Schlumberger Technology Corporation

Honeywell International Inc.

Frank F Espinosa

John R Lovell

Ashley Bernard Johnson

Gokturk Tunc

Walter David Aldred

Michael Paul Barrett

Zheng Rong Xu

Tudor Ioan Palaghita

Stephen D Hill

Warren Zemlak

Benjamin Peter Jeffryes

Geoffrey Charles Downton

Reinhart Ciglenec

Murtaza Ziauddin

L Michael McKee

Kjell Haugvaldstad

Riadh Boualleg

Srinand Sreedharan Karuppoor

William D Eatwell

Marc Allcorn

Bryan K Rogers

Luis F Peixoto

Steven Harrison

Andrew Prestridge

Steve Davies

David Milton Eslinger

Pierre-Yves Corre

Jean-Louis Pessin

Li Jiang

Robert J Schroeder

Terrence Dwight Bender

Bhavani Raghuraman

Gary Martin Oddie

Iain Michael Cooper

John W Still

Lawrence James Leising

Michael Hayes Kenison

Fadhel Rezgui

Colin Longfield

Fernando Garcia-Osuna

Mark Callister Oettli

Thomas George Stratton

Golchehreh Salamat

Radovan Rolovic

Michael G Gay

Andrew J Parry

Bart V Thomeer

Larry J Leising

Edgar Robert Mallison

Frederic Pauchet

Joel J Bodin

Stephen Davies

Avel Z Ortiz

Carlos J Delgado

Charles Miller

Alexander Joseph Marks

Moussa Kane

Mahmuda Afroz

Carolina Dautriche

Michael Orlet

Cory James

Zefer Erkol

William Bertram

Xuefei Sun

Sebastien Fremont

Ballard Andrews

Colin Whittaker

Chris Lenn

Ivan Hlestov

Michael Garwood

A well-logging tool for a geological formation includes a housing to be positioned in a borehole and an antenna assembly carried by the housing. The antenna assembly includes an antenna housing having a recess therein. A dielectric material layer comprises a basalt fiber composite and is within the recess. At least one antenna coil is supported by the dielectric material layer. An electrical connector is coupled to the at least one antenna coil. Resistivity processing circuitry is coupled to the electrical connector to determine an electrical resistivity of the geological formation based on the at least one antenna coil.

Basalt fiber composite for antenna in well-logging

A well-logging tool for geological formation has a borehole. A housing that is to be positioned within the borehole includes an opening. An electrically conductive winding is carried by the housing. A feedthrough assembly includes an elongate electrical conductor having opposing first and second ends and a medial portion extending therebetween. The first end is coupled to the electrically conductive winding. An integrally formed, monolithic, dielectric layer sounds the elongate electrical conductor and includes a first enlarged diameter end portion surrounding the first end of the elongate electrical conductor and is positioned within the opening. A reduced diameter portion surrounds the medial portion of the elongate electrical conductor.

Feedthrough assembly for electrically conductive winding

A well-logging tool for a geological formation has a housing to be positioned within a borehole and has first and second openings. A feedthrough assembly includes an elongate electrical conductor having opposing first and second ends and a medial portion extending therebetween. An integrally formed, monolithic, dielectric layer surrounds the elongate electrical conductor and includes a first enlarged diameter end portion surrounding the first end of the elongate electrical conductor and is positioned within the first opening. A second enlarged diameter end portion surrounds the second end of the elongate electrical conductor and is positioned within the second opening. A reduced diameter portion surrounds the medial portion of the elongate electrical conductor.

Feedthrough assembly for well-logging tool

A wellbore apparatus may include first and second tubular members joined together in end-to-end relation, the first tubular member having a reduced outer diameter end portion. The wellbore apparatus may further include a removable modular antenna assembly comprising a cylindrical dielectric housing removably positioned on the reduced outer diameter end portion of the first tubular member, at least one antenna coil carried by the cylindrical dielectric housing, and a first electrical connector coupled to the at least one antenna coil. The wellbore apparatus may also include resistivity processing circuitry coupled to the first electrical connector to determine an electrical resistivity of a wellbore based upon the at least one antenna coil.

Removable modular antenna assembly for downhole applications

A method and apparatus for testing a multi-zone reservoir while reservoir fluids are flowing from within the wellbore. The method and apparatus enables isolation and testing of individual zones without the need to pull production tubing. This abstract allows a searcher or other reader to quickly ascertain the subject matter of the disclosure. It may not be used to interpret or limit the scope or meaning of the claims.

