Schlumberger Technology Corporation

Carlos Maeso

Josselin Kherroubi

Daniel Quesada

Raphael Altman

Tarek M Habashy

Dzevat Omeragic

John C Rasmus

Jean-Christophe Auchere

Sofia N Davydycheva

Yong-Hua Chen

Alexis He

Isabelle M Dubourg

Valery Polyakov

Ana Escobar

Youssef Tamaazousti

Simone Di Santo

Raymond Kocian

Douglas Hupp

The disclosure relates to a method and system for downhole processing of data, such as images, including using a set of downhole sensors to measure parameters relative to the borehole at a plurality of depths and azimuths and detecting predetermined features of the borehole, using a downhole processor, with a trained machine-learning model and extracting characterization data, characterizing the shape and position of the predetermined features that are transmitted to the surface. It also provides a method and system for providing an image of a geological formation at the surface including transmitting a first dataset to the surface that will be used for reconstructing an image at the surface, downhole processing of a second dataset to detect predetermined features and extract characterization data that are transmitted at the surface and displaying a combined image comprising the predetermined features overlaid on the first image.

Methods for transmitting data acquired downhole by a downhole tool

Well log data may be used in well log operations by facilitating the identification of hydrogen carbon deposits. More specifically, the well log data may be used to generate visual representations. Aspects of the present disclosure relate to generating a color composite image based on multiple types of well log data and transforming the well log data into a color space. In further embodiments, the color composite image may be modified and/or objects within the color composite image may be identified.

Color composite geological image from well log measurements

In one embodiment, a computer-based method includes obtaining a borehole image deriving from a downhole tool in a borehole of a geological formation, performing dip picking on the borehole image to derive one or more structural dips, deriving a continuous structural dip based on the one or more structural dips, defining one or more locations of zone boundaries on the borehole image, deriving one or more zone boundaries based on the continuous structural dip and the one or more locations of zone boundaries, and defining one or more zones of the wellbore in a second image based on the one or more zone boundaries.

Method and system for dip picking and zonation of highly deviated well images

A method for determining a fracture aperture of a fracture aperture in a wellbore comprises measuring a resistivity of the wellbore with a downhole tool in a wellbore for obtaining an image of the wellbore. Based on the image, the method detects fractures in the wellbore, and calculates a fracture aperture of the detected fracture according to a predetermined model of the wellbore set up based on hypothesis relative to the configuration of the wellbore. Then, the method estimates a correction to the predetermined model when at least one of the hypothesis is not met, and determines an uncertainty range for the fracture aperture also using a measured parameter.

Method and apparatus for determining a fracture aperture in a wellbore

Embodiments of the disclosure involve a method comprising computing a true stratigraphic thickness ('TST') index based on one or more dynamic images, one or more measurement images, or combinations thereof. Computing the TST index comprises outputting a dynamic image value channel comprising a median value on each depth of the one or more dynamic images, a dynamic normalized image value channel comprising a normalization of the dynamic image value channel, a measurement image value channel comprising a median value on each depth of the measurement image, and the TST index. The method also involves computing a decomposition channel based on the TST, extracting lamination boundaries from the dynamic image value channel based on the decomposition channel, and computing the lamination properties based on the lamination boundaries.

Downhole imaging techniques using lamination analysis

A method for determining permeability of a subsurface formation includes measuring a parameter related to fluid content of the formation at a first time from within a wellbore penetrating the formation. A rate of entry of fluid from the wellbore into the formation is determined from the measurement of the parameter made at the first time. The permeability is determined from the rate of entry.

Method for estimating formation permeability using time lapse measurements

LWD measurements to be used for proactive well placement while drilling a high angle or horizontal wellbore in a reservoir are defined. An initial reservoir model is provided and a section is extracted for a planned wellbore trajectory. A secondary model is generated for the planned trajectory. An area of interest is identified where statistical uncertainty is high. Possible causes of the statistical uncertainty are identified that are not present in the initial reservoir model. A set of parameters are defined based on the possible causes of statistical uncertainty. The area of interest is logged with LWD tool. Sensitivities of the LWD tool response to a subset of parameters are evaluated by performing tertiary model for a range of the subset of parameters. The most sensitive parameters from the subset of parameters and corresponding measurements are identified. LWD measurements are defined based on the most sensitive parameters.

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Clamart, France

Carlos Maeso