Chevron Research Company

Glenn W Anderson

Stanley O Hutchison

Gordon L Newby

Odell C Masters

A wellhead expansion assembly for wells having a plurality of tubes carrying hot fluids into and out of a well. Thermal expansion of the tubing is a accommodated by provision of an expansion chamber for termination of each separate string of tubing. Expansion chambers are connected in series, female threaded end to male threaded end. A male end of a first expansion chamber is threadedly engaged with a wellhead donut while a terminal end of a last expansion chamber in the series is threadedly engaged with a cap.

Wellhead expansion assembly

A method and apparatus for placing a cement thermal packer is disclosed. The cementing collar of the present invention is assembled into a stream or hot fluid injection string and positioned along the well in the location where the packer is to be placed. Cement material for the packer is pumped down the injection string preceded by a separation plug and followed by a sealing plug. The separation plug seats in the cementing collar to cause the cement to be diverted to the annulus between the well casing and the injection string. The sealing plug seats in the collar while the placed cement sets to form the packer. The internals of the collar are sheared from the collar leaving a smooth injection string to the injection zone of the well.

Method and apparatus for placing a cement thermal packer

A wellhead assembly for wells having tubing carrying hot fluids into or out of the well. The tubing is subject to elongation due to thermal expansion from a fixed portion within the well. The present wellhead accommodates the thermal elongation and provides a noncontacting connection to the tubing from outside the wellhead. The wellhead may also be constructed to accommodate concentric tubing for hot fluids to or from separate portions of the well.

Dome-type packoff wellhead

A downhole concentric tubing string is disclosed for use in distributing steam, or other hot fluids, to separated subsurface formations along a well bore. The apparatus includes elements for deflecting the steam from one string into the annulus of a cased well for injection through openings into the formation, elements for conducting the steam in another of the concentric string to a second set of openings for injection into another portion of the formation, and elements for isolating and separating the two separate injection intervals.

Concentric steaming string downhole apparatus

A method for removing material from directional wells using centralized tubing to circulate foam in the well at a velocity in excess of 30 feet per minute.

Slant hole foam cleanout

A method of forming an impression sleeve on an impression packer for use in obtaining impressions in wells, the impression sleeve being formed of a mixture of partially cured synthetic nitrile rubber, natural rubber smoked sheet, silica powder and rubber processing oil.

Material for impression packer

A steam injection system including a steam deflector connectable into a tubing string which steam deflector provides for selectively passing steam through the tubing string to the bottom thereof or diverting steam from inside the tubing string out into the wall liner-tubing annulus and in a direction concentric with and substantially parallel to the longitudinal axis of the tubing string and above the bottom end thereof utilizing a sliding-sleeve arrangement and packer cup means packing off the well liner-tubing annulus both above and below the steam deflector.

Steam injection system for use in a well

A steam deflector connectable into a tubing string is provided for selectively passing steam through the tubing string to the bottom thereof or diverting steam from inside the tubing string out into the well liner-tubing annulus without causing a vortex effect and in a direction concentric with and substantially parallel to the longitudinal axis of the tubing string and above the bottom end thereof utilizing a sliding-sleeve arrangement.

Steam deflector for use in a well

A method of using an impression element to determine the actual size of a flow opening in a tubular member located in a well by comparing an extrusion formed on the impression element with calibrated data on extrusion size vs. actual hole size.

Method of determining actual size of flow openings in a tubular member

An impression packer for use in obtaining impressions in wells and having an impression sleeve formed of a mixture of partially curved synthetic nitrile rubber, natural rubber smoked sheet, silica powder and rubber processing oil.

Impression material for use in an impression packer

A method of using an impression element in a tubular member positioned in a well and having a flow opening located under liquid to obtain information on the effective connection to permeability of the flow opening with the formation penetrated by the well.

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Oildale, CA, United States of America

Glenn W Anderson