Abstract: The present invention relates to a downhole tool, comprising a hydraulic assembly, an arm assembly, the arm assembly comprising a wheel, a hydraulic motor for rotating the wheel, thereby driving the downhole tool in a forward direction, and a hydraulic pump unit for simultaneous generation of a first and a second pressurized fluid, characterized in that the arm assembly is movable between a retracted position and a projecting position in relation to the tool housing, and the downhole tool furthermore comprises an arm activation assembly for moving the arm assembly between the retracted position and the projecting position, and the hydraulic motor drives the downhole tool in the forward direction when the arm assembly is in the projecting position, the arm activation assembly being in fluid connection with the first pressurized fluid and the hydraulic motor being in fluid connection with the second pressurized fluid, a hydraulic control block for controlling the pressure of the first pressurized fluid having a

Abstract: The described embodiments relate to a downhole tool that can capture a ball in a trap to prevent both upwell and downwell movement of the ball. Further, certain embodiments described herein may prevent fluid from flowing past a captured ball in either the upwell or downwell directions. Ball and seat valves incorporating such ball trap assemblies can be used to create a bi-directional plug which prevents fluid flow in either direction when the ball trap is engaged with an appropriately configured ball.

Abstract: The invention provides a system and method for lining a borehole. The system comprises: an expandable tubular element extending into the borehole, wherein an end portion of a wall of the expandable tubular element is bent radially outward and in axially reverse direction to define an expanded tubular section extending around an unexpanded tubular section; a pipe extending through the expanded tubular section; a connecting device for connecting the pipe to the unexpanded tubular section, the connecting device allowing the pipe to rotate relative to the unexpanded tubular section around a longitudinal axis of the pipe; a rotating device for rotating the pipe relative to the unexpanded tubular section around said longitudinal axis; and an actuator for moving the pipe in axial direction into the expanded tubular section to extend the expanded tubular section and thereby to form a liner of the borehole.

Abstract: An interlock pipe joint includes a first and second tubular member. In some embodiments, an interrupted thread box and pin make up the interlock pipe joint. In other embodiments, a stepped interrupted thread box and pin make up the interlock pipe joint. In other embodiments, a twist-lock box and pin make up the interlock pipe joint. In some embodiments, an external or internal bushing is provided. In a method of operation, the first tubular member is inserted into the second tubular member by an axial insertion followed by a rotation to lock the pipe joint.

Abstract: A propulsion generator which employs one or more unbalanced rotors, such as fly wheels or other unbalance rotating members, which can be connected at a lower portion of a downhole coiled tubing string or other downhole tubular string for inducing propulsion of the coiled tubing. The unbalanced rotors may be oriented at different positions with respect to each other. The instantaneous fluid flow through the propulsion generator is substantially equivalent to the average fluid flow rate through the tool to provide relatively consistent fluid flow to downhole motors below the propulsion generator for operating the drill bit and/or cutters.

Abstract: A wellbore isolation device comprises: a first material and a second material, wherein the first material and the second material form a galvanic couple and wherein the first material is the anode and the second material is the cathode of the galvanic couple, and wherein the second material is a fiber or a plurality of fibers. A method of removing the wellbore isolation device comprises: contacting or allowing the wellbore isolation device to come in contact with an electrolyte; and causing or allowing at least a portion of the first material to dissolve.

Abstract: A wellbore isolation device comprises a first material and pieces of a second material, wherein the first material: is a metal or a metal alloy; forms a matrix of the portion of the wellbore isolation device; and partially or wholly dissolves when an electrically conductive path exists between the first material and the second material and at least a portion of the first and second materials are in contact with the electrolyte, wherein the pieces of the second material: are a metal or metal alloy; and are embedded within the matrix of the first material; wherein the first material and the second material form a galvanic couple and wherein the first material is the anode and the second material is the cathode of the couple. The isolation device can also include a bonding agent for bonding the pieces of the second material into the matrix of the first material.

Abstract: A wellbore system includes a sealing assembly for creating an annular seal between wellbore members. The sealing assembly includes a seal body having a u-shaped cross section, with elongate grooves formed on inner and outer walls thereof. A depth of the grooves varies along a length of the grooves to allow wickers to penetrate the groove by differing degrees when the walls are urged toward the wickers. The wickers can thus provide a high degree of both sealing and lockdown performance.

Abstract: Systems, apparatus and methods are described for purposes of initiating a response to detection of an adverse operational condition involving a system including a drill rig and an inground tool. The response can be based on an uphole sensed parameter in combination with a downhole sensed parameter. The adverse operational condition can involve cross-bore detection, frac-out detection, excessive downhole pressure, a plugged jet indication and drill string key-holing detection. A communication system includes an inground communication link that allows bidirectional communication between a walkover detector and the drill rig via the inground tool. Monitoring of inground tool depth and/or lateral movement can be performed using techniques that approach integrated values. Bit force based auto-carving is described in the context of an automated procedure.

