Ge Oil & Gas Esp, Inc.

Corken, Inc.

Baker Hughes Oilfield Operations LLC

General Electric Company

Baker Hughes, a Ge Compnay, LLC

Corken International Corporation

Baker Hughes Esp, Inc.

Michael Franklin Hughes

Mahendra L Joshi

David Allan Torrey

Jeremy Daniel Van Dam

John Jay Mack

Weijun Yin

Paul J Lutes

Vittorio Michelassi

Zhipeng Zhang

Scott Mordin Hoyte

Brian Paul Reeves

Patel Bhageerath Reddy

James Delwin Gray

Alan P Tiefenbrun

Scott Alan Harban

Sameer Vittal

Ronald A Schuller

Joseph John Zierer

Ahmed AlAdawy

Robert Klenner

Ameen Malkawi

Alexey Tyshko

Alireza Shahkarami

Robert Krumm

Willie Wystemp

James Hyatt

Victor Acacio

Don Crowder

Michael W Spidell

Mark Andrew Sporer

James J Davis

Renee He

Erik Stephen Robbins

Stephen Seymour

Aboel Hassan Muhammed

Hannah Kelly

Mohammad Chowdhury

Connor Hayes

Rene Du Cauze De Nazelle

A virtual sensor system includes one or more electric submersible pumping systems deployed in a reservoir and a computer system that receives data from the one or more electric submersible pumping systems. Field data is provided to computerized statistical models for predicting whether individual electric submersible pumping systems and the reservoir have undergone changes in condition. The statistical models are established with reference data obtained by running electric submersible pumping systems of known working condition in test wells under a variety of controlled conditions.

System and method for reservoir management using electric submersible pumps as a virtual sensor

A system and method of generating electricity. A work string extends into a wellbore. A heat pump unit at a surface location circulates a working fluid through the work string to absorb heat from a formation surrounding the wellbore. A turbine generates a rotation from the working fluid that has absorbed the heat. A generator generates electricity from the rotation of the turbine. The electricity is transmitted to the surface location via an electrical cable.

Downhole geothermal power generation and storage

A submersible pumping system for use in producing wellbore fluids from a wellbore within a subterranean formation includes a motor and a pump driven by the motor to produce the wellbore fluids. The pumping system further includes a self-supporting power cable connected to the pump. The self-supporting power cable includes a plurality of conductors and a plurality of strength members. A method of deploying and retrieving a submersible pumping system in a wellbore includes the steps of connecting a wireline to the submersible pumping system, connecting a self-supporting power cable to the submersible pumping system, lowering the submersible pumping system into the wellbore while the weight of the submersible pumping system is borne by the wireline. The method continues with the step of locating the submersible pumping system on a landing assembly, disconnecting the wireline from the submersible pumping system, and retrieving the wireline from the wellbore without removing the submersible pumping system from the wellbore.

Wireline-deployed ESP with self-supporting cable

A fluid processor for use in a downhole pumping operation includes a fluid processing stag, a nozzle stage and a gas compressor stage. The nozzle chamber is configured as a convergent-divergent nozzle and the variable metering member is configured for axial displacement within the convergent section to adjust the open cross-sectional area of the nozzle. A method for producing fluid hydrocarbons from a subterranean wellbore with a pumping system includes the steps of measuring a first gas-to-liquid ratio of the fluid hydrocarbons and operating a motor within the pumping system to operate at a first rotational speed. The method continues with the steps of measuring a second gas-to-liquid ration of the fluid hydrocarbons with the sensor module, where the second gas-to-liquid ratio is greater than the first gas-to-liquid ratio, and operating the motor at a second rotational speed that is faster than the first rotational speed.

Downhole wet gas compressor processor

A magnetic thrust bearing is designed for use in a pumping system that includes a pump driven by a motor through a shaft. The magnetic thrust bearing includes one or more platters that remain stationary with respect to the shaft and one or more thrust discs connected to the shaft and interleaved with the one or more platters. Each of the one or more platters includes a plurality of platter magnets and each of the one or more thrust discs includes a plurality of thrust disc magnets. The magnets on the platters and thrust discs are configured to produce repulsive magnetic forces as the thrust discs approach the platters.

Permanent magnet thrust bearing

A flow control system is provided for a horizontal well production system having a casing, a tube having an intake opening and disposed within the casing, and a gap formed between the casing and the tube. The flow control system includes a valve having an orifice, coupled to the tube and disposed proximate to the intake opening. The flow control system further includes an actuator coupled to the valve and configured to open the valve in response to a presence of a liquid in the gap, proximate to the intake opening, to permit flow of the liquid into the tube via the intake opening, and to close the valve in response to a presence of a gas in the gap, proximate to the intake opening, to prevent flow of the gas into the tube via the intake opening.

System and method for controlling flow in a well production system

A self-propelled, remotely-controlled equipment deployment vehicle is configured to deliver equipment to a desired location within the horizontal portion of a deviated wellbore. The deployment vehicle includes a cargo frame, an electric motor and an active mobility assembly. The active mobility assembly is connected to the cargo frame and powered by the electric motor. The cargo frame can be configured to transport, offload and accurately position the selected cargo. Alternatively, the equipment deployment vehicle can be configured with a passive mobility assembly that allows the equipment deployment vehicle to be pushed or pulled along the horizontal section of the wellbore without power.

