Baker International Inc.

Baker Oil Tools, Inc.

Bobby F Goad

Rudy B Callihan

Clyde S Wainwright, Jr

John F Muse

Gary A Miller

A running tool for a hydraulically set packer, hanger, or the like, having expandable slip elements held in a retracted position by an actuating sleeve during run-in, employs an annular piston to hold the actuating sleeve in a fixed locked position relative to the tubular body portion of the running tool, thus preventing inadvertent setting of the tool due to impacts received during the run-in of the tool. When the slips are positioned at their desired location in the well, an increase in fluid pressure applied to the tubular body portion of the running tool will effect an upward movement of the annular piston, shearing a shear screw which has held the piston during the run-in operation, releasing a positive lock engaged with the slip actuating sleeve, and effecting upward movement of the actuating sleeve to release the slips. A contractible ring is also moved by the piston and effects the locking of the actuating sleeve in an upward position after the slips are released, thus eliminating the possibility of the slips being unset by inadvertent downward movement of the actuating sleeve.

Locking mechanism for hydraulic running tool for well hangers and the

Mechanism for achieving the radial expansion of an annular elastomeric pack-off unit between the bore of a casing and the exterior of a liner, comprises a tubular sealing assembly threadably connected between the liner and the hanger and defining two inwardly projecting annular seals, an annular fluid pressure chamber, and radially disposed fluid inlet ports for the fluid pressure chamber located between the two inwardly projecting annular seals. An annular piston mounted in the annular pressure chamber effects the compressible expansion of an annular elastomeric seal element. A tubing extension of the work string is provided which may be selectively moved into sealing relationship with either or both of the internally projecting annular seals. During the cementing operation, the tubing extension engages both annular seals. After cementing, the tubing extension may be elevated by the work string to disengage from the lowermost one of the internally projecting annular seals and permit fluid pressure to be applied through the radial ports to the actuating piston. A backup or alternate method of operation is provided through the incorporation of radial ports in the work string pipe extension which are normally covered by a valve sleeve shearably secured to the pipe extension.

Pressure actuated pack-off and method

The disclosure relates to an improved apparatus for effecting the cementing of a liner at the bottom of a well bore. The liner sleeve assembly is inserted into the well bore on a hanger which is detachably connected to a running tool, which, in turn is connected to the work string by a torque transmitting expansion joint. The running tool may be fluid pressure actuated to set the hanger. In the event of failure of the fluid pressure setting operation, the hanger may be mechanically set by rotation of the work string transmitted to the running tool by the torque transmitting expansion joint.

Combination hydraulically set hanger assembly with expansion joint

A hanger for supporting dual tubing strings in a well casing from hanger mandrels which can swivel to facilitate threadedly connecting each mandrel to its associated tubing string. The hanger includes an orienting sleeve for receiving safety shut-off valves, the sleeve being adapted to swivel with respect to the rest of the hanger, making it easier to assemble the hanger onto the running and setting tool used for setting the hanger in the casing. The running and setting tool is releasably secured to the hanger. By imposing fluid pressure on the setting tool, the tubing hanger slips are expanded against the casing. Before the running and setting tool is released from the hanger and retrieved from the well casing, wire line retrievable blanking plugs can be set in the tubing string below the hanger, one plug being inserted in place in one tubing string before the hanger is lowered in the casing, and the other plug lowered through the running tool and hanger to its associated landing nipple in the other tubing string, to maintain the well under control after the running and setting tool is released from the hanger and retrieved at the top of the well bore in which the casing is confined.

Dual string tubing hanger and running and setting tool therefor

Apparatus for adjusting the distance between a lower tubing hanger anchored in a well casing to support a depending lower tubing string, and an upper tubing hanger at the well head, in which an adjustable spacer device has its lower end connected to the lower tubing hanger and its upper end to the lower end of a safety valve connected to an upper tubing string extending to the upper tubing anchor, the valve being controlled hydraulically by fluid under pressure imparted through a control line strapped, or otherwise secured, to the upper tubing string and extending from the top of the well to the safety valve. The upper tubing string, safety valve and control line, as well as the upper portion of the spacer, are rotatable as a unit with respect to the lower portion of the spacer to lower the unit relative to the lower tubing hanger until the upper tubing hanger lands on its well head seat, such action occurring without twisting the control tubing relative to the safety valve.

Growing community of inventors

San Antonio, TX, United States of America

Bobby F Goad