Schlumberger Technology Corporation

Sensia LLC

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Albert Hoefel

Kent David Harms

Steven G Villareal

Julian J Pop

Reinhart Ciglenec

Michael J Stucker

Jeremy Murphy

Jean-Marc Follini

Steven Villareal

Dudi Rendusara

Gocha T Chochua

Ashers Partouche

Jaideva C Goswami

William Ewan Brennan, Iii

Yves-Marie Clet Robert Subervie

Peter Swinburne

Jonathan Wun Shiung Chong

Alexander F Zazovsky

Jacques R Tabanou

Nam H Nguyen

Emmanuel Coste

Ricardo Vasques

Stephen Parks

Andrew Meredith

David J Rossi

Sylvain Ramshaw

Shayan Darayan

Thomas W Palmer, Ii

Pengyu Yuan

Magnus Hedlund

Leo Steenson

Yves-Marie Subervie

T Everett Chambliss

Francois Bernard

Taylor Johnson

Peter Swinburner

Ray Nold, Iii

Bradley S Underwood

Rongzhen Jin

Shivam Agrawal

Jonathan Chong

William E Brennan Iii

Jeremy T Murphy

Bradley Underwood

A system, method, and computer-readable medium for determining the flow rate and fluid density in an electrical submersible pump (ESP) and controlling the ESP based on the flow rate and density. In one implementation, an ESP system includes an ESP, drive circuitry, a current sensor, a voltage sensor, and a processor. The ESP includes an electric motor. The drive circuitry is electrically coupled to the ESP and is configured to provide an electrical signal to power the ESP. The current sensor is configured to measure a current of the electrical signal. The voltage sensor is configured to measure a voltage of the electrical signal. The processor is configured to calculate speed of a shaft of the electric motor based on a frequency induced by rotation of the motor detected in the current. The processor is also configured to calculate a density of fluid in the ESP based on the speed.

Electrical submersible pump control

A system for oil and gas production includes a drilling, pipeline, or power quality device, a sensor, and a storage device. The storage device has instructions stored thereon that, when executed by one or more processors, cause the one or more processors to perform operations. The operations include receiving first data from the sensor. The operations include determining whether the device is experiencing an event condition based on the first data The operations include generating one or more potential corrective actions responsive to a determination that the device is experiencing the event condition. The operations include calculating a reward value for each of the one or more potential corrective actions. The operations include identifying a first corrective action of the one or more potential corrective actions with a largest or most positive reward value The operations include controlling the device according to the first corrective action.

Event driven control schemas for artificial lift

A method can include operating a pump system; determining a condition associated with the pump system; and controlling the pump system based at least in part on the condition.

Pump system with neural network to manage buckling of a rod string

An electric submersible pump system can include a multiphase electric motor operatively coupled to a fluid pump; a multiphase power cable operatively coupled to the multiphase electric motor; and a controller that includes an input that receives measurements as to power supplied to the multiphase electric motor via the multiphase power cable and that processes the measurements to determine information germane to the operation of the electric submersible pump system.

ESP pump flow rate estimation and control

A method can include receiving sensor information from at least one sensor disposed in a downhole environment that includes an electric submersible pump operatively coupled to a power drive via a cable; receiving electrical information associated with transmission of power via the cable; and identifying a state of the electric submersible pump via an adaptive model of at least the cable and the electric submersible pump based at least in part on a portion of the sensor information and a portion of the electrical information.

Submersible electrical system assessment

The present discloses valve systems that include valve shift detection systems that can be employed to determine when a valve has shifted. In certain embodiments, the valve shift detection systems include a switch integrated into a valve block that may be closed upon shifting of the spool valve. In certain embodiments, the switch may include a component that completes a circuit upon contacting the valve. The valve shift detection systems also may include a controller designed to detect a voltage or current change produced by completing the circuit.

Valve shift detection systems and methods

A system includes a valve subassembly configured to be disposed along an internal flowline exit of a first internal flowline within a downhole drilling module. The valve subassembly includes an active valve configured to regulate flow of a fluid through the internal flowline exit and a passive valve configured to be passively controlled based on a differential pressure between a first volume of the downhole drilling module and a second volume surrounding the downhole drilling module.

While drilling valve system

Systems, methods, and devices for fault detection and tolerance in a downhole tool string are provided. If a fault is detected in an electrical path between tools of downhole tool string, one or more switches of a fault detection and tolerance circuit may be kept open to isolate the fault in an electrical path between tools of downhole tool string. If a fault is not detected, one or more switches of a fault detection and tolerance circuit may be closed to enable the transmission of signals on the electrical path. In some embodiments of fault detection and tolerance circuits, an additional one or more switches may be kept open to isolate the fault in electronics of the tool.

Fault detection and tolerance in downhole tool string assemblies

A system includes a valve assembly configured to be disposed within a downhole tool module, a valve of the valve assembly configured to regulate flow of a fluid within the downhole tool module, a pump configured to supply a hydraulic fluid to actuate the valve, and an actuator configured to drive the pump.

Pump actuated valve

A drilling system includes a first section of a drilling tool having a collar configured to hold internal components of the first section. The drilling system also includes a second section of the drilling tool configured to be coupled with the first section in a specific orientation relative to the first section. The second section is interchangeable with at least one different section.

Drilling tool system and method of manufacture

A downhole modular tool includes a first module, a second module, a third module, and one or more connectors for connecting the first, second, and third modules. Each module includes a drill collar, a drilling fluid passageway, a first fluid passageway, and a second fluid passageway. The one or more connectors connect any one of the first, second, and third modules, to another of the first, second, and third modules to transfer the drilling fluid, the first fluid, and the second fluid between the connected modules.

Modular connector

Detecting a failure mode of a fluid flow controller configured to control fluid flow between first and second chambers of a downhole positive displacement pump and a flow line, wherein the positive displacement pump comprises a piston moving in an axial reciprocating motion, and subsequently adjusting operation of the downhole positive displacement pump based on the detected failure mode such that the downhole positive displacement pump piston operates differently in different axial directions.

Adaptive pump control for positive displacement pump failure modes

Growing community of inventors

Sugar Land, TX, United States of America

Albert Hoefel