Page 414 - Characterization and Properties of Petroleum Fractions - M.R. Riazi

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394 CHARACTERIZATION AND PROPERTIES OF PETROLEUM FRACTIONS
TABLE 9.16—Composition of reservoir fluid of Problem 9.6.
recombined crude oils are given by Hu et al. [63]:
Well stream, Separator liquid, Separator gas, 9.9. The following data (Table 9.17) on two types of Chinese
Component mol% mol% mol% The reservoir temperature is at 339 K and measured
CO 2 0.18 Trace 0.22 bubble point pressures for oils 1 and 2 are 102.8 and
N 2 0.13 Trace 0.16
◦
C 1 61.92 7.78 75.31 74.2 bar, respectively. Densities of C 11+ fraction at 20 C
3
C 2 14.08 10.02 15.08 for oils 1 and 2 are 0.91 and 0.921 g/cm , respectively.
C 3 8.35 15.08 6.68 M 11+ for oils 1 and 2 are 428 and 443, respectively. At
i-C 4 0.97 2.77 0.52 the reservoir pressure of 150 bar, viscosities of oils 1
n-C 4 3.41 11.39 1.44
i-C 5 0.84 3.52 0.18 and 2 are 5.8 and 6.1 cP, respectively. Estimate the bub-
n-C 5 1.48 6.50 0.24 ble point pressures from an EOS for these two oils and
C 6 1.79 8.61 0.11 compare with available data.
6.85 34.33 0.06
C 7+ 9.10. Mei et al. [46] have reported experimental data on com-
Total 100 100 100 position of a well stream fluid from West China oil field
with compositions of separator gas and produced oil as
given in Table 9.18. Reservoir conditions (T and P), sat-
GOR is 4428 scf/bbl at 60 F. The API gravity of produced uration pressure of fluid at reservoir T, and the GOR of
◦
crude oil is 58.5. Calculate the following: reservoir fluid are also given in this table. Density of the
a. Composition of separator gas and liquid using Stand- reservoir fluid (well stream under reservoir T and P) has
ing correlation for K i . been measured and reported. From analysis of data it is
b. SG gas for separator gas. observed that there is an error in the composition of well
c. API gravity of separator liquid. stream as the sum of all numbers is 90.96 rather than
d. GOR in scf/bbl. 100. In addition reservoir temperature of 94 K is not
e. Stock tank liquid to well stream ratio in barrels/ correct (too low). Perform the following calculations to
MMscf. get correct values for the well stream composition and
f. Gas-to-feed ratio in Mscf/MMscf. reservoir temperature.
g. Compare predicted values with available laboratory a. Recombine separator gas and oil tank to get the orig-
values. inal well stream. Make appropriate material balance
9.7. For the gas condensate sample of Problem 9.6 calculate calculations, using molecular weight, to generate well
Z factor at the reservoir conditions of 186 F and 5713 stream composition. Also determine if given GOR is
◦
3
3
3
3
psia and compare it with the reported value of 1.107. in stm /m or m /m at separator conditions.
What is the value of gas condensate expansion factor in b. Use bubble-T calculations to calculate reservoir tem-
Mscf for each bbl at reservoir conditions? The measured perature at which corresponding saturation pressure
value is 1.591 Mscf/bbl. is 311.5 bar.
9.8. For the gas condensate sample of Problem 9.6 calculate c. Use trial-and-error procedure to find a temperature
dew point pressure (P d )at186 F and compare it with at which calculated density of reservoir fluid matches
◦
the measured value of 4000 psia. measured reported value at reservoir pressure. This
TABLE 9.17—Data on two Chinese crudes for Problem 9.9 [63].
Compound N 2 CO 2 C 1 C 2 C 3 i-C 4 n-C 4 i-C 5 n-C 5 C 6 C 7 C 8 C 9 C 10 C 11+
Oil 1 1.20 0.20 30.90 3.50 2.87 0.33 1.41 0.40 1.02 1.69 2.46 2.98 2.53 2.15 46.36
Oil 2 0.96 0.16 24.06 0.76 3.26 0.64 2.70 0.52 1.06 0.70 0.580 1.86 2.30 0.82 59.62
TABLE 9.18—Composition of an oil sample from Western China field [46].
a
Component Gas in separator, mol% Oil in tank, mol% Well stream ,mol%
CO 2 0.62 0.52
N 2 5.94 4.97
C 1 67.35 56.36
C 2 11.51 0.08 0.64
C 3 7.22 0.47 6.12
i-C 4 2.31 0.55 2.02
n-C 4 2.41 1.01 2.18
i-C 5 0.89 1.19 0.94
n-C 5 0.72 1.38 0.83
C 6 0.59 4.06 1.16
C 7 0.31 5.65 1.14
C 8 0.13 13.50 2.31
C 9 8.53 1.39
C 10 6.26 1.02
C b 57.32 9.36
11+
Initial reservoir Saturation Density of reservoir
3
pressure, bar Reservoir temp, K GOR, m /m 3 pressure, bar fluid, g/cm 3
410 94 a 440 311.5 0.5364
a Well stream composition and reservoir temperature are not correct. Find the correct values.
b
C 11+ fraction: M 11+ = 311 and SG 11+ = 0.838.

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