Schlumberger Technology Corporation

Schlumberger Technology Center

Schlumberger Holdings Limited

Prad Research and Development Limited

Services Pétroliers Schlumberger

Geoquest Systems B.v.

Schlumberger Technology B.v.

Dzevat Omeragic

Tarek M Habashy

Dean M Homan

Richard A Rosthal

Brian Oliver Clark

Thomas D Barber

Stephen D Bonner

Qiming Li

Jacques R Tabanou

Jean P Seydoux

Yong-Hua Chen

Michael Thiel

Jan Smits

Scott S Chesser

Lawrence Chou

Gerald N Minerbo

Keli Sun

Sushil Shetty

Nicolas Sebline

Saad Omar

John C Rasmus

Mark T Frey

Andrew J Hayman

Jian Yang

Jeffrey Miles

Philip S Cheung

Alain M Dumont

Cengiz Esmersoy

Tianhua Zhang

Andrei Davydychev

Chengbing Liu

Sofia N Davydycheva

Steve F Crary

Christophe Dupuis

Libo Yang

Jean-Michel Denichou

Peiwen Xia

Paul A Wand

Valery Polyakov

James F Bristow

Richard Timothy Coates

Edward Nichols

William John Bailey

Ugo Conti

Nicholas N Bennett

Helene Claire Climent

Hanming Wang

Carlos Maeso

Attilio C Pisoni

Alberto Malinverno

Zikri Bayraktar

Hui Xie

Chih-Hao Kuo

Raphael Altman

Bernadette Tabanou, Legal Representative

Niloofar Farnoosh

Shabnam Ghadar

Torbjørn Vik

Martin David

Raymond Kocian

Lingyun Hu

Yanqing Zeng

Douglas Hupp

William Bailey

Embodiments included herein are directed towards a system and method for analyzing an oilfield casing using an apparent thickness approach. Embodiments may include providing an induction instrument having at least one of a transmitter and a receiver configured to operate at one or more frequencies. Embodiments may further include generating, using data acquired by the induction instrument, one or more apparent thickness transforms for at least one of a measured attenuation and a phase response associated with an oilfield casing, wherein generating includes assuming a proportionate increase in all casing thicknesses.

System and method for analyzing an oilfield casing using an apparent thickness approach

Methods and systems are provided that predict electromagnetic properties of drilling mud and a formation, which involve a logging tool that measures current injected into a measurement zone adjacent a sensor electrode at multiple frequencies. The measured currents at the multiple frequencies are processed to determine complex impedances for the sensor electrode at the multiple frequencies. The complex impedances are used to generate input data, which is supplied to a system of artificial neural networks (ANNs) that is configured to predict and output electromagnetic properties of the drilling mud and the formation within the measurement zone and possibly tool standoff based on the input data. The system of ANNs can employ a cascaded architecture of multiple ANNs. The electromagnetic properties or tool standoff predicted by the system of ANNs can be used to construct a borehole image over varying azimuth and depth.

Well logging tool and interpretation framework that employs a system of artificial neural networks for quantifying mud and formation electromagnetic properties

Systems, computer-readable media, and methods for valuating measurement data, of which the method includes obtaining a first model of a subsurface volume, determining a baseline control parameter based on the first model, receiving new measurement data measured using a data collection device, the new measurement data representing one or more characteristics of the subsurface volume, and obtaining a second model of the subsurface volume based in part on the new measurement data. The first model is not based on the new measurement data. Further, the method includes determining an enhanced control parameter based on the second model, determining an enhanced value corresponding to the second model using the enhanced control parameter, determining a realized value corresponding to the second model using the baseline control parameter, and calculating a value of the new measurement data by comparing the enhanced value and the realized value.

Drilling measurement valuation

Embodiments of the present disclosure are directed towards a method for obtaining and analyzing flux leakage data. Embodiments may include measuring, using a magnetic flux leakage tool, magnetic flux leakage data from a casing and determining sensor liftoff data from the flux leakage data. Embodiments may also include performing outward analytic continuation of the magnetic flux leakage data from a sensor plane to one or more additional planes and extrapolating back from the one or more additional planes to a surface. Embodiments may include applying a model-based parametric inversion to the magnetic field flux leakage data and determining, based upon, at least in part, the model-based parametric inversion, a shape and size of a corresponding corroded area associated with the casing.

System and method for obtaining and analyzing flux leakage data in the inspection of oil and gas wells

Methods and systems for characterizing subterranean formations are described herein. One method includes performing electromagnetic logging measurements along a portion of a borehole traversing the subterranean formation using an electromagnetic logging tool to obtain electromagnetic data. The method also includes processing the electromagnetic data to determine a plurality of one dimensional formation models associated with the portion of the borehole. A two dimensional pixel grid is determined using the plurality of one dimensional formation models. The method further includes determining a two dimensional formation model for the subterranean formation by performing an inversion of the electromagnetic data using the two dimensional pixel grid. The methods and systems described herein can be used to steer a bottom-hole assembly during well placement.

Two dimensional pixel-based inversion

Inversion-based workflows are provided for real-time interpretation of the electromagnetic (EM) look-around and look-ahead measurements. The profile of a look-around zone is determined by interpreting EM measurements of a look-around zone. The profile of the look-around zone characterizes formation dip as well as vertical resistivity or resistivity anisotropy of one or more formation layers of the look-around zone. The profile of a look-ahead zone is determined by interpreting EM measurements of the look-ahead zone. The profile of the look-ahead zone characterizes formation dip as well as horizontal resistivity, vertical resistivity or anisotropy of one or more formation layers of the look-ahead zone. The workflows can also involve interpretation of look-around resistivity measurements to aid in the characterization of the look-around zone.

