Abstract: A method of joining a steel first member to a stainless steel second member includes buttering a first joint surface on the first member, the buttering including: preheating the first joint surface; welding a border layer of weld material to the first joint surface; and heat treating the border layer and the first joint surface after welding the border layer. A weld is formed between the first and second members after heat treating the border layer and the first joint surface. The border layer and a second joint surface on the second member are preheated; and a body of weld material is added between the border layer and the second joint surface.

Abstract: A telemetry tool joint may comprise a tool joint body adapted for connection to a downhole tubular as part of a tool string. The tubular may be a drill pipe or a downhole tool such as a drill bit or component of a bottom hole assembly. The tool joint body may comprise an axial bore comprising a bore wall having an interior wall surface and a tapered outer wall surface. The tapered outer bore wall surface may comprise a first continuous thread form having multiple turns comprising a first thread start and a first thread end and a second continuous thread form having multiple turns comprising a second thread start and a second thread end. The respective thread forms may be separated by a gap along the tapered outer bore wall surface. The gap may comprise one or more annular recesses adapted for housing a radially oriented inductive coupler.

Abstract: A drilling tractor tool in a drill string includes a rotating mandrel having an engagement part configured to rotate with the drill string; and a static sleeve disposed on the rotating mandrel configured to remain stationary during rotation of the rotating mandrel. The static sleeve includes a plurality of pockets that form a pathway from an interior of the static sleeve to an exterior of the static sleeve. The drilling tractor tool includes a plurality of force applicators each disposed in a respective pocket of the plurality of pockets of the static sleeve. The plurality of force applicators configured to extend through the respective pocket and apply a forward thrust to the drill string when extended. The engagement part of the rotating mandrel is configured to contact and cause to extend each of the plurality of force applicators respectively as the rotating mandrel rotates.

Abstract: A lineable tubular for use in subterranean exploration and production, such as oil, gas, and geothermal wells. The tubular may be part of a downhole tool string, including drill pipe and related downhole tools that may be found in the bottom hole assembly. The tubular may comprise a modified interior surface along its bore wall. The modified surface may comprise hard particles, rifling, threads, ridges and grooves, sand and ceramic grit, and knurling. The modified surface may aid in securing a liner within the tubular. The tubular may include connectable ends with box and pin end tool joints. The tool joints may be attached to an upset end of the tubular. The modified surface may run the length of the tubular or it may be restricted to the upset ends of the tubular and the respective tool joints. The tubular may comprise a seal gland within the tool joints.

Abstract: The present disclosure provides downhole tools, methods for three dimensional printing hardfacing on such downhole tools, and systems for implementing such methods.

Abstract: A tool for building a wellbore includes a tool body with a flow passage extending axially therethrough, a piston chamber formed radially through the tool body that intersects the flow passage of the tool body, a piston disposed in the piston chamber, at least one actuation element that exerts a force between the piston and the piston chamber, and a sleeve disposed within the flow passage of the tool body that includes at least one cutout. When the sleeve is in a first position within the tool body, the cutout is axially offset from the piston, and when the sleeve is in a second position, the cutout is axially aligned with the piston.

Abstract: An expandable tool includes a cutting block set. The cutting block set includes an upper cutting block and a lower cutting block, arranged longitudinally. The upper cutting block includes upper block splines having an upper block angle. The lower cutting block includes lower block splines having a lower block angle. The upper block angle is greater than the lower block angle, which directs the upper cutting block to extend radially further outward than the lower cutting block.

Abstract: A centraliser (10) for use in centralising tubing (12) in a bore (W) comprises a first end collar (14), a second end collar (16) and a number of elongate strut members (18). The strut members (18) are interposed between the first end collar (14) and the second end collar (16) and are circumferentially arranged and spaced around the first end collar (14) and second end collar (16). The strut member (18) have a first end portion (20), a second end portion (22), an intermediate portion (24) and angled wing portions (26) which extend from the intermediate portion (24).

Abstract: A mechanical rotary steering drilling tool for steering a drill string includes a test section, a clutch device, a control mechanism, and an execution part. The test section is used as an upper joint in cooperation with the tool. The clutch device is externally connected with a guide body and internally coupled with a mandrel. A groove on a cylindrical surface of a switch control cylinder is matched with a control screw to determine rotation of a fluid channel switch. A pushing block of the execution part extends out against a wellbore wall to push a drill bit for steering drilling after the fluid channel is opened.

