Transcript Pete 552 - METU | Middle East Technical University

PETE 216
Reservoir Rock and Fluid Properties
Fall 2006-2007
Dr. Mahmut Parlaktuna
CONVENTIONAL PVT MEASUREMENTS
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RESERVOIR ROCK AND FLUID PROPERTIES
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STANDARD PVT TESTS
Compositional Analysis
(CA)
Multistage Separation (MSS)
Constant Composition Expansion (CCE) (Flash
vaporization test)
Differential Liberation Expansion (DLE)
(Differential vaporization test)
Constant Volume Depletion (CVD)
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RESERVOIR ROCK AND FLUID PROPERTIES
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OIL PVT ANALYSES
 Bottomhole wellstream compositional
analysis through C7+,
 CCE
 DLE
 MSS
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COMPOSITIONAL ANALYSIS
GAS CHROMATOGRAPHY (GC)
LIQUID CHROMATOGRAPHY (LC)
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Constant Composition Expansion
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Constant Composition Expansion
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Constant Composition Expansion
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Y Function
Density (g/cm3)
Pressure (psig)
Relative Volume
5000
0.9639
0.6808
4500
0.9702
0.6763
4100
0.9756
0.6726
4000
0.9770
0.6716
3500
0.9845
0.6665
3000
0.9928
0.6609
2900
0.9946
0.6597
2800
0.9964
0.6585
2700
0.9984
0.6572
2620
1.0000
0.6562
2605
1.0021
2591
1.0042
2516
1.0157
2401
1.0353
2253
1.0648
2.497
2090
1.1041
2.418
1897
1.1627
2.325
1698
1.2415
2.229
1477
1.3611
2.122
1292
1.5000
2.033
1040
1.7839
1.911
830
2.1709
1.810
640
2.7603
1.718
472
3.6961
1.637
RESERVOIR ROCK AND FLUID PROPERTIES
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Constant Composition Expansion
6000
5000
Pressure (psig)
4000
Bubble point
3000
Pb
2000
1000
0
0.8
1.0
1.2
1.4
1.6
1.8
2.0
Relative Volume
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Constant Composition Expansion
Above bubblepoint
1  V 
co =- 

V  P T
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Constant Composition Expansion
2.6
2.4
2.2
Y function
2.0
1.8
  Pb -P  


