Reservoir Characterization to Inexpensively Evaluate the Exploitation Potential of a Small Morrow Incised Valley-fill Field

Kansas Geological Survey
Open-file Report 2002-9

Reservoir Simulation

Input GeoModel

Model Parameters

3 layer reservoir - Sands #1, #2, #3
74 by 32 grid cells per layer
Grid size 250 ft by 250 ft

Reservoir pressure (June 1982) = 1880 psi
Reservoir temperature = 124oF
Initial solution GOR (approximated) = 650 scf/STB

Oil density (reservoir conditions) = 43.9 lb/cu ft
Gas gravity (@ 60F, 30” Hg dry) = 0.765 (Air =1.0)

Water salinity = 2.5%
Water density (reservoir conditions) = 67.52 lb/cu ft
Water formation volume (124F & 2000 psi) = 1.01res bbl/STB

Pay Thickness Distribution

Sand #1 Sand #3
Sand #2 Wireline logs, DST, IP data, and core data were used to define the lateral and vertical architecture of the reservoir. The geologic model characterized the reservoir as comprising three major flow-units representing distinct sandstone beds namely sands #1, #2, and #3. For each well, porosity, BVW, and permeability cut-offs were applied on Super-Pickett plots in order to identify “netpay”. Well-level netpay data was used to grid and map the pay distribution in each sand body.

Porosity Distribution

Sand #1 Sand #3
Sand #2 Average grain density, needed for density log interpretation, was measured (from core plugs) to be 2.647 g/cc with a standard deviation of 0.012 g/cc. At each well, porosity was averaged over the net pay interval of each sand body. Porosity in the producing region of the field varies between 11 to 28%.

top of report

e-mail :
Last updated March 2002