Abstract: A drill bit made according to one embodiment includes a first member including one of a magnet and a coil, and a second member that moves relative to the first member, the second member including the other of the magnet and the coil, wherein the relative motion causes the generation of an electrical charge in the coil.

Abstract: Methods of coupling a bearing assembly to a downhole tool include forming at least a portion of a downhole component from a diamond-enhanced material, applying a metal material to a surface of the downhole component using an ultrasonic molten metal process, and coupling at least a portion of the surface of the downhole component to at least another component of the downhole tool. Downhole tools include at least one component of a bearing assembly that is configured to move relative to a portion of the downhole tool. The at least one bearing component comprises a diamond-enhanced material and is coupled to a portion of the downhole tool by an ultrasonic molten metal process.

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

Abstract: The invention relates to a device and a method for handling rod-shaped elements on drilling gear. The safety is inter alia increased by a device and a method wherein rod-shaped elements are placed on a placement device in defined positions and under defined conditions, the rod-shaped elements are separated on the placement device while being monitored, their safe support on a gripper is checked and once the elements are handed over to an elevator this action is confirmed.

Abstract: An anti-stall tool in an oil well drilling assembly that controls reciprocation of the drill bit by an electrical controller that alters weight-on-bit (WOB) depending upon measured downhole pressure or torque at the downhole motor. The electrical controller receives preset high and low working pressure limits for the downhole motor and activates a hydraulic valve system to keep the drill bit rotating by maintaining WOB during normal drilling operations, increasing WOB if sensed working pressure indicates that drill bit loading or torque is undesirably low, and reversing WOB by retracting the drill bit if excessive working pressure or torque is sensed.

Abstract: A force balanced asymmetric drilling reamer comprising a plurality of blades, each blade having at least one cutter section and a gage section. The cutter section is designed to have a plurality of cutting devices for cutting through swelling formations and cutting free sloughing formations. The gage section has a full bore diameter with gage elements flushly coupled to gage section's outer surface. The blades may be curve/concave shaped or boomerang/chevron shaped, which thereby agitate the cutting beds. At least a portion of the drilling reamer's diameter is incrementally force balanced, starting from the outermost diameter, so that the net radial force is less than 10% of weight on bit with respect to the center of rotation. This balancing allows a greater cutter longevity and provides for a better wellbore condition. Optionally, at least a portion of the drilling reamer's surface may be treated by nitriding for repelling the cuttings.

Abstract: A drill bit made according to one embodiment includes a bit body and at least one preloaded sensor in the bit body. In one aspect, the sensor may include a sensor element on a sensor body having a first end and a second end and wherein the sensor is preloaded after placing the sensor body in the bit body. In another aspect, the sensor may be preloaded outside the bit body and then placed in the bit body in a manner that enables the sensor to retain the preloading.

Abstract: Disclosed is a method of reinforcing a structure (10) having an elongate hole (14) or drilling the hole having an open proximal end (11) and a closed distal end (16). The method comprises the steps of inserting into the open end of the hole an elongate reinforcement core (20) carrying over at least part of its length an expandable sock (30), introducing a settable liquid (40), such as grout, into the sock at a first pressure so as to cause expansion of the sock toward the wall (18) of the hole (14), the sock being formed from a material which is permeable to the grout so as to allow the liquid to seep through the sock, reducing the pressure in the hole by means of a vacuum tube (23), whilst said introducing step is taking place, to at least a second pressure lower than the first pressure so as to encourage the grout to seep through the sock, to substantially fill the hole.

Abstract: An auger for digging holes that minimizes the amount of loose dirt excavated in and around the dug hole. The auger comprises an elongated shaft body whose axial longitudinal center is disposed in a parallel offset position from the axial engagement line of orientation with the driving source for rotationally driving the auger. The shaft body of the auger revolves in an eccentric lateral orbit as the auger rotates which digs the hole by pushing and widening the dirt in the hole rather than cutting and scraping. The distal end of the auger has a tapered configuration for initial penetration into the ground. The eccentric movement of the shaft body of the auger helps to compact the walls of the hole being dug.

