Abstract: A method includes receiving a well log having a signal. The method also includes identifying in the signal a first change point that demarcates a first signal region and a second signal region. The method also includes determining that the first signal region is inconsistent in comparison to the second signal region. The method also includes producing a modified well log by removing the first signal region from the signal in response to determining that the first signal region is inconsistent in comparison to the second signal region.

Abstract: A method includes determining a search window in a target well. The method also includes identifying one or more reference wells based at least partially upon a location of the target well. The method also includes predicting a plurality of locations of a target well marker in the target well based at least partially upon the one or more reference wells. The locations of the target well marker are within the search window. The method also includes determining similarity values for the locations of the target well marker. The method also includes assigning the target well marker to at least one of the locations based at least partially upon the similarity values.

Abstract: Methods and systems for augmented geological service characterization are described. An embodiment of a method includes generating a geological service characterization process in response to one or more geological service objectives and a geological service experience information set. Such a method may also include augmenting the geological service characterization process by machine learning in response to a training information set. Additionally, the method may include generating an augmented geological service characterization process in response to the determination information.

Abstract: Methods and systems for augmented geological service characterization are described. An embodiment of a method includes generating a geological service characterization process in response to one or more geological service objectives and a geological service experience information set. Such a method may also include augmenting the geological service characterization process by machine learning in response to a training information set. Additionally, the method may include generating an augmented geological service characterization process in response to the determination information.

Abstract: A method, apparatus, and program product may evaluate a field by receiving a dataset including well measurements collected from a plurality of wells in a field, generating a synthetic dataset from the received dataset by computing a plurality of synthetic samples from the received dataset using a self-organized may (SOM), and propagating one or more models generated from the synthetic dataset to the plurality of wells.

Abstract: A method for includes obtaining a well log comprising a sequence of measurements of a wellbore in a field, and generating change points in the well log based on the sequence of measurements. Each of the change points corresponds to a depth along the wellbore where a probability distribution of the well log changes. The method further includes generating a statistic for each of multiple intervals in the well log, where the intervals are defined by the plurality of change points, categorizing the intervals based on the statistic for each of the intervals to generate categorized intervals, and performing the operation based on the categorized intervals.

Abstract: A method for modelling saturation in a reservoir, comprising: obtaining capillary pressure data representing capillary pressure in the reservoir; obtaining permeability data representing permeability in the reservoir; determining a number of pore throats represented by the capillary pressure data; creating hyperbolic tangents based on the capillary pressure data equal in number to the number of pore throats; combining hyperbolic tangents to create a curve to fit the capillary pressure data and to define hyperbolic tangent parameters; combining at least one of the hyperbolic tangent parameters with the permeability data to define a saturation height function; modelling a saturation in the reservoir using the saturation height function; and displaying the saturation model based on the saturation height function.

Abstract: A system and method for correcting capillary pressure curves includes creating a capillary pressure curve using multiple linked hyperbolic tangents, determining a closure correction pressure cutoff of the capillary pressure curve, and correcting the capillary pressure curve. The correction may include normalizing the capillary pressure curve and extrapolating the capillary pressure curve.

Abstract: Computing systems, computer-readable media, and methods interpreting well logs, of which the method includes receiving data that comprises one or more well logs acquired using a tool disposed at a plurality of depths 423 in a bore in a subterranean environment, partitioning the data into segments, the individual segments containing data points, representing the segments as representative points in a parameter domain, determining reachability distances for the representative points in the parameter domain, initializing a cluster based on the reachability distances, identifying one or more segments as part of the cluster, and determining a physical feature represented in the one or more well logs based on the cluster.

Abstract: Systems, media, and methods for determining relative geochemical data are provided. Measurement data may be received that is indicative of relative yields of a plurality of chemical components in a rock formation. First absolute yields of at least a portion of the plurality of chemical components in a presence of 100% of a first volumetric component in the rock formation may be determined. Second absolute yields of at least a portion of the plurality of chemical components in a presence of 100% of a second volumetric component in the rock formation may also be determined. A volume of the first volumetric component, a volume of the second volumetric component, and a sum of yields of the plurality of chemical components may be determined using the first and second absolute yields and the relative yields.

Abstract: Methods, systems, and computer-readable media for assessing porosity and water saturation cutoff values for hydrocarbon volume estimation are described. The techniques can include determining a plurality of water saturation and porosity value pairs for locations regularly-spaced along at least one borehole. The techniques can further include plotting the plurality of water saturation and porosity value pairs on a graph and representing a plurality of percentiles of the estimated maximal hydrocarbon volume on the graph. The techniques can also include causing the graph to be displayed to a user, such that the user can visually observe a combined sensitivity to porosity and water saturation cutoffs values. The user can take various actions based on the display.

