Numerical Simulation Study on Steam-Assisted Gravity Drainage Performance in a Heavy Oil Reservoir with a Bottom Water Zone
Abstract
:1. Introduction
2. Prototype Reservoir
3. Numerical Simulation Model
4. Results and Discussion
4.1. Steam Injection Pressure Optimization
4.2. Effect of the Initial Gas Oil Ratio
4.3. Effect of Thickness of the Bottom Water Zone
4.4. Effect of Oil Saturation in the Bottom Water Zone
4.5. Effect of the Well Pair Location
4.6. Effect of Different Well Patterns
5. Conclusions
Author Contributions
Conflicts of Interest
References
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Parameter | Value |
---|---|
Depth (m) a | 500 |
Initial reservoir temperature (°C) a | 18 |
Initial reservoir pressure (kPa) b | 3350 |
Thickness of oil zone (m) a | 20 |
Porosity a | 0.34 |
Permeability in the oil zone (mD) a | 5000 |
Permeability in the bottom water zone (mD) a | 2000 |
Oil saturation a | 0.85 |
Formation compressibility (1/kPa) c | 2.0 × 10−6 |
Rock, over-/underburden heat capacity J/(m3·°C) d | 2.39 × 106 |
Rock, over-/underburden thermal conductivity J/(m3·°C) d | 2.333 × 105 |
Oil phase thermal conductivity J/(m3·°C) d | 2.0 × 104 |
Water thermal conductivity J/(m3·°C) d | 5.35 × 104 |
Method for evaluation of 3-phase Kro e | Stone’s second model |
Methane K-value correlation e K = (KV1/P) × EXP((KV4)/(T−KV5)) | |
KV1 (kPa) e | 5.4547 × 105 |
KV4 (°C) e | −879.84 |
KV5 (°C) e | −265.99 |
Properties | Value |
---|---|
Density @18·°C (kg/m3) a | 985 |
API gravity a | 12.4 |
Viscosity @ 18·°C (mPa·s) a | 25,000 |
Oil formation volume factor (m3/m3) a | 1.022 |
Initial solution GOR (Sm3/m3) b | 8.0 |
SARA composition (wt%) c | |
Saturates | 23.1 |
Aromatics | 41.7 |
Resins | 19.5 |
Asphaltenes | 15.3 |
Solids | 0.4 |
Water-Oil Relative Permeability | Liquid-Gas Relative Permeability | ||||
---|---|---|---|---|---|
Sw | Krw | Krow | Sl | Krg | Krog |
0.150 | 0.000 | 1.000 | 0.150 | 1.000 | 0.000 |
0.200 | 0.000 | 0.981 | 0.200 | 0.950 | 0.000 |
0.250 | 0.005 | 0.955 | 0.250 | 0.844 | 0.005 |
0.300 | 0.008 | 0.723 | 0.300 | 0.724 | 0.008 |
0.350 | 0.013 | 0.602 | 0.350 | 0.603 | 0.018 |
0.400 | 0.025 | 0.472 | 0.400 | 0.471 | 0.027 |
0.450 | 0.042 | 0.351 | 0.450 | 0.353 | 0.047 |
0.500 | 0.069 | 0.243 | 0.500 | 0.240 | 0.069 |
0.550 | 0.103 | 0.166 | 0.550 | 0.168 | 0.107 |
0.600 | 0.149 | 0.110 | 0.600 | 0.095 | 0.156 |
0.650 | 0.207 | 0.072 | 0.650 | 0.079 | 0.209 |
0.700 | 0.275 | 0.040 | 0.700 | 0.047 | 0.274 |
0.750 | 0.354 | 0.016 | 0.750 | 0.033 | 0.354 |
0.800 | 0.449 | 0.000 | 0.800 | 0.024 | 0.450 |
0.850 | 0.565 | 0.000 | 0.850 | 0.014 | 0.564 |
0.900 | 0.693 | 0.000 | 0.900 | 0.009 | 0.689 |
0.950 | 0.838 | 0.000 | 0.950 | 0.005 | 0.838 |
1.000 | 1.000 | 0.000 | 1.000 | 0.000 | 1.000 |
So,bw | OOIP | Rinc,OOIP | Rbw | Rinc,Rbw | RF | Rinc,RF | cEOR | Rinc,cEOR |
---|---|---|---|---|---|---|---|---|
% | 105 m3 | % | % | % | % | % | GJ/m3 | % |
0 | 3.775 | - | 41.953 | - | 48.972 | - | 4.062 | - |
10 | 3.886 | 2.943 | 46.462 | 10.748 | 49.250 | 0.568 | 3.994 | −1.671 |
20 | 3.997 | 5.884 | 45.557 | 8.591 | 49.024 | 0.107 | 3.912 | −3.682 |
30 | 4.108 | 8.827 | 45.242 | 7.838 | 49.581 | 1.245 | 3.752 | −7.627 |
40 | 4.219 | 11.768 | 43.274 | 3.149 | 45.886 | −6.301 | 3.624 | −10.782 |
50 | 4.330 | 14.711 | 37.311 | −11.066 | 43.282 | −11.619 | 3.325 | −18.128 |
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Ni, J.; Zhou, X.; Yuan, Q.; Lu, X.; Zeng, F.; Wu, K. Numerical Simulation Study on Steam-Assisted Gravity Drainage Performance in a Heavy Oil Reservoir with a Bottom Water Zone. Energies 2017, 10, 1999. https://doi.org/10.3390/en10121999
Ni J, Zhou X, Yuan Q, Lu X, Zeng F, Wu K. Numerical Simulation Study on Steam-Assisted Gravity Drainage Performance in a Heavy Oil Reservoir with a Bottom Water Zone. Energies. 2017; 10(12):1999. https://doi.org/10.3390/en10121999
Chicago/Turabian StyleNi, Jun, Xiang Zhou, Qingwang Yuan, Xinqian Lu, Fanhua Zeng, and Keliu Wu. 2017. "Numerical Simulation Study on Steam-Assisted Gravity Drainage Performance in a Heavy Oil Reservoir with a Bottom Water Zone" Energies 10, no. 12: 1999. https://doi.org/10.3390/en10121999