Processing & Imaging

Seismic attributes are widely used in hydrocarbon exploration and play a key role in prospect identification. Prestack seismic inversion has typically been the solution to derive earth properties, particularly velocity ratio and reflectivity derivatives which are then used to calculate various attributes. Traditionally, a sequential workflow using Full Waveform Inversion (FWI) followed by Least-Squares Reverse Time Migration (LS-RTM) has been employed to invert for subsurface velocity and reflectivity models. Recently, PGS introduced a new seismic inversion scheme that combines both inversions into a single process, PGS Ultima. A key aspect of the novel approach is the separation of the low- and high-wavenumber components of the earth model, enabling the simultaneous update of the velocity and reflectivity with minimum crosstalk. The approach is equivalent to performing FWI and LS-RTM simultaneously, where both velocity and reflectivity are continuously updated at each iteration. 

 

The iterative inversion compensates for incomplete acquisitions and varying illumination in the subsurface to provide true-amplitude earth reflectivity.

 

Using a wave equation parameterized in terms of velocity and reflectivity removes the need for a density assumption in the PGS Ultima multi-parameter inversion process. Velocity and reflectivity outputs from the inversion can in fact be used to extract additional properties, such as relative impedance and relative density, for prospectivity assessment in a reliable and data-driven approach.

 

The simultaneous inversion workflow has recently been extended to the prestack angle gather domain, which is crucial for improving our understanding of subsurface elastic properties. A key aspect of this approach is the extraction of angle information using elements obtained from the solution of the reflectivity-based wave equation. The inverted velocity and reflectivity models along with the derived relative impedance and density, and inverted pre-stack angle gathers, provide reliable information for subsequent amplitude versus angle (AVA) analysis and quantitative interpretation (QI).

 

PGS’ South Bank 3D seismic survey is located in the Salar Basin, which is an early Cretaceous, isolated rift basin with passive margin fill from late Cretaceous period and onward. Many fan systems have been identified along the margin using existing seismic data. They are interpreted as Oligocene in age, and the main prospectivity is believed to lie in these fans originating from the shelf and shelf-edge deltas. Class II and Ip anomalies are observed in the reservoir interval, along with class IV responses in the deeper section analogous to a modeled source rock in the region.

 

The slider image below shows the PGS Ultima velocity model and stacked reflectivity from angle gather output from the simultaneous inversion. The resolution in the velocity model allows accurate spatial positioning of seismic events, while the reflectivity output aids improved stratigraphic and quantitative interpretation. 

The simultaneous inversion products, i.e., velocity, angle dependent reflectivity, and the derived relative impedance and density, improve individual lead evaluation and provide better property constraints for QI analysis and anomaly interpretation. The high-resolution velocity model constrains lithologic relationships in the subsurface resulting in higher confidence quantitative analysis. PGS Ultima assists in derisking potential prospectivity in frontier areas of Canada’s petroleum basins.