The present invention provides a seismic signal processing method, device and system. The method comprises: obtaining an offset of a reflected seismic signal at a sampling point and the corresponding reflected wave arrival time; constructing a non-hyperbolic dynamic correction formula based on Pade approximation according to the offset of the reflected seismic signal at the sampling point and the corresponding reflected wave arrival time; extracting a vertical propagation velocity and anisotropy parameters of the reflected seismic signal according to the non-hyperbolic dynamic correction formula constructed based on Pade approximation.

An acoustic logging method includes obtaining first horizontal transverse isotropy (“HTI”) angles resulting from a time domain HTI algorithm. The method further includes obtaining one or more second HTI angles resulting from a frequency domain HTI algorithm. The method further includes generating a first HTI anisotropy log including a relative angle log based on the first and second HTI angles. The method further includes generating a first color map of the first HTI anisotropy log and displaying the first color map.

A method includes receiving information for a subsurface region; based at least in part on the information, identifying sub-regions within the subsurface region; assigning individual identified sub-regions a dimensionality of a plurality of different dimensionalities that correspond to a plurality of different models; via a model-based computational framework, generating at least one result for at least one of the individual identified sub-regions based at least in part on at least one assigned dimensionality; and consolidating the at least one result for multiple sub-regions.

A system and a method for producing an anisotropic velocity model. Vertical seismic profile (VSP) data is obtained for a geological area. At least two stiffness coefficients in a fourth-rank elasticity stiffness tensor are calculated based on p-wave and s-wave velocities determined using the VSP data. Microseismic profile data for the geological area is obtained and all remaining unknown stiffness coefficients in the fourth-rank elasticity stiffness tensor are calculated using the microseismic profile data.

A technique facilitates estimating elastic properties of formations by exciting a wavefield and acquiring the signal with and without azimuthal decompositions. For example, the elastic properties may be estimated by exciting a multipole wavefield and acquiring the signal with and without the azimuthal decomposition. The technique is effective for estimating elastic properties of azimuthally homogeneous and heterogeneous formations including isotropic and anisotropic formations.

A fracture simulation system is provided to determine anisotropic effective permeability of rock formations having natural fractures therein.

Disclosed is a method of characterising a subsurface volume. The method comprises: extracting a geobody from seismic data arranged within a discretised volume comprising a plurality of cells, the geobody comprising a subset of the plurality of cells, each cell of the subset having one or more properties indicative of a particular fluid phase. The extraction of the geobody comprises: determining a propagation probability value for each cell indicative of the probability that a front will propagate through the cell; beginning from a source within the discretised volume, using the propagation probability value to calculate a travel-time for each cell, the travel time describing the time the front takes to travel from the source point to the cell; and using the traveltimes to extract the geobody from the seismic data.

The orientation of the symmetry axis of an underground formation including an HTI layer is determined by comparing azimuthal Fourier coefficient of inversion results in distinct source-receiver azimuth ranges with values expected from the HTI assumption. A branch-stacking technique or prior knowledge may be used to select one of the anisotropy axis orientation values.

A portion of an anisotropy formation through which a wellbore is formed can be identified. An estimate of an elastic anisotropy parameter for the portion can be adjusted based on a first quality control analysis using the elastic anisotropy parameter for the portion. The first signal representing the elastic anisotropy parameter for the portion. The estimate of the elastic anisotropy parameter for the portion can be adjusted based on a second quality control analysis using estimates for the elastic anisotropy parameters for two or more portions of the anisotropy formation.

Various embodiments include apparatus and methods to operate to record a plurality of acoustic waveforms, to generate an objective function based on the plurality of acoustic waveforms, and to estimate a global minimum of the objective function. The plurality of acoustic waveforms can correspond to a plurality of acoustic dipole receivers azimuthally disposed around a tool to which the receivers are attached. Additional apparatus, systems, and methods are disclosed.