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Kansas Geological Survey Open-file Report 2002-9 |
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
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. |
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%. |
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Last updated March 2002
http://www.kgs.ku.edu/PRS/Poster/2002/2002-9/P3-01.html