Schlumberger Technology Corporation

Schlumberger Canada Limited

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Francois M Auzerais

Douglas E Miller

Richard Timothy Coates

Agathe Robisson

Jahir A Pabon

Syed Afaq Ali

Partha Ganguly

Elizabeth B Dussan V

Yucun Lou

Rod W Shampine

Tarek M Habashy

Arthur H Hartog

Philip F Sullivan

Dominic Joseph Brady

John David Rowatt

Dominique Guillot

Shitong Sherry Zhu

Henry Menkiti

Meng Qu

Ian David Richard Bradford

Curtis L Boney

Murat Ocalan

Sharath Chandra Mahavadi

Sandeep Verma

Irfan Bulu

Colin A Wilson

Sudeep Maheshwari

Terizhandur S Ramakrishnan

Leiming Li

Philippe Gambier

Shunfeng Zheng

Tsutomu Yamate

Robert J Schroeder

Smaine Zeroug

Bhavani Raghuraman

Kuo-Chiang Chen

Mehmet Parlar

Stephane Vannuffelen

Andrew L Kurkjian

Julio C Guerrero

Mathew M Samuel

Colin Allan Wilson

Toru Terabayashi

Ian D Bryant

Nitin Y Vaidya

Harald Quintus-Bosz

Douglas Pipchuk

David J Rossi

Peter J Photos

Zheng Rong Xu

John A Kerr

Ahmed Hammami

Jeffrey A Tarvin

Tullio Moscato

William Brian Underhill

Joshua P Kinsley

John Ratulowski

Peter Gerhard Tilke

Nicholas N Bennett

Jeffrey E Thomas

Rex Burgos

Robert Krush

William E Kenyon

Peter J Airey

William F Murphy

Robert Matthew Graham

S Sherry Zhu

Shawn Rimassa

Ian Bradford

Raj Kumar Michael Thambynayagam

Elena Borisova

Nathan Wicks

Kevin J Forbes

Kuo Chiang Chen

Fikri Kuchuk

Robin Mallalieu

Yogesh S Dave

Simone Musso

Laurent P Prouvost

Alfred J Costa

T S Ramakrishnan

Barbara I Anderson

Stephen D Mason

Javier Sanchez Reyes

Ching-Hua Tseng

Matthew Godfrey

Terry Sopkow

Roman Kats

Miranda Amarante

Julien Prosper Marc Aknin

Mohamed Aly Sadek

Bruce Alexander Mackay

Philip Kokel

Kenneth Kin-nam Liang

Robert Graham

Luiz Gomes

Gauri Joshi

Jonathan Andrew Bannister

James Helwig

Optical fiber connections and their applications in downhole assemblies are described herein. The downhole assembly includes a well completion element with an end that couples with a corresponding well completion element. An optical fiber extends along at least a portion of the well completion element and transmits an optical signal using a first mode. The well completion element includes an optical fiber connector that is coupled to the optical fiber. The connector also includes a mode converter that receives the optical signal from the optical fiber and converts the optical signal from the first mode to a second larger mode. This second larger mode may be more robustly communicated to a corresponding optical fiber connector affixed to the corresponding well completion element.

Optical fiber connection

Embodiments may generally take the form of a degradable composite structure and a method for controlling the rate of degradation of a degradable composite structure. An example embodiment may take the form of a degradable polymer matrix composite (PMC) including a matrix having: a degradable polymer, a fiber reinforcement, and particulate fillers. The fiber loading is between approximately 10% to 70% by weight and the particulate loading is between approximately 5% to 60%.

Degradable composite structures

Methods include introducing a multistage treatment fluid into one or more intervals of a wellbore, wherein the treatment fluid contains one or more stages of a polymer-forming composition and one or more stages of a spacer fluid and initiating polymerization of the one or more stages of polymer-forming composition. Methods may include designing a multistage treatment fluid containing one or more stages of a polymer-forming composition and one or more stages of a spacer fluid, wherein or more stages of the polymer-forming composition comprises a thermosetting polymer; and pumping the multistage treatment fluid into a wellbore, wherein the pumping rate is determined by constructing a model based upon (a) the minimum pumping rate determined from the critical reaction temperature and the downhole temperature, (b) the fracture closing time, (c) the temperature within one or more fractures, and (d) the maximum pumping rate.

In situ solid organic pillar placement in fracture networks

Methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore comprising one or more stages of geopolymer precursor composition containing a geopolymer precursor and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition. In another aspect, methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore that include one or more stages of geopolymer precursor composition, wherein the geopolymer precursor composition includes an emulsion having an oleaginous external phase, and an internal phase comprising one or more surfactants, a geopolymer precursor, and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition.

In situ formed inorganic solids in fracture networks

Methods and apparatus of adjusting matrix acidizing procedures are disclosed. An example method includes determining parameters of a wellbore fluid during a matrix acidizing procedure using at least a first sensor and a second sensor. The parameters include velocity of the wellbore fluid and a temperature difference between the first sensor and the second sensor. The method also includes, based on the parameters, determining a characteristic relative to an invasion length of a reactive fluid within the formation, the reactive fluid used in association with the matrix acidizing procedure.

