Basin-wide modeling is utilized to improve confidence of source rock presence and quality estimation. A 4D basin model incorporates geological model, geochemical models, and resettlement model for a region. Utilizing the 4D basin model provides consistency of internal data, geology-constrained basin-wide calculations, capability to capture local controls to allow basin-specific interpretations, reduction of reliance on empirical relationships, and capability to investigate source rock development through time.

The disclosure generally relates to devices and techniques for operating an electronic apparatus that controls a sensor, the devices and techniques including acquiring first sensing data through the sensor, identifying a data variation based on the first sensing data and sensing data for a first time point and a second time point acquired in advance based on a sampling period of the sensor, identifying target data among a plurality of predetermined meaningful data based on the identified data variation and determining a time point at which the target data is to be acquired, and controlling the sampling period based on the determined time point.

Receiver-consistent scalars of seismic receiver channels are used for time-lapse monitoring of a sub-surface earth formation. Signals are induced by seismic waves propagating through the earth formation adjacent to each respective seismic receiver channel. Each seismic receiver channel is acoustically coupled to the earth formation as present directly adjacent to the location of the seismic receiver channel in question. The base receiver-consistent scalars and the monitor receiver-consistent scalars of seismic receiver channels can be outputted to reveal changes in these receiver-consistent scalars. These changes can be used to delineate information about physical changes in the subsurface earth formation. The changes in the based receiver-consistent scalars and the monitor receiver-consistent scalars may be displayed visually.

A method of determining fracture complexity may comprise receiving one or more signal inputs from a fracturing operation, calculating an observed fracture growth rate based at least partially on the one or more signal inputs, calculating a predicted fracture growth rate, determining a fracture complexity value, and applying a control technique to make adjustments a hydraulic stimulation operation based at least in part on the fracture complexity value. Also provided is a system for determining a fracture complexity for a hydraulic fracturing operation may comprise a hydraulic fracturing system, a sensor unit to receive one or more signal inputs, a calculating unit, a fracture complexity unit, and a controller unit to apply a control technique to adjust one or more hydraulic stimulation parameters on the hydraulic fracturing system.

The invention notably relates to a computer-implemented method for processing a 4D seismic signal relative to a subsoil, the subsoil including a zone subject to extraction and/or injection, the method comprising: providing the 4D seismic signal; identifying a part of the 4D seismic signal corresponding to a zone of the subsoil distinct from the zone subject to extraction and/or injection; determining a noise model of the 4D seismic signal based on the identified part of the 4D seismic signal; and processing the 4D seismic signal based on the noise model. This improves the field of 4D seismic data processing.

There is disclosed a system and method for analyzing geological features of a reservoir, such as a subterranean hydrocarbon reservoir undergoing changes during different stages of its production, by utilizing an artificial neural network to learn from hydrocarbon reservoir production project. In an aspect, there is provide a system and method for utilizing data collected from 4D seismic studies in order to train an artificial neural network to recognize how physical properties of a hydrocarbon reservoir change over time, as the hydrocarbon reservoir is produced. In an embodiment, the system and method are adapted to generate and obtain a plurality of image slices or image planes derived from a 3D seismic baseline and at least one monitor acquired over the course production of the hydrocarbon reservoir. Corresponding 2D image slices derived from the 3D seismic baseline and a subsequent monitor are correlated and matched and are then used to train an artificial neural network to create a predictive model of how the reservoir may change over time.

Provided are techniques for developing a hydrocarbon reservoir that include: determining a reservoir model of a hydrocarbon reservoir that includes columns of gridblocks that represent a vertical segment of the reservoir; acquiring nano-images of a rock sample of the reservoir; determining, based on the nano-images, properties of an inorganic pore network and an organic pore network of the rock sample; generating a divided reservoir model of the reservoir that represents the inorganic and organic pore networks of the reservoir, including: for each of the columns of gridblocks, dividing each of the gridblocks of the column into: a water-wet gridblock associated with the properties of the inorganic pore network determined based on the nano-images; and an oil-wet gridblock associated with the properties of the organic pore network determined based on the nano-images; and generating, using the divided reservoir model, a simulation of the hydrocarbon reservoir.

Systems and methods for estimating reservoir productivity as a function of depth in a subsurface volume of interest are disclosed. Exemplary implementations may: obtain subsurface data and well data corresponding to a subsurface volume of interest; obtain a parameter model; use the subsurface data and the well data to generate multiple production parameter maps; apply the parameter model to the multiple production parameter maps to generate refined production parameter values; generate multiple refined production parameter graphs; display the multiple refined production parameter graphs; generate one or more user input options; receive the one or more user input options selected by a user to generate limited production parameter values; generate a representation of estimated reservoir productivity as a function of depth in the subsurface volume of interest using visual effects; and display the representation.

Exemplary implementations may: obtain, from the electronic storage, geological data corresponding to the geographic volume of interest; generate a framework for sediment deposition using a first set of multiple physical, chemical, biological, and geological processes; generate a framework for diagenesis using a second set of multiple physical, chemical, biological, and geological processes; generate a representation of sediment deposition by applying the geological data corresponding to the geographic volume of interest to the framework for sediment deposition; generate a representation of diagenesis based on the framework for diagenesis and the representation of sediment deposition; and display the representation of sediment deposition and the representation of diagenesis on a graphical user interface.

A method of mapping reservoir fluid in a mature field includes identifying a region of interest within a hydrocarbon field, drilling a plurality of production wells through the region of interest, and collecting mud gas data as each production well is drilled. This mud gas data is used to generate a reservoir fluid property log, such as gas-oil ratio log, along a length of each of the production wells, which is in turn used to generate a refined model based on the 4D seismic data. The refined model permits better reservoir fluid mapping and has an improved vertical resolution at the region of interest than the first model of the field.