Baker Hughes Corporation

Hughes Tool Company LLC

Baker Hughes, a Ge Compnay, LLC

John L Bearden

Ketankumar Kantilal Sheth

Steven Keith Tetzlaff

Jerald Ray Rider

Fred S Martin

Earl Bruce Brookbank

Joseph E Vandevier

Michael H Johnson

Donn Jason Brown

Paulo S Tubel

David H Neuroth

Larry A Watkins

John W Harrell

Dick Lee Knox

Don C Cox

Joseph F Donovan

Daniel James Turick

Gordon Lee Besser

Kenneth T Bebak

Alexander Crossley

William F Pranger

Ken Bebak

Ronald S Fordyce

J V Henry

Harold L Miller

William H Milne

Alexander W Crossley

An electric motor of an electric submersible pump is electrically isolated from a power conduit for diagnostic testing of the power conduit and wet connection components in place within a wellbore. The electric motor is electrically connected to the power conduit through a wet connection assembly having motor leads in electrical connection with a transfer contact and a receptacle assembly disposed on a tubing string having a supply contact electrically connected to the power conduit. Electric power flows through the power conduit, through the supply contact, through the transfer contact, and through the motor leads to the motor. The supply contact and the transfer contact are separated by a sliding sleeve that hydraulically inserts between the contacts, insulating the transfer contact and grounding the supply contact for testing. The contacts may also be separated by a relative rotation of the assemblies that grounds the supply contact for testing.

Isolating wet connect components for deployed electrical submersible pumps

A seafloor pump assembly is installed within a caisson that has an upper end for receiving a flow of fluid containing gas and liquid. The pump assembly is enclosed within a shroud that has an upper end that seals around the pump assembly and a lower end that is below the motor and is open. A separating device is connected to an upper end portion of the discharge pipe within the caisson. The separating device causes separation of gas from the flow containing gas and liquid to be enhanced prior to the flow reaching the operating liquid level in the caisson.

Caisson two-phase emulsion reducer

A test device for testing the integrity of a seal has a clear t-shaped liquid reservoir with three ends. A guide adapter is connected to the first end of the liquid reservoir and extends axially therefrom along an axis of the reservoir. A shaft adapter is connected to the second end of the body, opposite the first end. A test shaft with first and second ends extends axially through the first and second ends of the body and test and shaft adapters along the axis. The first end of the shaft is adapted to be connected to the rotating shaft of pump assembly.

Seal section assembly mechanical face seal integrity verification tool

A method of operating an electrical submersible pumping system that includes realtime monitoring of the wellbore fluid and adjusting pump speed so the fluid entering the pump remains subcooled. The method can include adding sensors within the wellbore and digitally storing fluid data accessible by a pump controller. The pump speed can be increased or decreased by adjusting the frequency of the electrical power delivered to the pump motor.

Method and device for maintaining sub-cooled fluid to ESP system

A submersible pumping system for use downhole, wherein the system includes a pump, an inlet section for receiving fluid, a pump motor, and a viscometer. Pumping system operating parameters are adjusted based on wellbore fluid viscosity measured by the viscometer. The viscometer can be disposed deep in the wellbore, adjacent the pump, seal, motor, at the pump intake or anywhere on the pumping system. The viscometer may be connected to a control system for controlling the pumping system in response to viscosity measurement and may include a sonic viscometer. A method of operating a downhole submersible pumping system is included that measures fluid viscosity in the wellbore during production operations. Pumping parameters can be adjusted based on the measured viscosity.

Viscometer for downhole pumping

A method for producing gas from a well with low pressure involves running a bottom hole pressure test to graph a P-Q curve. The operator computes a frictional pressure drop due to friction of the gas flowing through the production tubing to the surface. A packer is set above perforations in the well. A screw pump is selected that has a capacity equal to the sum of the frictional pressure drop plus a desired wellhead pressure. The screw pump has a flow rate capacity determined from the P-Q curve. The operator may vary the frequency of a downhole motor to achieve the desired wellhead pressure.

