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.

A fiber optic distributed sensing system for installation within a wellbore is provided. The system includes a first set of downhole sensors having one or more nuclear sensors with nuclear field sensitivity. The system additionally includes, a second set of downhole sensors having one or more ElectroMagnetic (EM) sensors with electromagnetic field sensitivity. The fiber optic distributed sensing system also includes a processor system configured to receive data measurements from the first and second sets of sensors and configured to conjointly process the data measurements into representations of physical attributes of the wellbore.

Aspects of the subject technology relate to systems, methods, and computer-readable media for synthesizing sonic logs for downhole environments. Data associated with a wellbore in a formation is accessed. A model configured to identify one or more characteristics associated with sound traveling through one or more formation is accessed. The data is applied to the model to predict a characteristics of the formation that is identifiable through sonic logging.

A method includes acquiring measurement values from at least two different types of downhole tools disposed in a portion of a bore in a formation; selecting formation parameters for joint inversion; building a near-bore fluid flow model of at least a portion of the formation that includes at least the portion of the bore; simulating fluid flow based at least in part on the near-bore fluid flow model and the selected formation parameters to generate simulated measurement values; comparing the acquired measurement values and the simulated measurement values; based at least in part on the comparing, revising at least one of the selected formation parameters to generate revised formation parameters and simulating fluid flow based at least in part on the near-bore fluid flow model and the revised formation parameters to generate revised simulated measurement values; and outputting at least the revised formation parameters to characterize the formation.