ARAMCO SERVICES COMPANY

Systems and methods are disclosed. The method may include receiving observed seismic data, and a first and a second seismic velocity model, each pertaining to a subterranean region of interest and, iteratively, determining synthetic reflection data based on the first and second seismic velocity model, determining traveltime shift data between the synthetic observed seismic data, and determining warped observed seismic data by applying the traveltime shift data to the observed seismic data. The method further includes determining conditioned traveltime shift data using local similarity based on shaping regularization from the synthetic reflection data, the warped observed seismic data, and the traveltime shift data, and determining a seismic velocity model based on the first seismic velocity model and the conditioned traveltime shift data. The method also includes determining a seismic image from observed seismic data and the seismic velocity model, and a location of a hydrocarbon reservoir using the seismic image.

A method for determining descriptors associated with borehole images. The method includes obtaining N≥1 borehole images, where N is an integer, and locating, in each borehole image within the N borehole images, one or more geological features associated with the borehole image. The method further includes determining, for each borehole image within the N borehole images, one or more descriptors associated with the borehole image, where each descriptor of the one or more descriptors includes an optimum polygon enclosing a geological feature of the one or more geological features associated with the borehole image.

Reservoir simulation is performed by constructing an embedded discrete fracture model (EDFM) having matrix grid cells and extra continuum grid cells in the simulation grid. The EDFM is integrated into a multi-porosity-multi-permeability (MPMP) framework of a parallel reservoir simulator. Each fracture polygon of the fractures in the reservoir is divided into a set of fracture cells for calculating matrix-fracture connections and fracture-fracture connections, which are all neighbor connections between grid cells that are face or edge neighbors. These neighbor connections may be intra-continuum connections or inter-continua connections that are stored in the matrix grid cells and/or fracture grid cells in the integrated EDFM/MPMP framework. The reservoir simulation is performed by the parallel reservoir simulator based on the cell connectivity data in the integrated EDFM/MPMP framework to facilitate well production of the reservoir.

Various systems and methods are discussed for characterizing well properties. As one of many non-limiting examples, a well property system is discussed that includes a sensor set, a logging system, an archive conversion system, and a well property prediction system. Each of the aforementioned components and systems may be configured to sense and/or operate on pressure, volume, and temperature data from at least one location at a well site.

Methods and systems are disclosed. The methods may include obtaining vertical seismic profile (VSP) data and a seismic velocity model for a subterranean region of interest and determining, using the seismic velocity model and reverse time migration, a pre-stacked migrated seismic image based on the VSP data. The pre-stacked migrated seismic image includes seismic slices. The methods may further include, for each of the seismic slices in turn, determining a coherency map, determining a weighting map based on the coherency map, and determining a corrected seismic slice by applying the weighting map to each of the seismic slices. The methods may still further include determining a post-stacked corrected migrated seismic image based on the corrected seismic slices and determining a location of a geological feature within the subterranean region of interest based, at least in part, on the post-stacked corrected migrated seismic image.

A system for enhancing traveltime information in a seismic dataset and determining a velocity model. The system includes a first initial velocity model, a forward modelling procedure, a machine-learned model, a drilling system with a wellbore planning system, and a computer. The computer is configured to: receive a non-synthetic seismic data set for a subsurface region of interest; perturb the first initial velocity model forming a first plurality of velocity models; simulate, with the forward modelling procedure, a first plurality of seismic data sets; form a first plurality of transformed seismic data sets with enhanced traveltime; train the machine-learned model using the first plurality of velocity models and the first plurality of transformed seismic data sets; transform the non-synthetic seismic data set to a non-synthetic transformed seismic data set; and process the non-synthetic seismic data set with the trained machine-learned model to predict a velocity model for the subsurface region.

A method for analyzing rock cores of a subterranean formation is disclosed. The method includes capturing core images of the rock cores that are collected from geographical locations in the subterranean formation, generating, by a computer processor and from the core images, sub-images by sub-dividing each of the core images, classifying, using a secondary machine learning model that automatically identifies artifacts induced from preparation of the rock cores, the sub-images into artifact-free sub-images and artifact-containing sub-images, and analyzing, using a primary machine learning model, the artifact-free sub-images to generate a core analysis result.

Examples of methods and systems are disclosed. The methods may include obtaining a seismic data regarding a subsurface region of interest, wherein the seismic data comprises a plurality of time-space waveforms. The methods may also include obtaining a seismic velocity model. The methods may further include determining a migrated seismic image based on the plurality of time-space waveforms and the seismic velocity model. The method may still further include generating a filtered seismic image by applying a depth-dependent attenuation operator to the migrated seismic image and determining a drilling target in the subsurface region based on the filtered seismic image.

Systems and methods are presented for determining a calibrated vertical seismic profile (VSP) with a distributed acoustic sensing (DAS) system in a borehole. The methods include obtaining a density log and an acoustic slowness log for the borehole; determining a first impedance, a DAS impedance from well log (DIL) curve, from the density log and the acoustic slowness log; obtaining a VSP dataset in the borehole; for each of the plurality of gauge lengths: determining a second impedance, a DAS from vibrations (DIV) curve, from the VSP dataset for the plurality of gauge lengths, and determining a fit between the DIV curves and the DIL curve by using a misfit functional for each of a plurality of depth adjustments. The method further includes determining the calibrated VSP by applying a preferred depth adjustment to the VSP dataset.

Examples of methods and systems are disclosed. The methods may include obtaining seismic data associated with a subsurface region of interest, wherein the seismic data comprises a plurality of time-space waveforms. The methods may also include determining a plurality of mechanical parameters corresponding to a formation of the subsurface region based, at least in part, on the plurality of time-space waveforms. The methods may further include generating a filtering region based on an artifact identified in the plurality of time-space waveforms. The methods may still further include determining a plurality of attenuation parameters based, at least in part, on the filtering region, the attenuation parameters being configured to attenuate the artifact. The methods may further include filtering the time-space waveforms to generate a plurality of filtered time-space waveforms. The method may still further include generating a seismic image of the subsurface region using the plurality of filtered time-space waveforms.