Schlumberger Technology Corporation

Intelliserv, Inc.

Inatelliserv, LLC

Schlumberger Canada Limited

Prad Research and Development Nv

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Brian Oliver Clark

Stephen D Bonner

Anthony Louis Collins

Dean M Homan

Richard A Rosthal

Mark T Frey

Dzevat Omeragic

Thomas D Barber

Jan Stefan Morley

David L Smith

Jacques A Jundt

Martin G Luling

Dhananjay Ramaswamy

Robert L Kleinberg

Bruce W Boyle

Weng C Chew

Reza Taherian

Raghu Madhavan

John F Hunka

Jacques J Orban

Geoffrey Charles Downton

Min-Yi Chen

Jan Smits

Jeffrey A Tarvin

Raphael Gadot

Scott S Chesser

Gerald N Minerbo

Qiming Li

Keith A Moriarty

Ruben Martinez

David Santoso

Jaideva C Goswami

Lise Hvatum

Aaron William Logan

Jonathan D Marshall

Bhavani Raghuraman

Scott Richard Woolston

Neil Cannon

Derek W Logan

John E Edwards

Daniel Hendricks

Cengiz Esmersoy

Christopher Paul Reed

Miguel F Pabon

Nobuyoshi Niina

Philippe F Salamitou

Joyce Wong

Desheng Zhang

Christophe Dupuis

Garry Holmen

Jason Braden

Gerald S Huchital

Dan Eugen Angelescu

Lili Zhong

Ashley Bernard Johnson

Benjamin Peter Jeffryes

Bruno Drochon

John C Rasmus

John R Lovell

Christopher Harrison

J Ernest Brown

Jean P Seydoux

Edward Nichols

Peter T Wu

Matthew T Sullivan

Kuo-Chiang Chen

Christian Chouzenoux

Jean-Marc Follini

Walter David Aldred

William F Puccio

Jean-Michel Hache

Remi Hutin

Ian D Bryant

Douglas D Griffin, Ii

Thomas H Zimmerman

Marc J Thiercelin

Anthony Robert Dopf

David Conn

Emmanuel Rioufol

Shyam B Mehta

William Brian Underhill

Robert J Utter

Hong Zhang

Yves Manin

Wayne J Phillips

Nikita Valentinovich Seleznev

Vassilis Varveropoulos

John Algeroy

Benny Poedjono

Steven Hough

Matthew Miller

Frank Morrison

Jan W Smits

Mark Flaum

Stanley R Thomas, Jr

Nicolas G Pacault

David L Best

Andreas Hausot

Tony Dopf

Tianxia Zhao

A system for determining a location and a diameter of a pipe deployed in a bore includes a plurality of circumferentially spaced acoustic transmitters and a plurality of circumferentially spaced acoustic receivers deployed in a wall of the bore. A processor is configured to identify and process received acoustic waveforms that are reflected by the pipe to compute the location and the diameter of the pipe. The system may include a drill string deployed in a drilling riser.

Acoustic detection of drill pipe connections

Methods for drilling a second well in a spatial relationship to a first well include positioning a magnetic field source in a first well or borehole and deploying at least two magnetometers in a second well or borehole. The magnetometers are separated by a known distance and each measure the magnetic field created by the magnetic field source that is located in the first borehole. The magnetic field measurements are used to calculate the locations of the two magnetometers with respect to the magnetic field source. The two locations define the axis of the second borehole with respect to the magnetic field source in the first borehole.

Multiple magnetic sensor ranging method and system

A system for determining a location of a drill pipe joint deployed in a bore includes at least one magnetometer deployed on the bore. A processor is in electronic communication with the magnetometer and is configured to process magnetic field measurements made by the magnetometer to determine at least one of an axial position and a lateral position of the drill pipe joint.

Magnetic detection of drill pipe connections

Devices and methods for well logging using a wear-resistant electrode are provided. A downhole device may include a drill collar and a first electrode mounted on the drill collar. Further, the first electrode may include a wear-resistant face. The first electrode may be movably coupled within the drill collar, and the first electrode may be configured to extend and retract into a wellbore to maintain contact with a wall of the wellbore. Furthermore, the first electrode may be configured to measure impedance of a geological formation.

Wear resistant electrodes for downhole imaging

A method of locating a conductive target from a wellbore includes generating a current flowing across an insulated gap in a downhole tool positioned in the wellbore, measuring an azimuthal magnetic field with at least one external magnetometer located proximate the exterior of the downhole tool, measuring a secondary magnetic field using a magnetometer disposed inside the downhole tool, computing at least one of a direction and a distance to the conductive target.

Method and apparatus for optimizing magnetic signals and detecting casing and resistivity

Devices and methods for well logging using a wear resistant electrode are provided. A downhole device may include a drill bit, a gauge pad mounted on the drill bit, and a first electrode mounted in the gauge pad. An insulating polycrystalline diamond (PCD) material may surround at least a portion of the first electrode. Additionally, the first electrode may include an electrically conductive wear resistant contact point that maintains constant contact with a wall of a wellbore. Additionally, the first electrode may measure an impedance of a geological formation during a drilling operation.

A system for drilling a subterranean wellbore includes a bottom hole assembly (BHA) coupled to a downhole end of a drill string. The BHA includes an electronic controller having a processor. The drill string includes downhole and uphole portions with the downhole portion made up of wired drill pipe and the uphole portion made up of non-wired drill pipe. The downhole portion further includes at least one downhole tool or sensor sub in communication with the BHA via the wired drill pipe communication link. Methods for making sensor measurements, downlinking data and/or commands to the BHA, and actuating a downhole tool make use of the system.

