Schlumberger Technology Corporation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Kai Hsu

Julian J Pop

Kentaro Indo

Peter S Hegeman

Anthony Robert Holmes Goodwin

Adriaan Gisolf

Chengli Dong

Oliver Clinton Mullins

Christopher Harrison

Steven G Villareal

Ashers Partouche

Anthony R H Goodwin

Ricardo Vasques

Nathan Mathew Landsiedel

Youxiang Zuo

Matthew T Sullivan

Christopher Albert Babin

Daniel Palmer

Thomas Pfeiffer

Alain Brie

Peter Swinburne

Sylvain Ramshaw

Henri-Pierre Valero

Andrew L Kurkjian

Kent David Harms

Yong Chang

Beatriz E Barbosa

Simon Edmundson

Andrew Carnegie

Adriaan Gerard Gisolf

Richard A Plumb

Emmanuel Desroques

Sihar Marpaung

Bo Yang

Miroslav Slapal

Michael W Frels

Daniel Schulz

Deopaul Dindial

Gary John Tustin

Christopher Del Campo

Lalitha Venkataramanan

Bhavani Raghuraman

Gocha T Chochua

Jacques A Jundt

Go Fujisawa

Shu-Kong Chang

Shahnawaz Hossain Molla

Jonathan Webster Brown

Mark Milkovisch

Ralph Michael D'Angelo

Hadrien Dumont

Roger Griffiths

Raymond V Nold, Iii

Elizabeth Jennings Smythe

Andrew John Carnegie

Ryan Sangjun Lee

Carsten Sonne

Ashley C Kishino

Bunker M Hill

Michael O'Keefe

Sepand Ossia

Hua Chen

Noriyuki Matsumoto

Thomas J Plona

Li Chen

James C Mayes

John Allan Nighswander

Fei Song

Dominique Dion

Sophie Nazik Godefroy

Lei Chen

Sergio Kostek

Kazumasa Kanayama

Bo Yu

Farshid Mostowfi

Anthony Smits

Fred E Stanke

Derek Ivan Copold

Alexis Petit

Ralphe Wiggins

Abhishek Agarwal

Michael M Toribio

Florian Risser

Michael Stangeland

Sophie Godefroy

Gordon Lane McDaniel

Jean-Pierre Masson

Curtis J Randall

Weiming Lan

Sashank Vasireddy

Gregory Au

Scott C Cook

Haitao Zhang

George Christopher Tevis

Isabelle Etchart

Antoine Fornari

Pete Hegeman

Jack Horkowitz

Samuel P Subbarao

Derek Caudwell

A method includes positioning a downhole acquisition tool in a wellbore in a geological formation. The method includes operating a pump module to gather information for a fluid outside of the downhole acquisition tool that enters the downhole acquisition tool from a first flowline, a second flowline, or both while the downhole acquisition tool is within the wellbore. Operating the pump module includes controlling a valve assembly to a first valve configuration that enables the fluid to flow into the downhole tool via the first flowline fluidly coupled to a first pump module. Operating the pump module includes controlling a valve assembly to a second valve configuration that enables the fluid to flow into the downhole tool via the second flowline fluidly coupled to a second pump module, and selectively using a turnaround module or a crossover portion disposed between the first flowline and the second flowline to permit discharging the fluid from one flowline to the other flowline by actuating a valve associated with the turnaround module when the first pump module or the second pump module is not in use.

Terminal modules for downhole formation testing tools

Embodiments present a method for fluid type identification from a downhole fluid analysis that uses machine learning techniques that are trained and derived from a computer model using pressure, temperature and downhole optical characteristics of sampled fluid.

Fluid type identification from downhole fluid analysis using machine learning techniques

This disclosure relates to a separating a fluid having multiple phases during formation testing. For example, certain embodiments of the present disclosure relate to receiving contaminated formation fluid on a first flow line and separating a contamination (e.g., mud filtrate) from the formation fluid by diverting the relatively heavier and/or denser fluid (e.g., the mud filtrate) downward through a second flow line and diverting the relatively lighter and/or less dense fluid upward through a third flow line. In some embodiments, the third flow line is generally oriented upwards at a height that may facilitate the separation of the heavier fluid from the relatively lighter fluid based on gravity and/or pumps.

System and method for fluid separation

The disclosure provides for a method for setting an inflatable packer. The method includes positioning an inflatable packer within a borehole, and pumping fluid into an inflatable element of the inflatable packer using a pump that is driven by a motor. The method includes measuring pressure of the inflatable element, determining a derivative of the measured pressure with respect to time, and determining onset of restraining of the inflatable element has occurred. Upon or after determining the onset of restraining, the method includes turning off the motor or slowing down an rpm of the motor. The disclosure also provides for a system, including a computer readable medium with processor-executable instructions stored thereon that are configured to instruct a processor to execute a pressure control algorithm to control a speed of the motor in response to pressure measurement data from the pressure sensor.

