Schlumberger Technology Corporation

Smith International, Inc.

Other

Westerngeco L.l.c.

M-i Drilling Fluids UK Limited

Westerngeco L.l.p.

Anadrill, Inc.

Schlumberger Technology Corporaton

Schlumberger Technology Coporation

Jacques J Orban

Shunfeng Zheng

Vishwanathan Parmeshwar

Nick Paul Krippner

Jonathan D Marshall

Scott Richard Woolston

Jordan Dane Englund

James C Mayes

Babak Bob Arefi

Brian Oliver Clark

Claude J Vercaemer

Brian Rogers

R Craig Boswell

Carlos White

David Milton Eslinger

Arthur Ignatius Watson

Gokturk Tunc

Daniel Manwill

Nathan Elijah Fuller

Benjamin Peter Jeffryes

Craig Boswell

Joe Rodney Berry

Neil W Richardson

Neil Cannon

Spyro J Kotsonis

Daniel Hendricks

Dominique Guillot

Klaus Joachim Zanker

Jim Shumway

Bartley Patton

Sami Iskander

Hao Lam

Lauro De Camargo

Jean-Christophe Priser

Eric Erickson

Evgeny Mikhailovich Sviridov

Mikhail Gotlib

Joseph Hope

Scott Steven Dahlgren

Jerome Miles

Ashley Bernard Johnson

Peter D Wraight

Erik B Nelson

Daniel Madsen

Michael H Du

William F Puccio

Joel Rondeau

Jean-Michel Hache

James Linklater

David L Malone

Richard John Harmer

Christopher Bogath

Guy James Rushton

Ray Cummins

Andre E Orban

Neilkunal Panchal

Didier Dominguez

Kurt Held

Irene Gabler

Jean-Paul Jour

Hervé Anxionnaz

Ramez Guindi

Alexey Yurievich Vdovin

Mikhail Iakimov

Simon Frederick Tong

Andre Salvaire

Scott Wolston

Roy Squire

Victor Garcia

Kevin Rees

Christopher Jones

Alexander S Trushin

Ray R Sherrill

Maxim Yurievich Vdovin

Maxim Y Radov

John E Davis

Mihail Vladilenovich Gotlib

Jo Acquaviva

Stanislav N Veritchev

Dursun Sedat Kilic

Pavel T Zubkov

A method for identifying a wellbore condition includes capturing a first image of cuttings on or downstream from a shale shaker using a first camera. A size, shape, texture, or combination thereof of the cuttings in the first image may be determined. A wellbore condition may be identified based on the size, shape, texture, or combination thereof of the cuttings in the first image.

Shale shaker imaging system

Embodiments disclosed provide a pump assembly including a first pump for delivering at least one fluid. The first pump may include a first inlet coupled to the first pump for delivering at least one first fluid to the first pump, a second inlet coupled to the first pump for delivering at least one second fluid to the first pump, a first discharge coupled to the first pump for delivering the at least one first fluid at a first pressure, and a second discharge coupled to the first pump for delivering the at least one second fluid at a second pressure. In some embodiments, the first discharge and the second discharge are isolated from each other.

Cement mixer and multiple purpose pumper (CMMP) for land rig

Apparatus and methods pertaining to moving a train rig between locations associated with corresponding different wellsites. Equipment carried by the train rig is operable in conjunction with forming wells each extending beneath a corresponding one of the wellsites. An adjustable swing arm mechanically and electrically connected to the train rig comprises a medium-voltage (MV) cable. The adjustable swing arm extends from the train rig to connect the MV cable to one of a plurality of MV electrical hubs each electrically connected to a remote MV electrical power source via, at least, MV electrical lines suspended above the wellsites. A piece of equipment carried by the train rig is energized by MV electrical power delivered via the adjustable swing arm, and then operated in conjunction with the subterranean well formation.

Adjustable cable management system

An electric submersible pump (ESP) with reduced vibration is provided. In an implementation, an ESP section has radial bearings placed at shaft locations of reduced vibration to reduce wear. The locations of reduced vibration are selected to avoid areas of high vibration and vibrational waves that reinforce each other due to structure resonance and natural excitation frequencies. In an implementation, a radial bearing is positioned at a node of reduced vibration of a standing vibrational wave. In an implementation, a succession of multiple radial bearings are spaced at different intervals from each other to avoid conventional even spacing of the bearings that causes standing waves, resonance waves, and vibrational waves at natural excitation frequencies. In an implementation, a span between adjacent radial bearings is selected to spare other adjacent bearings at different spans the effects of vibrations that may extend over a range of excitation frequencies in the ESP section.

