The goal of this three-year project was to provide a quantitative definition of reservoir heterogeneity. This objective was accomplished through the integration of geologic, geophysical, and engineering databases into a multi-disciplinary understanding of reservoir architecture and associated fluid-rock and fluid-fluid interactions. This interdisciplinary effort integrated geological and geophysical data with engineering and petrophysical results through reservoir simulation to quantify reservoir architecture and the dynamics of fluid-rock and fluid-fluid interactions. An improved reservoir description allows greater accuracy and confidence during simulation and modeling as steps toward gaining greater recovery efficiency from existing reservoirs. A field laboratory, the Sulimar Queen Unit, was available for the field research. Several members of the PRRC staff participated in the development of improved reservoir description by integration of the field and laboratory data as well as in the development of quantitative reservoir models to aid performance predictions. Subcontractors from Stanford University and the University of Texas at Austin (UT) collaborated in the research and participated in the design and interpretation of field tests. The three-year project was initiated in September 1993 and led to the development and application of various reservoir description methodologies. A new approach for visualizing production data graphically was developed and implemented on the Internet. Using production data and old gamma rays logs, a black oil reservoir model that honors both primary and secondary performance was developed. The old gamma ray logs were used after applying a rescaling technique, which was crucial for the success of the project. In addition to the gamma ray logs, the development of the reservoir model benefitted from an inverse Drill Stem Test (DST) technique which provided initial estimates of the reservoir permeability at different wells. A new single-well wettability test was conducted for the first time in the field and provided insight on the wettability of a large reservoir volume. The field wettability test pointed towards a mixed-wet system. Wettability tests performed at the laboratory indicated the same wetting state. The results of the crosswell seismic data were used to develop a new approach in the estimation of interwell reservoir properties using neural networks. With a fuzzy logic methodology, a minipermeameter, and thin sections, a new technique for petrographic analysis was developed. Combining the information from outcrop data, logs, crosswell seismic, and petrographic analysis, a new geological model is proposed for the Queen formation. The results of the three year project were presented to oil companies producing from the Queen formation and various publications were prepared to describe the results of the project.