism being deformable.
E21C 35/197 - Means for fixing picks or holders using sleeves, rings or the like, as main fixing elements
B28D 1/18 - Working stone or stone-like materials, e.g. brick, concrete, not provided for elsewhere; Machines, devices, tools therefor by milling, e.g. channelling by means of milling tools
86.
Positive displacement motor with radially constrained rotor catch
A moving cavity motor or pump, such as a mud motor, comprising: a rotor, a stator, and one or more apparatus for constraining (i.e., controlling or limiting) the movement of the rotor relative to the stator, where the apparatus for constraining is operable with the rotor catch.
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
F03C 2/08 - Rotary-piston engines of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing
F04C 13/00 - Adaptations of machines or pumps for special use, e.g. for extremely high pressures
F04C 15/00 - Component parts, details or accessories of machines, pumps or pumping installations, not provided for in groups
A cutter assembly may include a sleeve having at least one passageway extending through the sleeve from a outer surface thereof into an inner surface thereof; at least one rotatable cutting element disposed in the sleeve, wherein the at least one rotatable cutting element has a circumferential groove formed in a side surface thereof, wherein when the inner rotatable cutting element is disposed in the sleeve, the circumferential groove is aligned with the passageway; and a retention element disposed in at least a portion of the passageway and the circumferential groove to retain the at least one rotatable cutting element in the sleeve, wherein the retention element has an axis that is parallel to a tangent of the rotatable cutting element side surface at least one point of contact with the rotatable cutting element.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts - characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
E21B 10/633 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements independently detachable
88.
Method and apparatus for controlling bottom hole pressure in a subterranean formation during rig pump operation
A method for maintaining pressure in a wellbore during drilling operations is disclosed. The method includes the steps of providing fluid from a reservoir through a drill string, circulating the fluid from the drill string to an annulus between the drill string and the wellbore, isolating pressure in the annulus, measuring pressure in the annulus, calculating a set point backpressure, applying back pressure to the annulus based on the set point back pressure, diverting fluid from the annulus to a controllable choke, controllably bleeding pressurized fluid from the annulus, separating solids from the fluid, and directing the fluid to the reservoir. An apparatus for maintaining pressure in a wellbore during drilling operations that includes an adjustable choke for controllably bleeding off pressurized fluid from the wellbore annulus. A backpressure pump for applying a set point backpressure, and a processor for controlling the adjustable choke and backpressure pump are also disclosed.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
89.
Methods for analyzing and designing bottom hole assemblies
A method for selecting a bottomhole assembly, including performing a first dynamic simulation of a first bottomhole assembly, performing at least a second dynamic simulation of the first bottomhole assembly, in which the at least a second dynamic simulation includes a different constraint than the first dynamic simulation, and outputting results for both the first dynamic simulation and the second dynamic simulation, in which the results include at least one output showing performance as a function of position along the bottomhole assembly.
E21B 41/00 - Equipment or details not covered by groups
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
A carbide composite for a downhole tool may be formed by depositing a first layer on a substrate, and a second layer at least partially adjacent to the first layer. The first and second layers may each include carbides, metal binders, organic binders, or a combination thereof. The first and second carbide layers may have a different particle size, particle shape, carbide concentration, metal binder concentration, or organic binder concentration from one another.
An underreamer for increasing a diameter of a wellbore. The underreamer may include a body having an axial bore extending at least partially therethrough. An electromagnetic activation system may be disposed at least partially within the bore of the body. A valve may be disposed within the bore of the body and coupled to the electromagnetic activation system. The valve may include a mobile element and a static element. The mobile element may be coupled to the electromagnetic activation system and move from a first position where the mobile element obstructs fluid flow through the valve to a second position where the mobile element permits fluid flow through the valve. A cutter block may be movably coupled to the body and move radially-outward as the mobile element moves from the first position to the second position.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 44/06 - Automatic control of the tool feed in response to the flow or pressure of the motive fluid of the drive
E21B 7/28 - Enlarging drilled holes, e.g. by counterboring
E21B 34/06 - Valve arrangements for boreholes or wells in wells
An underreamer for increasing a diameter of a wellbore. The underreamer may include a body with first and second cutter blocks coupled to the body. The first cutter block may have a recess formed therein, and the second cutter block may be positioned in the recess. The first and second cutter blocks may move between retracted and expanded states. In the retracted state, the first and second cutter blocks may have an outer diameter less than or equal to an outer diameter of the body. In the expanded state, the first and second cutter blocks may have different outer diameters, with each being greater than the outer diameter of the body. A method may include running the underreamer into a wellbore, expanding the first and second cutter blocks, and moving the underreamer axially in the wellbore to increase the diameter of the wellbore.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 7/28 - Enlarging drilled holes, e.g. by counterboring
E21B 10/26 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
A drilling system may include one or more downhole components to which a torque is applied. To determine the torque, the rotational velocity may be determined at two locations on a downhole component. An angle of twist may be determined by taking the integral of the rotational velocity at the two points, and the torque may be proportional to the angle of twist. The angle of twist, physical properties based on the geometry and material of the downhole component may be used, and the distance between the two locations may be used to calculate the torque.
