Baker Hughes Corporation

Robert H McCoy

Gordon Lee Besser

Dick Lee Knox

Jerald Ray Rider

Dustin B Campbell

Robert Dan Allen

Larry James Parmeter

Steven Keith Tetzlaff

Alan Craig Reynolds

Suresha Roshani O'Bryan

Kevin R Bierig

James Edward Layton

Joo Tim Ong

James C Jackson

Lance Travis Robinson

Joseph Scott Thompson

Francis D Doherty

Bryan D Schulze

William J Carter

Brian Haapanen

Ken Bebak

Richard Bristow

Douglas Detherow

Systems and methods for employing gauge packages for use with a wet-connect ESPs. In one embodiment, a modular gauge package includes a body, a gauge electronics assembly housed within the body, and a pair of electrical connectors at the upper and lower ends of the body, where power is passed through the body from one connector to the other. The electrical connector at the top of the body engages a complementary electrical connector on the bottom of a pump motor. The electrical connector at the bottom of the body engages a complementary electrical connector at the end of a production conduit. The connector at the bottom of the body may be identically configured with the connector at the bottom of the pump motor, and the connector at the top of the body may be identically configured with the connector at the end of the production conduit.

Modular down hole gauge for use in retrievable electric submersible pump systems with wet connect

A system for determining whether a motor in an electrical submersible pump is backspinning is described herein. The system comprises a sensor mounted in a well bore proximate to a ground surface, the sensor outputting a backspin signal; a communication link connected to the sensor, the communications link communicating the backspin signal; and a controller receiving the backspin signal from the communications link and processing the backspin signal to determine whether the motor is backspinning. Computer readable instructions associated with the system perform the steps of: monitoring the signal to determine whether the signal is above a threshold, the threshold for determining whether the signal is a noise signal or a backspin signal, and outputting the backspin signal; impeding operable AC power to the motor, responsive to the backspin signal; monitoring the backspin signal to determine whether the backspin signal is below the threshold; and returning AC power to the motor responsive to the determination that the backspin signal is below the threshold.

Device, computer program product and computer-implemented method for backspin detection in an electrical submersible pump assembly

A system for detecting a backspin condition of a motor in an electrical submersible pump is disclosed herein. The system comprises a sensor mounted proximate to the motor, the sensor outputting a signal, a power cable connected between a motor and a controller, the power cable supplying a three phase AC voltage to the motor, one phase of the three phase signal having a control signal thereon; electronics connected to the sensor, the electronics receiving the signal and propagating the signal to the controller; and a computer defining the controller, the controller having a non-transitory memory, a computer processor, and a computer program product stored on the memory and executable by the processor, the computer program product performing a process of controlling the variable speed drive of the motor and a process of monitoring the signal from the sensor to determine if the motor is backspinning.

A venturi structure is supported below an ESP preferably off its gauge assembly below its motor so that the surrounding casing or wellbore defines the venturi path leading to the suction connection of the ESP. Multiple pressure sensing locations are provided in case the gauge that defines the venturi path is disposed off center in the bore or if the bore is on an incline. The gauge can receive forms of different sizes depending on the size of the surrounding tubular where the forms use an incline of preferably 15-20 degrees and allow for measuring differential near the perforations and at the constriction location so that the flow can be computed using the Bernoulli Equation.

Coaxial electric submersible pump flow meter

An electrical submersible pump assembly has a pump discharge head with an integrally formed pump discharge pressure port. The discharge head is mounted directly to the pump and couples the pump to production tubing. A static pressure port extends directly through the side wall of the discharge head. The pressure port includes a tubing connector for hydraulic tubing to run down to the gauge. Inside the discharge head, a flow limiter is located in the pressure port to stop the loss of fluid if there is a break in the tubing connector or hydraulic line. Alternatively, the discharge head may incorporate a venturi or other pressure drop structure to allow the fluid flow to be measured via a pressure drop across an orifice. The venturi may be configured as an insert to permit it to be replaced after it has become worn by abrasive flow.

