Schlumberger Technology Corporation

Anadrill, Inc.

Chevron U.s.a. Inc.

Schlumberger Technology Corpoation

Schlumberger Technology Coproration

Services Petroliers Schlumberger

John C Rasmus

Dean M Homan

William Lesso

John James

Siddharth Misra

Koji Ito

Shahzad Asif

Michael Lynn Evans

Jeffrey Miles

Richard J Radtke

Gong Li Wang

John Paul Horkowitz

Sushil Shetty

Tarek M Habashy

Dzevat Omeragic

Alexander F Zazovsky

Gerald N Minerbo

Shashi Menon

Denis Heliot

Fernando Garcia-Osuna

Raymond V Nold, Iii

Ridvan Akkurt

Vikas Jain

Christopher Edward Morriss

David Furse Allen

Sylvain Wlodarczyk

James Curtis Brannigan

Florent D'Halluin

Valerian Guillot

Yuteng Jin

Christian Stolte

Natalie Uschner-Arroyo

Brian Oliver Clark

Jacques R Tabanou

Aria Abubakar

Denise E Freed

Vladimir Vaynshteyn

Harold Pfutzner

David Conn

Roger Griffiths

Richard E Lewis

Roberto Suarez-Rivera

Shyam B Mehta

Christopher Paul Reed

Wayne J Phillips

Steven Hough

Gallyam Aidagulov

Frank Shray

Carlos Maeso

Simon G Fleury

Carlos Torres-Verdin

David Handwerger

Chang-Yu Hou

Edward M Tollefsen

Georgiy Bordakov

George Bordakov

Jack LaVigne

Hui Xie

Xiao Bo Hong

Raphael Altman

Alex Ahrenst

Alexander Kostin

Lee Dolman

David Maggs

Martinus Johannes Bernardus Bogaerts

Dominic P McCann

Walter D Aldred

Mohammad Taghi Salehi

Joan Abadie

Ankur Prakash

Taesoo Kim

Abhijeet Nayan

Najmud Dowla

Marcus Turner

Amanda L Weber

Scott Paul

Edward Stockhausen

Ana Peternell

Aditya Gupta

Vittorio Picco

Vitor Villar De Andrade E Silva

Methods and systems for augmented geological service characterization are described. An embodiment of a method includes generating a geological service characterization process in response to one or more geological service objectives and a geological service experience information set. Such a method may also include augmenting the geological service characterization process by machine learning in response to a training information set. Additionally, the method may include generating an augmented geological service characterization process in response to the determination information.

Augmented geological service characterization

A method can include receiving dielectric data from a downhole dielectric tool of a drillstring disposed in a borehole in a target material that includes a target material boundary between the target material and one or more other materials; generating a geosteering command, based at least in part on the dielectric data, that calls for orienting a drill bit of the drillstring with respect to the target material boundary; and issuing the geosteering command to a geosteering actuator of the drillstring.

Dielectric-based geosteering

A method for evaluating saturation of a kerogen bearing subterranean formation includes obtaining conductivity and permittivity values of the formation and providing an effective medium model relating the conductivity and the permittivity to a water filled porosity of the formation and an effective aspect ratio of graphitic kerogen particulate in the formation. The obtained conductivity and the permittivity values are input into the model which is in turn processed to compute the water filled porosity. The method may further optionally include evaluating the water filled porosity to estimate a hydrocarbon producibility of the formation.

Method for saturation evaluation of graphitic kerogen bearing formations

Aspects of the present disclosure relate to a method for determining a contact angle, a wettability, or both, of one or more types of solid particles within a geological formation. The method may include identifying a relative conductive of the type of solid particles and identifying a frequency range for one or more EM measurements. The method may also include determining a contact angle associated with at least one type of solid particles within the geological formation using the electromagnetic measurements corresponding to the frequency range.

Systems and methods for determining properties of porous, fluid-filled geological formations based on multi-frequency measurements

A method can include receiving neutron data and density data for a borehole in a geologic formation; determining a migration length value for a layer of the geologic formation based at least in part on the neutron data; forward modeling at least the layer based at least in part on the migration length value and the density data; and outputting, based at least in part on the forward modeling, modeled neutron data for the layer.

Geologic formation neutron porosity system

Aspects of the present disclosure relate to a method for determining a wettability of one or more types of solid particles within a geological formation. The method may include receiving a plurality of electromagnetic measurements within a frequency range from an electromagnetic well-logging tool. The method may also include determining a contact angle associated with at least one type of solid particles within the geological formation using the electromagnetic measurements.

