A method for estimating a far field seismic energy source signature includes using detected near field seismic signals corresponding to actuation of each one of a plurality of seismic energy sources in an array of seismic energy sources. The near field seismic signals are detected at two spaced apart locations in the near field of each seismic energy source, the at least two spaced apart locations being arranged such that a direction of propagation of the detected near field seismic signals is determinable from the detected near field signals. A notional source signature for each seismic energy source and a notional ghost for each seismic energy source using the detected near field seismic signals. A far field signature is determined for the plurality of seismic energy sources using the determined notional source signature and notional ghost signature from each seismic energy source.

A method for 2D seismic data acquisition includes determining source-point seismic survey positions for a combined deep profile seismic data acquisition with a shallow profile seismic data acquisition wherein the source-point positions are based on non-uniform optimal sampling. A seismic data set is acquired with a first set of air-guns optimized for a deep-data seismic profile and the data set is acquired with a second set of air-guns optimized for a shallow-data seismic profile. The data are de-blended to obtain a deep 2D seismic dataset and a shallow 2D seismic dataset.

A system and method for hydraulic fracturing and monitoring microseismic events related to hydraulic fracturing are described. One method describes a method of hydraulic fracturing gas production comprising drilling and casing a gas production well with a horizontal section within a formation layer, perforating the horizontal section of the well at a known location, and monitoring the resulting seismic waves using an array of geophones. Using the seismic waves resulting from the perforation shot, subsequent microseismic events may be located using a root mean square velocity and average velocity and without the use of a depth velocity model.

A method includes receiving seismic data including signals collected using a receiver, the seismic data representing a subsurface volume, identifying a downgoing wavefield and an upgoing wavefield in the seismic data, identifying direct arrivals in the downgoing wavefield, estimating at least first-order multiple reflection signals in the upgoing wavefield based on the downgoing wavefield, the upgoing wavefield, and the direct arrivals, and generating seismic images representing the subsurface volume based at least in part on the at least first-order multiple reflection signals.

The method comprises providing at least one seismic source in a seismic source area and providing a plurality of seismic receivers in said seismic source area, said method comprising measuring a first type of ground vibrations induced in a subsurface of the area of interest by the at least one seismic source with the plurality of seismic receivers. The method further comprises measuring with the plurality of seismic receivers at least one second type of ground vibrations induced by a mechanical source different from the or from each seismic source and analyzing the second type of ground vibrations to determine at least one information among: a physical parameter of the subsurface and/or, a presence of human and/or an animal and/or a vehicle.

A method and system for generating and displaying a low frequency model for a seismic survey region are provided. The method and system may include defining a seismic survey geometry of the seismic survey region; processing seismic data to generate a stacked seismic data and well log data to obtain elastic attributes; importing stacked seismic data and processed well log data into the defined seismic survey geometry; generating envelope data using the stacked seismic data; generating a low frequency trace for each well; calculating a least-squares optimized coefficient model at each well location based upon the generated envelope data and the low frequency trace for each well; interpolating the coefficient model to the seismic survey geometry using a covariance technique and the imported stacked seismic data; and generating a three-dimensional low frequency model by inversion using the envelope data and the interpolated coefficient model for display.

A method and apparatus for data acquisition including: acquiring a first set of data for a survey area with streamer receivers on a streamer spread; and simultaneously acquiring a second set of data for the area with ocean bottom receivers, the first and second sets of data together forming a complete dataset for velocity modeling and imaging. A method including: navigating a first propulsion source along a first path in the area, wherein a streamer spread and a first seismic source are coupled to the first propulsion source; navigating a second propulsion source along a second path in the area, wherein a second seismic source is coupled to the second propulsion source; while navigating the first and second propulsion sources, activating at least one of the first and second seismic sources; and acquiring data with receivers on the streamer spread and with ocean bottom receivers distributed throughout the area.

Methods and systems to separate seismic data associated with impulsive and non-impulsive sources are described. The impulsive and non-impulsive sources may be towed through a body of water by separate survey vessels. Receivers of one or more streamers towed through the body of water above a subterranean formation generate seismic data that represents a reflected wavefield produced by the subterranean formation in response to separate source wavefields generated by simultaneous activation of the impulsive source and the non-impulsive source. Methods and systems include separating the seismic data into impulsive source seismic data associated with the impulsive source and non-impulsive source seismic data associated with the non-impulsive.

A method and system for generating and displaying a low frequency model for a seismic survey region are provided. The method and system may include defining a seismic survey geometry of the seismic survey region; processing seismic data to generate a stacked seismic data and well log data to obtain elastic attributes; importing stacked seismic data and processed well log data into the defined seismic survey geometry; generating envelope data using the stacked seismic data; generating a low frequency trace for each well; calculating a least-squares optimized coefficient model at each well location based upon the generated envelope data and the low frequency trace for each well; interpolating the coefficient model to the seismic survey geometry using a covariance technique and the imported stacked seismic data; and generating a three-dimensional low frequency model by inversion using the envelope data and the interpolated coefficient model for display.

A method for obtaining zero-offset and near zero offset seismic data from a marine survey, with separation of direct arrival information and reflectivity information, the method including: modeling a direct arrival estimate at a passive near-field hydrophone array by using a notional source separation on active near-field hydrophone data; generating reflection data for the passive near-field hydrophone array by subtraction of the modeled direct wave from data recorded by the passive near-field hydrophone array; generating near zero-offset reflectivity traces by stacking the reflection data for the passive near-field hydrophone array on a string-by-string basis or on a combination of strings basis.