Remote controlled self propelled deployment system for horizontal wells

A distributed artificial lift system is configured for use in a wellbore that includes a vertical section and at least one lateral section connected to the vertical section. The distributed artificial lift system includes a first remote assembly positioned within the first lateral section. The first remote assembly includes an equipment deployment vehicle and cargo selected from the group consisting of electric remote pumping units, tubing, tubing connectors, tubing adaptors, sensor packages, gas separators, perforating tools, injection pumps and other downhole components. The first remote assembly is optionally self-propelled and remotely-controlled.

Distributed lift systems for oil and gas extraction

An electric submersible pumping system has an electric motor, a pump assembly driven by the electric motor and a sensor module. The sensor module preferably includes a detachable sensor array that can be selectively released from the sensor module. In preferred embodiments, the detachable sensor array includes a self-propelled sensor array vehicle that has a drive motor, a drive mechanism driven by the drive motor and a sensor array. The detachable sensor array provides a wellbore condition signal that can be used to automatically adjust the performance of the electric submersible pumping system.

Forward deployed sensing array for an electric submersible pump

Bypass valve assembly that selectively establishes a bypass path for a fluid delivery system and having a body member with a fluid inlet and a bypass fluid outlet, a slidable piston assembly and a slidable cage assembly. Spring members bias the piston assembly and the cage assembly to a closed position to prevent fluid flow from the fluid inlet to the bypass fluid outlet when the delivery pressure is between an upper first threshold pressure value and a lower second threshold pressure value. When the delivery system pressure exceeds the first threshold pressure value, the piston assembly is moved to a first open position that permits fluid flow to the bypass fluid outlet; and when the delivery system pressure is less than the second threshold pressure value, the piston assembly is moved to a second open position to permit fluid flow to the bypass fluid outlet.

Liquid/vapor bypass valve

A delivery system for transferring a delivery fluid from a delivery tank to a customer tank while maintaining a predetermined vessel pressure in the delivery tank, including a pump assembly pumping fluid from the delivery tank and a piping system passing the pumped fluid to the customer tank. A diverter diverts a slip stream portion of the pumped delivery fluid and a heat exchanger assembly selectively heats or cools the slip stream portion for return to the delivery tank. A sensor monitors a selected condition in the delivery tank and a controller responds to the sensor to control the amount and thermal condition of the slip stream returned to the delivery tank.

Delivery system for liquefied gas with maintained delivery tank pressure

A bearing arrangement for a pump is adapted for controlling thrust loads and limiting undesirable axial movement of components. The pump has a shaft having first and second shaft ends, and the pump may be configured so that the shaft is drivable from one or both of the shaft ends. The first and second shaft ends are respectively supported in a first and second bearing arrangement. Each bearing arrangement includes a radial main bearing having an inner race disposed around the shaft end. The inner race contacts a mounting ring to transfer outwardly axial thrust forces against a thrust bearing assembly. Each bearing arrangement is retained by a bearing cap contacting against an outer side of the thrust bearing assembly. A shim having a selected thickness can be placed between the bearing cap and the housing in order to position the internal pump components in an axially centered position to maintain proper clearances in order to minimize wear.

Pump with improved bearing arrangement for axial position control

A sliding vane pump having an inside liner with a constant radius pump arc and a constant radius stop arc, connected together by cycloidal arcs. The liner has inlet slots arranged extending around a perimeter of a liner extending into the pump arc for maximum filling of the pumping volume. A herringbone-shaped slot arrangement is provided on a outlet side which increases vane life, increases sealing around the vanes on the outlet side, and decreases liner wear. A relief/fill porting arrangement is provided to pressurize the fluid in the pump chamber, or alternately to relieve pressure from the pump chamber. An improved thrust absorber is described particularly useful for truck mounting of the pump. An asymmetrical inside profile for the liner assists in pump operation by providing a fluid mathematical profile which approaches zero acceleration forces at the point of tangency.

Vane pump

A sliding vane pump having a hydraulic vane actuation system. The pump includes a case with a liner having an eccentric surface therein. A rotor and shaft rotate within the liner. The rotor has a plurality of radial slots therein, with a vane slidably disposed in each of the slots. Each vane has a radially inner edge with first and second sides extending substantially normally therefrom. A radially outer edge extends normally from the first side and is opposite and substantially parallel to the radially inner edge. A beveled edge extends radially inwardly from the outer edge and interconnects the outer edge with the second side. As the rotor rotates, the beveled edge is the leading edge of the vane. A plurality of radially oriented holes are defined through each vane. The holes intersect the inner edge and a portion of the beveled edge and a portion of the outer edge. Fluid travels radially inwardly and outwardly through the holes in the vanes as the rotor rotates, providing hydraulic actuation of the vanes outwardly, as well as providing fluid relief therefor.

Sliding vane pump

Growing community of inventors

Oklahoma City, OK, United States of America

Michael Franklin Hughes