Schlumberger Technology Corporation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Jacques R Tabanou

Reinhart Ciglenec

Jean P Seydoux

Dzevat Omeragic

Reza Taherian

Jian Yang

John Paul Horkowitz

Julian J Pop

Martin E Poitzsch

David Lee Alumbaugh

Jaideva C Goswami

James P Brady

Andrew Hawthorn

Alexander F Zazovsky

Mark T Frey

Emmanuel Legendre

Peter T Wu

Qiming Li

Denis Heliot

Kambiz A Safinya

Koji Ito

Christopher Edward Morriss

Anthony Goodwin

Abdurrahman Sezginer

Tarek M Habashy

Dean M Homan

John C Rasmus

Richard A Rosthal

Thomas D Barber

David L Smith

Albert Hoefel

Christian Chouzenoux

Walter David Aldred

Thomas D MacDougall

Remi Hutin

Ian D Bryant

Alain M Dumont

Gary A Hazen

Kenneth L Havlinek

Frank Shray

Troy Fields

Shahzad Asif

Arthur D Liberman

Attilio C Pisoni

Andre E Orban

Dimitrios K Pirovolou

M Reza Taherian

Fabienne Legendre

Cheng Bing Liu

Georgi Kutiev

Christian Stolte

Denis Heilot

Bernadette Tabanou, Legal Representative

Ernesto Garcia

Bradley S Underwood

Paul Michael Ray

Clive Eckersley

J N Antoine

Bradley Underwood

A technique provides a methodology for improving surveys of subterranean regions. The methodology comprises estimating macro anisotropy and an intrinsic or micro anisotropy of an overburden. A surface electromagnetic survey is conducted, and the data from the survey is inverted based on or including information gained from estimating the macro anisotropy and/or intrinsic anisotropy. A processor system can be used to conduct the inversion with the adjustments for anisotropy to improve the information provided by the survey.

System and method for improving surface electromagnetic surveys

A surface seismic survey is generated or obtained from Earth's surface and is based on time in which acoustic waves are reflected to Earth's surface. One or more tools measure density and sonic velocity of a subsurface formation. An estimate of acoustic impedance is obtained from the density and the sonic velocity to generate a synthetic seismic survey. The synthetic seismic survey and the surface seismic survey are compared and/or correlated. The acoustic impedance can be iteratively estimated until the synthetic seismic survey matches the surface seismic survey. Matching the surface seismic survey with the synthetic seismic survey may ensure that the surface seismic survey may be calibrated in actual depth.

System and method for generating true depth seismic surveys

A method for sampling fluid in a subterranean formation includes reducing a viscosity of the fluid, pressurizing a portion of the subterranean formation, and collecting a fluid sample. Specifically, a viscosity of the fluid in a portion of the subterranean formation is reduced and a portion of the subterranean formation is pressurized by injecting a displacement fluid into the subterranean formation. A sample of the fluid pressurized by the displacement fluid is then collected.

Methods and apparatus to sample heavy oil in a subterranean formation

A method for estimating a fracture aperture in a formation penetrated by a well includes obtaining at least one of a vertical resistivity (Rv) and a horizontal resistivity (Rh) of the formation; obtaining a mud resistivity (R) or a matrix resistivity (R); and estimating the fracture aperture. The estimating of the fracture aperture may be performed by solving the following two equations:+(1&#x2212;)&#xb7;and 1/&#xb7;1/+(1&#x2212;)&#xb7;1/,wherein Vis the fracture aperture.

Method and system to estimate fracture aperture in horizontal wells

A method for sampling fluid in a subterranean formation includes, reducing a viscosity of a fluid, pressurizing a portion of the subterranean formation and collecting a fluid sample. Specifically, a viscosity of a fluid in a portion of the subterranean formation is reduced and a portion of the subterranean formation is pressurizing by injecting a displacement fluid into the subterranean formation. A sample of the fluid pressurized by the displacement fluid is then collected.

A method for processing well logging data includes method dividing the well logging data into a number of constant dimensional effect segments, where each constant dimensional effect segment defines an interval having a similar dimensional effect on the log response. The well logging data is taken from a highly deviated well. The method further includes dividing the constant dimensional effect segments into a number of constant property intervals, each constant dimensional effect segment including at least one corresponding constant property interval, and each constant property interval defining a wellbore distance over which a formation property is substantially constant that results in a log response having a low variance. The method further includes providing the constant property intervals to an output device. The method further includes determining constant property intervals in 3D volume space projected them into true stratigraphic thickness, and providing the resulting log-squared data to the output device.

Log processing in highly deviated wellbores

Method and system for visualizing one or more properties of a subterranean earth formation while drilling a borehole using probability information from a modeling process. Probability waveforms based on information from a plurality of borehole stations may be plotted, either alone or superimposed onto other graphical representations, to provide a visual display that is easily interpreted by a user to make geosteering decisions. The probability waveforms include peaked sections that are proportional to the amount of uncertainty or error associated with a boundary estimate at a particular distance from an axis of the borehole. By providing a visual display of the uncertainty, a user can make better geosteering decisions.

System and method for displaying data associated with subsurface reservoirs

A method for determining a property of formations surrounding an earth borehole being drilled with a drill bit at the end of a drill string, using drilling fluid that flows downward through the drill string, exits through the drill bit, and returns toward the earth's surface in the annulus between the drill string and the periphery of the borehole, including the following steps: obtaining, downhole near the drill bit, a pre-bit sample of the mud in the drill string as it approaches the drill bit; obtaining, downhole near the drill bit, a post-bit sample of the mud in the annulus, entrained with drilled earth formation, after its egression from the drill bit; implementing pre-bit measurements on the pre-bit sample; implementing post-bit measurements on the post-bit sample; and determining a property of the formations from the post-bit measurements and the pre-bit measurements.

Downhole measurement of formation characteristics while drilling

An orientation vector, referred to hereinafter as the 'geosteering vector,' is directed to the more conductive formation area within the DOI of the tool and away from the more resistive formation areas. Accordingly, drilling in a direction opposite the geosteering vector leads to more resistive formation. Also, the disclosed geosteering vectors obtained from the real and imaginary components will not align with each other for non-planar formations and therefore the misalignment of the geosteering obtained from real and imaginary components is indicative of a non-planar formation. A superposition method is disclosed which can be used to calculate electromagnetic (EM) couplings in a non-planar geometry formation (as well as in a planar geometry formation) in real time, without requiring two or three dimensional modeling calculations.

Electromagnetic directional measurements for non-parallel bed formations

A method and apparatus for drilling at least one wellbore from an offsite location is provided. Each wellbore is located at a wellsite having a drilling rig with a downhole drilling tool suspended therefrom. The downhole drilling tool is selectively advanced into the earth to form the wellbore. The downhole drilling tool is operated according to a wellsite setup. Wellsite parameters are collected from a plurality of sensors positioned about the wellsite. The wellsite parameters are transmitted to an offsite control center. The offsite control center performs an analysis of the wellsite parameters and automatically adjusts the wellsite setup from the offsite control center based on the analysis.

Wellbore drilling method

A tool for electromagnetic logging of a formation includes a tool body configured to move in a borehole penetrating the formation; an antenna array disposed on the tool body; and an electronic unit configured to control operation of the antenna array, wherein the antenna array comprises at least one transmitter and at least one receiver, wherein at least one selected from the group consisting of the at least one transmitter and the at least one receiver comprises a printed circuit antenna.

Apparatus for electromagnetic logging of a formation

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Houston, TX, United States of America

Jacques R Tabanou