Much work remains to be done with this complex and fascinating data set. A top priority would be to map the data volumes properly in depth so that depth slice images can be interpreted accurately. Unfortunately, since lateral velocity variations within the reservoir are very strong, expensive depth migration methods are needed to perform this task. And 3-D depth migration, in turn, requires an accurate estimate of the 3-D subsurface interval velocity model.
Aside from imaging work, it would be very interesting to collaborate with someone on doing fluid-flow simulations of the steamflood process. These results could then be mapped through rock physics transformations with the core measurements to seismic properties. Then full waveform seismic modeling could be done and the result could be compared with the field data.
Taking that train of though one step further brings us to the ultimate - ``seismic history matching''. One could imagine constructing a complete iterative loop of fluid-flow simulation, rock physics transformation, seismic modeling, history matching with production data and seismic time-lapse data, and updating the reservoir simulation model. This integrated modeling and processing sequence offers exciting new possibilities for the future of optimal hydrocarbon reservoir management and controlled fluid-flow processes.