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These PVT properties are usually obtained in the laboratory and are unique to a given reservoir fluid. , yg, y0 , T, Ph• and B0 for a large number of hydrocarbons. These correlations should be used only in the absence of PVT properties obtained for the specific reservoir. EXAMPLE 3-1 PVT properties below the bubble-point pressure: Impact on oil reserves Calculate the total formation volume factor at 3000 psi for the reservoir fluid described in Appendix B. What would be the reduction in volume of oil (STB) in 4000 acres of the reservoir described in the same Appendix when the average pressure is reduced from the initial pressure to 3000 psi?
This is a time-dependent calculation, done in discrete intervals. Combination with volumetric material balances (treated in Chapter 9) will allow the forecast of rate and cumulative production versus time. For this exercise, calculate the IPR curves for zero skin effect but for average reservoir pressures in increments of 500 psi from the "initial" 5651 to 3500 psi. Use all other variables from Appendix A. Drainage radius is 2980 ft. Solution Equation (2-37) is the generalized pseudo-steady-state equation for any drainage shape and well position.
In an initially saturated reservoir, all three points would be within the two-phase envelope. For comparison, the paths for the 41 42 Chap. l! e 0.. Q) a: I : I I I I ' I I I 3000 I I I I I ! 2500 I I I I / 1§ ,_ 2000 -~ 3l • Retrograde Condensate Reservoirs / 1500 ,,..... /... ) 1000 Figure 3-1 Schematic phase diagram of a hydrocarbon mixture. Marked are reservoir, bottomhole, and wellhead flowing conditions for an oil reservoir. 500 0 50 100 150 200 250 300 350 Reservoir Temperature (°F) fluids in a retrograde gas condensate reservoir and in a single-phase gas reservoir are shown.