Halliburton Energy Services, Inc.

Otis Engineering Corporation

Halliburton Company

Colby M Ross

Ralph Harvey Echols

Syed Hamid

Ralph H Echols, Iii

William Mark Richards

Gregory William Garrison

Thomas Jules Frosell

Dhirajlal C Patel

Tyson Harvey Eiman

Frank Giusti, Jr

Ronald Van Petegem

William David Henderson

Pat M White

Henry Louis Restarick

Carter R Young

Peter Reid Maher

Samuel Martinez

Phillip Terry Thomas

James D Hendrickson

Dean S Oneal

Robert L Thurman

Richard M Sproul

Jim Venditto

Ross M McCurley

Brian P Manzi

Lewis D Proctor

Brock Wayne Watson

Marion Dewey Kilgore

Anthony M Badalamenti

Imre I Gazda

Jimmie R Williamson, Jr

Travis Thomas Hailey, Jr

Bryon David Mullen

Thomas Owen Roane

Ronald W McGregor

Karluf Hagen

Timothy J Noack

David Leslie Lord

Robert C Hammett

Keith Wayne Scott

Ronnie D Finley

Jack W Tamplen

Alireza B Rahimi

Andrew R Lane

Abdel Hamid Rawhi Abeidoh

Jhess Menard

Andrew Penno

Danny P Lewis

Derek J McCulloch

Rufus Mullins, Jr

Ronald C Sadlin

Timothy F LaBruyere

Henry I Restarick

Clifford David Wohleb, Jr

Thomas A Zeltmann

Jameel U Rahman

Peter R Maher

A plug retrieval tool includes a mandrel lowerable into a wellbore. A retrieval head is coupled to the mandrel for selectively latching onto a plug. A shroud is telescopically coupled to the mandrel about the retrieval head and moveable repeatedly between an extended position below the retrieval head for displacing debris on the plug and a retracted position for moving the retrieval head closer to the plug to latch onto the plug. A resistance mechanism provides a resistance to moving the shroud each time the shroud is moved toward the retracted position.

Resettable telescoping plug retrieving tool

Disclosed is a gravel pack service tool that utilizes an internal closure device to set a packer. One disclosed system includes a completion string including at least one packer, a service tool configured to be arranged within the completion string and having an interior that provides a flow path for fluids and a crossover tool, and a closure device arranged within the flow path and being actuatable between an open position and a closed position in response to a signature pressure pulse detected by the closure device, wherein, when the closure device is in the open position, the fluids are able to bypass the closure device and flow to lower portions of the service tool, and wherein, when the closure device is in the closed position, the fluids are prevented from bypassing the closure device and a pressure within the service tool is increased to set the at least one packer.

Gravel pack service tool used to set a packer

A system and method for deployment of an isolation seal assembly wherein an isolation seal assembly is releasably attached to a reverse circulation debris removal tool. The system includes a debris removal tool having a head with an elongated snorkel extending from the head; and an isolation seal assembly attached to the head with a shear device so that the snorkel protrudes past the end of the isolation seal assembly. The isolation seal assembly further includes a tubular with a latch adjacent a first end, an external seal below the latch, and openings formed along tubular between latch and the seal. The debris removal tool is used to engage the isolation seal assembly with a lower completion assembly. The openings in the isolation seal assembly permit the debris removal tool to continue to function after the isolation seal assembly is engaged with the lower completion assembly.

Reverse circulation debris removal tool for setting isolation seal assembly

Hydraulic setting tools, packer setting systems, and methods thereof are provided. The hydraulic setting tool includes a mandrel containing a main flow path, a piston housing surrounding at least a portion of the mandrel, and a piston disposed between the piston housing and the mandrel. A cavity is defined at least partially between the piston, the piston housing, and the mandrel. The tool also includes a port passing through the mandrel and configured to provide fluid communication between the main flow path and of the cavity, and an isolation sleeve located within the mandrel and movable along the main flow path between a closed position and an opened position to control the fluid communication between the main flow path and the cavity via the port. A remotely activated valve is located downstream from the isolation sleeve along the main flow path and controls the fluid passing therethrough.

Downhole interventionless tools, systems, and methods for setting packers

A method and apparatus that includes positioning a completion string that has an internal passageway and that has an external surface that at least partially defines an external region within a wellbore; isolating a zone of the external region from a wellbore hydrostatic pressure; measuring a pressure within the external region of the isolated zone; determining whether the pressure within the external region of the isolated zone is within a predetermined pressure range; and operating a valve that controls a flow of a fluid through a flow path from the internal region to the external region of the isolated zone when the pressure within the external region is outside of the predetermined pressure range.

Downhole pressure maintenance system using a controller

A method and apparatus that includes an elongated base pipe having an external surface at least partially defining an external region and an internal surface at least partially defining an internal region; and a pressure maintenance device disposed in the base pipe and comprising: a flow path that extends between the internal region and the external region; and a valve having a gas charged chamber, the valve allowing the flow of a fluid from the internal region to the external region through the first flow path when a pressure differential between a pressure associated with the internal region and a pressure associated with the gas charged chamber is less than a maximum pressure threshold and when a pressure differential between the external region and the pressure associated with the gas charged chamber is greater than a minimum pressure threshold.