Abstract: The present disclosure provides downhole tools, methods for three dimensional printing hardfacing on such downhole tools, and systems for implementing such methods.

Abstract: Apparatuses are disclosed for providing directional control of bore drilling equipment. In an embodiment, the apparatus includes a hydraulic pump having an input shaft for receiving an input torque from a drill pipe and being connected in use to a drilling head. In addition, the apparatus includes control arrangement for varying the rate of fluid flow through the pump. The control arrangement includes a closed loop oil-filled system including the hydraulic pump and a main valve. Oil from the pump is routed through the main valve before returning to a pump input. In addition, the control arrangement includes an orifice control system which is operable to control the position of the main valve in response to an input signal from a control processor.

Abstract: A rotary steerable device includes a steering pad disposed with a drilling tool and radially moveable relative to a centerline of the drilling tool to apply a steering force to a borehole wall. The steering pad has a front face to contact the borehole wall and having a diameter or width and a tapered section that tapers inward at a taper angle toward the centerline along a taper length in the direction from a take-off position to a leading edge relative to one of a rotational direction of the drilling tool or a drilling direction.

Abstract: A steering assembly includes a housing having a longitudinal axis, a mandrel having a front connecting extremity and a rear connecting extremity, the mandrel passing through the housing and arranged in a first position coaxially to the longitudinal axis of the housing, a deflector device configured to exert a side force on the mandrel to offset the front connecting extremity of the mandrel from the longitudinal axis, and a tool face assembly configured to rotate the front connecting extremity of the mandrel in a desired direction.

Abstract: A method of determining when tool string parameters should be altered to avoid undesirable effects that would likely occur if the tool string were employed to drill a borehole includes, modeling portions or an entirety of the tool string in the borehole under steady state loading conditions, identifying deflections of the tool string with the modeling when buckling would occur for specific tool string parameters, and calculating whether whirl exhibiting similar deflections of the tool string to those identified during buckling would be undesirable.

Abstract: In accordance with embodiments of the present disclosure, a rotary steerable tool and a gamma sensor assembly are provided. These systems may include scintillation detection sensors mounted in a pressure sleeve assembly coupled to a rotating drive shaft and/or an electronics insert of the rotary steerable tool. The sensors may each be mounted in an atmospheric pressure environment within a respective pressure sleeve. The pressure sleeves may each rotate with the drive shaft and the electronics insert. The sonde-based arrangement of the systems may facilitate relatively high sensitivity measurements taken at a rotating portion of the rotary steerable tool. This may allow directional gamma measurements and bulk gamma measurements to be determined at the rotating section of rotary steerable tool.

Abstract: A drilling motor for directional drilling in a wellbore has a drill bit at a downhole end, a bent housing having a first bend spaced above the drill bit and defining a first angle, the first bend having an inside bend surface and an outside bend surface, and a guide element that biases the first bend toward the first angle when the bent housing is positioned within a straight section of the wellbore. The guide element may be a pad, a centralizer or a second bend in the bent housing.

Abstract: A described bottom hole assembly includes a drill bit arranged at a distal end of a drill string and rotatable about a first central axis, the drill bit exhibiting a first unbalance force acting laterally on the drill bit at a first angular orientation, a first unbalance force marking physically applied to the drill bit and corresponding to the first unbalance force, a tool arranged axially from the drill bit, the tool exhibiting a second unbalance force acting laterally on the tool at a second angular orientation, and a second unbalance force marking physically applied to the tool and corresponding to the second unbalance force, wherein an angular offset between the first and second unbalance forces markings is able to be manipulated in order to obtain a minimized or desired tandem resulting unbalance force.

Abstract: A fiber optic cable assembly may include a fiber optic cable that has a jacket and a plurality of optical fibers enclosed by and extending longitudinally within the jacket. The fiber optic cable assembly may also include a micro-duct disposed around at least a portion of the jacket, for example, where the cable is buried below grade. The fiber optic cable assembly may further include an insulating layer disposed around at least a portion of the micro-duct, and an outer layer disposed around the insulating layer. The insulating layer and the outer layer may protect the micro-duct and the cable in the event of high temperature exposure that may arise from nearby high temperature utilities, such as in a manhole, as well as to enable the fiber optic cable to be air jetted through the micro-duct from a starting point to a terminating point of a cable routing path.

