How does the oil formation volume factor depend on the reservoir pressure?
How does the oil formation volume factor depend on the reservoir pressure?
Oil is slightly compressible. Hence, the oil formation volume factor increases slightly with decline in reservoir pressure due to expansion of the liquid phase as long as the reservoir produces above the bubble point.
What is gas formation factor?
Gas formation volume factor is defined as the ratio of gas volume under reservoir conditions to the gas volume at STP, expressed as(2.62)Bg=VVsc=pscpTTsczzsc=0.0283zTpwhere.
How do you calculate water formation volume factor?
The produced water formation volume factor (FVF), Bw, is defined as the volume at reservoir conditions occupied by 1 stock tank barrel (STB) of formation water plus its dissolved gas….Nomenclature.
| Bw | = | Water formation volume factor |
|---|---|---|
| ρrc | = | density of water at reservoir conditions, lbm/ ft3 |
Which two factors influence the gas formation volume factor?
Formation Volume Factor It is a very strong function of pressure, and a weak function of temperature and gas composition. The dry gas formation volume factor is the gas volume at reservoir conditions divided by the gas volume at standard conditions.
How do you calculate gas recovery factor?
Boi = formation volume factor = 1.05 + (N × 0.05), where N = number of ft3 of gas produced per bblbarrels of oil (gas-oil ratio or GOR). For example, if a well has a GORgas-oil ratio of 1,000, then Boi = 1.05 + (10 × 0.05) = 1.1.
What is the difference between bbl and STB?
1.2. 1 General definitions. Oilfield units volumes in oilfield units are barrels (bbl or B); 1 bbl=5.615 ft3 or 0.159 m3. A STB is the same volume defined at some surface standard conditions (in the stock tank) which are usually 60°F and 14.7 psi.
How do you find the volume of gas formation factor?
For example, gas formation volume factor is often determined with reasonable accuracy using the real gas equation of state PV = ZnRT where n is the number of moles of gas in volume V at pressure P and temperature T.
How is GOR oil and gas calculated?
A method as claimed in claim 1, characterized in that said volume ratio (GOR) is determined by the relation: GOR = R TOC 100 · k · ρ r ρ o where: ρo is the density of the liquid hydrocarbon at the surface (generally estimated at 0.8), ρr is the estimated rock density, R is the measured ratio of the volume of gas …
What is formation volume factor?
Formation volume factor is a measure of the ratio of the volume occupied by a fluid phase at reservoir conditions divided by the volume occupied by the fluid phase at surface conditions. Surface conditions are typically stock tank or standard conditions.
How do you calculate the reservoir pore volume?
Pore Volume = Net Volume x Porosity. Hydrocarbon Volume = Pore Volume x (1 Water Saturation) STOOIP/STOIIP = Hydrocarbon Volume / Oil Formation Volume Factor. Recoverable Oil Volume = STOIIP x Oil Recovery Factor.
How do you convert BBL to STB?
qo = STB/day for oil (at stock tank conditions)…3.1: Oilfield Measures and Units.
| 1 MMSTB | = 1,000 MSTB | = 1,000,000 STB |
|---|---|---|
| 1 MMbbl | = 1,000 Mbbl | = 1,000,000 bbl |
| 1 MMSCF | = 1,000 MSCF | = 1,000,000 SCF |
| 1 MM ft3 | = 1,000 M ft3 | = 1,000,000 ft3 |
| 1 MMSTB/day | = 1,000 MSTB/day | = 1,000,000 STB/day |
Is STB and BBL the same?
What is the formation volume factor of gas?
The formation volume factor of gas is defined as the ratio of the volume of gas at the reservoir temperature and pressure to the volume at the standard or surface temperature and pressure ( ps and Ts ).
How is the oil formation volume factor dependent on bubble point pressure?
The oil formation volume factor is strongly dependent on the values estimated for both the bubble point pressure and the solution gas-oil ratio. What are the PVT properties that depend on the value estimated for the oil formation volume factor?
Why are reservoir pressures maintained above the bubble point?
So far we have considered reservoir pressures maintained above the bubble point. At reservoir pressures above the bubble point, only single phase oil exists. Below the bubble point, solution gas evolves out of the oil becoming free gas in the reservoir. When this occurs, the oil and gas coexist in the reservoir.
How do you find the volume factor of an ideal gas?
For example, gas formation volume factor is often determined with reasonable accuracy using the real gas equation of state PV = ZnRT where n is the number of moles of gas in volume V at pressure P and temperature T. The gas is an ideal gas if gas compressibility factor Z = 1.