Electric submersible pump with reduced vibration

A well construction system with motor equipment having at least one of a drawworks motor, a top drive motor, or a combination thereof, and an electrical power system having a power recovery and regeneration system. The power recovery and regeneration system includes at least one energy storage device that is not a capacitor bank. The well construction system may be operated by generating AC power that is made available on an AC node, converting AC power available on the AC node to DC power available on a DC node, storing energy based on DC power available on the DC node by the power recovery and regeneration system, and regenerating the stored energy from the power recovery and regeneration system to AC power, DC power, or a combination thereof for consumption by an electrical consumer of the well construction system.

Electrical power generation and distribution system with power recovery and regeneration

Systems and methods for drilling a wellbore. The method includes measuring a first distance that a drilling device is raised while connected to a drill string, determining a weight-on-bit in the drill string, determining a second distance to lower the drilling device such that a drill bit at a lower extremity of the drill string approaches toward a bottom of the wellbore, based on the first distance and the weight-on-bit, and lowering the drilling device by the second distance.

Drill bit distance to hole bottom measurement

Methods and apparatus for simultaneous operation of a variable-frequency drive (VFD) and a controller. The VFD drives an electric motor of a drilling rig machine. The controller controls temperature of an insulated-gate bipolar transistor device (IGBT) of the VFD by controlling an air mover in response to real-time temperature data. The air mover generates airflow into a passage, the airflow thereby interacting with radiating members extending into the passage from a heat sink thermally coupled with the IGBT in the inner housing outside the passage.

Air cooled variable-frequency drive

A tubular measuring system having a sensor at a predetermined position with respect to a datum and a processing device comprising a processor and a memory storing computer program code in signal communication with the sensor. The sensor generates a signal indicative of a feature of a tubular, and the processing device receives and processes the signal to determine position of the feature of the tubular with respect to the datum.

Tubular measurement

A system to control a drilling of a wellbore may include a drill string within the wellbore, wherein a wired communication system is along the drill string, at least one measurement sub configured to monitor at least one drilling parameter connected to the drill string and the at least one measurement sub being connected to the wired communication system; a drill bit at a distal end of the drill string; a drawwork mechanically coupled to the drill string and configured to lower the drill string attached thereto in the wellbore; a power controlling electronic connected to a motor of the drawwork, configured to control a drawwork unspooling speed; and a surface controller in communication with the power controlling electronic of the drawwork configured to: determine at least one drilling parameter along the drill string from measurements taken from the at least one measurement sub, the measurements being transmitted to the controller through the wired communication system; and control the drawwork to increase or reduce a weight-on-bit (WOB) of the drill bit based on the determined drilling parameters.

System and method for drilling weight-on-bit based on distributed inputs

A sensor assembly may include a housing made of a non-magnetic material. The housing may define an interior chamber. A shaft may extend from the housing. A bearing may be positioned around the shaft. An impeller may be positioned around the shaft and the bearing, and the impeller may include a magnetized portion. A sensor may be positioned within the interior chamber and/or proximate the magnetized portion. The sensor may detect the magnetized portion of the impeller to sense a rate of rotation of the impeller. The rate of rotation of the impeller may correspond to changes in flow rate of the fluid. As the flow rate of the fluid, and the rate of rotation of the impeller change in predetermined manners, control signals may be conveyed to activate a tool.

Sensor activated downhole cutting tool

An integrated drilling rig machine is disclosed. An integrated power and electronics unit (IPEU) includes all components necessary to transmit power from a generator to rig machines such as a mud pump, drawworks, top drive, etc. A housing contains a rectifier, a transformer, inverter(s), and starter motors. The inverters are coupled to rig machines and the starter motors are coupled to auxiliary devices such as cooling fans, lubrication pumps, communication systems, etc. A controller controls operation of the IPEU according to instructions received from a remote device.

Integrated drilling rig machine

An underreamer for increasing a diameter of a wellbore. The underreamer may include a body having an axial bore extending at least partially therethrough. An electromagnetic activation system may be disposed at least partially within the bore of the body. A valve may be disposed within the bore of the body and coupled to the electromagnetic activation system. The valve may include a mobile element and a static element. The mobile element may be coupled to the electromagnetic activation system and move from a first position where the mobile element obstructs fluid flow through the valve to a second position where the mobile element permits fluid flow through the valve. A cutter block may be movably coupled to the body and move radially-outward as the mobile element moves from the first position to the second position.

Underreamer for increasing a wellbore diameter

An apparatus for delivering tools within a drill string may include an instrument line including a mechanically resistant external structure with an internal cavity. The instrument line may be configured to be deployed into the drill string. The apparatus may include one or more isolated wires positioned within the internal cavity. The apparatus may also include one or more tools removably coupled to the instrument line and positionable within the drill string. The one or more tools may be configured to provide measurements of conditions within a wellbore via the one or more isolated wires.

Instrument line for insertion in a drill string of a drilling system

Growing community of inventors

Sugar Land, TX, United States of America

Jacques J Orban