Downhole assembly employing wired drill pipe

A system and a method use dual telemetry for tools located in a wellbore. A first telemetry system and a second telemetry system coordinate communication with the tools. Both the first telemetry system and the second telemetry system may transmit data regarding the tools and/or drilling conditions from the tools to a surface location simultaneously. The first telemetry system or the second telemetry system may communicate with the surface location if communication using the other telemetry system is interrupted. The first telemetry system and the second telemetry system may have a master/slave relationship so that data requests from a specific telemetry system do not interfere with data requests from the other telemetry system.

System and method for using dual telemetry

A method (and system) is provided that enhances production of hydrocarbons from a subterranean formation by identifying at least one target interval of the subterranean formation that is in proximity to a pay interval, wherein the at least one target interval has an electrical resistance less than electrical resistance of the pay interval. A plurality of electrodes are placed in positions spaced apart from one another and adjacent the at least one target interval. Electrical current is injected into the target interval by supplying electrical signals to the plurality of electrodes. The electrical current injected into the at least one target interval passes through at least a portion of the at least one target interval in order to heat the at least one target interval and heat the pay interval by thermal conduction for enhancement of production of hydrocarbons from the pay interval.

Electrical heating of oil shale and heavy oil formations

A method and apparatus are provided for making directional measurements toward a formation of different resistivity that is proximate to the borehole, but which is not penetrated by the borehole. The methods and apparatus include the use of at least one insulated gap and at least one magnetometer positioned within a non-magnetic housing that is disposed within a non-magnetic tubular. An electric current is applied across the insulated gap, which results in current leaking into the surrounding formations. When a formation of contrasting resistivity is proximate to the logging apparatus, the magnetometer detects a secondary magnetic field due to the contrasting formation. The direction of the secondary magnetic field can be used to determine the direction to the contrasting formation. The magnitude of the secondary magnetic field can be used to determine the distance position to the contrasting formation.

Method and apparatus for directional well logging

A method for drilling a well includes applying a current across a drill collar that surrounds an internal magnetometer. The current travels across the drill collar and along one or more other current paths to return to the drill collar. The method also includes using the magnetometer to measure magnetic fields due to the current being applied across the drill collar and the current across one or more other current paths while the drill collar is disposed at a first angle of rotation and rotating the drill collar to a second angle of rotation. The method further includes measuring the magnetic fields using the internal magnetometer while the drill collar is disposed at the second angle of rotation and determining a relationship between the current across the drill collar and a portion of the magnetic fields due to the current across the drill collar measurable by the internal magnetometer.

Method for calibrating current and magnetic fields across a drill collar

Systems and methods for well-drilling operations involving magnetic ranging with a rotating magnetic dipole are provided. In one embodiment, a system for determining a relative location of a magnetic dipole includes a three-axis magnetometer configured to obtain measurements of a time-dependent magnetic field caused by the magnetic source rotating about an axis and data processing circuitry configured to determine a transverse angle of rotation of the measurements such that one of two transverse components is in phase with one axial component when the transverse angle of rotation is used to transform the measurements. The data processing circuitry may determine a spatial relationship between the magnetic source and the three-axis magnetometer based at least in part on the transverse angle of rotation.

Systems and methods for well positioning using a transverse rotating magnetic source

Apparatus and methods for locating faults in inductively coupled wired drill pipe while drilling. In one embodiment, apparatus includes a drill string and a wired drill pipe fault monitor. The drill string includes a plurality of wired drill pipes. Each wired drill pipe includes an inductive coupler at each terminal end. The wired drill pipe fault monitor is coupled to the wired drill pipes. The fault monitor includes an impedance measuring system and a fault locator. The impedance measuring system is configured to measure, while drilling the borehole, an input impedance of the wired drill pipes. The fault locator is configured to determine a propagation constant for the wired drill pipes, and to analyze the measured input impedance and determine, as a function of the measured input impedance and the propagation constant, a location of a fault in the wired drill pipes.

System and method for determining fault location

An inductive coupler apparatus have a first inductive coupler with a first magnetic center shaft having a recessed portion, a first outer magnetic layer disposed around the first magnetic center shaft, and a first coil disposed around the first magnetic center shaft and disposed within the first outer magnetic layer and a second inductive coupler with a second magnetic center shaft having a recessed portion, a second outer magnetic layer disposed around the second magnetic center shaft, and a second coil disposed around the second magnetic center shaft and disposed within the second outer magnetic layer. When the first and second inductive couplers are in the coupled position the inductive couplers can provide for the transmission of power and/or communication between downhole tools in a bottom hole assembly.

Inductive coupler

Various embodiments of methods and systems for wireless power and/or data communications transmissions to a sensor subassembly above a mud motor in a bottom hole assembly are disclosed. Power and/or data are supplied by rotary modulator and power generation system positioned above the mud motor. Wires may connect to an annular coil. Power and/or communications are transmitted through the annular coil to an inductively coupled second, mandrel coil that is attached to the rotor. By leveraging resonantly tuned circuits and impedance matching techniques for the coils, power and/or data can be transmitted efficiently from one coil to the other despite relative movement and misalignment of the two coils.

Casing drilling bottom hole assembly having wireless power and data connection

Growing community of inventors

Sugar Land, TX, United States of America

Brian Oliver Clark