Schlumberger Technology Corporation

William Brian Underhill

Joseph P Varkey

Maria Auxiliadora Grisanti

David Geehyun Kim

Paul Wanjau

Colin Allan Wilson

Alfredo Fayard

David Gerez

Scott W Leaney

Brian Oliver Clark

Arthur H Hartog

Francois M Auzerais

Xiaowei Weng

Masahiro Kamata

Andrew L Kurkjian

Jean-Michel Hache

Joel Herve Le Calvez

Cengiz Esmersoy

Peter J Airey

Kazumasa Kanayama

Jiro Takeda

Olga Kresse

Utpal Ganguly

James T Rutledge

Shawn Maxwell

Herve Denaclara

Sebastien Isambert

Daniel Gordon Raymer

Craig Cipolla

Mark Mack

Nicolas Roumilly

Theodore Bruce Lafferty, Jr

Simon Severance

Samantha Rist

John B Elmer

A system includes a cable and at least one coupling device installed along the cable. The coupling element has one or more through cavities for receiving the cable, and configured to hold the cable when disposed in the cavity against a surface of the wellbore.

Systems and methods for holding wireline device against well

A system includes a cable and a toolstring. The toolstring may couple to the cable to enable the toolstring to be placed in a wellbore. The toolstring includes a sensor that can collect measurements relating to the wellbore. An electromagnetic or anchoring device may selectively hold the toolstring or the cable against a surface of the wellbore.

A seismic system that includes a seismic source configured to generate a first seismic signal and a second seismic signal in a formation adjacent the seismic source. A first downhole sensing device disposed in a first borehole configured to detect the first seismic signal and the second seismic signal in the formation; and a first surface acquisition system is in communication with the first downhole sensing device. The first surface acquisition system is configured to: determine a first reference transit time based at least in part on detection of the first seismic signal by the first downhole sensing device; a first subsequent transit time based at least in part on detection of the second seismic signal by the first downhole sensing device; and whether a synchronization variation is expected to be present based at least in part on the first reference transit time and the first subsequent transit time.

Downhole seismic sensing synchronization systems and methods

Systems, methods, and computer-readable media for designing a microseismic monitoring project. The method includes receiving data representing the microseismic monitoring project for at least one subterranean volume, the data including data representing a plurality of factors associated with a design of the microseismic monitoring project. The method also includes conducting a sensitivity analysis to determine a relative sensitivity between at least two of the plurality of factors, and determining whether to update a modelling scenario for the microseismic monitoring project based on the relative sensitivity.

Microseismic sensitivity analysis and scenario modelling

A method of performing a fracture operation is provided at a wellsite. The wellsite is positioned about a subterranean formation having a wellbore therethrough and a complex fracture network therein. The complex fracture network includes natural fractures, and the wellsite stimulated by injection of an injection fluid with proppant into the complex fracture network. The method involves generating wellsite data comprising measurements of microseismic events of the subterranean formation, modeling a hydraulic fracture network and a discrete fracture network of the complex fracture network based on the wellsite data, and performing a seismic moment operation. The method involves determining an actual seismic moment density based on the wellsite data and a predicted seismic moment density based on shear and tensile components of the simulated hydraulic fracture network, and calibrating the discrete fracture network based on a comparison of the predicted moment density and the actual moment density.

Method of calibrating fracture geometry to microseismic events

A distributed acoustic wave detection system and method is provided. The system may include a fiber optic cable deployed in a well and configured to react to pressure changes resulting from a propagating acoustic wave and an optical source configured to launch interrogating pulses into the fiber optic cable. In addition, the system may include a receiver configured to detect coherent Rayleigh noise produced in response to the interrogating pulses. The CRN signal may be used to track the propagation of the acoustic waves in the well. Such capability allows the location of the cement sheath, as well as measuring the bonding of cement to at least a casing string at least partially surrounded by a cement sheath.

Methods for locating a cement sheath in a cased wellbore

A technique includes providing a source in a first well and a seismic receiver in a second well to detect a seismic event that is caused by the source. The technique includes referencing clocks in the source and receiver to a common reference time frame and determining a time in the reference time frame at which the seismic source generates the seismic event.

Technique and system for performing a cross well survey

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

Methods and apparatus for creating a velocity profile of a formation surrounding a borehole by checkshot measurements while moving the tool along the borehole. A conveyance and a sensor section are configured to move the sensor section in the borehole. At least one receiver is configured to detect signals generated at or near the surface while the sensor section is moving in the borehole.

Methods and apparatus for performing moving checkshots

A borehole seismic acquisition tool configured for release from a stuck position within a borehole having a tool body with at least one sensor package, an anchoring arm, and anchoring arm linkage adapted to connect the anchoring arm to the tool body. The anchoring arm linkage includes a weakpoint mechanism adapted to break in response to a minimum threshold amount of breaking force being applied upon the weakpoint mechanism. The anchoring arm includes a first end adapted for contacting a borehole wall surface and a second end pivotally attached to the anchoring arm linkage. The anchoring arm also includes a movable cam removably secured to the first end via a first connector pin. The cam being at least partially rotatable about the first connector pin and configured and arranged to rotate against the borehole wall by a pulling force at a top portion of the borehole seismic acquisition tool.

Anchor arm for seismic logging tool

A well logging instrument is disclosed which includes a housing operatively coupled to a well logging conveyance and movable within the wellbore. The housing has therein a formation testing system and an axial extension mechanism. The axial extension mechanism controllably extends and retracts to allow the formation testing system to perform tests and take samples in an axially fixed position in the wellbore while the housing moves through the wellbore.

Formation testing instrument having extensible housing

An apparatus for communication with a downhole tool includes uphole and downhole equipment. The uphole equipment includes a signal source (or array) coupled to a programmable triggering system and a precision clock. Optionally, the uphole equipment may include receivers for capturing reference signals near the source and may include telemetry equipment for receiving MWD signals from the downhole equipment. The downhole equipment includes one or more receivers, signal processing equipment, memory, and a precision clock. Optionally, the downhole equipment also includes MWD telemetry equipment for transmitting data to the surface. The methods of the invention include, but are not limited to, synchronizing the recordation of signals detected downhole with the firing of the signal source and processing the recorded signals to eliminate useless information. The methods of the invention present several techniques for true source signal recognition whereby actual signal information is extracted from the recordings of the receivers so that the ultimate stored data is compact and virtually 100% useful. This elimination of useless data conserves valuable telemetry time and/or enables longer operation of the apparatus before tripping out to retrieve stored data by using memory efficiently.

Growing community of inventors

Richmond, TX, United States of America

William Brian Underhill