A method for seismic processing includes receiving seismic data representing a subsurface volume. The seismic data includes a first horizontal component and a second horizontal component. The first and second horizontal components are rotated such that the first horizontal component is substantially aligned with a source of a seismic wavefield and the second horizontal component is substantially transverse to the source of the seismic wavefield. A splitting intensity is determined at a boundary of the subsurface volume using the first and second horizontal components after the first and second horizontal components are rotated. An anisotropic parameter is determined for a portion of the subsurface volume as a function of time using the splitting intensity.

Near real-time methodologies for maximizing return-on-fracturing-investment for shale fracturing. An example system can calculate, based on sonic data and density data, mechanical properties and closure stress of a portion of shale rocks for fracture modeling. The system can generate one or more rock mechanical models based on the mechanical properties and closure stress of the portion of shale rocks, and perform one or more fracture modeling simulations based on one or more treatment parameter values. Based on the one or more fracture modeling simulations, the system can generate a neural network model which predicts a fracture productivity indicator of an effective propped area (EPA) and/or an effective propped length (EPL), and calculate a return-on-fracturing-investment (ROFI) based on the EPA or EPL predicted by the neural network model.

Methods and devices for seismic exploration of an underground formation including an orthorhombic anisotropic medium or a tilted transverse isotropic medium are provided. Isotropic-type processing techniques use effective elastic parameter values calculated based on elastic parameter values, anisotropy parameter values and azimuth angle values for the orthorhombic anisotropic medium. For the tilted transverse isotropic medium, the effective elastic parameter values depend also on the tilt angle thereof.

Methods and apparatuses for processing seismic data acquired with multicomponent sensors build an accurate S-wave velocity model of a surveyed underground formation using a full waveform inversion (FWI) approach. PS synthetic data is generated using approximative acoustic equations in anisotropic media with a P-wave model, a current S-wave velocity model and a reflectivity model as inputs. The current S-wave velocity model is updated using FWI to minimize an amplitude-discrepancy-mitigating cost function that alleviates the amplitude mismatch between the PS observed data and the PS synthetic data due to the use of the approximative acoustic equations.

Systems and methods for estimating orthorhombic anisotropy parameters of subsurface rock layers are provided. An initial three-dimensional (3D) model of layers in a subsurface formation is generated. Particular combinations of seismic source and receiver locations associated with a vertical seismic profile (VSP) survey of the formation are selected based on a simulation of seismic wave propagation through each layer of the initial 3D model. A global inversion is performed using data points selected from travel time data associated with the VSP survey in order to estimate different sets of anisotropy parameters for the layers of the initial 3D model, where the selected data points correspond to the selected source-receiver combinations. The initial 3D model is refined with an optimal set of anisotropy parameters selected from the estimated parameter sets. The refined 3D model is provided for seismic analysis and well planning operations to be performed for the subsurface formation.

A method for seismic processing includes receiving seismic data representing a subsurface volume. The seismic data includes a first horizontal component and a second horizontal component. The first and second horizontal components are rotated such that the first horizontal component is substantially aligned with a source of a seismic wavefield and the second horizontal component is substantially transverse to the source of the seismic wavefield. A splitting intensity is determined at a boundary of the subsurface volume using the first and second horizontal components after the first and second horizontal components are rotated. An anisotropic parameter is determined for a portion of the subsurface volume as a function of time using the splitting intensity.

Systems and methods that include receiving reservoir data of a hydrocarbon reservoir, receive an indication related to selection of a wavefield propagator, application of the wavefield propagator utilizing Fourier Finite Transforms and Finite Differences to model a wavefield associated with a Tilted Orthorhombic media representative of a region of a subsurface comprising the hydrocarbon reservoir, and processing the reservoir data in conjunction the wavefield propagator to generate an output for use with seismic exploration above a region of a subsurface comprising the hydrocarbon reservoir and containing structural or stratigraphic features conducive to a presence, migration, or accumulation of hydrocarbons.

Fracture orientation ambiguity in the results of amplitude variation with offset and azimuth inversion is overcome by using additional geological information. Methods, apparatus and executable codes stored on non-transitory media cause, for each interface encountered by traces in a CMP gather, calculating angle-dependent azimuthal Fourier coefficients, performing a nonlinear inversion of amplitude versus offset and azimuth, AVOAz, equations built using the angle-dependent azimuthal Fourier coefficients to determine possible fracture orientations, and selecting one of the possible fracture orientations using constraints based on the additional geological information.

Example computer-implemented method, computer-readable media, and computer system are described for generating subterranean imaging data based on initial isotropic and/or anisotropic velocity models for the vertical seismic profile (VSP) data and stored ocean bottom sensor (OBS) data. In some aspects, VSP data and OBS data of a subterranean region are received. Angle attributes for each image point are computed to image primary reflection and free surface multiples of the received VSP data and OBS data, respectively. Angle-domain common-image gathers (ADCIG) are generated according to a ray-equation method based on the angle attributes computed based on the received VSP data and OBS data, respectively. The ADCIG are further post-processed.

A horizontal component of marine seismic survey data from an ocean bottom seismic survey can be migrated using a primary wave velocity model. The horizontal component can comprise a shear converted wave. An image of a subsurface location can based on the migration can be produced. Migrating the horizontal component can comprise wave-equation migrating the horizontal component, where the horizontal component is input as both a source wavefield and a receiver wavefield.