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PtE_412_HW_Set_11_Spring_2006

# PtE_412_HW_Set_11_Spring_2006 - Input Data magenta Value...

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PtE 412/464 Homework Set 11 Due 4/11/07 1. Calculate the change in productivity index (i.e., the P.I. ratio) for a well in which steam is injected to a radius of 30 feet. Assume radial, steady-state flow and the following information: Cold oil viscosity = 4,000 cp Hot oil viscosity = 4 cp Drainage radius = 330 ft Wellbore radius = 0.5 ft Oil FVF = 1.0 rb/stb (constant) Oil permeability = 1,000 md (constant) Pay thickness = 50 ft 2. Estimate the oil recovery (%OOIP) versus reservoir pressure for a reservoir being produced by fluid expansion above the bubble point and solution gas drive below the bubble point. Use the Muskat method for forecasting solution gas drive performance. Report the oil recovery (%OOIP) at abandonment pressure and the maximum obtainable recovery (P= 0 psia). Utilize the correlations presented in Chapter 1 of Craft & Hawkins to derive the necessary reservoir and fluid properties, given the following input data:
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Unformatted text preview: Input Data ( magenta ): Value Units Value Units Reservoir Lithology: ss ls, ss Reservoir Depth: 8,000 ft Initial Oil Saturation 80% % Reservoir Pressure: 3,500 psia Residual Oil Saturation 30% % Reservoir Temperature: 225 o F Endpoint Oil Rel Perm 1.00 dim Reservoir Porosity: 20% % Oil Rel Perm Exponent 2.00 dim Abandonment Pressure: 500 psia Oil Gravity: 32.0 o API Endpoint Gas Rel Perm 0.60 dim Bubble Point Pressure: 1,800 psia Gas Rel Perm Exponent 2.00 dim Gas Gravity: 0.60 dim CO2 Content: 0% % Irreducible Water Saturation 20% % H2S Content: 0% % Endpoint Water Rel Perm 0.10 dim Water Salinity: 2% wt% solids Water Rel Perm Exponent 2.00 dim Assume a power function of the form K r = K r endpoint * S dim ^ Exponent for relative permeability, where S dim = (phase saturation/max phase saturation)....
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