Other

The Western Company of North America

Ctc International Inc.

Monty E Harris

Richard A Sukup

Edward T Wood

Robert T Brooks

Michael O Dion

Derrel G Gurley

Patrick C Hyde

A method and apparatus for temporarily storing the lower portion of a string of drill pipe in a well which has a cased portion wherein a packer, installed between a storm valve located below the packer and an actuator located above the packer, is set in the annulus between the drill pipe and the well casing, the actuator being designed to close the valve upon initial axial movement of the upper portion of the drill pipe, and then to become disengaged from the lower portion of the set drill pipe allowing the remaining surface suspended drill pipe and actuator to be retrieved as in the case of a floating drill ship or set aside for reconnection and reopening of the storm valve after a storm has passed.

Storm valve

A wellhead isolation tool is mounted to a wellhead to isolate the bore of the wellhead from a treating fluid being injected. The isolation tool has a housing which has an upper section and a lower section. A valve is connected between the upper and lower sections. A mandrel is slidably carried in the housing and moves from an upper position spaced entirely in the housing to a lower position extending through the bore of the wellhead. In the lower position, the upper end of the mandrel is below the valve. This allows the valve to be closed and the upper section removed. The treating line is attached to the upper end of the valve. The nozzle has annular recesses formed in it to enhance turbulence to reduce erosion.

Wellhead bore isolation tool

A liner hanger will actuate remotely in a well to support a liner in casing. A running tool is secured to drill pipe and attached to the upper end of the liner. The liner hanger mounts to the exterior of the liner and includes a pair of tapered wedge members mounted in opposition to each other. The lower wedge member is stationarily secured to the liner for movement with it. The upper wedge member is carried in an extended running-in position by a retainer. A stop member is mounted above the lower wedge member by a connector. The connector secures the stop member to the liner for movement with it while running-in. Once on bottom, the stop member is released from the connector by stroking the drill pipe. Continued upward movement of the drill pipe will be relative to the stop member because it will engage the casing to remain stationery with the casing. The wedge members will move upward, with the upper wedge member contacting the stop member and being prevented from further upward movement. The retainer shears, allowing the lower wedge member to continue upward movement, sliding and wedging against the upper wedge member to lock the liner to the casing.

Liner hanging, sealing and cementing tool

A stage valve with particular use in cementing a well bore annulus where the stage valve has pressure operated valve member for opening a flow passage in the stage valve and the valve member has differential pressure areas which maintain the valve member open while a fluid moves through the flow passage in one direction and which can be closed by fluid moving in an opposite direction. The flow passage has a choke to develop a pressure differential from the flow of fluid. Spring members can be used with the valve member to close the flow passage when the pressure differential of the fluid flow in one direction is insufficient to maintain the valve member in an open position.

Hydraulic port collar

A mechanical setting tool for setting a flow control tool in an oil or gas well using the drill string includes a mandrel with means for attachment to the end of the drill string. Slips are releasably carried on the mandrel by a first release structure. A cone is releasably carried on the mandrel by a second release structure and has tapered surfaces confronting the slips. A stinger is carried on the lower end of the mandrel and has a third release means for releasably engagement to the flow control tool being set. A setting sleeve is releasably engaged to the mandrel by way of a fourth release structure between the sleeve and the cone.

Mechanical setting tool

A downhole tool for controlling the flow of fluids through the well casing includes a tubular mandrel with a flow control valve therein. A radially expandable seal member encircles the mandrel and a sub-bottom defines an abutment member, attached to and movable with the mandrel, for engaging one side of the seal member. A bottom cone is positioned around the mandrel and on the opposite of the seal member from the sub-bottom. The cone has a sleeve extending therefrom positioned between the seal and the mandrel on which the seal member is carried. An upper cone is positioned around the mandrel with slips segments being positioned between the upper and bottom cones. An upper radially expandable seal member encircles the mandrel and its carried on a sleeve extending from the upper cone. A lock hub is positioned around the mandrel and on the side of the upper cone opposite the upper seal and slip segments. The hub is slideable on the mandrel toward the sub-bottom for forcing the cones to converge against the slip segments, causing the segments to ride up on the cones and move radially outwardly. Sequentially the expandable seals are compressed and expanded radially outwardly for engagement against the casing wall. To facilitate drillability, components of the tool are formed of a synthetic resin composite, specifically a polyamide material that is glass fiber filled at a level of a minimum of about 30% by weight, having an extremely high modulus of elasticity and having a heat deflection temperature of about 400.degree. F. fully loaded.

Drillable well-fluid flow control tool

In an oil or gas well, a cement retainer setting tool for setting and pumping cement therethrough includes an inner piston defining a bore and an activation sleeve carried on the piston and defining an annular space between the piston and sleeve. A sleeve ring is formed inwardly from the activation sleeve and is positioned within the annular space beween the piston and the sleeve. Ports are provided to the piston above the sleeve ring for communicating a retainer setting pressure to the sleeve ring to move the sleeve downwardly relative to the piston upon application of such pressure. A plug means for plugging the lower end of the piston is provided therein. The plug means is disengagable upon application of a predetermined pressure greater than the retainer setting pressure. A second port structure is provided for connecting the lower end of the piston to a cement retainer, or other tool.

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Azle, TX, United States of America

Monty E Harris