Halliburton Energy Services, Inc.

Peter Ojo Olapade

Christopher Michael Jones

Bin Dai

Dingding Chen

Anthony Herman Van Zuilekom

James Martin Price

Michael Thomas Pelletier

Michel Joseph LeBlanc

Mehdi Alipour Kallehbasti

A method may comprise forming a data matrix, extracting chromatographs of a mud filtrate and a formation fluid, extracting concentration profiles of the mud filtrate and the formation fluid, and decomposing a data set on an information handling machine using a bilinear model. A system may comprise a downhole fluid sampling tool and an information handling tool. The downhole fluid sampling tool may comprise one or more multi-chamber sections, one or more fluid module sections, one or more gas chromatographers, wherein the one or more gas chromatographers are disposed in the one or more fluid module sections, and an information handling system.

Predicting contamination and clean fluid properties from downhole and wellsite gas chromatograms

A method and a system for determining fluid contamination. The method may comprise monitoring a fluid sample, wherein the fluid sample comprises a reservoir fluid contaminated with a well fluid, and obtaining input parameters, wherein the input parameters comprise fluid properties obtained from measurement of the fluid sample and mud filtrate composition. The method may further comprise representing a mud composition as a Gaussian distribution, selecting a plurality of input data during a pumpout, determining calculated fluid properties of the reservoir fluid using an equation of state filtrate analysis, and further obtaining updated vales of iterative parameters for use in a mole fraction distribution function. The system may comprise a downhole fluid sampling tool operable to obtain fluid samples of a reservoir fluid contaminated with a well fluid while the downhole fluid sampling tool is disposed in a wellbore, and a processor.

Drilling fluid contamination determination for downhole fluid sampling tool

A method and system for estimating clean fluid composition and properties. A method may comprise disposing a downhole fluid sampling tool into a wellbore, wherein the downhole fluid sampling tool comprises optical instrumentation, obtaining a fluid sample with the downhole fluid sampling tool, wherein the fluid sample comprises a reservoir fluid contaminated with a well fluid, identifying input parameters from at least one sensor response on the optical instrumentation, and predicting a clean fluid sample of the reservoir fluid using an asymptote of a dimensional reduction analysis and equation of state. A system may comprise a downhole fluid sampling tool and a processing unit. The downhole fluid sampling tool may further comprise an optical instrumentation operable to obtain fluid samples of a reservoir fluid contaminated with a well fluid while the downhole fluid sampling tool is disposed in a wellbore.

Predicting clean fluid composition and properties with a rapid formation tester pumpout

A method may comprise positioning a downhole fluid sampling tool into a wellbore; performing a pressure test operation within the wellbore; performing a pumpout operation within the wellbore; identifying one or more formation parameters at least in part from the at least one pressure test operation or the at least one pumpout operation; building a correlation model that relates a pumpout trend to the one or more formation parameters; determining a time when the downhole fluid sampling tool takes a clean fluid sample utilizing at least the correlation model; and acquiring the clean fluid sample with the downhole fluid sampling tool from the wellbore. Additionally, a system may comprise a downhole fluid sampling tool configured to: perform a pressure test operation within a wellbore; and perform a pumpout operation within the wellbore.

Contamination prediction of downhole pumpout and sampling

A thermal sensor module, comprising: a housing, wherein the housing comprises a first end and a second end, wherein the housing is hollow and configured to allow a fluid to flow into the housing through the first end and exit through the second end; a heat source, wherein the heat source is disposed at a central axis of the housing and traverses at least partially through the housing; and a temperature sensor, wherein the temperature sensor is positioned in the housing to measure temperature of the fluid flowing in the housing.

Sensor to measure thermal conductivity and heat capacity of reservoir fluids

A method may comprise positioning a downhole fluid sampling tool into a wellbore, performing a pressure test operation within the wellbore, performing a pumpout operation within the wellbore, identifying when a clean fluid sample may be taken by the downhole fluid sampling tool from at least the pressure test operation and the pumpout operation, and acquiring the clean fluid sample from the wellbore. A system may comprise a downhole fluid sampling tool and an information handling machine. The downhole fluid sampling tool may further comprise one or more probes attached to the downhole fluid sampling tool, one or more stabilizers attached to the downhole fluid sampling tool, and a sensor placed in the downhole fluid sampling tool configured to measure drilling fluid filtrate.

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Richmond, TX, United States of America

Peter Ojo Olapade