Methods, systems and apparatus for coiled tubing testing

Inflatable packers are provided with one or more components to improve longevity and/or functionality. One or more of the packer components utilizes reinforced materials incorporated in a manner that enables the improved longevity and/or functionality.

Inflatable packers

The present disclosure relates to a coiled tubing unit. The coiled tubing unit may include coiled tubing with a cable disposed within the coiled tubing. Further, the coiled tubing unit may include a spool about which at least a portion of the coiled tubing is wound, an injector header configured to move the coiled tubing, and a cable slack monitoring feature. The cable slack monitoring feature may be configured to detect an accumulation of cable slack in a portion of the coiled tubing.

Cable monitoring in coiled tubing

A drive mechanism is described for moving/controlling objects/mechanisms/systems coupled with a drillstring and/or pipe. The drive mechanism may be axially arranged on a drillstring or pipe, compact, capable of fine control and delivering high torque or the like and may be electrically and/or hydraulically powered. The drive mechanism may comprising a driving member comprising a plurality of drivers linearly translatable with respect to the driving member, each driving member having at their ends a male engaging portion and an associated driven member, comprising a plurality of female receiving portions adapted to receive a male engaging portion, the arrangement being such that linear translation of a driver causes its engaging portion to engage with a female receiving portion and the action of the engaging portion produces a reaction in the receiving portion causing displacement of the driven member in a direction other than that of the translatable driver.

Drive mechanism

The present invention recites a method and apparatus, wherein said methods and apparatus comprises an actuator comprising a first plate, a pocket extending through the first plate, the pocket in fluid communication with a pressurized fluid source and a second plate coupled to a component that is to be actuated, wherein the first plate, the second plate, and the pocket are dimensioned such that when a pressurized fluid is discharged through the pocket, the velocity of the fluid through a gap between the first plate and the second plate creates a pressure drop sufficient to pull the second plate toward the first plate.

Actuators, actuatable joints, and methods of directional drilling

The present invention recites a method, system and apparatus, wherein said method, system and apparatus comprises a gauge pad for a rotary component received within a borehole, the gauge pad comprising an exterior surface dimensioned for rotation in close proximity to the borehole, a pocket extending through the exterior surface, the pocket in fluid communication with a pressurized fluid source, and wherein the exterior surface is dimensioned such that when a pressurized fluid is discharged through the pocket, the velocity of the fluid through a gap between the exterior surface and borehole creates a pressure drop sufficient to pull the rotary component toward the gauge pad.

Gauge pads, cutters, rotary components, and methods for directional drilling

Methods for creating packers at a desired location or locations within a wellbore for use in specific wellbore applications. A slurry of fluid medium and hydrolysable particulate matter is flowed to a downhole position and dehydrated. At this location, the particulate matter is released from the fluid medium and accumulated. The continual accumulation of the slurry and consequent deposition of particulate matter creates a degradable packer at the desired location within the wellbore. The particulate matter may be formed of an acid particle which may be removable, degradable, or hydrolysable under certain conditions of temperature, time, hydration, pH, and/or pressure. Either simultaneous with or subsequent to a wellbore activity, the packer is partially or completely removed from the wellbore.

Methods of forming acid particle based packers for wellbores

A connection between coiled tubing and a connector includes a plurality of dimples formed by a tubing, each dimple is disposed within a respective pocket formed in a connector to form at least two rows of dimple-pocket connections, wherein the fit of the dimples within the pockets of the rows graduates from tighter to looser along the length of the connection. The connection may further include a seal member positioned between the tubing and the connector positioned between at least two of the rows of dimple-pocket connections formed. A method of connecting coiled tubing to a connector includes the steps of graduating the dimple-pocket connections from tighter to looser along the length of the connection.

Method of connecting coiled tubing to a connector

The present invention provides a packer cup system for use inside a wellbore comprising a packer cup and a backup component coupled thereto. In one configuration, the backup component further comprises a support member and a rubber ring disposed between the support member and the packer cup. The support member is configured to prevent the rubber ring from moving toward the support member.

Packer cup systems for use inside a wellbore

Although the methods have been described here for, and are most typically used for, hydrocarbon production, fluid diversion measurement systems and methods are described. One method includes inserting a tubular tubing having one more fluid injection ports into a wellbore, injecting a treatment fluid through the injection port, and determining differential flow of the treatment fluid at one or more wellbore based on measuring the concentration of at least one particular component of a wellbore fluid located in the annulus formed between the wellbore and tubular; and using the measured parameters in realtime to monitor, control, or both monitor and control diversion of the fluid.

Method of monitoring fluid placement during stimulation treatments

Growing community of inventors

Titusville, NJ, United States of America

Frank F Espinosa