Abstract: A method can include receiving seismic survey data of a subsurface environment from a seismic survey that includes a source arrangement of sources that is spatially denser than a receiver arrangement of receivers; processing the seismic survey data using the principle of reciprocity for performing interpolation across the receivers to generate processed seismic survey data; and generating an image of at least a portion of the subsurface environment using the processed seismic survey data.

Abstract: A method includes acquiring seismic data of a region that utilizes multiple seismic energy sources and seismic energy receivers where the seismic data include blended seismic data for a number of emissions from a corresponding number of the multiple seismic energy sources; determining spatially distributed coherent noise properties for the region using the blended seismic data; via the spatially distributed coherent noise properties, modeling coherent noise as at least two coherent noise models for at least two of the emissions from a corresponding at least two of the multiple seismic energy sources; via the coherent noise models, attenuating coherent noise in a portion of the blended seismic data to generate coherent noise attenuated blended seismic data; deblending the coherent noise attenuated blended seismic data to generate deblended seismic data; and rendering an image of at least a portion of the region to a display using the deblended seismic data.

Abstract: 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.

Abstract: A method can include receiving information associated with an interface between a first medium and a second medium where the information includes sensor data; based on at least a portion of the information, estimating wave properties that include elastic properties, depth-dependent properties and horizontal slowness; and, based on the estimated wave properties, calculating an orientation of a sensor utilized to acquire at least a portion of the sensor data.

Abstract: A method includes acquiring seismic data of a region that utilizes multiple seismic energy sources and seismic energy receivers where the seismic data include blended seismic data for a number of emissions from a corresponding number of the multiple seismic energy sources; determining spatially distributed coherent noise properties for the region using the blended seismic data; via the spatially distributed coherent noise properties, modeling coherent noise as at least two coherent noise models for at least two of the emissions from a corresponding at least two of the multiple seismic energy sources; via the coherent noise models, attenuating coherent noise in a portion of the blended seismic data to generate coherent noise attenuated blended seismic data; deblending the coherent noise attenuated blended seismic data to generate deblended seismic data; and rendering an image of at least a portion of the region to a display using the deblended seismic data.

Abstract: 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.

Abstract: Systems, methods, and media for modeling and filtering noise in seismic surveys are disclosed. Methods, systems, and computer program products in accordance with the present disclosure perform operations including obtaining seismic information of a region resulting from a source waveform applied to the region. The operations also include obtaining an estimate of visco-elastic properties of a near-surface of the region. The operations further include determining an estimate of propagation of guided waves in the region based on the estimate of visco-elastic properties of a near-surface of the region. Additionally, the operations include determining a model of the guided waves in the near-surface of the region using the estimate of propagation of the guided waves and an estimate of the source waveform. Moreover the operations include determining a filtered output of the seismic information by removing the model of the guided waves from the seismic information.

Abstract: A method can include receiving information associated with an interface between a first medium and a second medium where the information includes sensor data; based on at least a portion of the information, estimating wave properties that include elastic properties, depth-dependent properties and horizontal slowness; and, based on the estimated wave properties, calculating an orientation of a sensor utilized to acquire at least a portion of the sensor data.

Abstract: Systems, methods, and media for modeling and filtering noise in seismic surveys are disclosed. Methods, systems, and computer program products in accordance with the present disclosure perform operations including obtaining seismic information of a region resulting from a source waveform applied to the region. The operations also include obtaining an estimate of visco-elastic properties of a near-surface of the region. The operations further include determining an estimate of propagation of guided waves in the region based on the estimate of visco-elastic properties of a near-surface of the region. Additionally, the operations include determining a model of the guided waves in the near-surface of the region using the estimate of propagation of the guided waves and an estimate of the source waveform. Moreover the operations include determining a filtered output of the seismic information by removing the model of the guided waves from the seismic information.

Abstract: Various implementations described herein are directed to methods for processing seismic data. The methods may include generating a computer-generated synthetic coherent noise model using a first seismic dataset that had been acquired with seismic sensors in a base seismic survey. The methods may include modifying a second seismic dataset that had been acquired in a repeat seismic survey using the computer-generated synthetic coherent noise model to generate a modified second seismic dataset having reduced coherent noise.