Abstract: Latching device for a drilling device comprising a latching body mountable in an outer tube, an unlatching tube slidably mountable around the latching body, two latches attached to the latching body and pivotable between a deployed position in which the latch cooperates with the outer tube in order to latch the latching body to said outer tube and a retracted position for unlatching the latching body from the outer tube, a piston sliding around the latching body and secured to the unlatching tube, and a compression spring mechanism pressing the piston towards the latches in order to maintain the latches in their deployed position, a pulling force exerted on the unlatching tube compressing the spring mechanism to prevent the piston from pressing against the latches which position themselves in their retracted position.

Abstract: A control apparatus for use in controlling the fluid pressure in a borehole during drilling of the borehole, the apparatus including an inlet suitable for connection to a pump, a main outlet suitable for connection to a drill pipe, and an overflow outlet suitable for connection to a fluid reservoir, the inlet being connected to the main outlet by a main flow conduit, and the overflow outlet being connected to the main flow conduit by means of an overflow conduit, wherein the overflow conduit is provided with a pressure regulator by means of which the pressure of fluid in the main flow conduit may be maintained at or around a predetermined pressure value.

Abstract: A system for damping vibration in a drill string can include a magnetorheological fluid valve assembly having a supply of a magnetorheological fluid. A remanent magnetic field is induced in the valve during operation that can be used to provide the magnetic field for operating the valve so as to eliminate the need to energize the coils except temporarily when changing the amount of damping required The current to be supplied to the coil for inducing a desired magnetic field in the valve is determined based on the limiting hysteresis curve of the valve and the history of the magnetization of the value using a binary search methodology. The history of the magnetization of the valve is expressed as a series of sets of current and it resulting magnetization at which the current experienced a reversal compared to prior values of the current.

Abstract: A system for recovering a fluid from a subterranean formation, including a production wellbore having a substantially horizontal production length extending through the formation, and a trench extending through the formation. A method of constructing a trench section in a subterranean formation, including providing within the formation an access wellbore having a substantially horizontal access wellbore length, introducing a trench cutting tool into the access wellbore, and advancing and retracting the trench cutting tool through the access wellbore in order to cut slots in the formation in a trench direction away from the access wellbore, repeatedly until a number of slots required to complete the trench section has been cut.

Abstract: A drilling system includes a downhole well control device that can be used to control out-of-norm wellbore conditions. The downhole well control device can control one or more selected fluid parameters. The well control device in cooperation or independent of surface devices exerts control over one or more drilling or formation parameters to manage an out-of-norm wellbore condition. An exemplary well control device hydraulically isolates one or more sections of a wellbore by selectively blocking fluid flow in a pipe bore and an annulus. The control device also selectively flows fluid from the pipe bore to the annulus. A communication device provides on-way or bidirectional signal and/or data transfer between the controller(s), surface personnel and the well control device. Exemplary application of the well control device include controlling a well kick, controlling drilling fluid being lost to the formation and controlling a simultaneous kick and loss.

Abstract: A downhole telemetry system for use in a wellbore including borehole fluid. The system includes a stator including flow channels though the stator and a rotor including flow channels though the rotor. The rotor is rotatable on a drive shaft by the force of the borehole fluid flowing through the rotor. The rotation of the rotor creates pressure variations in the borehole fluid related to the movement of the rotor channels relative to the stator channels, thus forming a carrier wave. A regulating system adjusts the amount of fluid force on the rotor for a given flow rate of borehole fluid to maintain the frequency of the carrier wave within a range of a target frequency. Also, an alternator drivable by the rotation of the drive shaft provides power to the system. The system also includes an encoder capable of adjusting the rotation of the rotor to modulate the carrier wave.