Abstract: A telescoping joint is provided with one or more control lines and is usable for landing a subsea tubing hanger. The telescoping joint can include an inner mandrel, an outer mandrel, a seal between the inner mandrel and the outer mandrel, and a coiling chamber. The outer mandrel is controllably releasable from the inner mandrel by a release mechanism. The seal is sealably engaged with the outer mandrel for continuously sealing an inner area defined by the inner mandrel from a wellbore environment exterior to the telescoping joint as the outer mandrel axially moves relative to the inner mandrel. A control line is coiled in the coiling chamber and the coiling chamber is axially positioned between the release mechanism and the seal.

Abstract: A downhole filtration tool to remove sand and other solid particles from production fluid in a subterranean well. The downhole filtration tool includes a perforated mandrel surrounded by at least one filter element made of an open weave polymeric fiberglass material. In addition, the downhole filtration tool may include an additional screen or mesh installed in a separating annulus intermediate of the mandrel and the filter element to provide a filter having improved permeability and resistance to chemical and physical forces.

Abstract: Systems and methods for producing forced axial vibration of a drillstring. Systems include a cam housing positioned above a drill bit in a drillstring, a rotatable cam positioned internal of the cam housing, the rotatable cam having at least one cam surface exhibiting reciprocating axial movement upon rotation of the rotatable cam, and a non-rotatable cam follower positioned internal surface of the cam housing and having at least one cam follower surface engaging the cam surface. The cam follower transfers the reciprocating axial movement to the drill bit. The rotatable cam is rotated by a fluid-powered positive displacement power section positioned above and mechanically attached to the rotatable cam in the drillstring to effect the rotation of the rotatable cam, and thus effect the reciprocating axial movement of the drill bit.

Abstract: An apparatus includes a first structure having a cavity containing a first coupler portion, and a first cover to sealably cover the cavity. In addition, a second structure for engaging the first inductive structure has a cavity containing a second coupler portion. A second cover is sealably covers the cavity of the second structure.

Abstract: A downhole power generation device includes a tubular housing configured to be disposed within an annular space and around a portion of production tubing. The housing includes a flow compartment configured to receive a flow of fluid therethrough when the power generation device is in a power generation mode, and an electronics compartment comprising a controller and a power generation unit. The downhole power generation device further includes a turbomachinery system comprising a rotor disposed within the flow compartment and comprising a rotor hub and a plurality of rotor blades, wherein the rotor rotates when the flow of fluid traverses the flow compartment. The downhole power generation device also includes a port coupled to the flow compartment, through which fluid enters the flow compartment.

Abstract: A downhole power generation system includes a tubular power generation device configured to be disposed in an annular space around a portion of a production tubing, wherein the power generation device is switchable between a power generation mode and a bypass mode. The system also includes a power storage device electrically coupled to the tubular power generation device and configured to store power generated by the power generation device. The power generation device comprises at least one power generation path and at least one bypass path. The at least one power generation path comprises at least one power generation mechanism which generates power when traversed by fluid. The at least one power generation path is open in the power generation mode and closed in the bypass mode.

Abstract: A downhole tool has a housing, mandrel, and ball seat. The housing defines a first bore, and the mandrel defines a second bore. The mandrel is disposed in the first bore of the housing and defines an annular space with the housing. The ball seat is rotatably disposed in the second bore of the mandrel and defines an interior passage with a seat profile. First and second pistons are disposed in the annular space on opposing sides of the ball seat. These first and second pistons are movable along an axis of the tool in the annular space in opposing directions and are adapted to rotate the ball seat. Additionally, first and second biasing members are disposed in the annular space and bias the first and second pistons toward one another to reset the ball seat in the absence of pressure.

Abstract: An apparatus for delivering drill pipe has a support frame, a catwalk platform, and a slide platform that are pivotally connected together. A drill pipe rack, a chain drive, and a kicker direct the drill pipe to and from the catwalk platform. A hydraulically actuated piston lifts the catwalk platform and slide platform into alignment to create a single inclined delivery platform extending from the ground to the rig floor. A powered means lifts or lowers the drill pipe along the delivery platform.

Abstract: The disclosure herein relates generally to devices and methods usable during well drilling and surface operations. More particularly, the disclosure herein relates to a rig incorporating a coiled tubing injector that engages downhole tools.

Abstract: A tool assembly is provided that includes an actuatable tool such as a valve or a setting tool. And includes a location device that senses the location of the tool assembly within a tubular body based on a physical signature. The tool assembly also includes an on-board controller configured to send an activation signal to the actuatable tool when the location device has recognized a selected location of the tool based on the physical signature. The actuatable tool, the location device, and the on-board controller are together dimensioned and arranged to be deployed in the wellbore as an autonomous unit.

Abstract: A hydraulic oil well pumping arrangement employs a compensating type hydraulic pump, a directional valving arrangement and a proportioning valving arrangement. When the directional valve is energized, oil is directed to the rod end of the hydraulic cylinder. In one embodiment, a time delay halts the movement of the sucker rod or pumping string to allow accumulation of oil in a slow following well. In another embodiment, the pumping string rapidly falls to the bottom of the stroke in order to shake or jar debris from the string.