Abstract: Wellbore subassemblies usable to create a flowpath between a formation and a wellbore can include an inner sleeve and an outer sleeve positioned internal to and external of a core, the core having sockets containing charge assemblies. Upon actuation of the charge assemblies, the inner and outer sleeves are both simultaneously penetrated to form a fluid flowpath between the interior of the subassembly and the formation exterior to the subassembly. The structure of the subassembly can enable it to be lowed and used as part of a tubular conduit string both before and after perforation, the charge assemblies being unobtrusively embedded within the wall of the subassembly.

Abstract: A bottom hole assembly for one trip perforating and treating a wellbore, the bottom hole assembly including: a tool body including an outer surface and an upper end; a fluid passage extending into the tool body from the upper end; a valve to provide (i) in one orientation fluid access from the fluid passage to an outlet port opening to the outer surface and (ii) in another orientation fluid access from the fluid passage to a perforating gun actuation fluid supply channel while sealing fluid access from the fluid passage to the outer surface; an annular sealing member encircling the outer surface below the outlet port; and a perforating gun carried below the resettable, annular sealing member and hydraulically actuable to detonate by fluid communication through the perforating gun actuation fluid supply channel.

Abstract: In a hydrocarbon producing wellbore, liquids (oil, condensate, water of mixtures thereof) from the formation may accumulate and build up a hydrostatic pressure gradient, which can kill gas production. Various embodiments of the present invention include a plunger lift system that can remove said formation liquids from a wellbore. A piston, including a sleeve with a hollow passage may travel downhole, accumulate formation liquids and utilizing the gas pressure deliver said formation liquids to the top of the wellbore for removal. The piston face may be one single wall that closes the hollow passage or the piston face may be comprised of a plug and an seat that unite to form a complete piston face downhole. Aspects of the plunger lift system, for example the sleeve and or the plug may be at least partially formed from materials that are buoyant in the formation liquids.

Abstract: A bottom hole assembly for one trip perforating and treating a wellbore, the bottom hole assembly including: a tool body including an outer surface and an upper end; a fluid passage extending into the tool body from the upper end; a valve to provide (i) in one orientation fluid access from the fluid passage to an outlet port opening to the outer surface and (ii) in another orientation fluid access from the fluid passage to a perforating gun actuation fluid supply channel while sealing fluid access from the fluid passage to the outer surface; an annular sealing member encircling the outer surface below the outlet port; and a perforating gun carried below the resettable, annular sealing member and hydraulically actuable to detonate by fluid communication through the perforating gun actuation fluid supply channel.

Abstract: A perforating gun assembly including: an upper end; a perforating gun connected to the upper end; a hydraulically actuated tool connected to the perforating gun on an end opposite the upper end; and a fluid conduit extending through the upper end and to the hydraulically actuated tool, the fluid conduit allowing fluid communication past the perforating gun to the hydraulically actuated tool such that fluid can be communicated through the upper end to actuate the hydraulically actuated tool.

Abstract: A rotating tag bar is positioned below a progressive cavity pump stator for supporting at least a portion of a rod string a rotor. A tubular housing is secured to the stator and is fitted with a rotatable platform. The platform blocks downward stretch of the rotor and then rotatably support the rotor on a thrust bearing. Thereby, rotor-imposed loads on the platform translate into tensile loads directed into the stator, which is suspended from tubing string, lessening the load on the rod string and thereby both reducing the need for extreme accuracy in rotor positioning and reducing rod string and tubing wear. Optionally, a no-turn tool transmits load from the stator into the casing. In operation, the rotor is landed to contact the platform. The rotor is then lifted a distance less than the anticipated stretch so that when in operation, the rotor sets down on the platform and transfers at least a portion of the rod string load into stator.