Abstract: An expandable apparatus may comprise a tubular body, a valve piston and a push sleeve. The tubular body may comprise a fluid passageway extending therethrough, and the valve piston may be disposed within the tubular body, the valve piston configured to move axially within the tubular body responsive to a pressure of drilling fluid passing through the fluid passageway and configured to selectively control a flow of fluid into an annular chamber. The push sleeve may be disposed within the tubular body and coupled to at least one expandable feature, the push sleeve configured to move axially responsive to a flow of fluid into the annular chamber extending the at least one expandable feature.

Abstract: An expandable apparatus may comprise a tubular body, a valve piston and a push sleeve. The tubular body may comprise a fluid passageway extending therethrough, and the valve piston may be disposed within the tubular body, the valve piston configured to move axially downward within the tubular body responsive to a pressure of drilling fluid passing through a drilling fluid flow path and configured to selectively control a flow of fluid into an annular chamber. The push sleeve may be disposed within the tubular body and coupled to at least one expandable feature, the push sleeve configured to move axially responsive to the flow of fluid into the annular chamber extending the at least one expandable feature. Additionally, the expandable apparatus may be configured to generate a signal indicating the extension of the at least one expandable feature.

Abstract: The present invention relates to an emulsion, consisting of an oil phase and an aqueous phase and comprising as emulsion components (?1) 15 to 40% by weight of at least one water-immiscible organic solvent as solvent of the oil phase, (?2) 15 to 40% by weight of water as solvent of the aqueous phase, (?3) 10 to 40% by weight of at least one surfactant, (?4) 10 to 40% by weight of an alkoxylated fatty alcohol and (?5) 0 to 25% by weight of at least one other additive, wherein the quantities by weight of the components (?1) to (?5) are each relative to the total weight of the emulsion, and together add up to 100% by weight. The invention further relates to a method for producing an emulsion, to the emulsion which can be obtained from said method, to the use of an emulsion, to a method for cleaning the surfaces of well holes, drilling devices or drillings, to a method for producing a well bore, and to a method for producing an oil or a gas.

Abstract: Bearings for downhole tools including a first bearing member and a second bearing member, at least one of the first and second bearing members having a channel formed therein. Methods of cooling bearings of downhole tools comprise flowing a fluid within a channel formed in at least one bearing member. Heat is transferred from at least the at least one bearing member to the fluid. The fluid is flowed away from the at least one bearing member.

Abstract: A status indicator for determining a position of an extendable member in an expandable apparatus. The status indicator is configured to decrease a cross-sectional area of a portion of a fluid path extending through an expandable causing a pressure of a fluid within the fluid path to increase when an extendable member of the expandable apparatus is in an extended position. By determining the pressure of the fluid within the fluid path, one can determine the position of the status indicator within the fluid path and thereby determine whether the extendable member of the expandable apparatus is in the extended or a retracted position.

Abstract: A drilling assembly for drilling two or more casing sections into a subterranean formation includes a first casing bit and a second casing bit, each casing bit of different diameter affixed to a respective casing section of different diameter, at least two casing bits and the two or more casing sections arranged in a telescoping relationship. The second casing bit includes a bit body having a face on which two different types of cutting elements are disposed, the first type being cutting elements for drilling at least one subterranean formation and the second type being cutting elements for drilling through the first casing bit.

Abstract: Taught is an auger having a working head (15), a ratcheting T-handle (50), and a shaft (20) attached there between forming a hand-powered ratcheting auger for drilling holes near the ground surface. Shaft (20) may include one or more lengths of extension shaft parts to control the length of the shaft. Working head (15) contains a drill-bit (14), semi-circular non-planar cutting blades (12), a working head shaft part (22), with the drill-bit and cutting blades fixedly attached to the working head shaft part and shaft part (22) detachably attached to shaft (20). The auger may also include an air induction unit 66 including an air-receiving opening in the T-shaped handle; an air-line 60 positioned within a hollow of the shaft connecting the air-receiving opening with air exhaust openings so as a jet of the air can blow out of said auger to break up and blow away the drilling detritus.