E21B 45/00 - Measuring the drilling time or rate of penetration
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
94.
Cutting structures for fixed cutter drill bit and other downhole cutting tools
A cutting tool may includes a tool body; a plurality of blades extending from the tool body; and a plurality of non-planar cutting elements disposed along each of the plurality of blades, the plurality of non-planar cutting elements form a cutting profile, in a rotated view of the plurality of non-planar cutting elements into a single plane, the cutting profile including a cone region, a nose region, a shoulder region, and a gage region. The plurality of non-planar cutting elements include a first shape in at least one of the cone region, nose region, shoulder region, and gage region, and a second, different shape in at least one other region.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/55 - 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
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
95.
Cutting structures for fixed cutter drill bit and other downhole cutting tools
A cutting tool may include a tool body, blades extending from the tool body, and primary cutting elements and backup cutting elements are on each of blades. The backup cutting elements may be behind and at approximately the same radial distance from the axis of the tool body as a corresponding primary cutting element, where the primary cutting elements include cutting elements having a first non-planar shape and the backup cutting elements include cutting elements having a second, different non-planar shape.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 10/55 - 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
An underreamer for increasing a diameter of a wellbore. The underreamer includes a body having an axial bore extending at least partially therethrough. A mandrel is disposed within the bore of the body and has a port formed radially therethrough. A sleeve is disposed radially-outward from the mandrel. The sleeve blocks fluid flow through the port in the mandrel when the sleeve is in a first position, and the sleeve is axially-offset from the port in the mandrel when the sleeve is in a second position. A flow tube is coupled to the mandrel. The sleeve moves from the first position to the second position when fluid flows through the flow tube and through a channel disposed in the mandrel. A cutter block is movably coupled to the body and is responsive to fluid flow from the axial bore through the port in the mandrel.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 7/28 - Enlarging drilled holes, e.g. by counterboring
E21B 44/06 - Automatic control of the tool feed in response to the flow or pressure of the motive fluid of the drive
A polycrystalline diamond body, and a method for making a carbonate polycrystalline diamond body includes combining a first quantity of diamond particles with a first quantity of magnesium carbonate to form a first layer in an enclosure, the first layer having a working surface, and placing a second quantity of magnesium carbonate in the enclosure forming a second layer, the first layer and the second layer forming an assembly. A quantity of at least one of silicon or aluminum is mixed in with or placed adjacent to at least one of the first layer or the second layer. The assembly, including the at least one of silicon or aluminum, is sintered at high pressure and high temperature, causing the at least one of silicon or aluminum to infiltrate at least one layer of the assembly, forming a polycrystalline diamond body.
B24D 3/00 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents
B24D 3/02 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent
B24D 11/00 - Constructional features of flexible abrasive materials; Special features in the manufacture of such materials
B24D 18/00 - Manufacture of grinding tools, e.g. wheels, not otherwise provided for
A method for making a carbonate polycrystalline diamond body includes combining a first quantity of diamond with a first quantity of magnesium carbonate to form a first layer for forming a working surface, and combining a second quantity of magnesium carbonate to form a second layer adjacent to the first layer, forming an assembly. The method includes placing a quantity of silicon or aluminum in or adjacent to at least a portion of the assembly and sintering the assembly including the silicon or aluminum at high pressure and high temperature, causing the silicon or aluminum to infiltrate at least one layer of the assembly.
B24D 3/00 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents
B24D 3/02 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special nature; Abrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent
B24D 11/00 - Constructional features of flexible abrasive materials; Special features in the manufacture of such materials
B24D 18/00 - Manufacture of grinding tools, e.g. wheels, not otherwise provided for
A locking clutch to selectively transmit torque from a stator of a downhole tool to a rotor of the downhole tool includes at least one locking pawl disposed upon the rotor, wherein the at least one locking pawl comprises a load path, at least one pivot axis, and a mass center, wherein the at least one locking pawl is biased into an engaged position by a biasing mechanism, wherein the at least one locking pawl transmits force from the stator to the rotor along the load path when in the engaged position, and wherein centrifugal force urges the at least one locking pawl into a disengaged position when the rotor is rotated above a disengagement speed.
F16D 43/16 - Internally controlled automatic clutches actuated entirely mechanically controlled by angular speed with centrifugal masses themselves being the clutching members with clutching members having interengaging parts
F16D 43/14 - Internally controlled automatic clutches actuated entirely mechanically controlled by angular speed with centrifugal masses themselves being the clutching members
An apparatus comprises a mandrel having a longitudinal axis and further comprises a plurality of pivoting elements spaced apart along a circumference of a cross-section of the mandrel. Each of the pivoting elements is pivotable around a transversal axis that is perpendicular to the longitudinal axis.