Methods and apparatus of adjusting matrix acidizing procedures

Methods and apparatus for analyzing the material properties and behavior of cement as it hydrates under simulated downhole conditions. A wellbore cement simulator includes a temperature and pressure controlled innermost oil-filled container; an annulus in contact with the innermost container configured to hold a cement sample; a mesh sleeve in contact with the annulus wherein the mesh sleeve is water permeable to permit hydration of the cement sample; a steel sleeve in contact with the mesh sleeve; an elastomeric bladder surrounding the steel sleeve; and a temperature and pressure controlled outermost oil-filled container.

Wellbore cement simulator

A fiber optic distributed vibration system for detecting seismic signals in an earth formation is provided. The system includes a fiber optic cable deployed in a borehole that extends into the earth formation and which is configured to react along its length to a seismic wave incident on the fiber optic cable from outside the borehole. An optical source launches an optical signal into the fiber optic cable while the seismic wave is incident thereon. A receiver detects coherent Rayleigh noise (CRN) produced in response to the optical signal. A processing circuit processes the detected CRN signal to determine characteristics of the earth formation.

Detection of seismic signals using fiber optic distributed sensors

A predetermined condition in a fluid-filled wellbore system can be detected by generating at least one sound in the wellbore system in response to the condition, such that a detectable change is created in some characteristic of the emitted sound, and detecting the at least one sound and the change, the detection being indicative that the predetermined condition has occurred. Equipment for facilitating detection of the condition can include a trigger operable in response to the condition; a generator operable to emit sound in the borehole and to create a detectable change in some characteristic of the emitted sound in response to the trigger; and at least one sensor operable to monitor the sound and detect the change, the detection being indicative that the predetermined condition has occurred. It is also possible to estimate a value of a property of a fluid-filled wellbore system. This can be accomplished by recording data including at least one of pressure and rate of flow at one or more locations in the wellbore system, and then estimating the value of the property by employing a model for predicting at least one of pressure and rate of flow dependent upon parameters detailing at least one of wellbore system geometry, viscoacoustic properties of the fluid and entrained solids contained in the wellbore system, locations of boundaries and entrained solids, and characteristics and locations of disturbances to pressure and flow in the wellbore system, in order to determine a best prediction of some attribute of the recorded data.

Wireless logging of fluid filled boreholes

Apparatus and a method for delivering a rod in a cylinder including propagating a rod in a cylinder along the interior of the cylinder, and introducing a motion in an orientation orthogonal to a length of the rod, wherein the motion comprises multiple motion sources along the length of the rod, and wherein the multiple motion sources comprise a control system that controls at least one of the motion sources. An apparatus and method for delivering a rod in a cylinder including a cylinder comprising a deviated portion, a rod comprising a length within the cylinder, multiple motion sources positioned along the length of the rod, and a control system in communication with at least one of the motion sources, wherein the control system controls the location of frictional contact between the rod and cylinder over time.

Method and apparatus of distributed systems for extending reach in oilfield applications

The current application discloses methods and systems for generating mechanical tube waves in fluid filled boreholes penetrating subterranean formations. In one embodiment, the system of the current application comprises an energy storage chamber; a fast operating valve connected to the energy storage chamber; a pipe connected to the valve and extending to the liquid-filled borehole; wherein the energy storage chamber contains a first pressure that is substantially different from a second pressure in the pipe so that a fast operation of the valve generates a tube wave in the pipe.

Mechanical tube wave sources and methods of use for liquid filled boreholes

A technique provides a system and methodology for detecting and monitoring erosion in various environments, including downhole environments. A tracer element is located in a component such that sufficient erosion of the component due to fluid flow exposes the tracer element. A monitoring system is disposed for cooperation with the tracer element such that exposure of the tracer element is detected by the monitoring system. The monitoring system outputs appropriate data indicative of the erosion to enable adjustments to the fluid flow.

Erosion tracer and monitoring system and methodology

A value of a property of a fluid-filled wellbore system can be detected. This can be accomplished by recording data including at least one of pressure and rate of flow at one or more locations in the wellbore system, and then estimating the value of the property by employing a model for predicting at least one of pressure and rate of flow dependent upon characteristics and locations of disturbances to pressure and flow in the wellbore system, in order to determine a best prediction of some attribute of the recorded data.

A method and apparatus is disclosed for monitoring microseismic activity in a formation. The method and apparatus include placing a tool string having a shuttle including a sensor thereon in a stimulation well, and activating the shuttle to acoustically couple the sensor to an inner surface of a casing. The sensor is acoustically decoupled from the tool string. Fluid is then injected into the formation via the tool string. The sensor is reengaged with the tool string. The tool string may then be removed from the stimulation well or moved to another position along the wellbore.

Method and apparatus for monitoring acoustic activity in a subsurface formation

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Boston, MA, United States of America

Francois M Auzerais