Abstract: An apparatus and method for damping vibration, especially torsional vibration due to stick-slip, in a drill string, Sensors measure the instantaneous angular velocity of the drill string at one or more locations along the length of the drill string. One or more vibration damping modules are also spaced along the length of the drill string. When torsional vibration above a threshold is detected, the damping module imposes a reverse torque on the drill that dampens the torsional vibration. The reverse torque can be created by imparting a frictional resistance to the rotation of the drill string. The frictional resistance can be created externally, by extending friction pads from the damping module so that they contact the bore hole wall and drag along the bore hole as the drill string rotates, or internally by anchoring a housing mounted on the drill string to the wall of the bore hole and then imposing frictional resistance on a fluid, such as a magnetorheological fluid, flowing within the drill string.

Abstract: In a well extending from the surface of the earth to a deposit of production fluid there beneath, a system for delivering the contents of the deposit to the earth's surface. The system comprising a rod string capable of being driven by a source of motive power at the earth's surface, including an internally overshot assembly rod at the end of the rod string; a downhole assembly, including a pump and receiver with a shaft extending upwardly from the downhole assembly, the receiver shaft being connectable to the overshot assembly such that rotation of the rod string and overshot assembly drives the pump to push the production fluid to the surface of the earth.

Abstract: A method and system for directionally drilling a wellbore. The method includes measuring an off-bottom rotating torque applied to a drill string in the wellbore. A steerable drilling motor is oriented proximate a bottom of the drill string in a selected direction, and a surface rotational orientation of the drill string is measured. Torque is applied to the drill string at the surface to maintain the surface rotational orientation. The applied torque is automatically increased and decreased by a selected amount related to the measured off-bottom rotating torque.

Abstract: A system, in certain embodiments, includes a joint and an energy harvesting system. The energy harvesting system includes an energy conversion system configured to convert kinetic energy from movement of the joint into electrical energy.

Abstract: A steering assembly includes a housing having a longitudinal axis, a mandrel having a front connecting extremity and a rear connecting extremity, the mandrel passing through the housing and arranged in a first position coaxially to the longitudinal axis of the housing, a deflector device configured to exert a side force on the mandrel to offset the front connecting extremity of the mandrel from the longitudinal axis, and a tool face assembly configured to rotate the front connecting extremity of the mandrel in a desired direction.

Abstract: The invention relates to a rotary drill stem component for exploration of a hydrocarbon well with drilling mud in movement around the component from a bottom of the well towards the surface. The drill can include a central tubular element having an axis of revolution and extended on either side respectively by a first and a second tool joint each respectively and successively including a first cylindrical portion connected to the tubular element, a second tapered portion, a third cylindrical portion with a radius greater than that of the tubular element. The drill can include a threaded end which can connect the component to another component, the component including a first shell provided with one or more functional zones, the first shell being mounted on one of the tool joints in a cohesive and removable manner.

Abstract: In some embodiments, apparatus and systems, as well as methods, may operate to couple a stator to a borehole, and to move a rotor relative to the stator to generate electrical current to power a borehole tool.

Abstract: A method of drilling a wellbore includes running a drilling assembly into the wellbore through a casing string, the drilling assembly having a tubular string, a stabilizer, and a drill bit; applying a force to an arm of the stabilizer, thereby causing the arm to retract; and removing the stabilizer and the drill bit from the wellbore.

Abstract: The present invention relates a high-strength nonmagnetic stainless steel, containing, by weight percent, 0.01 to 0.06% of C, 0.10 to 0.50% of Si, 20.5 to 24.5% of Mn, 0.040% or less of P, 0.010% or less of S, 3.1 to 6.0% of Ni, 0.10 to 0.80% of Cu, 20.5 to 24.5% of Cr, 0.10 to 1.50% of Mo, 0.0010 to 0.0050% of B, 0.010% or less of O, 0.65 to 0.90% of N, and the remainder being Fe and inevitable impurities; the steel satisfying the following formulae (1) to (4): [Cr]+3.3×[Mo]+16×[N]?30??(1), {Ni}/{Cr}?0.15??(2), 2.0?[Ni]/[Mo]?30.0??(3), and [C]×1000/[Cr]?2.5??(4), wherein [Cr], [Mo], [N], [Ni], [Mo] and [C] represent the content of Cr, the content of Mo, the content of N, the content of Ni, the content of Mo and the content of C in the steel, respectively, and {Ni} represents the sum of [Ni], [Cu] and [N], and {Cr} represents the sum of [Cr] and [Mo]. The present invention further relates to a high-strength nonmagnetic stainless steel part containing the steel and a process for producing the same.