Automation of packer inflation

Embodiments of the disclosure can include systems and methods for formation fluid sampling. In one embodiment, a method can include monitoring a relationship between a first characteristic of a formation fluid extracted from a formation and a second characteristic of the formation fluid extracted from the formation, determining, based at least in part on the monitoring, that a linear trend is exhibited by the relationship between the first characteristic of the formation fluid extracted from the formation and the second characteristic of the formation fluid extracted from the formation, and determining a reservoir fluid breakthrough based at least in part on the identification of the linear trend, wherein the reservoir fluid breakthrough is indicative of virgin reservoir fluid entering a sampling tool.

Systems and methods for formation fluid sampling

Apparatus and methods for obtaining a data response of a fluid as a function of pressure of the fluid, and estimating a dew point pressure of the fluid by detecting an inflection pressure, a downward curve pressure, a characteristic change pressure, and an intersection pressure of the function representative of the data response. The estimated dew point pressure of the fluid based on at least one of the inflection pressure, the downward curve pressure, the characteristic change pressure, and the intersection pressure.

Prediction of saturation pressure of fluid

A method for measuring asphaltene content of a crude oil is provided. In one embodiment, the method includes measuring an optical density of a live crude oil within a well and calculating a formation volume factor of the live crude oil based on the measured optical density. The method also includes determining asphaltene content of the live crude oil based on the measured optical density and the calculated formation volume factor of the live crude oil. Additional methods, systems, and devices are also disclosed.

Method of obtaining asphaltene content of crude oils

A downhole tool is operated to pump fluid from a subterranean formation while obtaining fluid property measurements pertaining to the pumped fluid. The downhole tool is in communication with surface equipment located at the wellsite surface. The downhole tool and/or surface equipment is operated to estimate a first linear, exponential, logarithmic, and/or other relationship between compressibility and pressure of the pumped fluid based on the fluid property measurements. The downhole tool and/or surface equipment may also be operated to estimate a second linear, exponential, logarithmic, and/or other relationship between formation volume factor and pressure of the pumped fluid based on the first relationship. The downhole tool and/or surface equipment may also be operated to measure and correct optical density of the pumped fluid based on the first relationship.

Determining formation fluid variation with pressure

A method includes operating a downhole acquisition tool in a wellbore in a geological formation. The wellbore or the geological formation, or both, contain a reservoir fluid. The method also includes receiving a portion of the reservoir fluid into the downhole acquisition tool and performing downhole fluid analysis using the downhole acquisition tool in the wellbore to determine at least one measurement associated with the portion of the reservoir fluid. The at least one measurement includes fluid density, optical density, or both. The method also includes using a processor of the downhole acquisition tool to obtain compressibility of the reservoir fluid based at least in part on the fluid density, the optical density, or both and determining a composition of the reservoir fluid based at least in part on the compressibility.

Downhole characterization of fluid compressibility

Techniques for improving implementation of a downhole tool string to be deployed in a borehole formed in a sub-surface formation. In some embodiments, a design device determines a model that describes expected relationship between properties of the downhole tool string, the borehole, the sub-surface formation, and mud cake expected to be formed in the borehole; determines calibration locations along the borehole based on properties of the borehole; determines candidate spacer configurations based on contact force expected to occur at contact points between the downhole tool string and the mud cake when deployed with each of the candidate spacer configuration via the model; and determines a final spacer configuration to be used to attach one or more spacers along the downhole tool string based on expected head tension to move the downhole tool string when deployed in the borehole with each of the candidate spacer configurations via the model.

Downhole toolstring spacer placement systems and methods

Obtaining in-situ, at a first time, first optical spectral data associated with a formation fluid flowing through a downhole formation fluid sampling apparatus, and then obtaining in-situ, at a second time after the first time, second optical spectral data associated with the formation fluid flowing through the downhole formation fluid sampling apparatus. A wavelength-independent scattering intensity within the formation fluid flowing through the downhole formation fluid sampling apparatus is then determined based on the first and second optical spectral data, and a wavelength-dependent scattering intensity within the formation fluid flowing through the downhole formation fluid sampling apparatus is determined based on the first and second optical spectral data.

Scattering detection from downhole optical spectra

Growing community of inventors

Sugar Land, TX, United States of America

Kai Hsu