Abstract: In an aspect, an apparatus for use in a wellbore includes a tubular and a drilling assembly configured to carry a drill bit at an end thereof, wherein the drilling assembly is configured to be positioned within the tubular, wherein the tubular and drilling assembly are configured to be run in the wellbore together. The apparatus also includes an actuation device in the tubular configured to selectively extend the drilling assembly from and retract the drilling assembly into the tubular.

Abstract: A drilling fluid, spacer fluid and cementing compositions for use in subterranean wells are disclosed along with methods for making using same, where the compositions include a weighting system having an effective amount of a metal silicon alloy, mixtures of metal silicon alloys, or mixtures of metal silicon alloys and conventional weighting agents, to produce compositions having a desired high density, while retaining other fluid properties such as pumpability, gas tight sealing, low tendency to segregate, and reduced high temperature cement strength retrogression.

Abstract: A managed bulk drilling system that employs a guide wire for ranging and crosswell telemetry. Some system embodiments include multiple drilling assemblies operating in the vicinity of a reference well that contains an electrical cable. The electrical cable is coupled to a surface control system. The control system uses the electrical cable as part of an antenna to receive uplink signals from the drilling assemblies and to broadcast down-link signals to the drilling assemblies. The uplink signals can include position data and the downlink signals can include individual steering commands to adjust the trajectories of each drilling assembly. The cable can also generate a guidance field for the drilling assemblies to detect and follow.

Abstract: A drilling apparatus including a hydraulically powered hammer having a piston to impact a drill bit; a shuttle valve to control reciprocation of the piston; and an accumulator for hydraulic fluid; at least one drill rod having a first connection valve for connection of the drill rod to the connection valve of the hammer; and a second connection valve for connection of the drill rod to the first connection valve of a like drill rod or to a rotation device. The piston and shuttle valve are positioned substantially in-line to the axis of movement of the hammer. The accumulator is positioned proximate to the shuttle valve; and the first connection valve, and second connection valve having at least one poppet valve positioned proximate to a corresponding valve seat.

Abstract: A drill rig (10) comprises a tower (12) and a drill head (14) that is able to travel linearly up and down the tower (12). The drill head (14) provides torque to a drill string (16) attached to the drill head (14) ad thus to a drill bit (18) coupled to a distal end of the drill string (16). The drill head (14) is traversed along the tower (12) by a plurality of rams (22a, 22b) and (22c) (hereinafter referred to in general as “rams 22”). The rams (22) provided hold back and pull down for the drill bit (18) via the drill head (14). The rams (22) are selectively operable to enable the hold back and pull down applied to the drill bit to be selectively varied. Thus for example a first of the rams (22a) is selected to operate when drilling to a first depth, then the rams (22b) and (22c) are selected to operate when drilling to a second greater depth; and finally all three rams (22a, 22b) and (22c) are selected to operate when drilling to a third greater depth.

Abstract: The present invention relates to method and apparatus for drilling a large diameter hole in the ground. The present invention comprises a hammer drill (40) installed at the bottom of a rod (104) assembled in multi-stages at support means on the ground comprising a pilot hammer drill (44, 48, 49) and a reamer hammer drill (41, 46, 47) coupled to each other through a key structure (42, 43) formed in the vertical direction so as to allow simultaneous rotation and up-and-down movement relative to each other, wherein in a drilling operation, a repetition is made such that the hammer drill (40) is made to rotate and the pilot hammer drill (44, 48, 49) is lowered to drill a pilot hole of small diameter (w) to a predetermined depth (d) and is lifted up to original position, and then the reamer hammer drill (41, 46, 47) is lowered to enlarge the hole to a large diameter (W) down to the predetermined depth (d).