Abstract: Systems, methods, and media for processing formation pressure test data are provided. The method includes determining using a processor, a plurality of regressions for measurements of the formation pressure test data, and determining that two or more of the plurality of regressions represent a fluid code. The method also includes combining the two or more of the plurality of regressions representing the fluid code to generate a first fluid-type regression, and combining two or more other ones of the plurality of regressions representing a second fluid code to generate a second fluid-type regression. The method further includes determining that the first fluid-type regression and the second fluid-type regression are in a first hydraulic zone, and calculating a location of a boundary between the first fluid-type regression and the second fluid-type regression by extrapolating the first and second fluid-type regressions to a point of intersection therebetween.

Abstract: Methods and systems for augmented geological service characterization are described. An embodiment of a method includes generating a geological service characterization process in response to one or more geological service objectives and a geological service experience information set. Such a method may also include augmenting the geological service characterization process by machine learning in response to a training information set. Additionally, the method may include generating an augmented geological service characterization process in response to the determination information.

Abstract: A method, apparatus, and program product may evaluate a field by receiving a dataset including well measurements collected from a plurality of wells in a field, generating a synthetic dataset from the received dataset by computing a plurality of synthetic samples from the received dataset using a self-organized may (SOM), and propagating one or more models generated from the synthetic dataset to the plurality of wells.

Abstract: A method for includes obtaining a well log comprising a sequence of measurements of a wellbore in a field, and generating change points in the well log based on the sequence of measurements. Each of the change points corresponds to a depth along the wellbore where a probability distribution of the well log changes. The method further includes generating a statistic for each of multiple intervals in the well log, where the intervals are defined by the plurality of change points, categorizing the intervals based on the statistic for each of the intervals to generate categorized intervals, and performing the operation based on the categorized intervals.

Abstract: A system and method for correcting capillary pressure curves includes creating a capillary pressure curve using multiple linked hyperbolic tangents, determining a closure correction pressure cutoff of the capillary pressure curve, and correcting the capillary pressure curve. The correction may include normalizing the capillary pressure curve and extrapolating the capillary pressure curve.

Abstract: A method for modelling saturation in a reservoir, comprising: obtaining capillary pressure data representing capillary pressure in the reservoir; obtaining permeability data representing permeability in the reservoir; determining a number of pore throats represented by the capillary pressure data; creating hyperbolic tangents based on the capillary pressure data equal in number to the number of pore throats; combining hyperbolic tangents to create a curve to fit the capillary pressure data and to define hyperbolic tangent parameters; combining at least one of the hyperbolic tangent parameters with the permeability data to define a saturation height function; modelling a saturation in the reservoir using the saturation height function; and displaying the saturation model based on the saturation height function.

Abstract: A method and system for modeling saturation in a reservoir that includes obtaining capillary pressure data representing capillary pressure in a reservoir, obtaining permeability data representing permeability in the reservoir, determining a number of pore throats represented by the capillary pressure data, creating a set of hyperbolic tangents equal in number to the number of pore throats, combining the set of hyperbolic tangents to create a curve to fit the capillary pressure data and to define a set of hyperbolic tangent parameters, combining at least one of the hyperbolic tangent parameters with the permeability data to define a saturation height function, modeling USER a saturation in the reservoir using the saturation height function, and displaying the saturation model based on the saturation height function.

Abstract: Methods, systems, and computer-readable media for assessing porosity and water saturation cutoff values for hydrocarbon volume estimation are described. The techniques can include determining a plurality of water saturation and porosity value pairs for locations regularly-spaced along at least one borehole. The techniques can further include plotting the plurality of water satoration and porosity value pairs on a graph and representing a plurality of percentiles of the estimated maximal hydrocarbon volume on the graph. The techniques can also include causing the graph to be displayed to a user, such that the user can visually observe a combined sensitivity to porosity and water saturation cutoffs values. The user can take various actions based on the display.

Abstract: A method having obtaining one or more porosity data of a subsurface of the Earth using a data acquisition tool; computing one or more permeability data from the porosity data using a transformation function; computing a first quantile regression function and a second quantile regression function of the one or more permeability data; producing a combined mean regression function of the one or more permeability data by summing the first quantile regression function and the second quantile regression function, wherein the first quantile regression function is multiplied by a first coefficient and the second quantile regression function is multiplied by a second coefficient; and using the combined mean regression function to predict a mean permeability of the subsurface.