P 

Y=
1.6
1.4
  Vt -Vb  


 Vb 
1.2
1.0
0
500
1000
1500
2000
2500
Pressure (psig)
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Differential Liberation Expansion
Bg =
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 T  P 
VR
=Z    sc 
Vsc
 Tsc   P 
RESERVOIR ROCK AND FLUID PROPERTIES
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Differential Liberation Expansion
Pressure
(psig)
Rsd
(SCF/bbl)1
Rsd
(vol/vol)1
Bod2
Btd3
Oil density
(g/cm3)
Z
Bg4
Incremental
gas gravity
2620
854
152
1.600
1.600
0.6562
2350
763
136
1.554
1.665
0.6655
0.846
0.00685
0.825
2100
683
122
1.515
1.748
0.6731
0.851
0.00771
0.818
1850
612
109
1.479
1.859
0.6808
0.859
0.00882
0.797
1600
544
97
1.445
2.016
0.6889
0.872
0.01034
0.791
1350
479
85
1.412
2.244
0.6969
0.887
0.01245
0.794
1100
416
74
1.382
2.593
0.7044
0.903
0.01552
0.809
850
354
63
1.351
3.169
0.7121
0.922
0.02042
0.831
600
292
52
1.320
4.254
0.7198
0.941
0.02931
0.881
350
223
40
1.283
6.975
0.7291
0.965
0.05065
0.988
159
157
28
1.244
14.693
0.7382
0.984
0.10834
1.213
0
0
0
1.075
0.7892
2.039
Gravity of residual oil = 35.1 °API @ 60 °F
1 Volume of gas at the standard conditions per volume of residual oil.
2 Volume of oil at indicated pressure and temperature per volume of oil at the standard conditions.
3 Volume of oil plus liberated gas at indicated pressure and temperature per volume of residual oil at the standard conditions.
4 Volume of gas at indicated pressure and temperature per volume at the standard conditions.
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Multistage Separation Test
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Multistage Separation Test
Separator
Pressure (psig)
50 to 0
100 to 0
200 to 0
300 to 0
Gas oil ratio
(SCF/bbl)1
Gas oil ratio
(SCF/STB)2
715
737
41
41
637
676
91
92
542
602
177
178
478
549
245
246
Stock-tank oil gravity
(°API at 60 °F)
40.5
40.7
40.4
40.1
Formation
Volume
factor
(vol/vol)3
1.481
1.474
1.483
1.495
Separator
volume
factor
(vol/vol)4
Specific
gravity of
flashed gas
1.031
0.840
1.007
1.338
1.062
0.786
1.007
1.363
1.112
0.732
1.007
1.329
1.148
0.704
1.007
1.286
1
GOR per barrel of oil at indicated pressure and temperature.
GOR per barrel of stock-tank oil at 60 °F.
3 FVF per barrel of stock-tank oil at 60 °F.
4 Separator oil volume factor per barrel of stock-tank oil at 60 °F.
2
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Multistage Separation Test
800
1.500
1.495
795
1.490
790
780
1.475
1.470
775
Oil FVF (vol/vol)
1.480
1.465
770
1.460
GOR (SCF/STB)
FVF
765
1.455
760
1.450
0
50
100
150
200
250
300
350
Pressure (psig)
41.0
40.9
Stock-tank oil gravity (°API)
GOR (SCF/STB)
1.485
785
40.8
40.7
40.6
40.5
Oil gravity
40.4
40.3
40.2
40.1
40.0
0
50
100
150
200
250
300
350
Pressure (psig)
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GAS CONDENSATE PVT ANALYSES
 Recombined Wellstream Compositional Analysis
(CA)
 Constant Composition Expansion (CCE) (Flash
vaporization test)
 Constant Volume Depletion (CVD)
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Constant Composition Expansion
Pressure (psig)
Relative volume (V/Vsat)3
Z4
Volume of Retrograde liquid (%)5
7975
0.9395
1.2866
0.00
7540
0.9599
1.2429
0.00
7250
0.9765
1.2158
0.00
71831
0.9787
1.2074
0.00
7105
0.9826
1.1991
0.00
6960
0.9935
1.1876
0.00
68222
1.0000
1.1718
0.00
6743
1.0068
1.1660
0.30
6598
1.0174
1.1530
0.82
6380
1.0312
1.1302
1.73
6090
1.0550
1.1039
2.92
5655
1.0971
1.0661
4.79
5075
1.1687
1.0120
7.18
4495
1.2632
0.9764
9.40
3915
1.3959
0.9401
11.02
3335
1.5841
0.9094
12.40
2610
1.9773
0.8894
13.15
1
Initial reservoir pressure
Saturation pressure at reservoir temperature
3 V = volume of fluid at saturation pressure and reservoir temperature
sat
4 Z=PV/nRT (n total number of moles)
5 (Volume of retrograde liquid at indicated pressure / total volume at saturation pressure)*100
2
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Constant Composition Expansion
2.5
14
12
2.0
8
1.5
6
1.0
4
Relative volume (V/Vsat)
Volume of Retrograde liquid (%)
Liquid volume (%)
Relative Volume (V/V sat)
10
2
0.5
0
0.0
0
1000
2000
3000
4000
5000
6000
7000
8000
-2
9000
Pressure (psig)
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Constant Volume Depletion
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Constant Volume Depletion
Z
Volume of
Retrograde liquid
(%)
Pressure (psig)
Cumulated production (%)
Specific gravity of
produced gas
7975
0.00
0.943
1.2866
0.00
7540
0.00
0.943
1.2429
0.00
7250
0.00
0.943
1.2158
0.00
7183
0.00
0.943
1.2074
0.00
7105
0.40
0.943
1.1991
0.00
6960
1.51
0.943
1.1876
0.00
6822
2.17
0.943
1.1718
0.00
5800
9.67
0.889
1.0767
4.31
4930
17.66
0.845
1.0056
7.53
3915
29.89
0.797
0.9479
10.18
3045
42.90
0.760
0.9176
11.28
2030
60.29
0.737
0.9171
11.32
1160
76.17
0.728
0.9476
10.49
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Constant Volume Depletion
12
Condensate Drop-out (%)
10
8
6
4
2
0
0
1000
2000
3000
4000
5000
6000
7000
8000
Pressure (psig)
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Constant Volume Depletion
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Constant Volume Depletion
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