Abstract
Difficulties in imaging subsalt data in the Gulf of Mexico are well documented. Even with the latest wide azimuth acquisition technology the quality of imaging subsalt is quite variable. 3D VSPs offer the potential to improve reservoir imaging as compared to surface data and to calibrate the reservoir to the surface seismic. The major drawbacks to 3D VSPs are that they are quite expensive due to the rig time required and by their very nature offer a narrow illumination window around the wellbore. To extract more information from 3D VSPs than standard P‐wave processing two avenues were investigated: 1) The utilization of the reverse time migration (RTM) imaging algorithm which offers the possibility to increase the lateral coverage of 3D VSPs because it honors two‐way propagation and all multiples in the model. 2) Processing for converted wave modes of energy.
Sign-in/Register to access full text options 
Talk to us
Join us for a 30 min session where you can share your feedback and ask us any queries you have
Schedule a call
