Baker Hughes Corporation

Baker Hugues Incorporated

Bruce Erwin Proctor

Kelley L Phillips

Donn Jason Brown

Brown Lyle Wilson

David Lester Olson

Edward C Kanady

Douglas W Berry

Matthew R Porter

Doug W Berry

A progressing cavity well pump system has a stator secured to a string of tubing. A drive head at the surface rotates the tubing and the stator. The pump rotor is held against rotation by an anchor mechanism. The tubing, stator, rotor and anchor mechanism are installed in the well in a single trip.

Tubing driven progressing cavity pump and method of pumping well fluid from a well

A progressing cavity pump is located within a well and has a gas separator for separating gas before reaching the pump. The pump has a rotor that is driven by a string of rods extending to the surface. A drive shaft for the gas separator is coupled to the rotor during pumping operation both for axial as well as rotational movement. The rotor assembly, when lowered through the tubing, stabs into engagement with the drive shaft of the gas separator in one version. In another version, the gas separator drive shaft is lowered through the tubing with the rotor and stabs into a hub sleeve in the gas separator.

Floating shaft gas separator

A progressing cavity pump (PCP) system that may be deployed in an existing well configuration without the need for a workover rig. A stator and tubing stop are first set in a conduit, such as production tubing, at a desired depth. In subsequent wireline runs, a pack-off and upper tubing stop are installed above the stator, which results in the stator assembly being set by tubing stops on top and bottom and results in the conduit above the PCP being isolated from the wellbore below. Installation of the system is completed by installing the rotor and by installing top-side drive equipment in the usual way. The PCP system allows the deployment of lift systems within existing well configurations without any element being deployed on tubing and provides the ability to retrofit a well with an insertable pump within existing tubing.

Non-tubing deployed well artificial lift system

A progressing cavity rod-driven well pump utilizes a tag shoulder above a helical passage of the stator. The pump stator is located at the lower end of a string of tubing. The tag shoulder is more restrictive than a passage through the tubing. A pump rotor is secured to a string of rods and has a stop located above the rotor. The rotor is lowered on the rods until the stop lands on the tag shoulder. Then the operator lifts the rods and the rotor to accommodate for expected stretch during operation. By removing the rods and rotor, monitoring tools can be lowered through the tag shoulder and stator.

Method and apparatus for aligning rotor in stator of a rod driven well pump

A submersible pump assembly has a pump section, a seal section and a motor section. Within each section are shafts. The adjacent shaft sections are matingly engaged with one another, and are connected by fasteners. The fasteners consist of a key and a screw that fits within the key. The fasteners secure the adjacent shaft sections to one another to transmit torque from one shaft to the other, and to transmit thrust in axial tension from one shaft to the other.

Tension thrust ESPCP system

A downhole pump assembly is suspended by tubing in a well. The pump assembly has a separator attached below a progressing cavity pump with a flexible shaft to accommodate the concentric path of the shaft of the separator and the eccentric path of the rotor of the pump. Vanes on the shaft of the separator use centrifugal force to separate the heavier liquids from the lighter gases in the well fluids. The separator discharges the gas into the casing and the liquid to the pump. A motor drives both the separator and the pump. A gear reduction unit is located between the motor and the pump in order to reduce the rotational speed from the motor to the desired rotational speed of the rotor for the pump.

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Tulsa, OK, United States of America

Bruce Erwin Proctor