Downhole gas compressor

A protection system for an artificial lift device including but not limited to electrical submersible pump (ESP) and an electrical submersible progressing cavity pup (ESPCP). The artificial lift device is suspended on a tubing string into a wellbore where the artificial lift device contacts well fluids. The artificial lift device is provided with a barrier such as an intake barrier or output barrier that deters an ingress of well fluids into the artificial lift device. As a result, the artificial lift device may remain idle and submerged within well fluids for an extended period of time without experiencing degradation of the artificial lift device internals. The intake barrier may include a plug, burst disk, dissolvable material, a selectively openable barrier such as a sleeve or a spring biased member or other member that is capable of providing a suitable barrier. The barrier may be removed once the artificial lift device is ready for operation. The artificial lift device may be filled with a protective fluid. An optional pressure sensor may be provided that is in communication with the interior of the backup unit for communicating with a compressor that may be activated to maintain a positive pressure within the artificial lift device to prevent well fluids from entering the unit. The protection system of the invention is desirable for protecting an idle artificial lift device, including when the artificial lift device is a backup unit in a multi-artificial lift device deployment.

Protection scheme and method for deployment of artificial lift devices in a wellbore

A method for installing a submersible pump assembly that allows deployment in a live well under pressure. In some of the embodiments, a pressure barrier is installed in the well lower than a length of the submersible pump assembly. The submersible pump assembly is lowered on a line into the chamber, then a lubricator at the surface seals around the line by allowing the pressure barrier to be released and the submersible pump assembly to be lowered into the well to a desired depth. Preferably, there is a lower pressure barrier in the well. The upper pressure barrier may be a packer that may be collapsed and retrieved alongside the submersible pump assembly. The pressure barrier also may be a packer that is temporarily set in the well, then engaged by the submersible pump assembly, with the pump assembly and packer then being lowered as a unit to a further depth in the well.

Live well deployment of electrical submersible pump

An improved electrical submersible pump is disclosed in which a processor downhole is utilized to monitor one or more subsurface conditions, to record data, and to alter at least one operating condition of the electrical submersible pump. Novel uses are described for downhole gas compression, the delivery of particulate matter to wellbore sites, and for the disposal of waste.

Electrical submersible pump and methods for enhanced utilization of electrical submersible pumps in the completion and production of wellbores

A gas compressor is employed downhole in a well for pressurizing formation gas. The gas compressor is driven by a downhole electrical motor. The downhole assembly also includes a pump. The pump might be located below the motor and driven by the same motor. In that event, the pump pumps liquid being produced by the formation downward to a liquid disposal formation. Also, the pump may pump the liquid to the surface, with the gas being delivered into a repressurizing zone.

The motor cooling and protection system has a shroud concentrically disposed about a motor housing of a downhole motor. The shroud is sealed from well fluids in the well and defines and annular chamber between the motor housing and the shroud. A longitudinal annular baffle is located in the chamber and partitions the chamber into two annular and concentric sub-chambers. The two sub-chambers have axially spaced apart communication openings such that the two sub-chambers are in fluid communication with each other. A cooling fluid having high conductive heat transfer rates is located in the chamber for circulating between the two sub-chambers, through the communication openings, to facilitate and enhance the transfer of heat between the motor and the well fluids.

Downhold motor cooling and protection system

A centrifugal submersible pump has wear resistant features to resist erosion due to sand laden fluid from a well. The pump has diffusers and impellers located within the housing. Each diffuser has a diffuser sleeve with a coaxial bore. The diffuser sleeve is of a material harder than the remaining portions of the sleeve. A hardened lower hub locates slidingly within each diffuser sleeve. The lower hub rotates with the shaft. Each impeller has an upper hub that locates above the lower hub and is also carried by the shaft for rotation with the shaft. The upper hub extends into the bore of the next upward diffuser sleeve. The lower hub is of a material harder than the upper hub and the vane section of the impeller.

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Claremore, OK, United States of America

John L Bearden