Abstract: A lateral isolator (200) has a tubular body with an upstream end and a downstream end. The lateral isolator (200) also includes an inner member (210) having a pivot ring (220) disposed within the tubular body. A first elastomeric package (236) is disposed between the tubular body and the inner member (210) longitudinally between the pivot ring (220) and the upstream end. A second elastomeric package (236) is disposed between the tubular body and the inner member (210) longitudinally between the pivot ring (220) and the downstream end.

Abstract: A release mechanism for a jarring tool is formed by a plurality of segmented release lugs. Each lug includes a plurality of axial spaced projections on an inner surface and a plurality of grooves on an outer surface. The projections have either different widths or are separated by varying distances and releasably engage corresponding grooves in a mandrel located within a housing of the tool. The release lugs are positioned between a trigger sleeve and the mandrel.

Abstract: A release mechanism for a jarring tool is formed by a plurality of segmented release lugs. Each lug includes a plurality of axial spaced projections on an inner surface and a plurality of grooves on an outer surface. The projections have either different widths or are separated by varying distances and releasably engage corresponding grooves in a mandrel located within a housing of the tool. The release lugs are positioned between a trigger sleeve and the mandrel. The release lugs may be supported by an annular ring member.

Abstract: The present disclosure relates generally to wellbore cleanout and, more particularly, to an improved tool used to remove debris from an interior of a tubular string. The tool may comprise a number of combinations of varying subsystems able to customize the tool to the operator's needs. A cleaning tool may comprise a body, a first centralizer, wherein the first centralizer is disposed at a first end of the body, a second centralizer, wherein the second centralizer is disposed at a second end of the body, and at least one subsystem, wherein the at least one subsystem is disposed on the body.

Abstract: A stabilizer assembly for incorporation in a drill string. The stabilizer assembly includes a tubular member and a stabilizer sleeve slidably disposed about the tubular member. The tubular member has a first castellated portion extending externally around the tubular member, and the stabilizer sleeve has a second castellated portion engaging the first castellated portion. The tubular member includes a first shoulder extending externally around the tubular member, and the stabilizer sleeve further includes a second shoulder extending internally around the stabilizer sleeve. The first and second shoulders at least partially define an annular space between the tubular member and the stabilizer sleeve. A key is disposed within the annular space such that an axial load path between the tubular member and the stabilizer sleeve is substantially through the first and second shoulders and the key and substantially not through the first and second castellated portions.

Abstract: An insulating component for inclusion in a down hole drill string comprising a first part or connected group of parts, and a second part or group of parts. The first part or group of parts includes a first connection site and the second part or connected group of parts includes a second connection site. The insulating component also includes a first right-hand threaded connection located between the first connection site and the second connection site, and a second, left-hand threaded connection located between the first connection site and the second connection site. The first part or group of parts is electrically insulated from the second part or group of parts through insulating material provided between the first part or group of parts and the second part or group of parts, so that the first and second connection sites are electrically insulated from one another.

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 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 method of releasing a safety joint in a subterranean well can include disconnecting a tubular string at the safety joint without rotation of the tubular string. A safety joint for use in a subterranean well can include sections which are separated from each other in response to a predetermined number of relative longitudinal and non-rotational displacements between the safety joint sections. Another method of releasing a safety joint in a subterranean well can include fully actuating a jar multiple times, the jar being interconnected in a same tubular string with the safety joint, and then disconnecting the tubular string at the safety joint in response to non-rotational displacement of the tubular string.

Abstract: An impact apparatus conveyable in a tool string via conveyance means within a wellbore. The impact apparatus comprises a first portion, including a first interface coupled with a first tool string component, a first engagement feature, and a first impact feature. The impact apparatus also comprises a second portion, including a second interface coupled with a second tool string apparatus, a second engagement feature in selectable engagement with the first engagement feature, and a second impact feature positioned to impact the first impact feature in response to disengagement of the first and second engagement features and a tensile force applied across the tool string by the conveyance means. A release member positionable between first and second positions in response to a signal carried by the conveyance means prevents disengagement of the first and second engaging features when in the first position but not the second position.

Abstract: A percussion hammer bit retention system including a retainer having at least three (3) tabs, a hammer bit having first and second elevated surfaces that each define pathways and slot openings for rotational receipt of the tabs, and a custom chuck further including slot openings for receipt of the tabs. The application of tabs in combination with the elevated surfaces and indexed slot openings distinguish the present invention over the prior art. In application, in order to fully separate the retainer from the assembly, the tabs are indexed in a manner that only allows them to pass through the aligned slot openings on the first elevated surface in one (1) position every 360 degrees, and then through the aligned slot openings on the second elevated surface in one (1) position every 360 degrees, and then through the indexed slots on the custom chuck in one (1) position every 360 degrees.

Abstract: A bit retainer system comprising a casing, a driver sub adapted to be disposed around a shank of a bit, and a bit retainer. The driver sub comprises a threaded connector, a threaded pin end configured to engage with the hammer case, and a stop. The bit retainer comprises a load carrying threaded connector configured to engage with the threaded connector of the driver sub, and a catch thread configured to retain the head of a bit to the system.

Abstract: A stabilizing sleeve device for an impact drill bit used in underground drilling operations. The cylindrical tubular device has arcuate keys on a bottom edge for interlocking with keyways in the shoulder of a hammer drill bit and a locking key groove in its top edge.

Abstract: An oil tool release joint with a top sub that has a pin end which inserts into an opening in a bottom sub provides an alternative remote tool for separating pipe string segments after rotation. The subs are held together by shear pins which are wedged through holes in the bottom sub into recesses in the top sub. The bottom sub has uphole extending splines that engage slots in the top sub when the subs are connected. The splines and slots translate rotational motion from one sub to the other. The joint releases upon the application of a force sufficient to shear the shear pins either by hydraulic pressure in the drill string, an upward pull on the top sub or both. A guide ring encircles the uphole ends of the splines to guide material into the bottom sub when the joint is separated.

Abstract: A shear sub for installation in the drill string used to rotate a drill bit in the drilling of wells includes a mandrel extending upwardly for connection to the drill string. A housing slidably enclosing the mandrel extends downwardly below the mandrel and is threaded for connection directly, or indirectly, through joints of drill pipe to the drill bit. Rotation and longitudinal movement of the housing relative to the mandrel during drilling is prevented by shear pins which engage the housing and the mandrel to hold the housing in a position in which lugs extending inwardly therefrom are directly above and in alignment with splines extending outwardly from the mandrel. If an obstruction to drilling occurs that results in excessive torque on the drill string, the shear pins are sheared. On lifting and rotating the drill string, the mandrel moves upwardly relative to the housing whereupon the lugs interlock with the splines to allow rotation of the drill bit as it is lifted off bottom.