Field UCSI is at its primary recovery stage (Figure 1). The geological information indicates that there are 13 reservoir layers. Seismic data indicates that there is an aquifer attached to the field, probably from eastern direction. To estimate future production from the field which the very first production activity on 1 January 2010, a simulation study will be conducted using Eclipse Black Oil. The first stage if this process is to construct a base case simulation model which will be later calibrated to past production measurement by history matching. Figure 1 Model Dimension Based on the amount of data available and the computer resources, it has been decided to carry out the simulation using 3D model comprising 13 simulation layers, corresponding to the 13 geological layers, with 52 columns of cells in the lateral direction and 36 rows of cells in the transverse direction. The aquifer volume will be modeled by an analytical aquifer (Fetkovich). There are 9 producers, 2 for gas and 7 for oil. Producers that are close to the aquifer may be converted to injector later. Infill wells may be drilled to increase oil recovery factor. Fluid properties The reservoir oil is initially under-saturated. But with production, the reservoir pressure has dropped below the bubble point pressure. The fluid properties are believed to be constant throughout the reservoir. The below data was obtained from well drilled throughout the reservoir. The Ky/Kz ratio of all layers is 10. A corner point geometric representation of the reservoir and 8-fault model have been exported from Petrel with name UCSI.GRDECL. Layer Kx, Ky mD Poro Layer Kx, Ky mD Poro 1 235 0.16 8 337 0.20 2 249 0.20 9 270 0.16 3 32 0.07 10 320 0.16 4 257 0.15 11 270 0.17 5 266 0.18 12 290 0.18 6 124 0.17 13 300 0.21 7 337 0.23 At later time the reservoir engineering team decided to look more detail in box (11,12,1) to (13,15,12) by dividing the global cells in X and Y direction by 3 and Z direction by 2. Then to those cells, they assign new permeability value for X direction 100 mD and Y direction 150 mD. Fluid PVT and Rock Compressibility Data At surface conditions, the oil density is 49.999 lb/ft3, the density of reservoir water is 63.698 lb/ft3, and gas is 0.050674 lb/ft3. From PVT analysis the following properties have been obtained for the oil. The data are presented in several tables. Oil PVT data Gas PVT data  The water formation volume factor Bw is 1.0132 rb/stb at 3118.3 psia with constant water viscosity µw 0.39851 cp and compressibility 2.7438 x 10-6 (psi)-1.  The rock compressibility is 9.8141 x 10-7 (psia)-1 at 5801.5 psia. From special core analysis, the following two phase relative permeability and capillary pressure curve have been obtained. Saturation Table Data Instructions 1. Create codes in RUNSPEC, GRID, and PROPS, sections. 2. Use unformatted file type 3. Request unified input and output and field units. 4. Request output of the grid geometry file, the static reservoir properties file, the transmissibility in x and y direction, and non-neighbor connections. 5. Fix all errors. The case and instruction will be continued and amended in Project Case 2.