Methods and systems employing look-around and look-ahead inversion of downhole measurements

A method and system is provided for drilling a wellbore that traverses a geological formation using a drilling tool. The method and system derives a plurality of formation models that characterize the geological formation. The number of formation models represent layer structures with a heterogeneity (such a fault) offset laterally at variable distance relative to position of the drilling tool. Simulated directional resistivity data of the drilling tool is derived from the plurality of formation models. Certain simulated directional resistivity data are combined or selected for processing as multi-dimensional cross-plot data. Measured directional resistivity data obtained by the drilling tool is used to evaluate the multi-dimensional cross-plot data to determine distance of the heterogeneity relative to position of the drilling tool. The determined distance of the heterogeneity relative to position of the drilling tool can used for controlling drilling direction and can be stored in computer memory and used in other reservoir analysis.

Drilling with information characterizing lateral heterogeneities based on deep directional resistivity measurements

Systems and methods are disclosed for well logging using radiation detection and/or emission of gamma rays. A method according to the disclosure includes collecting data from the subterranean formation using a nuclear density tool, wherein the nuclear density tool is configured to collect data to form an azimuthal image. The method further includes characterizing a section of the subterranean formation comprising data and images acquired in a high angle wellbore section, a horizontal wellbore section, or a combination thereof. The method additionally includes performing a parallel inversion using apparent densities and volumetric photoelectric factor images to build a formation model, wherein the parallel inversion comprises a high angle workflow that models high angle wellbore sections and a horizontal workflow that models horizontal wellbore sections.

Inversion-based workflow for consistent interpretation of nuclear density images in horizontal wells

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

Methods for determining oil-water contact positions and water zone resistivities are provided. In one example, the method may involve performing a 1D inversion on data collected by a resistivity logging tool. Further, the method may involve scanning a resistivity profile of a reservoir generated by the 1D inversion for a boundary position below the resistivity logging tool. Furthermore, the method may involve applying a local residual weighted average on the boundary position to generate an initial estimation of an oil-water contact position and inverting the initial estimation of the oil-water contact to generate water zone resistivity and a modified oil-water contact position. Additionally, the method may involve running a smoothing local post-processing operation to generate a layered model and performing a 2D inversion on the layered model.

Workflow for navigation with respect to oil-water contact using deep directional resistivity measurements

Systems, methods, and apparatuses to generate a formation model are described. In one aspect, a logging system includes a transmitter to produce an electromagnetic field in a borehole, a receiver in the borehole to detect a first field signal induced by the electromagnetic field at a first depth of investigation and a second field signal induced by the electromagnetic field at a second depth of investigation, and a modeling unit to perform a first one-dimensional inversion on the first field signal and a second one-dimensional inversion on the second field signal, build a two-dimensional model from the first one-dimensional inversion and the second one-dimensional inversion, and perform a two-dimensional inversion on the two-dimensional model to generate a two-dimensional formation model.

Methods and apparatuses to generate a formation model

A method for determining orientation of an electrical resistivity boundary in a wellbore includes using measurements of an electromagnetic property of formations traversed by the wellbore at at least one axial spacing between a multiaxial electromagnetic transmitter and a multiaxial electromagnetic receiver, and determining a symmetrized angle using measurements of the electromagnetic property made using receiver components transverse to a well logging instrument axis and a transmitter component along the axis. At least a relative orientation of the electrical boundary with respect to an orientation of the well logging instrument is determined using the symmetrized angle.

Generalized directional measurements and using symmetrized and anti-symmetrized angles to indicate orientation of anisotropy and formation boundaries

A method for characterizing a subterranean formation traversed by a wellbore includes generating a reservoir model using data collected from the formation, generating a perturbation object comprising a perturbation of the wellbore, integrating the perturbation object with the reservoir model, and forming a geological model wherein the perturbation object is integrated in the reservoir model.

Integrating reservoir modeling with modeling a perturbation

Techniques for log squaring using both directional and non-directional electromagnetic measurements are disclosed. The techniques described herein can be used for determining bed boundary locations and assigning resistivity values to each layer in a layered earth model, regardless of well deviation. Potential bed boundary locations can be derived from both directional and non-directional electromagnetic measurement data. The bed boundary locations from the directional and non-directional measurements can then be consolidated using a weighted averaging scheme, where weight can be dependent based on apparent formation dip. By combining the results from both directional and non-directional measurements, the log squaring techniques described herein can be used in most wells regardless of the well angle (the angle can be arbitrary). Once bed boundaries are selected, formation properties, such as horizontal resistivity (Rh) and vertical resistivity (Rv) can be assigned to the model layers.

Method for selecting bed boundaries and log squaring using electromagnetic measurements

Disclosed herein is a method of determining a relation between a resistivity logging tool and casing in an earth formation. The method includes acquiring coupling voltages for different tool face angles, between different antenna components of different axes of a transmitting station transmitting into the earth formation and different antenna components of different axes of a receiving station receiving from the formation, using the resistivity logging tool. Then, spatial Fourier coefficients are extracted from the coupling voltages, using a computing device associated with the resistivity logging tool. The relation between the resistivity logging tool and the casing is then determined as a function of the spatial Fourier coefficients and at least one resistivity measurement of the earth formation, using the computing device.

Use of transverse antenna measurements for casing and pipe detection

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Lexington, MA, United States of America

Dzevat Omeragic