Abstract: A method for drilling a wellbore includes drilling the wellbore by injecting drilling fluid into a top of a tubular string disposed in the wellbore at a first flow rate and rotating a drill bit. The tubular string includes: the drill bit disposed on a bottom thereof, tubular joints connected together, a longitudinal bore therethrough, a port through a wall thereof, and a sleeve operable between an open position where the port is exposed to the bore and a closed position where a wall of the sleeve is disposed between the port and the bore. The method further includes moving the sleeve to the open position; and injecting drilling fluid into the port at a second flow rate while adding a tubular joint(s) to the tubular string. The injection of drilling fluid into the tubular string is continuously maintained between drilling and adding the joint(s).

Abstract: There is provided a method for drilling a hole into the ground and installing a geothermal transfer loop. A drilling apparatus is positioned at a desired location. The drilling apparatus includes a rotating and vibrating apparatus, such as a sonic drill, for rotating and vibrating a hollow drill string into the ground. The hollow drill string having an inner space. A hole is drilled to a desired depth by rotating and vibrating the hollow drill string into the ground while discharging fluid into the inner space of the hollow drill string. The fluid forming a fluid column in the inner space of the drill string. The fluid column impedes entry of ground materials into the inner space of the drill string and is vibrated to create a water hammer for adding an additional drilling force. A geothermal transfer loop is lowered into the inner space of the hollow drill string and the drill string is removed from the ground. The method may also include discharging grouting material into the hole.

Abstract: An under-reamer includes a body and extendable cutters mounted on the body. The under-reamer is configured to be cycled between a first configuration in which the cutters are retracted and a second configuration in which the cutters are movable between retracted and extended positions. A control mechanism is provided and is configurable to prevent the under-reamer cycling between the first and second configurations and thus maintains the under-reamer in a selected one of the first and second configurations.

Abstract: A hydraulic control system includes a first motor, a second motor, a pump operatively associated with the first motor, a first coupling valve operatively associated with the second motor, first parallel valves operatively associated with the second motor, and a first switching valve operatively associated with the first coupling valve and the first parallel valves. The first switching valve is configured to switch the first coupling valve between a first coupling state and a second coupling state opposite the first coupling state and to switch the first parallel valves between a first parallel state and a second parallel state opposite the first parallel state. While the first parallel valves are in the first parallel state a portion of the output of the first motor drives the second motor while the first parallel valves are in the second parallel state, the output of the pump drives the second motor.

Abstract: A drill bit according to one embodiment includes a center member configured to rotate at a first speed and an outer member disposed outside the center member, wherein the outer member is configured to rotate at a second speed. The drill bit also includes a first cutter disposed on the center member and a second cutter disposed on the outer member, wherein the first speed and second speeds are configured to control a resultant side force of the drill bit.

Abstract: An apparatus for drilling a wellbore (10) is disclosed, the apparatus comprising a lowermost pilot drill bit (16) having a diameter less than that of the diameter of wellbore (12) drilled by the apparatus, above which is a reamer, having an adjustable drill diameter from a first diameter less than that of the pilot drill to a second diameter greater than that of the pilot drill, above which is a body portion (24) having a lower diameter less than that of the pilot drill and an upper diameter greater than that of the pilot' drill but less than the second diameter of the reamer.

Abstract: A drill bit for drilling a borehole in earthen formations comprising a bit body having a bit axis and a bit face. In addition, the drill bit comprises a primary blade extending radially along the bit face, the primary blade including a cutter-supporting surface that defines a blade profile in rotated profile view extending from the bit axis to an outer radius of the bit body. The blade profile is continuously contoured and includes a plurality of concave regions. Further, the drill bit comprises a plurality of cutter elements mounted to the cutter-supporting surface of the primary blade. Each cutter element on the primary blade has a forward-facing cutting face with a cutting edge adapted to penetrate and shear the earthen formation.

Abstract: Earth-boring tools comprise a body having a face at a leading end. A plurality of cutting elements are disposed over the face and configured as a plurality of kerfing pairs comprising two or more cutting elements disposed at substantially the same radial position relative to a bit axis, wherein each of the at least two cutting elements follows substantially the same cutting path when the bit is rotated about its axis. Earth-boring tools are further configured so that a summation of a lateral force generated during drilling by each cutting element of the plurality of cutting elements is directed toward a side of the body.