System, method and apparatus for electrical submersible pump assembly with pump discharge head having an integrally formed discharge pressure port

A transmitter generates an acoustic ping in a fluid in a borehole, and a receiver monitors waves resulting from the acoustic ping. Responsive to the monitored waves, an attribute of the fluid is estimated, including a sonic velocity, a mixture of gas and oil, a mixture of water and oil, an amount of sand, an amount of gas, an amount of skin effect, or a depth of fluid. An operation of the artificial lift device is then controlled responsive to the estimated attribute. Alternately, a sonic velocity is estimated for the fluid through an analysis of a sample pumped to the surface or through an analysis of monitored waves. A depth of the fluid is calculated responsive to the estimated sonic velocity for the fluid in the borehole and the monitored T-waves. The operation of the artificial lift device is then controlled responsive to the calculated depth of fluid.

Using an acoustic ping and sonic velocity to control an artificial lift device

A downhole submersible pump system, method, and apparatus utilizes fiber optic sensors and distributed temperature sensors below the submersible pump to monitor pump discharge pressure and temperature, intake pressure and temperature, and motor temperature. In addition, distributed temperature sensors are used below the pump to monitor the perforations within the well bore.

System, method, and apparatus for downhole submersible pump having fiber optic communications

Embodiments of the present invention beneficially provide circuits and methods which isolate downhole electronics of a well pump assembly from a power surge. The pump assembly includes a motor and a housing, including head, base, and manifold plate. The head has a hollow interior and a shoulder. The head is mounted to the motor so that, in operation, oil from the motor fills the interior of the head. The base has an outside diameter to fit snugly inside the head. The manifold plate is located between an upper end of the base and the shoulder of the head so that the axis of the manifold plate is perpendicular to the axis of housing. A gauge circuit and an isolation circuit are mounted to the manifold plate. The isolation circuit includes active semiconductor elements to detect excessive voltage and to protect the gauge circuit from the excessive voltage.

Apparatus and method for active circuit protection of downhole electrical submersible pump monitoring gauges

A remote instrument control and reporting system utilizes a host communication gateway based on hardware and software that interfaces with a field device, remote terminal unit, or control system that operates across multiple communications infrastructures to a common back end data delivery system. This design allows Modbus hosts or similar SCADA polled technologies, such as a field bus that utilizes various industrial protocols to control instruments at and acquire instrumentation data from physically isolated installations. In particular, this design is well suited for applications such as oil well electrical submersible pumps. The data is communicated through, for example, a low Earth orbit satellite into a host communications gateway that simulates within a host computer environment the same polling registers that the data was collected from in the remote locations.

System, method, and apparatus for command and control of remote instrumentation

A method of installing a submersible electrical pump assembly in a well monitors the integrity of the pump assembly and electrical cable while the pump assembly is being run. The pump assembly has at least one sensor that measures a parameter in the environment of the pump assembly. A battery-powered test unit is mounted to the reel of cable, and a lead of the unit is connected to the power cable. While lowering the completion equipment, test voltage is supplied from the unit via the power cable through the motor to the sensor. The unit transmits an indication to a remote monitor that the sensor is operational.

Method for installing well completion equipment while monitoring electrical integrity

Seismic data is collected by using an electrical submersible pump assembly in a well that is producing well fluid. By sweeping the rotational speed of the pump assembly through a selected range at selected intervals, seismic waves of varying frequency are emitted. These seismic waves are then picked up with a seismic sensor located at the surface or located in another well. If the seismic sensors are located in another well, the signal from the sensor may be transmitted to the surface by superimposing the data onto the power cable leading to the pump located in that other well. The seismic survey may be repeated at regular intervals, and the results will reveal the changes that have taken place over time in the reservoir.

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Talala, OK, United States of America

Robert H McCoy