Abstract: In one embodiment, a wear band comprises a rotating element having a bore receivable on a tubular, the bore comprising first and second bore portions slidably receiving first and second sleeve bearings. Outer surfaces of the sleeve bearings slidably engage the bore portions and the bores of the sleeve bearings slidably engage the tubular. A first stop collar and a second stop collar may be received on the tubular to together straddle the rotating element and sleeve bearings to longitudinally secure the rotating element in a position on the tubular. The tubular may be included within a tubular string run into a borehole or into the bore of an installed casing, such as in casing while drilling. The rotating element provides stand-off between a tubular and the wall of a bore, reduces frictional resistance to longitudinal sliding and also to rotation of the tubular string within the bore.

Abstract: A downhole stabiliser (5), such as a drill motor stabiliser, comprises at least one reaming means and/or reinforcing means (10). The present invention also relates to an assembly (30), such as a downhole drilling assembly (31), comprising at least one such stabiliser (5) and/or a drill bit (40,41) comprising a gauge bit (42) at or near a drilling end (45) thereof, and a connection means (46) for connecting the drill bit (40,41) to a drill motor assembly (60), wherein the drill bit gauge (42) comprises a substantially cylindrical portion having a length less than or equal to approximately 1.0 times the nominal bit diameter. The present invention also relates to a novel locking mechanism (80), such as a lock and key mechanism, to allow locking of a shaft (70?), e.g. a motor drive shaft (71?), through or together with a stabiliser (5?).

Abstract: A downhole stabiliser (5), such as a drill motor stabiliser, comprises at least one reaming means and/or reinforcing means (10). The present invention also relates to an assembly (30), such as a downhole drilling assembly (31), comprising at least one such stabiliser (5) and/or a drill bit (40,41) comprising a gauge bit (42) at or near a drilling end (45) thereof, and a connection means (46) for connecting the drill bit (40,41) to a drill motor assembly (60), wherein the drill bit gauge (42) comprises a substantially cylindrical portion having a length less than or equal to approximately 1.0 times the nominal bit diameter. The present invention also relates to a novel locking mechanism (80), such as a lock and key mechanism, to allow locking of a shaft (70?), e.g. a motor drive shaft (71?), through or together with a stabiliser (5?).

Abstract: Embodiments of the disclosure provide a rigid centralizer having at least one annular band with radially extending embossed flutes spaced around an outer surface of the at least one annular band and a plurality of elongated connecting posts welded to an inner surface of the at least one annular band to form a tubular receiving annulus.

Abstract: A rotary steerable drilling system that is operable to drill vertical wellbores and automatically maintain a vertical wellbore drilling path. The system includes a control module for operating solenoid valves that control an amount of fluid pressure applied to bias pad piston/cylinders. The control module is operable to determine when the system is deviating from vertical, in what direction the system is deviating, and where the bias pads are in relation to the direction of deviation. Based on these determinations, the control module actuates the requisite bias pads by controlling the amount of fluid pressure applied to the bias pad piston/cylinders to direct the system back to the vertical drilling path.

Abstract: The current invention provides a drill pipe of standard weight with an integral wear pad. The drill pipe with integral wear pad provides increased durability while retaining the strength, flexibility, lightweight, and other performance characteristics of standard weight drill pipe. The current invention also provides methods for making a standard weight drill pipe with integral wear pad.

Abstract: An apparatus for keeping a down hole drilling tool vertically aligned has a tubular body having an axis, an inner bore, at least one perpendicular channel and at least one set of steering elements disposed on opposed sides of the tubular body and engaging the at least one perpendicular channel of the tubular body. The at least one perpendicular channel permits the steering elements to move perpendicularly to the axis of the tubular body and restricts movement parallel to the axis of the tubular body. The first and second steering elements are engaged such that movement of the first or second steering element toward an extended position relative to the tubular body moves the other steering element toward a retracted position relative to the tubular body. Actuators are carried by the tubular body that selectively actuate the steering elements toward the extended position to steer the down hole drilling tool.

