PETE 310 Lecutre 17 - Properties of Black Oils
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Transcript PETE 310 Lecutre 17 - Properties of Black Oils
PETE 310
Lecture # 17
Chapter 10 – Properties of Black
Oils - Reservoir Fluid Studies
Fluid Properties for Reservoir
Engineering Processes
The fluid properties of interest to the
Reservoir Engineer are those that affect
the mobility of fluids within the
reservoirs these are used in material
balance calculations
Properties at surface conditions for
transportation and sales (API, viscosity,
oil quality)
Fluid Properties for Reservoir
Engineering Processes
PVT properties are determined from 5
specific lab procedures
–
–
–
–
–
Flash liberation tests
Differential Liberation Tests
Viscosity Measurements
Separator Tests
Compositional measurements
Fluid Properties Determined
Oil Properties
–
–
–
–
–
Bubble Point Pressure
Bo
Rs
Bt
Co and mo
Gas properties
– z
– Bg and mg
Compositions oil & gas
Oil Sampling Procedures
Bottom hole or subsurface samples
Separator Samples
SAMPLE BEFORE RESERVOIR
PRESSURE DROPS BELOW Pb
1.Flash Vaporization Test
V
2
V
t1
oil
3
V t3 = V b
1
t2
oil
4
5
gas
V
oil
gas
V
t4
t5
oil
oil
Hg
Hg
Hg
Hg
Hg
P 1 >> P
b
P2 > P
b
P3 = P
b
P4 < P
b
P5 <P
4
Temperature of Test = Reservoir Temperature
1.Flash Vaporization Test
Properties determined
– Pb
– Co
Determination of Pb
Determination of Co
2.Differential Separation
Test
Gas off
1
2
3
4
gas
5
gas
gas
oil
oil
Hg
oil
oil
Hg
oil
Hg
Hg
P1 = Pb
P2 < Pb
oil
Hg
P2 < Pb
P2 < P b
P3 < P
2
< Pb
Temperature of Test = Reservoir Temperature
2.Differential Separation
Test
Properties Determined
– Oil formation volume factor at the Bubble
Point pressure Bodb and below the bubble
point pressure Bod
– Solution gas-oil ratio at the Bubble Point
pressure Rsdb and below the bubble point
pressure Rsd
– Isothermal compressibility (derived property)
3. Separator Tests
Tests performed at a combination
of different Temperature and
Pressure pairs
3. Separator Tests
Goals: Maximize API, minimize BoSb
& RsSb
Optimization of Separator 2
Conditions
3300
2.86
Solution Gas Oil Ratio at Pb (Rsb)
3280
2.84
3260
2.82
3240
2.80
3220
3200
2.78
3180
3160
50
o
T
= 75 F 2.76
Sep2
100
150
200
Separator 2 Pressure (psia)
250
300
Formation Volume Factor at Pb (Bob)
High Pressure Separator @ 900 psia and 100 ºF
Comparison between 1 & 2
Separators Stages (volatile oil)
2.96
3440
One Separator Stage
3420
2.94
3400
2.92
3380
3360
Low Pressure Separator @ 300 psia and 75ºF
o
T
= 160 F
Sep1
400
500
600
700
800
Separator 1 Pressure (psia)
2.90
900
1000
Formation Volume Factor at Pb (Bob)
Solution Gas Oil Ratio at Pb (Rsb)
3460
Typical PVT Properties for a
Black Oil and a Volatile Oil
3.2
3.0
Formation Volume Factor (Bo)
o
T =180 F
R
Black Oil
Volatile Oil
Black Oil Correlation
2.8
2.6
2.4
2.2
2.0
1.8
1.6
1.4
1.2
1.0
P
b
P
b
0
1000
2000
3000
Pressure (psia)
4000
5000
Typical PVT Properties for a
Black Oil and a Volatile Oil
4000
o
T =180 F
R
Solution Gas Oil Ratio (Rs)
Black Oil
Volatile Oil
Black Oil Correlation
3000
2000
1000
0
P
b
0
1000
2000
3000
Pressure (psia)
P
b
4000
5000
Nomenclature
4. Compositional Tests
http://www.rpi.edu/dept/chem-eng/Biotech-Environ/CHROMO/chromintro.html
http://www.rpi.edu/dept/chem-eng/Biotech-Environ/CHROMO/chroanim.html