Page 26 - PVT Property Correlations
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Introduction Chapter | 1  7



                                   Hydrocarbon vapor Hydrocarbon liquid
                                                                 Water phase
                                   phase (gas phase)  phase (oil phase)
              Surface gas                X             X
              Stock-tank oil (surface oil)  X          X
              Surface water                                          X

             FIGURE 1.5 Relation of fluids produced on surface and reservoir phases for MBO models.
             MBO, modified black-oil.

             simulation, nodal analysis, and artificial lift design) and for most common
             reservoir-depletion processes (e.g., primary and secondary recovery).


             Modified Black-Oil (MBO) Models
             The MBO model (also called extended black oil) is similar to black-oil mod-
             els in most respects; it differs, however, in the way it handles oil produced
             on surface (stock-tank oil) (Spivak and Dixon, 1973). The oil produced on
             surface is assumed to come from both the reservoir gas and oil phases. The
             MBO model is therefore capable of handling the oil produced from the gas
             phase. This capability is important for modeling both volatile oil and gas
             condensate fluids, as the oil produced from the gas phase can be significant.
             Fig. 1.5 shows the relation of fluids produced on surface (surface gas and
             stock-tank oil) and the phases existing in the reservoir (gas and oil phases).
                Four PVT functions are required for the MBO model in addition to oil
             and gas viscosity. Viscosities are defined and obtained in much the same
             way as in black-oil models. The four functions are (1) oil formation volume
             factor, (2) solution gas oil ratio, (3) gas formation volume factor, and
             (4) vaporized oil gas ratio. The definitions of these functions are given in
             the following equations:
                                  Reservoir oil volume at T and P
                            B o 5                                       ð1:1Þ
                                 Stock   tankoil from reservoir oil
                                  Surface gas from reservoir oil
                            R s 5                                       ð1:2Þ
                                 Stock   tankoil from reservoir oil
                                 Reservoir gas volume at T and P
                          B g 5                                         ð1:3Þ
                               Surface gas volume from reservoir gas
                             Stock   tankoil volume from reservoir gas
                         R v 5                                          ð1:4Þ
                               Surface gas volume from reservoir gas
                The first three functions have the same definitions for both black-oil and
             MBO models. The partitioning of how much surface gas comes from the
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