Schlumberger Technology Corporation

Intelliserv, Inc.

Shinshu University

Nissin Kogyo Co., Ltd.

Dowell, a Division of Schlumberger Technology Corporation

Nissan Kogyo Co., Ltd.

Prad Research and Development Nv

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Raghu Madhavan

David Santoso

Bruce W Boyle

Brian Oliver Clark

Remi Hutin

Lise Hvatum

Rogerio Tadeu Ramos

Robert J Schroeder

Tsutomu Yamate

Qiming Li

Jacques A Jundt

Jean-Michel Hache

Dinesh R Patel

Toru Noguchi

Jean-Marc Follini

Vladimir Vaynshteyn

Christopher Paul Reed

Hiroyuki Ueki

Satoshi Iinou

James D Hendrickson

Shigeki Inukai

Jim B Benton

Masaei Ito

Mitchell G Willcox

Michael Stangeland

Mark Sherman

Manuel P Marya

Geoffrey Charles Downton

Morinobu Endo

L Michael McKee

Walter David Aldred

Go Fujisawa

Hiroshi Nakajima

Jagdish H Shah

Indranil Roy

Shyam B Mehta

John Allen Thomas

Eric Udd

Sophie Nazik Godefroy

Nicolas G Pacault

Dudi Rendusara

Randall LeBlanc

Frederic Latrille

Kanu Chadha

Stacy L Johnson

Philip Dryden

Stephen C Balkunas

Joseph Montero

Mami Nishida

Yu Hatori

Andrew J Tucker

Harjit S Kohli

Randall P Leblanc

Fracture-resistant and self-lubricating wear surfaces are provided. In an implementation, a machine surface that is subject to wear is coated with or is constructed of a metallic nanostructure to resist the wear and to provide fracture-resistant hardness, built-in lubrication, and thermal conductivity for heat-sinking friction. The metallic nanostructured surface may be used, for example, on a face seal, bushing, bearing, thrust member, or hydraulic flow passage of an electric submersible pump. In an implementation, the metallic nanostructured surface is a nanocrystalline alloy including nanograin twins of a body-centered cubic (BCC), face-centered cubic (FCC), or hexagonal closest packed (HCP) metal. The nanostructured alloy may include atoms of copper, silver, gold, iron, nickel, palladium, platinum, rhodium, beryllium, magnesium, titanium, zirconium, or cobalt, and may provide more hardness and lubricity than diamond-like carbon coatings or carbides.

Fracture-resistant self-lubricating wear surfaces

A system for use in a drilling operation that includes uphole electronic equipment and a drill string suspended in an earth borehole, a section of wired drill pipe that is part of a communication link between a downhole tool and the uphole electronic equipment, an interface for communicating between the section of wired drill pipe and a communication source/destination. The system includes a housing having a generally cylindrical outer shape which has a passage there through. The housing has a WDP end connectable to the section of wired drill pipe and a further end connectable to the communication source/destination. The system also includes a WDP circuit module disposed within the housing. The WDP circuit module electrically coupleable with the wired drill pipe section. The system includes a further circuit module, disposed within the housing, which is electrically coupled with the WDP circuit module and electrically coupleable with the communication source/destination.

Interface and method for wellbore telemetry system

A drilling system comprises a drillstring including a dill bit, a bottomhole assembly coupled to the drill bit, and a plurality of interconnected tubular members coupled to the bottomhole assembly. A first tubular member includes a communication link having a first annular inductive coupler element disposed in an annular recess in a first end, a second annular inductive coupler element disposed in an annular recess in a second end, and a cable coupling the first annular inductive coupler element to the second annular inductive coupler element. In addition, the drilling system comprises a first signal level determination unit disposed in the drillstring and configured to determine a level of a first signal communicated from the second inductive coupler element. Further, the drilling system comprises an axial load determination unit configured to determine an axial load at the first signal level determination unit based on the level of the first signal.

Systems and methods for detecting drillstring loads

A method for making a conduit for transmitting signals along its length includes forming one or more grooves in at least one of the inner and outer walls of a tubular body that extend substantially to a communicative coupler, and securing one or more conductive wires within the one or more grooves. A conduit for transmitting signals along its length in a borehole environment includes one or more conductive wires extending through and being secured within one or more grooves of a tubular body, the one or more conductive wires in signal communication with a communicative coupler so as to establish one or more wired links. The conduit may include a means for securing the one or more conductive wires within the one or more grooves.

