Solvent-Type and -Ratio Impacts on Solvent-Aided SAGD Process
- Weiqiang Li (Texas A&M University) | Daulat D. Mamora (Texas A&M University) | Yamin Li (Occidental Petroleum Corporation)
- Document ID
- Society of Petroleum Engineers
- SPE Reservoir Evaluation & Engineering
- Publication Date
- June 2011
- Document Type
- Journal Paper
- 320 - 331
- 2011. Society of Petroleum Engineers
- 5.8.5 Oil Sand, Oil Shale, Bitumen, 5.4.10 Microbial Methods, 5.3.4 Reduction of Residual Oil Saturation, 5.4.6 Thermal Methods, 4.1.2 Separation and Treating, 5.3.9 Steam Assisted Gravity Drainage, 4.1.5 Processing Equipment, 5.4.7 Chemical Flooding Methods (e.g., Polymer, Solvent, Nitrogen, Immiscible CO2, Surfactant, Vapex), 5.4.2 Gas Injection Methods, 4.3.4 Scale, 5.5.1 Simulator Development, 5.2.1 Phase Behavior and PVT Measurements, 5.7.2 Recovery Factors
- Steam assisted gravity drainage (SAGD), Solvent coinjection, Drainage mechanism, Athabasca
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- 1,365 since 2007
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Coinjecting solvent with steam under a steam-assisted-gravity-drainage (SAGD) process to reduce the required steam for production has gained importance in recent years. An extensive 2D simulation study to better understand the drainage mechanism of steam-with-solvent coinjection in the SAGD process shows that the condensation time difference of solvent and steam results in different films of gas solvent, liquid solvent, and water along the fluid interface. There is an optimal solvent-type and -concentration-ratio range for a particular reservoir and operating condition. Coinjecting the solvent at low concentration ratios can take advantage of the solvent dilution effect without losing too much heat effect from steam. In addition, this study indicates coinjection of suitable solvent mixtures may lead to better performance than injection of pure solvent in the field.
|File Size||1 MB||Number of Pages||12|
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