Derivation of PVT Correlations for the Gulf of Suez Crude Oils.

Abstract

Proper evaluation of physical properties of hydrocarbon mixtures is a prerequisite for the design of various stages of oil field operations.In many cases these properties are required at a time when the only information available consists of oil and gas gravities and reservoir pressure and temperature. The purpose of this study is to utilize a sufficient base of laboratory-measured PVT data to derive specific empirical correlations for the prediction of the saturation pressure Pb, gas in solution Rs and tool in this work is some of regression analyses techniques. The correlations are based on 90 experimentally measured data which represent about 30 independent reservoirs.These data are expressed in terms of the usually measured field parameters-flash separation gas-oil ratio, tank oil gravity, surface gas gravity (at separator conditions) and reservoir temperature.The gases are relatively free from non-hydrocarbons. Statistical accuracy tests show that the application of derived correlations for Egyptian reservoirs gives more accuracy than the known correlations (Standing and Glaso).The use of the derived relationships requires no graphs nor charts, and their applicability is convenient to use with the computer or calculator.

Mathematical Correlation Predicting Stock Tank Oil Density for Egyptian Crude Oils at Standard Conditions

“…Each study claimed that the resulting correlation would provide the best approximation of PVT properties for the local region compared to the other commonly used correlations. Studies performed by El-hoshoudy et al [4] ,Macary and Batanony [5],Hanafy et al [6], Glasso [7] ,Dokla and Osman [8] ,Marhoun [2], Labedi [9] all supported this conclusion [5]. Multiple linear/nonlinear least-squares regression analysis will be used to develop the new correlations after screening of the used parameters.…”

Rigorous Modeling of Solution Gas–Oil Ratios for a Wide Ranges of Reservoir Fluid Properties

“…Figure 5 illustrates graphically the calculated AARD for the model developed, as well as all comparative methods investigated in the study. From Table 2 and Figure 5, it can be concluded that the methods of Baniasadi et al [42], Al-Shammasi [55], Macary and El-Batanony [53], Dindoruk and Christman [56], and Al-Marhoun [9] are, after the method proposed in this study, the most accurate for the calculation of solution GOR with AARD values of 23.15, 32.95, 36.54, 36.89, and 42.01%, respectively. Table 3 lists some random data points selected from the databank, and Table 4 summarizes the estimated values for the data points presented in Table 3 using method developed and empirical methods discussed above.…”

“…A comprehensive comparison analysis was undertaken between the model developed in this study and widely-used empirically derived methods including the Farshad et al method [2], Macary and ElBatanony method [53], Petrosky and Farshad method [24], Vazquez and Beggs method [16], Al-Marhoun method [9], Kartoatmodjo and Schmidt method [54], Al-Shammasi method [55], Standing method [23], Glaso [20], Baniasadi et al method [42], and Dindoruk and Christman method [56] in order to evaluate the performance of the method in predicting solution GOR data. Table 2 reports the statistical results obtained for the comparisons undertaken.…”

Empirical estimating of black oils bubblepoint (saturation) pressure

“…Dokla and Osman (1992) presented a set of correlations based on 51 bottom-hole samples from United Arab Emirates reservoirs. Macary and El-Batanoney (1993) developed correlations based on 90 experimentally measured data from 30 independent Egyptian reservoirs. The bubblepoint correlation of Kartoatmodjo and Schmidt (1994) was developed based on 5,392 data points from 740 PVT samples from South East Asia, North America, the Middle East and Latin America.…”