Applied Petroleum Reservoir Engineering (Second Edition) by B. C. Craft, M. Hawkins, Ronald E. Terry
By B. C. Craft, M. Hawkins, Ronald E. Terry
The most up-tp-date, utilized publication out there for petroleum engineers, geologists and others operating within the improvement and creation of oil and fuel fields and people taken with the circulation of flooring water, this revised variation displays the advances made in reservoir engineering calculation thoughts. a variety of genuine international examples make clear the fabric, offering the reservoir engineer with the sensible details to make utilized calculations.
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Additional info for Applied Petroleum Reservoir Engineering (Second Edition)
040 bbl/STB. The coefficient of temperature expansion for the 30° 1500 2000 PRESSURE, PSIA Fig. 12. Formation volumc factor of the Big Sandy Field reservoir oil, by flash liberation at reservoir temperature of 160°? 27) where 13 is the temperature coefficient of expansion of the oil. The formation volume factor, symbol B0 and the abbreviation FVF, at any pressure may be defined as the volume in barrels that one stock tank barrel occupies in the formation (reservoir) at reservoir temperature and with the solution gas which can be held in the oil at that pressure.
11. Solution gas-oil ratio of the Big Sandy Field reservoir oil, by flash liberation at reservoir temperature of 160°F In Chapter 6 it will be shown that the solution gas-oil ratio and other fluid properties depend on the manner by which the gas is liberated from the oil. The nature of the phenomenon is discussed together with the complications it introduces into certain reservoir calculations. For the present, however, for the sake of simplicity this phenomenon is ignored, and a stock tank barrel of oil is identified with a barrel of residual oil following a flash, liberation process, and the solution gas-oil ratios by flash liberation is used.
210 bbl at 1200 psia. 11 shows an initial solution gas of 567 SCF/STI3 and at 1200 psia 337 SCF/STB, the difference 230 SCF being the gas liberated down to 1200 psia. 743 bhl/STB—thc two-phase volume factor at 1200 psia It may also be obtained by Eq. 1200 PSIA T01sI60F C P*r14j PSIA Tcn'IGOF D Fig. 13. Visual conception of the change in single-phase and in two-phase formation volume factors for the Big Sandy reservoir fluid 6. Review of Crude Oil Properties 37 Figure 113 (C) shows these separate and total volumes at 1200 psia At 14 7 psia and 160°F (D), the gas volume has increased to 676 cu ft and the oil volume has decreased to 1 040 bbl.