RETRACTED: Hybrid Chemical Enhanced Oil Recovery Techniques: A Simulation Study
Abstract
:1. Introduction
2. Methodology
2.1. Experimental Investigation
2.2. Interaction Between PPG and Surfactant
2.3. Governing Equations for Polymer and Surfactant Flooding
2.4. Governing Equations for PPG
3. Results and Discussion
3.1. Water Cut
3.2. Oil Rate
3.3. Injected Pressure
3.4. Recovery Factor
4. Conclusions
Author Contributions
Funding
Acknowledgments
Conflicts of Interest
Abbreviations
Parameter | Description |
Polymer concentration, ppm | |
Polymer adsorption concentration, ppm | |
Inaccessible pore volume, dimensionless | |
Porosity, fraction | |
Water saturation, dimensionless | |
Rock density, | |
PPG retention in the porous media, fraction | |
Original porosity, fraction | |
Filtration coefficient, 1/m | |
Initial filtration coefficient, 1/m | |
y | Experimental indices, dimensionless |
z | Experimental indices, dimensionless |
x | Experimental indices, dimensionless |
m | Geometrical constant parameter which is related to the grain sizes of the filler in the clean medium, dimensionless |
Experimental coefficient; dimensionless | |
SWR | the swelling ratio in the polymer solution |
Porosity reduction, dimensionless | |
Value of specific deposit saturation, dimensionless | |
Desorption coefficient, dimensionless | |
Filtration rate, m/min | |
C | Gelled particles mass concentration which is in the suspension mode, percent |
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Layers | Sand Thickness (m) | Water Saturation (%) | |
---|---|---|---|
1 | 2.72 | 47.31 | 541.47 |
2 | 1.13 | 45.37 | 546.28 |
3 | 1.30 | 48.14 | 581.67 |
4 | 0.72 | 48.55 | 602.54 |
5 | 1.12 | 49.63 | 658.32 |
6 | 1.90 | 49.89 | 664.22 |
Layer | Porosity | Oil Saturation (%) | ||
---|---|---|---|---|
1 | 200 | 20 | 0.15 | 0.8 |
2 | 400 | 40 | 0.16 | 0.8 |
3 | 600 | 60 | 0.17 | 0.8 |
4 | 800 | 80 | 0.18 | 0.8 |
5 | 1000 | 100 | 0.19 | 0.8 |
6 | 1200 | 120 | 0.20 | 0.8 |
7 | 1400 | 140 | 0.21 | 0.8 |
8 | 1600 | 160 | 0.22 | 0.8 |
9 | 1800 | 180 | 0.23 | 0.8 |
10 | 2000 | 200 | 0.24 | 0.8 |
Depth (m) | 1173–1230 |
Net Thickness (m) | 14.2 |
Porosity (%) | 33 |
1.5–2.5 | |
Oil Viscosity (mPa.s) | 16.3 |
Temperature (°C) | 65.9 |
Salinity (mg/L) | 5923 |
Stage | Procedure |
---|---|
1 | Water injected into the core sample to reach the water cut up to 98%. |
2 | 0.7 PV of polymer with the concentration of 1000 mg/L is injected. |
3 | 0.3 PV of water is injected again. |
4 | 0.3 PV of PPG with the concentration of 2000 mg/L is injected. |
5 | 0.2 PV of cross-linking agent with a concentration of 100 mg/L is injected. |
6 | 0.3 PV of surfactant is injected. |
7 | Water injected into the core sample to reach the water cut up to 98%. |
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Zhou, H.; Davarpanah, A. RETRACTED: Hybrid Chemical Enhanced Oil Recovery Techniques: A Simulation Study. Symmetry 2020, 12, 1086. https://doi.org/10.3390/sym12071086
Zhou H, Davarpanah A. RETRACTED: Hybrid Chemical Enhanced Oil Recovery Techniques: A Simulation Study. Symmetry. 2020; 12(7):1086. https://doi.org/10.3390/sym12071086
Chicago/Turabian StyleZhou, Haiyan, and Afshin Davarpanah. 2020. "RETRACTED: Hybrid Chemical Enhanced Oil Recovery Techniques: A Simulation Study" Symmetry 12, no. 7: 1086. https://doi.org/10.3390/sym12071086