Abstract: A down-the-hole assembly includes a housing assembly having a head end and a bit end. The housing assembly further includes an inlet joint having an inlet channel defined therein, a sealing portion positioned toward the bit end relative to the inlet joint, and an outlet portion positioned toward the bit end relative to the sealing portion. A hammer assembly including a piston has a piston channel defined therein that includes an inlet in fluid communication with the inlet channel and an outlet in fluid communication with the housing assembly.

Abstract: A holding device insertable into a central bore of a drill string component, the central bore having a first diameter along at least part of a central portion of the drill string component and a second diameter proximate ends of the drill string component. The second diameter is lower than the first diameter. The holding device includes an elongated body forming at least partly a housing for a transmission line. The elongated body has transversal dimensions lower than the second diameter. A plurality of arcuate elements are arranged along the elongated body and distinct from and attached to the elongated body. The arcuate elements are elastically bendable so as to be able to move through the second diameter and have a largest chord greater than the first diameter in a free state so as to be able to expand within the first diameter once past the second diameter.

Abstract: A subterranean drilling system may include a drill string and a rotary drill bit coupled to the drill string. The rotary drill bit may include a bit body and a cutting element coupled to the bit body, with the cutting element being structured to rotate in response to torque applied to the cutting element. The system also may include a cam assembly coupled to the drill string, a cam follower assembly in contact with a cam surface of the cam assembly, and a torque-applying structure coupled to the cam follower assembly. The torque-applying structure may be configured to apply torque to the cutting element in response to relative rotation between the cam assembly and the cam follower assembly.

Abstract: In one embodiment, a method for drilling a wellbore includes an act of drilling the wellbore by injecting drilling fluid through a tubular string disposed in the wellbore, the tubular string comprising a drill bit disposed on a bottom thereof. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The drilling fluid and cuttings (returns) flow to a surface of the wellbore via an annulus defined by an outer surface of the tubular string and an inner surface of the wellbore. The method further includes an act performed while drilling the wellbore of measuring a first annulus pressure (FAP) using a pressure sensor attached to a casing string hung from a wellhead of the wellbore. The method further includes an act performed while drilling the wellbore of controlling a second annulus pressure (SAP) exerted on a formation exposed to the annulus.

Abstract: The steel drill string attached to a drilling bit during typical rotary drilling operations used to drill oil and gas wells is used for a second purpose as the casing that is cemented in place during typical oil and gas well completions. Methods of operation are described that provide for the efficient installation a cemented steel cased well wherein the drill string and the drill bit are cemented into place during one single drilling pass down into the earth. The normal mud passages or watercourses present in the rotary drill bit are used for the second independent purpose of passing cement into the annulus between the casing and the well while cementing the drill string into place during one single pass into the earth. A one-way cement valve is installed near the drill bit of the drill string that allows the cement to set up efficiently under ambiently hydrostatic conditions while the drill string and drill bit are cemented into place during one single drilling pass into the earth.

Abstract: A method of forming a supported subterranean well bore in which, in one disclosed embodiment, a first drill bit is mounted on a first string of casing tubulars via a steerable tool, and the drill bit is used to form a first bore. Upon reaching the required depth the casing string is cemented in place to support the formed bore and a second drill bit is mounted on a second casing string and is inserted into the first casing string. The second drill bit is used to drill through the wall of the first casing string and proceed to form a second, deeper bore. Once the second drill bit has reached the required depth, the second casing string is cemented in place to support the second bore.