Abstract: A rotary steering apparatus for a drill string in which a bending section induces a bend in a portion of the bottom hole assembly of the drill string by using the rotation of the drive shaft that drives the drill bit during normal drilling, while operating at a reduced or zero drilling mud flow rate, to drive a reduction gear that rotates a nut or cam so as to place a tension tube into tension. The tension tube abuts a flexible housing and places the flexible housing in compression. The flexible housing has a local weakening formed in it that causes it to preferentially bend in a predetermined direction. Compression in the flexible housing causes the housing to bend, which bends a portion of the bottom hole assembly so as to alter the direction of drilling. Rotation of the drive shaft at reduced or zero mud flow rate also causes the drive shaft to drive rotation of a second reduction gear the output of which rotates the bent portion of the bottom hole assembly thereby altering its tool face angle.

Abstract: An assembly for use in subsurface drilling includes a downhole downhole probe supported by a centralizer. The centralizer comprises a tubular member that extends around the downhole probe. A wall of the centralizer is fluted to provide inward contact points that support the downhole probe and outward contact points that bear against a bore wall of a section of drill string. The downhole probe may be supported for substantially its entire length.

Abstract: A non-rotating downhole sleeve adapted for casing centralization in a borehole. The sleeve includes a tubular body made of hard plastic with integrally formed helical blades positioned around its outer surface and an inner surface which allows drilling fluid to circulate to form a non-rotating fluid bearing between the sleeve and the casing. The tubular sleeve comprises a continuous non-hinged wall structure for surrounding the casing. The non-rotating centralizer sleeve reduces sliding and rotating torque at the surface while drilling the casing, for example, with minimal obstruction to drilling fluid passing between the casing and the surrounding borehole.

Abstract: The invention relates to a guide frame for guiding a cutting apparatus within a pipe incorporated into the ground, having a framework body which can be inserted into the pipe and comprises a guide, along which the cutting apparatus can be displaced, a bracing means for tensioning and fixing the framework body in the pipe, and an adjusting means, with which the cutting apparatus can be adjusted within the pipe in a transverse direction relative to the pipe axis. The invention further relates to a method for anchoring a pipe in the ground.

Abstract: A downhole assembly for insertion into a borehole comprising an articulated mandrel, a passive and an active damping mechanism operating on said mandrel for exercising control over torsional stick-slip and further proposing an improvement over the prior art which diminishes lateral shock.

Abstract: The current invention provides a drill pipe of standard weight with an integral wear pad. The drill pipe with integral wear pad provides increased durability while retaining the strength, flexibility, lightweight, and other performance characteristics of standard weight drill pipe. The current invention also provides methods for making a standard weight drill pipe with integral wear pad.

Abstract: The invention provides a down-the-hole drill assembly (21) comprising an assembly of a bit (9) and co-operating chuck (19) including a bit (9) mounting with an external sleeve (4) surrounding the bit (9) mounting, the sleeve (4) during operation of the drill being clamped between the chuck (19) and the bit head (9). The sleeve (4) provides a shield against ingress of debris into the bit and chuck assembly, and provides control of exhaust from the assembly. The sleeve (4) further provides control of a pin (107) releasably engaging the bit (9) to the chuck (19).

Abstract: Described are drilling subs that may be connected in a drill string for reducing the accumulation of debris on the exterior of the drill string or otherwise facilitating the return of drilling fluid during drilling operations. A plurality of radially spaced stabilizing blades protrude from an exterior surface of the drilling subs to define exterior flow channels therebetween through which drilling fluid returning to the surface may is directed. Diverting nozzle passages are provided that extend between an inner axial passage of the drilling subs and the exterior surface of the drilling subs. The diverting nozzle passages exhibit a radial spacing corresponding to a radial spacing of the exterior flow channels such that drilling fluid discharged from the diverting nozzle passages is directed toward the exterior flow channels.