Mechanical downhole pressure maintenance system

A setting tool for setting a packer in a wellbore includes a housing defining a hydraulic chamber, a piston disposed in the chamber, a pump coupled to the chamber via a flowline, and a setting sleeve directly or indirectly coupled to the piston. The pump may be used to pump pressurized fluid into the hydraulic chamber for pushing the piston in a direction, and the setting sleeve may be used to apply a compressive force to a packer element of the packer in response to the piston being pushed in that direction. The setting tool may include a sensor used to collect a measurement relating to a force on the workstring, in addition to a controller designed to receive a signal from the sensor and to provide a control signal to the pump based on the sensor signal.

Packer setting tool with internal pump

An exemplary downhole system includes a completion string positioned within a wellbore and providing at least an upper seal bore and a downhole device that includes a sliding sleeve. A service tool is extendable within the completion string and includes a shifting tool assembly and provides a mandrel, a shifting tool coupled to the mandrel, and upper equalization seals arranged on the mandrel and sealingly engageable with the upper seal bore. The shifting tool is engageable with the sliding sleeve to move the downhole device at least partially between a closed position, where a pressure differential between a subterranean formation and an interior of the completion string is assumed by primary sealing elements of the downhole device, and an open position, where the pressure differential is assumed by at least the upper equalization seals.

Shifting tool assembly that facilitates controlled pressure equalization

A method and apparatus that includes an elongated base pipe having an external surface at least partially defining an external region and an internal surface at least partially defining an internal region; and a pressure maintenance device disposed in the base pipe and includes a first flow path that extends between an opening in the external surface and an opening in the internal surface; a first valve that controls the flow of a first fluid through the first flow path; a first pressure differential sensor that controls the actuation of the first valve and is in fluid communication with the external region; and a pressurized fluid source in fluid communication with the first pressure differential sensor; wherein a first pressure differential threshold associated with the first pressure differential sensor is the difference between a pressure within the external region and the pressurized fluid source.

Downhole pressure maintenance system using reference pressure

Certain aspects are directed to a device designed to relieve compression in a length of pipe. The device provides a load ring that can absorb and isolate load until a shear sleeve is shifted and shear pins are sheared. A specific aspect provides a packer release compaction joint that has a shifting sleeve having a first internal shoulder configured to engage a shifting tool; a shear sleeve having a raised abutment; a load ring mounted on the shear sleeve, the load ring having an outer diameter and positioned forward of the first side of the raised abutment; a snap ring mounted around the outer diameter of the load ring. Action of a shifting tool against the first internal shoulder of the shifting sleeve causes the snap ring to move away from the load ring and move to the second side of the raised abutment.

Packer release compaction joint

A locating assembly includes an inner mandrel and an outer mandrel. The outer mandrel is connected to the inner mandrel via a frangible device. The locating assembly also includes a positioning device connected to the outer mandrel. Further, the locating assembly is directly or operatively connected to a tool, and the tool is located within a wellbore. An application of a first downward force causes the positioning device to move to a first position, and, when the positioning device is in the first position, the tool is located and maintained in a first position. An application of a second downward force causes the inner mandrel to move relative to the outer mandrel into a second position, and, when the inner mandrel is in the second position, the tool is located and maintained in a second position.

Single action, dual position, weight-down locating assembly

A fracturing/gravel packing tool system with dual flow capabilities. A method of treating a well includes the steps of: flowing a fluid into the well through a work string while simultaneously flowing another fluid into the well through an annulus; and directing each of the fluids to the exterior of a well screen in the well. A well treatment system includes a slurry and a fluid flowed into a well. The slurry has an initial density, but the fluid is mixed with the slurry in the well, thereby causing the slurry to have a reduced density in the well. Another method of treating a well includes the steps of: installing a gravel packing assembly including a well screen in the well; flowing a slurry and a fluid into the well; mixing the slurry with the fluid, thereby reducing a density of the slurry in the well; and flowing the reduced density slurry about an exterior of the well screen.

Fracturing/gravel packing tool system with dual flow capabilities

A fracturing/gravel packing tool with variable direction and exposure exit ports. A system for delivering an erosive flow into a subterranean well includes a port displacing in the well while the erosive flow passes through the port. Various displacement devices may be used in the system to displace the port.

Fracturing/gravel packing tool with variable direction and exposure exit ports

A fluid flow control device () for use in a wellbore to control the inflow of production fluids comprises a sand control screen () having a base pipe () with a first set of openings () that allows the production fluids to flow therethrough and a sleeve () coaxially disposed adjacent to the base pipe (). The sleeve () has a second set of openings () that allows the production fluids to flow therethrough. The sleeve () is selectively positionable relative to the base pipe () such that a pressure drop in the production fluids is selectively controllable by adjusting an alignment of the first set of openings () relative to the second set of openings ().

Fluid flow control device and method for use of same

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Carrollton, TX, United States of America

Colby M Ross