Halliburton Energy Services, Inc.

Gary John Geoffroy

Thomas Jules Frosell

Stephen Michael Greci

Michael Linley Fripp

Tyson Harvey Eiman

Jason P Witte

Kevin Harrell

Gustavo Dias De Casto Cervo

Stephen Michael Grecci

In general, in one aspect, embodiments relate to a resettable latch assembly for latching downhole to a mating mandrel; that comprises a mandrel, a latch collet disposed on the mandrel, wherein the latch collet is radially flexible with respect to the mating mandrel, and an energy transfer line extending a length of the mandrel; wherein the resettable latch assembly is latchable, releasable, and relatchable to the mating mandrel with translational movement.

Resettable latch assembly with energy transfer line(s) feed through

This disclosure may generally relate to subterranean operations and, more particularly, to systems and methods for setting a packer. Specifically, embodiments of the present disclosure may provide real-time verification of setting a packer in order to form a seal within a wellbore. A system for packer setting may comprise a packer, a telemetry module operable to wirelessly receive one or more control signals from a surface location, and a control module coupled to the telemetry module and the packer, wherein the control module is operable to actuate the packer in response to the one or more control signals from the surface location.

Packer setting and real-time verification method

Methods and systems for a remote control flow path system in a wellbore. In one embodiment, the system comprises a plurality of transceivers spaced in the wellbore; a telemetry module operable to wirelessly receive control signals from a surface location by way of the plurality of transceivers and to wireless transmit signals to the surface location by way of the plurality of transceivers; a control module comprising a controller, a pump, and a reservoir of hydraulic fluid; a plurality of valves; and a plurality of control lines for the hydraulic fluid, wherein the plurality of control lines are disposed between the pump and the plurality of valves; wherein the control module is operable to hydraulically actuate one or more of the valves to open or closed positions in response to the control signals from the surface location to create one or more flow paths in the wellbore.

Remote control flow path system for gravel packing

An apparatus for controlling fluid flow into a well includes an outer tubular member and an inner tubular member. The outer tubular member includes a screen configured to enable fluid flow therethrough between an exterior and an interior of the outer tubular member. The inner tubular member is configured to be positionable within the outer tubular member. The inner tubular member is a remotely activated flow control device configured to control fluid flow between an exterior and an interior of the inner tubular member.

Well apparatus with remotely activated flow control device

A sleeve on a downhole work string or a completion string may be actuated without movement of the work string, by positioning the work string within the completion string such that a sleeve positioned in a recess on a surface the work string or the completion string, in combination with surfaces of the work string and the completion string define a chamber on a side of the sleeve. A fluid may be pumped from a fluid source through a fluid passageway in the work string to the chamber for forcing the sleeve to actuate from an open position to a closed position or vice versa. In some aspects, multiple sleeves may be actuated concurrently via additional fluid passageways that are in fluid communication with one another. In some aspects, multiple sleeves may be actuated independently via additional fluid passageways that are fluidly isolated from one another.

Tubing assembly for hydraulic shifting of sleeve without tool movement

A completion running tool includes a body that defines a central flow passage and one or more radial flow ports. A piston is coupled to the body at a releasable coupling and positioned for longitudinal movement within a piston chamber defined radially between the body and an outer shroud. A prop sleeve is positioned in the central passage and defines one or more apertures that facilitate fluid communication between the central passage and a piston setting chamber via the one or more radial flow ports. The prop sleeve is movable within the central flow passage between a first position, where the prop sleeve radially supports the releasable coupling and thereby prevents disengagement of the piston, and a second position, where the piston is able to disengage from the releasable coupling and move within the piston chamber.

Hydraulic packer setting tool with anti-preset feature

A completion string can have an outer surface and an inner surface, a first fluid passageway being defined between the outer surface and the inner surface. The inner surface can define an inner region of the completion string and can have a recess that is sized to receive a sleeve that is moveable between an open position and a closed position. The inner region can be sized to receive a work string at a position at which a surface of the work string cooperates with the sleeve and the inner surface of the completion string to define a first chamber on a side of the sleeve, the first chamber being hydraulically sealed by a plurality of sealing elements. The work string can define a second fluid passageway to provide fluid communication with the first chamber.

A wellbore apparatus positionable within a wellbore with a tubular string includes a fracturing assembly and a latch. The fracturing assembly includes a housing comprising a flowbore formed therein and a port, a flow control device configured to move with respect to the housing to selectively allow fluid communication from the flowbore to an exterior of the housing through the port, and a wellbore securing device configured to secure the fracturing assembly within the wellbore. The latch is configured to removably couple the fracturing assembly to the tubular string.

Fracturing assembly with clean out tubular string

A method can include closing a valve interconnected between sections of a washpipe of a service tool string by displacing the service tool string relative to a completion string, thereby preventing flow through the washpipe. A well system can include a service tool string reciprocably received in a completion string, the service tool string including a washpipe received in a well screen, and a valve which selectively permits and prevents flow through the washpipe. The completion string can include a structure which operates the valve in response to displacement of the service tool string relative to the completion string. Another method can include closing a valve by partially withdrawing a service tool string from a completion string, thereby preventing flow through a washpipe of the service tool string.

Growing community of inventors

Plano, TX, United States of America

Gary John Geoffroy