Abstract: An elongated percussive rock drilling element comprises at least one thread portion and a flush channel. At least the thread portion is made of a corrosion resistant steel having a structure with a martensite content greater than about 50 wt-% and less than about 100 wt-%, in which the steel comprises C+N greater than about 0.1 wt-% and less than or equal to about 0.8 wt-% and Cr greater than or equal to about 11 wt-% or Cr greater than or equal to about 5 wt-%, Mo less than or equal to about 5 wt-%, W less than or equal to about 5 wt-%, Cu less than or equal to about 2 wt-%, Mo+W+Cu greater than about 0.5 wt-% or Cr+3.3 (Mo+W)+16N greater than about 10 wt-%. The surface of said at least one thread portion of said corrosion resistant steel is ball blasted.

Abstract: What is provided is a method and apparatus wherein a swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve or housing can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve or housing of the swivel.

Abstract: The present invention relates to downhole tools, and in particular an underreamer tool for use in a wellbore of an oil or gas well and a method of actuation. In an embodiment, the underreamer tool has body having a longitudinal axis and a fluid conduit, a tool element and an actuation device configured to urge the tool element relative to the body from a first configuration into a second configuration. In this embodiment, a portion of the tool has a curved actuation surface and as the tool element is urged across the curved actuation surface, the tool element is moved radially with respect to the body of the tool. Typically, the actuation device may include a piston driven by pressure of fluid circulated through the fluid flow conduit.

Abstract: A method for recovering gases and/or liquids stored within one or more gas and/or liquid reservoirs comprising locating the upper consolidated boundary of the one or more gas and/or liquid reservoirs; drilling an access well which extends downwardly to at least adjacent the upper consolidated boundary of the one or more gas and/or liquid reservoirs; drilling a section of the access well extending along or adjacent at least a portion of the upper consolidated boundary of the one or more gas and/or liquid reservoirs; creating permeability pathways into the one or more gas and/or liquid reservoirs to enable the release of gas and/or liquid from the one or more gas and/or liquid reservoirs into the access well; and recovering the released gas and/or liquid through the access well.

Abstract: Various embodiments relate to a bearing assembly including a support ring configured to reduce thermal warping under operational temperature conditions, a bearing apparatus that may utilize such a thrust-bearing assembly, and applications that incorporate the disclosed bearing apparatuses such as downhole motors in subterranean drilling systems, directional drilling systems, and many other apparatuses. In an embodiment, a bearing assembly includes a plurality of superhard bearing elements distributed circumferentially about an axis. The thrust-bearing assembly further includes a support ring having the plurality of superhard bearing elements mounted thereto.

Abstract: A jib assembly for use with a drill rig includes a jib boom having a first end and a second end. The jib boom is to rotate about the first end and the second end is configured to be coupled to a mast assembly mount. The jib assembly also includes an articulation assembly having at least one variable length link having a first end and a second end. The first end of the variable length link is offset from the jib boom and the second end is configured to be pivotingly coupled to the mast assembly mount.

Abstract: Cutting elements having a substrate and a layer of superhard material sintered to the substrate are disclosed. The layer includes a working surface at a first surface. From the interface of the layer with the substrate, a reaction zone extends into the layer toward the working surface and a binder metal depletion zone extends into the substrate toward a base surface. The layer of superhard material has a composition including chromium or an alloy thereof. Also disclosed is an abrasive compact having a body with a composition including (i) a superhard material, (ii) a metal from a grain growth inhibitor or a metal from a metallic carbide other than WC, and (iii) an iron group binder metal. Cutting elements incorporating the abrasive compact, and drill bits incorporating abrasive compacts and cutting elements are also disclosed as well as methods of manufacture and methods of cutting material.

Abstract: A cutting element for an earth-boring tool. The cutting element comprises a substrate base, and a volume of polycrystalline diamond material on an end of the substrate base. The volume of polycrystalline diamond material comprises a generally conical surface, an apex centered about a longitudinal axis extending through a center of the substrate base, a flat cutting surface extending from a first point at least substantially proximate the apex to a second point on the cutting element more proximate a lateral side surface of the substrate base. Another cutting element is disclosed, as are a method of manufacturing and a method of using such cutting elements.