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©KA
PPA
200
4 -0
4101
5
Pressure - Volume BehaviourSingle Component System
Liquid
Gas
Pressure
Volume
Bubblepoint
FIRST BUBBLEOF GAS
LAST DROPOF LIQUID
Dewpoint
©KA
PPA
200
4 -0
4101
5
Pressure - Temperature BehaviourSingle Component System
liquid
Criticalpoint
gas
©KA
PPA
200
4 -0
4101
5
Three Dimensional Phase DiagramSingle Component System
LiquidGas
Pres
sure
VolumeTemperature
Liquid
GasCriticalpoint
©KA
PPA
200
4 -0
4101
5
Pressure - Volume BehaviourTwo Component System
Liquid
Gas
Pressure
Volume
Bubblepoint
FIRST BUBBLEOF GAS LAST DROP
OF LIQUID
Dewpoint
©KA
PPA
200
4 -0
4101
5
Pressure - Temperature BehaviourHydrocarbon Mixture
Temperature
RESERVOIRRESERVOIR RESERVOIR
©K
AP
PA
200
4 -0
4101
5Oil P-T Behaviour
Temperature
RESERVOIRRESERVOIR RESERVOIR
Black Oil
Volatile Oil
A
A’
C
©KA
PPA
200
4 -0
4101
5Oil Reservoir below Bubble Point
1. Pressure above Bubble Point. Wellsproduce oil and associated gas.
2. Pressure drops below Bubble Point. Bubbles of solution gas form in reservoir.
3. Critical gas saturation reached.Gas is now mobile.
4. Gas flows towards producing wells.Wells now produce oil, associated gas and solution gas.
©KA
PPA
200
4 -0
4101
5Oil Reservoir below Bubble Point
1. As fluid is produced, the reservoir pressure drops towards abandonment.2. The Oil production is high at first, rapidly dropping off as more gas is
produced.3. At critical gas saturation, the Gas-Oil ratio rises rapidly to a maximum, then
falls as the lower gas compressibility offsets the increased gas mobility.
©KA
PPA
200
4 -0
4101
5
Temperature
RESERVOIRRESERVOIR RESERVOIR
Gas P-T Behaviour
Wet gas
Dry gas
A
C
©KA
PPA
200
4 -0
4101
5
Temperature
RESERVOIRRESERVOIR RESERVOIR
Gas Condensate P-T Behaviour
Rich gas condensate
Lean gas condensate
AA’
C
B
©KA
PPA
200
4 -0
4101
5Fluid Parameters
Essential parameters in Well Test Analysis
Volume factor B
Viscosity µ
Compressibility ct
©KA
PPA
200
4 -0
4101
5Formation Volume factors
BoBwBg
Reservoir conditions
Surface conditions
GasWaterOil
OilGas
Solution gas
Water
Solution gas
Rs Rsw
©KA
PPA
200
4 -0
4101
5Retrograde Gas Condensate
Bg
Reservoir conditions
Surface conditions
Gas
Gas
Condensate
GLR
©KA
PPA
200
4 -0
4101
5Formation Volume Factor
B = Fluid volume at standard conditions
Fluid volume at reservoir conditions
This factor transforms surface flow rate valuesinto downhole conditions flow rate values.
Typical values Oil 1.3 to 2.4Gas 0.003 to 0.01
©KA
PPA
200
4 -0
4101
5Viscosity
Viscosity µ
Is a measure of a fluid’s internal resistance to flow
.. a sort of internal friction.
It depends on pressure, temperature and gravity.
Typical values Oil 0.2 to 30 cpGas 0.01 to 0.05 cp