Method and conduit for transmitting signals

A hybrid telemetry system for passing signals between a surface control unit and a downhole tool is provided. The downhole tool is deployed via a drill string into a wellbore penetrating a subterranean formation. The hybrid telemetry system includes an uphole connector, a downhole connector, and a cable operatively connecting the uphole and downhole connectors. The uphole connector is operatively connectable to a drill string telemetry system for communication therewith. The downhole connector is operatively connectable to the downhole tool for communication therewith.

Wellbore telemetry system and method

A rotary coupler for transferring electrical power and data between members is presented wherein the coupler has a first member having an internal surface, a first inductor positioned on the internal surface, a second member and a second inductor carried on a portion of the second member and positioned internal of the first inductor, wherein one of the inductors rotates relative to the other inductor.

Electrical transmission between rotating and non-rotating members

A seal member includes a hydrogenated acrylonitrile-butadiene rubber (HNBR) and carbon nanofibers. The seal member has a number of cycles to fracture of 7000 or more when subjected to a tensile fatigue test at a temperature of 70&#xb0; C., a maximum tensile stress of 4 N/mm, and a frequency of 1 Hz. The seal member exhibits excellent abrasion resistance.

Seal member

The seal member includes a tetrafluoroethylene-propylene copolymer (FEPM) and carbon nanofibers. The seal member has a number of cycles to fracture of 10 or more when subjected to a tension fatigue test at a temperature of 150&#xb0; C., a maximum tensile stress of 2 N/mm, and a frequency of 1 Hz. The seal member exhibits excellent heat resistance and abrasion resistance.

Apparatus for determining downhole fluid temperatures are described. An example apparatus for measuring a temperature of a downhole fluid includes a sensing element for measuring a physical or chemical property of the downhole fluid, and a plurality of electrical connections to enable the sensing element to measure the chemical or physical property and provide an output signal representative of the chemical or physical property, wherein at least one of the electrical connections is configured to function as a thermocouple to sense a temperature of the downhole fluid.

Apparatus for determining downhole fluid temperatures

An expandable tubular sleeve having utility for lining a downhole tubular member includes a tubular body having a portion that is predisposed to initiate expansion thereof under the application of internal fluid pressure. The predisposed portion of the body may be a plastically-deformed portion formed, e.g., by application of mechanical force to a wall of the body. The predisposed portion of the body may be defined by a portion of the body having reduced wall thickness. The reduced wall thickness may be achieved, e.g., by reinforcing the wall thickness everywhere except the predisposed portion. The predisposed portion of the body may be formed by modifying the material properties of the body, e.g., by localized heat treatment. The sleeve and related apparatuses and methods are useful for securing and protecting a cable having one or more insulated conductive wires for transmission of signals between locations downhole and at the surface.

Vibrating wire viscometers are described. Some example vibrating wire viscometer housings include a flowline through the housing to expose a first wire to a downhole fluid, a cavity in the housing to hold a magnet and to conduct one or more additional wires from the flowline to a signal generator, first and second electrically conductive posts mechanically coupled to the housing to hold the first wire in tension within the flowline, and a seal mechanically coupled to the housing to prevent access to the magnet by the downhole fluid.

Vibrating wire viscometers

A cable link may include a first link connector in signal communication with at least one sensor in a drill string and coupled to the drill string, a second link connector spaced apart from the first link connector and in signal communication with a telemetry system, the second connector link coupled to the drill string, and a linking cable having signal connectors at each end thereof, the linking cable having at least one of an electrical conductor and an optical fiber therein, the signal connectors each configured to latch proximate a respective one of the first and second link connector.

Cable link for a wellbore telemetry system

A method for determining electrical condition of a wired drill pipe includes inducing an electromagnetic field in at least one joint of wired drill pipe. Voltages induced by electrical current flowing in at least one electrical conductor in the at least one wired drill pipe joint are detected. The electrical current is induced by the induced electromagnetic field. The electrical condition is determined from the detected voltages.

Method and apparatus for locating faults in wired drill pipe

The disclosure has application for use in conjunction with an operation of drilling an earth borehole using: a drilling rig, a drill string having its generally upper end mechanically coupleable with and suspendable from the drilling rig, and a bottom hole assembly adjacent the lower end the drill string, the bottom hole assembly including a drill bit at its lower end. A method is set forth for obtaining information about at least one parameter sensed at the bottom hole assembly, including the following steps: providing at least one measuring device in the bottom hole assembly, the at least one measuring device producing measurement data representative of a measured condition at the bottom hole assembly; providing an uphole processor system at the earth's surface; providing a drill string telemetry system coupled with the at least one measuring device and coupled with the uphole processor system; and transmitting the data from the measuring device to the uphole processor system via the drill string telemetry system.

Bidirectional drill string telemetry for measuring and drilling control

Growing community of inventors

Houston, TX, United States of America

Raghu Madhavan