Prediction of Saturation Pressures for Condensate-Gas and Volatile-Oil Mixtures
- E.I. Organick (United Gas Corp.) | B.H. Golding (United Gas Corp.)
- Document ID
- Society of Petroleum Engineers
- Journal of Petroleum Technology
- Publication Date
- May 1952
- Document Type
- Journal Paper
- 135 - 148
- 1952. Original copyright American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. Copyright has expired.
- 5.2 Reservoir Fluid Dynamics, 4.1.5 Processing Equipment, 4.6 Natural Gas, 5.2.1 Phase Behavior and PVT Measurements, 5.8.8 Gas-condensate reservoirs, 4.1.2 Separation and Treating, 6.5.3 Waste Management
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A simple correlation is presented for the prediction of saturation pressures in condensate-gas and volatile-oil mixtures. Saturation pressure is related directly to the composition of the mixture with the aid of two generalized composition characteristics, the molal average boiling point, and the modified weight average equivalent molecular weight. The need for hydrocarbon equilibrium constants is entirely eliminated. Only the values of the two composition parameters need be obtained, and these are calculated in a simple and reproducible manner from the stream analysis of the mixture and the ASTM distillation for the heavy ends.
The correlation is given in the form of a set of 14 working charts in which saturation pressures, either retrograde dew points or bubble points, are plotted vs temperature, forming partial phase envelopes for mixtures having discrete values of the composition parameters, the molal average boiling point, and the modified weight average equivalent molecular weight.A locus of critical states on each chart intersects the partial phase envelopes, distinguishing retrograde dew point pressures from bubble pressures.
A comparison between experimental and predicted saturation pressures reveals that: the probable error of the predicted values, when considering the data as a whole (214 experimental points), is five per cent; for high gas/oil ratio condensate fluids (approximately 40,000 or more cu ft/bbl) the probable error is about 8 per cent. In either case, however, the probable error is comparable with the overall uncertainty of the data from which the correlation is derived.
There is a present need for a simplified, yet reasonably accurate method for predicting upper phase boundaries of reservoir fluids. In the case of high gas/oil ratio fluids, namely the so-called highly volatile oils and the condensate gases, no simple method, accurate within 5 to 10 per cent, is now available by which bubble point and retrograde dew point pressures may be predicted.
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