Halliburton Company

Halliburton Energy Services, Inc.

Kevin R Manke

Paul David Ringgenberg

Roger Lynn Schultz

Neal Gregory Skinner

William Ellis Standridge

Matthew Todd Howell

Jesse Cale Porter

Matt T Howell

Adam Kent Neer

H Kent Beck

Tracy Michael Martin

David S Wesson

Harold Kent Beck

Harold Wayne Nivens

Robert Anthony Moore

Gregory A Kliewer

Charles M MacPhail

Don S Folds

Iosif Joseph Hriscu

Curtis E Wendler

William L Bohan

Allen R Young

Robert Preston Clayton

Anthony Valencia

Ricardo R Maldonado

J Allan Clark

Cleo (John) Clayton Holland

Samuel Bianco

Harold E Powers

David R Smith

Adam K Neer

Jesse C Porter

William E Standridge

Tracy Martin

Matthew T Howell

A slip for use in the anchoring of a downhole tool in the well casing wherein the anchors include a plurality of buttons and at least one wicker. The slip is positioned about a mandrel and radially expands upon the application of force. The buttons and wicker first engage the casing in response to a first force, and the wicker deformably engages the casing in response to a second force. The second force causes the wicker to cut into and deform the casing, thereby anchoring the downhole tool for high-pressure operations.

Drillable slip with buttons and cast iron wickers

A downhole tool for use in a well has a mandrel with an expandable sealing element disposed thereabout. The mandrel has a head portion threadedly connected thereto. A shoulder in the head portion and an upper end of the mandrel define an annular space. A sleeve with a bore therethrough may be positioned in the annular space. The head portion may be removed and a solid plug installed so that it fits within the annular space and so that the downhole tool will act as a bridge plug. The downhole tool has slip rings made up of a plurality of individual slip segments that are adhesively bonded to one another at the sides thereof.

Interchangeable drillable tool

A downhole tool releasing mechanism which includes a collet for releasably engaging a mandrel of a downhole tool. A retaining band is circumferentially disposed about the fingers of the collet for maintaining engagement of the collet and the mandrel prior to application of a predetermined axially directed force on the releasing mechanism. Upon application of such a force the collet fingers expand, breaking the shear band, the mandrel is released and the downhole tool is disengaged.

Downhole tool releasing mechanism

A downhole tool has a mandrel with a sealing element disposed thereabout. The sealing element is movable from an unset position to a set position in which the sealing element engages the well. Extrusion limiters are positioned at the ends of the sealing element. The extrusion limiters have first and second layers and the first and second layers are different materials. The second layer may be made up of a plurality of discs. At least one of the discs may be a disc with an irregularly shaped outer peripheral edge and a generally circular inner peripheral edge. A plurality of the discs with the irregularly shaped outer edge may be stacked and may be stacked with a generally circular or ring-shaped segmented disc. The first and second layers are stacked and then molded into a final shape for placement at the ends of the sealing element.

Multiple layer extrusion limiter

A downhole tool assembly has a sleeve with a continuous j-slot, a lug rotator ring configured to move axially relative to the sleeve and having a lug configured to move within the continuous j-slot, and a rupture disk configured to prevent the lug from moving within the continuous j-slot during run-in. A method of activating the downhole tool assembly includes lowering the downhole tool assembly into a well bore on a tool string, rupturing the rupture disk, allowing the lug to move within the continuous j-slot, and setting the downhole tool assembly by lifting upward and pushing downward on the tool string.

Method of activating a downhole tool assembly

The downhole tool assembly has a sleeve with a continuous j-slot, a lug rotator ring configured to move axially relative to the sleeve and having a lug configured to move within the continuous j-slot, and a rupture disk configured to prevent the lug from moving within the continuous j-slot during run-in. The method includes lowering the downhole tool assembly into a well bore on a tool string, rupturing the rupture disk, allowing the lug to move within the continuous j-slot, and setting the downhole tool assembly by lifting upward and pushing downward on the tool string.

A zonal isolation device comprises a packer assembly and an internal setting mechanism operable to actuate the packer assembly from an unset position to a set position, wherein the zonal isolation device is resettable and retrievable. Another zonal isolation device comprises a packer assembly, a setting mechanism operable to actuate the packer assembly from an unset position to a set position in response to hydraulic pressure alone, and a locking mechanism operable to lock and unlock the packer assembly from the set position in response to hydraulic pressure alone. A method for setting a zonal isolation device within a well bore comprises running the zonal isolation device in an unset position within the well bore on a work string, applying a differential pressure between the work string and the well bore, and actuating the zonal isolation device to a set position in response to the differential pressure alone.

Hydraulic coiled tubing retrievable bridge plug

A run-in and retrieval device for a downhole tool comprises a first set of lugs disposed on a first component of the device connected to a tool string, and a second set of lugs disposed on a second component of the device connected to the downhole tool, wherein the first set of lugs interact with the second set of lugs in a connected position. A method for running at least one downhole tool into a well bore comprises forming a releasable connection between an overshot connected to a tool string and a mandrel connected to the at least one downhole tool, running the at least one downhole tool into the well bore via the tool string, manipulating the at least one downhole tool in the well bore; and, rotating the overshot less than 360 degrees with respect to the mandrel to release the connection therebetween.

