Basin Modeling Route to Seismic Inversion

Marek Kacewicz
Chevron Energy Technology Company, 14141 Southwest Freeway, Sugar Land, TX 77478

The quality of basin modeling results, such as pressure and hydrocarbon migration pathways, depend on the quality of rock properties derived from wells and through seismic inversion. Seismic attributes representing present day rock properties, as well as fluids and gases in the system, give us an idea of reservoir connectivity and of lateral and vertical seals in a 3D petroleum system. If utilized in a high resolution 3D basin model, they provide a framework in which hydrocarbons are assumed to migrate from source rocks to reservoirs.
Non-uniqueness of seismic inversion results in more than one possible basin model, i.e. more than one possible pressure field, more than one hydrocarbon migration scenario, etc. Any inconsistencies between hydrocarbon migration pathways and saturations derived from basin modeling and well calibration data may indicate potential problems with seismic inversion. If analyzed properly, the inconsistencies can be utilized to improve seismic inversion through iterative corrections of seismic impedance / porosity / capillary entry pressure transforms.
This paper presents methodology and workflows for building integrated seismic inver­sion/basin models. Case studies from Kutei Basin (Indonesia) and from the Gulf of Thailand introduce the process and show how seismic inversion combined with invasion per­colation based basin modeling improved our understanding of complex petroleum systems of SE Asia Tertiary basins.

AAPG Search and Discover Article #90066©2007 AAPG Hedberg Conference, The Hague, The Netherlands