Halliburton Energy Services, Inc.

David Christopher Beck

Donn Jason Brown

Robert Charles De Long

Ryan Bridwell Ashbaugh

Ketankumar Kantilal Sheth

Trevor Alan Kopecky

Walter Dinkins

Luke Golden Janger

Wesley John Nowitzki

David Linn Self

Christopher Watson

Robert C De Long

An electric submersible pump (ESP) assembly. The ESP assembly comprises a centrifugal pump, an electric motor mechanically coupled by a drive shaft to the centrifugal pump, wherein the electric motor comprises a stator and a rotor, a bearing, wherein the bearing is disposed inside the electric motor, and a magnetic shield disposed in the electric motor between bearing and the rotor and stator.

Shielding for a magnetic bearing in an electric submersible pump (ESP) assembly

A seal includes an outer housing and a seal bag internal to the outer housing. The outer housing can be positioned between a pump and an electric motor of an electric submersible pump. The seal bag can include an outer layer and an inner layer. The outer layer can be made from a first material to retain a structure of the outer layer in a swellable state in a wellbore. The inner layer can be made from a second material that is swellable in the wellbore in response to contact with a polar substance to seal a tear in the outer layer.

Seal bag for seal of an electric submersible pump

A system for protecting an Electrical Submersible Pump (ESP) string from gas slugs in a downhole well environment. The system comprises an intake tube having a first and second end and one of a packer having a bypass channel and an inverted shroud coupled to the intake tube and the ESP string. The intake tube is independent of a pump and a motor of the ESP string. The system can comprise a bypass tube for channeling the gas slug downstream of the pump. The bypass tube is integrated with the packer. The inverted shroud is coupled with the first end of the intake tube and a section of production tubing downstream from the pump and the motor. The inverted shroud forms a bypass path channel within a casing annulus.

ESP string protection apparatus

A pump system for pumping production fluids from a wellbore or pumping well treatment fluids into a wellbore comprising: an axial flux electric motor; a seal section coupled to the axial flux motor; a pump intake coupled to the seal section; a pump coupled to the pump intake, and a fluid discharge coupled to the pump. The torque capacity axial flux motor may be modified without removing the axial flux motor from the pump.

Axial flux submersible electric motor

An electric submersible pump includes a pump and an electric motor coupled to the pump. An electric submersible pump also includes a seal that is positioned between the pump and the electric motor. The seal has an outer housing and a seal bag internal to the outer housing. The seal bag has an outer layer and an inner layer. The outer layer is made from a first material to maintain the structure of the seal bag in a swellable state within the wellbore environment. The inner layer is made from a second material that can swell in response to contact with a polar substance and seal a tear in the outer layer of the seal bag.

A method comprises operating an electric submersible pump (ESP) motor downhole in a well. The ESP motor is electrically connected to a variable speed drive (VSD) proximate to the well. The operating comprises measuring a revolution rate and a motor current of the ESP motor for a first period of time and performing a first adjustment of a voltage output of the VSD. The method comprises measuring, after the first adjustment, the revolution rate and the motor current of the ESP motor for a second period of time determining a difference between the motor current measured for the first period of time and the motor current measured for the second period of time; and performing a second adjustment of the voltage output of the VSD based on a change in the revolution rate and the motor current between the first period of time and the second period of time.

Dynamic power optimization system and method for electric submersible motors

An electric submersible pump includes a pump, an electric motor that is coupled to the pump by a rotatable shaft, a seal section that is positioned between the pump and the electric motor. The seal section contains an additive and a motor oil for the electric motor. The additive includes one or more superabsorbent polymers or imidate salts to contact the motor oil and to react with a wellbore fluid from a wellbore to prevent premature failure of the electric submersible pump from the wellbore fluid contamination of the motor oil.

Chemical sequestration of wellbore fluids in electric submersible pump systems

A system comprises an electric submersible pump (ESP) motor electrically coupled to a variable speed drive (VSD) that outputs voltage to the ESP motor. The system comprises a magnet on a shaft of the ESP motor and a downhole sensor coupled to the magnet, wherein the downhole sensor is to measure a magnetic flux of the magnet. The system comprises a VSD controller to control the VSD, wherein the VSD controller comprises a processor and a non-transitory memory storage having instructions stored thereon that are executable by the processor to perform operations comprising: obtaining a measurement of at least one pump performance variable and a motor current for a first period of time to establish a first data set and making a first adjustment to a voltage output from the VSD to the ESP motor, the first adjustment having a first adjustment type.

A downhole tool and method therefor use a deviated flow path to prevent/mitigate fallback of solids during shutdown of an ESP. The deviated flow path leverages the direction of fallback downhole and the relative inertias of the solid particulates and the fluid to minimize fallback into the ESP. The particulates change flow direction more slowly than fluid, and thus largely avoid the deviated flow path to instead fall through a bypass path during fallback. This obviates the need for mechanical valves that may be subject to excessive mechanical wear or other issues associated with solid particulates.

Modified sand fallback prevention tool

An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor, a centrifugal pump, and a hybrid magnetic thrust bearing, wherein the hybrid magnetic thrust bearing is disposed inside the electric motor or disposed inside the centrifugal pump.

Hybrid magnetic thrust bearing in an electric submersible pump (ESP) assembly

A motor of an electric submersible pump (ESP) is positioned in a wellbore. Measured data is received from one or more sensors. A first deep learning model running on a motor controller of the ESP determines first operating parameters or first operating conditions for the ESP based on the measured data. The motor controller sends the first operating parameters or first operating conditions to a centralized computer system. A second deep learning model running on the centralized computer system determines second operating parameters or second operating conditions associated with the ESP based on the first operating parameters or first operating conditions. The centralized computer system sends the second operating parameters or second operating conditions to the motor controller. The motor controller adjusts operation of the motor of the ESP based on the second operating parameters or second operating conditions.

Distributed machine learning control of electric submersible pumps

Permanent magnet motors (PMMs) can develop oscillations during motor startup that can cause damage to electric submersible pump (ESP) components. A system and method are presented for identifying mechanical and/or electrical caused oscillations in a PMM through the analysis of oscillations in current and torque measurements. A control system within a surface motor controller receives current and/or torque measurements from downhole sensors. The control system employs one or more algorithms designed to detect oscillations in the measurements. Upon detecting oscillations that are consistent with oscillations in the motor from mechanical or electrical causes, the control system automatically initiates protective action to prevent damage to the ESP components.

Measurement guided oscillation detection for motor protection

An electric submersible pump (ESP) assembly. The ESP assembly comprises an electric motor, a centrifugal pump, and a hybrid magnetic radial bearing, wherein the hybrid magnetic radial bearing is disposed inside the electric motor or disposed inside the centrifugal pump.

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Broken Arrow, OK, United States of America

David Christopher Beck