Halliburton Energy Services, Inc.

Robert Charles De Long

Ketankumar Kantilal Sheth

Donn Jason Brown

David Christopher Beck

Hassan Mansir

Dezhi Zheng

Jeffrey G Frey

Trevor Alan Kopecky

Christopher Watson

Christopher Michael Jones

Bin Dai

Wei Zhang

Etienne M Samson

Nagaraja K Pai

Walter Dinkins

Ryan Bridwell Ashbaugh

Andras Bencze

Lucas Samuel Batista Santos

Donn J Brown

A system comprising a power cable to be positioned downhole in a wellbore formed in a subsurface formation, wherein the power cable generates a magnetic field. The system comprises a first energy harvesting device coupled with the power cable and configured to harvest power from the magnetic field, wherein the power is to be supplied to one or more downhole devices.

Energy harvesting device for downhole application

Some implementations include an apparatus configured to, in a wellbore, eliminate voltage on one or more first conductors that are electrically connected to a surface-based power source. The apparatus may include a shorting ring electrically connectable to the first conductors and configured to electrically short the first conductors upon establishing an electrical connection with the first conductors. The apparatus may include a solenoid assembly to actuate in response to power on the first conductors from the surface-based power source. The apparatus may include a pin slider assembly connected to the first conductors and configured to move, in response to actuation by the solenoid assembly, between an electrical connection with the shorting ring and an electrical connection with one or more second conductors that have an electrical connection with a permanent magnet motor winding in the wellbore.

Current-controlled circuit breaker for electrical submersible pump motor leads

A fluid flow rate sensor. The fluid flow rate sensor comprises an elongated structure; a heating element installed into a first end of the elongated structure; a first temperature transducer coupled to an outside of the elongated structure at a first predefined location; a second temperature transducer coupled to the outside of the elongated structure at a second predefined location; and a control unit that is configured to turn the heating element on and off, to analyze a first temperature indication received from the first temperature transducer, to analyze a second temperature indication received from the second temperature transducer, to determine a flow rate of a fluid that is in intimate contact with the outside of the elongated structure based on analyzing the first temperature indication and the second temperature indication, and to output the flow rate via a communication line.

System and method of determining reservoir fluid flow condition and composition downhole

Disclosed embodiments relate to a pulsed-power drilling system, in which a pulsed-power drill is conveyed downhole and operated via coiled tubing. The coiled tubing may be configured to simultaneously transmit power and drilling fluid downhole. For example, the coiled tubing may include a flexible hollow fluid tube configured to transport drilling fluid therein, and a flexible cable tube disposed within the fluid tube. The cable tube may have one or more cable disposed within protective tubing, protecting the cables from drilling fluid in the fluid tube. Methods of making and using such coiled tubing with pulsed-power drills are also disclosed.

Pulsed-power drilling system with integrated power and communication coiled tubing conveyance

A downhole electric submersible pump (ESP) assembly. The downhole ESP assembly comprises a permanent magnet motor (PMM) comprising a first drive shaft, a stator, and a rotor disposed within the stator and comprising a core coupled to the first drive shaft, wherein the core retains a first permanent magnet element within a first magnet pocket defined by the core that extends axially parallel to the first drive shaft and retains a second permanent magnet element within a second magnet pocket defined by the core that extends axially parallel to the first drive shaft; a seal section having a second drive shaft coupled to the first drive shaft; and a pump assembly having a third drive shaft coupled to the second drive shaft.

Permanent magnet motor

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 downhole electric submersible pump (ESP) assembly. The downhole ESP assembly comprises a hybrid permanent magnet motor (PMM) comprising a first drive shaft, a stator, and a rotor comprising a first permanent magnet element, a second permanent magnet element, and an induction squirrel cage, wherein the rotor is mechanically coupled to the first drive shaft and disposed within the stator; a seal section having a second drive shaft coupled to the first drive shaft; and a pump assembly having a third drive shaft coupled to the second drive shaft.

Hybrid permanent magnet motor

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

In artificial lift production systems, a reduction in pressure and temperature as production fluids migrate to the surface can cause a buildup in the production tubing that reduces or stops production. To remove buildup, an ESP can be operated at low efficiency and low flow operating conditions to generate heat in the pump. The heat increases the temperature of the production fluid in the pump. When the heated production fluid is transported to the surface, the fluid increases the temperature of the production tubing resulting in a melting of the solidified wax blocking the production tubing. As the wax melts, the production fluid carries it toward the surface. Over time, the heated production fluid will melt enough solidified wax to open the production tubing to a full flow capacity, thus allowing standard production operation to continue.

Wax removal in a production line

Methods to improve fluid flow of a multi-phase mixture, methods to separate fluids of a multi-phase mixture, and downhole multi-phase fluid mixture systems are disclosed. A method to improve fluid flow of a multi-phase mixture includes positioning a first acoustic device and a second acoustic device around a conveyance that provides a fluid flow path for a first fluid in a first phase and a second fluid in a second phase to simultaneously flow through the conveyance. The method also includes determining a flow rate and a fluid condition of the fluid mixture. The method further includes generating a standing acoustic wave through the conveyance based on the flow rate and the fluid condition to break down the first fluid into droplets having volume within a threshold volume.

Methods to improve fluid flow of a multi-phase mixture, methods to separate fluids of a multiphase mixture, and multi-phase fluid mixture systems

An electric submersible pump (ESP) electric motor. The ESP electric motor comprises a housing; a stator retained within the housing; a drive shaft; and an at least one rotor mechanically coupled to the drive shaft and located concentric with and inside of the stator, wherein an inside surface of the stator defines a groove extending from an upper end to a lower end of the stator, an outside surface of the at least one rotor defines a groove extending from an upper end to a lower end of the at least one rotor, an inside surface of the at least one rotor defines a groove extending from an upper end to a lower end of the at least one rotor, or an outside surface of the drive shaft defines a groove extending from below an male splines at an upper end to a lower end of the drive shaft.

Oil circulation in an electric submersible pump (ESP) electric motor

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

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.

Growing community of inventors

Sand Springs, OK, United States of America

Robert Charles De Long