Evaluating
Water-Flooding Incremental Oil Recovery Using Experimental Design, Middle
Miocene to Paleocene Reservoirs, Deep-Water
Dessenberger, Richard1,
Kenneth McMillen2, Joseph Lach1 (1) Knowledge Reservoir,
Many deep-water
We used an experimental design approach
to analyze dynamic simulation of two static models loosely based on the stratigraphy and reservoir properties from a thick-bedded
middle Miocene reservoir (e.g. Tahiti Field) and a thinner-bedded Paleocene
(e.g. Great White Field). Modeled variables included geological parameters
(structural dip, faulting, facies and aquifer size),
reservoir parameters (absolute permeability and heterogeneity), fluid
properties and production variables.
The results of the dynamic simulation
were evaluated using Experimental Design. The interpretation process involved
five steps: identifying uncertainty parameters and ranges, running simulations
for a wide variety of parameters, generating relationships of recovery factor
as a function of uncertainty, identifying parameter importance and determining
incremental oil recovery due to water injection. For these experiments, the incremental
recovery for aquifer-supported fields is small with a P50 value of 7%. Key
water-flooding variables are depofacies, aquifer
size, permeability, fault transmissibility and oil saturation. The least
important are bed dip, injection voidage-replacement,
and PVT properties.
AAPG Search and Discover Article #90063©2007 AAPG Annual Convention, Long Beach, California