Abstract: Systems and methods for reducing the amount of torque transferred to the Bottom Hole Assembly and the drill string during drilling operations are disclosed. The drill string includes an optionally non-rotatable portion. A rotational hold down system is positioned at a first position on the drill string where it is not rotationally coupled to the drill string. The rotational hold down system is then moved to a second position on the drill string where it is rotationally coupled to the optionally non-rotatable portion of the drill string. In the second position, one or more bars on the rotational hold down system substantially prevent rotation of the optionally non-rotatable portion of the drill string.

Abstract: A gripper for use in a downhole tool is provided. The gripper can include an actuator, an engagement assembly, and an expandable assembly. The engagement assembly can comprise a leaf-spring like elongate continuous beam. The expandable assembly can comprise a linkage including a plurality of links. The linkage can be coupled to the actuator such that the actuator expands the expandable assembly which in turn expands the engagement assembly. One or more keyed connections can inhibit rotational misalignment of the expandable assembly from the engagement assembly. In operation, during one stage of expansion radial forces are transmitted to the engagement assembly through both interaction of a rolling mechanism on the engagement assembly with the expandable assembly and pressure of the linkage assembly directly on an inner surface of the engagement assembly. The one or more keyed connections can preferably facilitate full retraction of the expandable and engagement assemblies.

Abstract: A downhole, hydraulically actuated drilling stabilizer that provides versatility in a bottom-hole assembly. The drilling stabilizer can be used in a directional drilling application to help control the inclination in an extended reach or horizontal well. The drilling stabilizer has stabilizer blade members with an angular design portion that provides versatility in a bottom-hole assembly. The stabilizer could also be used in a conventional rotary bottom-hole assembly, or positioned below a steerable motor.

Abstract: An element for a drill string includes at least one zone bearing on a wall of the drilled hole, the bearing zone including at least one bearing section with an external diameter greater than the diameter of the other portions of the element, and two activation zones substantially adjacent to the bearing zone and disposed upstream and downstream of the bearing zone. The activation zones include a plurality of grooves with a generally helical shape about the axis of the element. The bearing zone includes two guide sections in a shape of a convex rounded body of revolution, disposed upstream and downstream of the bearing section in a manner adjacent to the bearing section, and tangential to the bearing section and to the activation zones.

Abstract: Sleeves, stabilizers and other well tools may be formed with fluid flow paths or channels extending through one or more blades disposed on the exterior portions of such well tools. The blades and associated fluid flow paths extending therethrough may allow optimum fluid flow rates and volumes to enhance lifting of formation cuttings and downhole debris along with cleaning exterior portions of the well tool and an associated rotary drill bit. Location, configuration, orientation and/or dimensions associated with such blades and associated fluid flow paths or channels may also be modified to provide an enlarged pad or contact surface on exterior portions of one or more blades while maintaining desired fluid flow rates and volumes over exterior portions of the well tool. Such pads or contact surfaces may have optimum surface areas for contacting adjacent portions of a wellbore during directional drilling of the wellbore.

Abstract: A drilling tool (1) for drilling downhole, comprising a drilling head (2) in connection with a first portion (18) of the drilling tool, a driving unit (9) for driving the drilling head and the first portion forward in a longitudinal movement while drilling, and a feed control (19) for controlling the longitudinal movement of the drilling head.

Abstract: Implementations of the present invention include drill string components having a thread extending around a body. The leading end of the thread can have a configuration that resists jamming and cross-threading. In particular, the leading end of the thread can include a planar surface normal to the body. The leading end of the thread can provide an abrupt transition to full thread depth that helps reduce or eliminate cross-threading. The leading end of the thread can be oriented at an angle relative to the axis of the drill string component. When mating male and female threads are similarly structured, the mating threads slide together along an interface at the thread start face and are drawn into a fully thread-coupled condition. The thread starts may have full circumference mating with no jamming positions.

Abstract: Generally, a sonde, associated components and methods are described which can be used in conjunction with an inground tool having an inground tool housing that defines an inground tool cavity such that the inground tool cavity is exposed to an ambient pressure environment which surrounds the inground tool during an inground operation. A sonde housing assembly includes an exterior configuration that is receivable within the inground tool cavity. The sonde housing assembly at least partially defines a sonde interior and is further configured for receiving the pressure sensor body of a pressure sensor in a pressure sealed engagement. A sonde electronics package is supported within the sonde interior and is at least configured to receive the pressure signal and transfer a corresponding pressure signal from the sonde.