Run-in and retrieval device for a downhole tool

Apparatus for cutting openings in a wall of a well. The apparatus includes a mandrel with a jetting sleeve slidably disposed about the mandrel. The mandrel has a plurality of slots defined therein and the jetting sleeve has a plurality of jetting openings aligned with the slots so that fluid will pass through the mandrel, the slots in the mandrel, and the jetting openings. The jetting nozzles are received in the jetting openings and travel in the slots in the mandrel. The flow of jetting fluid through the mandrel causes the jetting sleeve to move on the mandrel so that slots may be cut in the wall of the well.

Method and apparatus for well perforating

Systems and methods particularly suitable for open hole formation testing are provided. In a described embodiment, a method of performing a test on a formation intersected by a wellbore includes the steps of flowing fluid into an apparatus from the formation, displacing a fluid barrier of the apparatus in one direction, flowing the formation fluid out of the apparatus and back into the formation by applying pressure to the apparatus, and displacing the fluid barrier in an opposite direction.

Open hole formation testing

Integrated drilling and evaluation systems and methods for drilling, logging and testing wells are provided. The drilling and evaluation systems are basically comprised of a drill string, a drill bit carried on a lower end of the drill string for drilling a well bore, logging while drilling means included in the drill string for identifying subsurface zones or formations of interest, packer means carried on the drill string above the drill bit for sealing a zone or formation of interest below the packer means, and a fluid testing means included in the drill string for controlling the flow of well fluid from the zone or formation of interest into the drill string. The drilling and evaluation systems and methods for using the systems allow one or more subsurface zones or formations of interest in a well to be drilled, logged and tested without the necessity of removing the drill string from the well.

Integrated well drilling and evaluation

An improved mechanical system selectively locks the tester valve of an annulus pressure responsive tester valve in position for an indeterminate number of well annulus pressure cycles. The tester valve also features a multi-range metering cartridge which is operable to meter fluid over a wide range of differential pressures. The metering cartridge provides an adjustable resistance flow path which permits fluid flow across the cartridge. The resistance of the flow path is adjustable by selectively diverting the fluid through a series of fluid flow resistors. Resistance may be increased either by adding a number of flow resistors serially or by adding a single flow resistor which itself provides a greater fluid flow resistance.

Mechanical lockout for pressure responsive downhole tool

An improved mechanical system selectively locks the tester valve of an annulus pressure responsive tester valve in position for an indeterminate number of well annulus pressure cycles. The tester valve can be closed upon demand. The forces which accomplish opening of the ball valve act across a power piston, but the forces which close the valve act across an actuating piston. The tester valve can be run into a well with an operating element of the tester valve, in a first position such as a closed position. Upon reaching the desired depth within the well and setting of an associated packer system, well annul us pressure is then increased to a first level above hydrostatic pressure to move the power piston and thus move the tester valve to an open position. During a normal mode of operation, well annulus pressure can be cycled between hydrostatic pressure and the first level to open and close the tester valve. A fluid transfer assembly is included within the power piston which is operable to transfer fluid across the power piston. The fluid transfer assembly also includes an oppositely disposed check valve to allow unrestricted fluid flow across the power piston in the opposing direction during a release of annulus pressure. The tester valve also features a multi-range metering cartridge which is operable to meter fluid over a wide range of differential pressures.

An improved mechanical system selectively locks the tester valve of an annulus pressure responsive tester valve in position for an indeterminate number of well annulus pressure cycles. The tester valve can be closed upon demand. The forces which accomplish opening of the ball valve act across a power piston, but the forces which close the valve act across an actuating piston. The tester valve can be run into a well with an operating element of the tester valve in a first position, such as a closed position. Upon reaching the desired depth within the well and setting of an associated packer system, well annulus pressure is then increased to a first level above hydrostatic pressure to move the power piston and thus move the tester valve to an open position. During a normal mode of operation, well annulus pressure can be cycled between hydrostatic pressure and the first level to open and close the tester valve. A fluid transfer assembly is included within the power piston which is operable to transfer fluid across the power piston. The tester valve also features a multi-range metering cartridge which is operable to meter fluid over a wide range of differential pressures.

An annulus pressure responsive tool of the type which contains lateral circulation ports and a ball valve, each operable between open and closed positions to configure the tool into different modes of operation. These modes include a well test position in which the ball valve is open and the circulation ports are closed, a blank position in which the ball valve and circulation ports are both closed, and a circulating position in which the ball valve is closed and the circulating ports are open. Through manipulation of annulus pressure, the tool mode can be changed during the annulus pressure release to move out of the well test position and into the blank and circulating positions. An operating mandrel assembly is slidably disposed within the exterior housing of the tool and its movement dictates the positions of both the circulation ports and the ball valve. The operating mandrel is moveable by means of an annulus pressure conducting channel which is capable of receiving:, storing and releasing annulus pressure increases. A ratchet assembly associates the operating mandrel assembly and housing and functions as an overrideable position controller to dictate response of the operating mandrel assembly to annulus pressure changes.

Growing community of inventors

Flower Mound, TX, United States of America

Kevin R Manke