Methods may include emplacing a resistivity logging tool in a borehole; stimulating an interval of the formation in the borehole; obtaining at least one resistivity log of the interval of the formation, wherein the resistivity log comprises a survey of one or more depths into the formation; determining a radial invasion of the stimulating fluid into the interval of the formation; and inverting the radial invasion to obtain an input and entering the input into an effective medium model; solving the effective medium model and generating an effective wormhole radius profile and thickness for the interval of the formation.

Effective medium theory of acidized carbonate matrix resistivity employed to calculate the apparent geometric parameters of the wormholes

A method can include receiving measurements of a fluid mixture where the measurements are acquired by at least one downhole tool; performing a multiphysics inversion of the measurements to generate nuclear parameter values for the fluid mixture; performing a multivariate interpolation using the generated nuclear parameter values that accounts for intermolecular interactions in the fluid mixture; and determining a composition of the fluid mixture based on the multivariate interpolation.

Reservoir fluid characterization system

An electromagnetic measurement tool for making multi-frequency, full tensor, complex, electromagnetic measurements includes a triaxial transmitter and a triaxial receiver deployed on a tubular member. An electronic module is configured to obtain electromagnetic measurements at four or more distinct frequencies. The measurement tool may be used for various applications including obtaining a resistivity of sand layers in an alternating shale-sand formation; computing a dielectric permittivity, a conductivity anisotropy, and/or a permittivity anisotropy of a formation sample; and/or identifying formation mineralization including discriminating between pyrite and graphite inclusions and/or computing weight percent graphite and/or pyrite in the formation sample.

Multi-frequency electromagnetic tensor measurements

The highly valuable properties of resistivity and dielectric constant of a geological formation may be determined using an induction measurement, even for a geological formation with bed boundary or dipping effects, using a one-dimensional (1D) formation model. Induction measurements may be obtained in a wellbore through the geological formation using one or more downhole tools. One or more processors may be used to perform an inversion to estimate resistivity and dielectric constant values of the geological formation. The inversion may be performed using the induction measurements and a one-dimensional model that includes a number of geological layers.

Determining dielectric constant and resistivity with induction measurement

A formation characterization system can include a processor; memory accessibly by the processor; instructions stored in the memory and executable by the processor to instruct the system to: acquire induction measurements in a borehole in a formation using an induction tool; determine dielectric properties of the formation using the induction measurements; and generate a log that characterizes particles in the formation based on the dielectric properties.

Formation characterization system

Methods and apparatus for characterizing a subterranean formation traversed by a wellbore including collecting data from the formation using a tool wherein the tool collects data to form an azimuthal image, characterizing a section of the formation comprising data and images acquired in a high angle wellbore section or horizontal wellbore section using a parametric model, and performing an inversion using apparent densities and volumetric photoelectric factor images to build a formation model wherein the inversion is tailored for high angle wellbore sections and/or horizontal wellbore sections.

Inversion-based workflow for processing nuclear density images in high-angle and horizontal wells

A method for automatic interpretation of bulls-eye and sinusoidal features observed in LWD images is disclosed. In some embodiments, the method includes an automatic workflow for extracting smooth contours from images that demarcate boundaries of structural features, followed by projection of the contours to three-dimensional (3D) point clouds in the well coordinate system for structural interpretation. The method may characterize both sinusoidal features and bulls-eye features, taking into account variations of formation dip/azimuth, or well inclination/azimuth, on the topology of a structural feature. The disclosed method may be sufficiently fast for use in real-time analysis and interpretation, or to provide constraints for physics-based data inversion processing.

Automatic method for three-dimensional structural interpretation of borehole images acquired in high-angle and horizontal wells

A method for transforming a 2D or 3D earth volume geometry into a 1D earth volume geometry includes performing a measurement using the measurement sensor in a wellbore. A layer boundary in the 2D or 3D earth volume geometry that is nearest to the measurement sensor is identified. A vector from the measurement sensor is generated toward the nearest layer boundary. A first intersection is identified between the vector and the nearest layer boundary, and a second intersection is identified between the vector and another layer boundary. Simulated boundaries that extend through the first and second intersections and are perpendicular to the vector are generated. The 1D earth volume geometry that is bounded by the first and second intersections is identified. A property value is extracted from the 2D or 3D earth volume geometry between the first and second intersections. The property value is assigned to the 1D earth geometry.

Method for determining petrophysical properties from logging measurements

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Richmond, TX, United States of America

John C Rasmus