Video: Simulation of Viscoelastic Polymer Flooding - From the Lab to the Field
- Pengpeng Qi (Kemira Chemicals, LLC) | Hamid Lashgari (University of Texas at Austin) | Haishan Luo (University of Texas at Austin, TOTAL) | Mojdeh Delshad (University of Texas at Austin) | Gary Pope (University of Texas at Austin) | Matthew Balhoff (University of Texas at Austin)
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- Society of Petroleum Engineers
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- 2018. Copyright is retained by the author. This presentation is distributed by SPE with the permission of the author. Contact the author for permission to use material from this video.
- 5.7 Reserves Evaluation, 5.4 Improved and Enhanced Recovery, 5.7.2 Recovery Factors, 5.3.4 Reduction of Residual Oil Saturation, 5.3.6 Chemical Flooding Methods (e.g., Polymer, Solvent, Nitrogen, Immiscible CO2, Surfactant, Vapex), 5.5 Reservoir Simulation, 5.4 Improved and Enhanced Recovery, 5 Reservoir Desciption & Dynamics, 4.3.4 Scale, 5.5.2 Core Analysis
- Chemical EOR, Polymer, Reservoir simulation, residual oil saturation, Viscoelasticity
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Experimental data in numerous publications show that viscoelastic polymers can significantly reduce residual oil saturation under favorable conditions. The effect of viscoelasticity is in addition to improved sweep efficiency of polymer flooding. The residual oil saturation decreases with increasing dimensionless Deborah number (a measure of the relative elasticity). We used these extensive coreflood data to develop a new model that is referred to here as an Elastic Desaturation Curve (EDC). The new EDC model was implemented into a reservoir simulator and used to simulate polymer floods at both the lab and field scales. The simulated coreflood results match the experimental oil cut, oil recovery and pressure drop data. The simulator was then used to predict the effectiveness of polymer floods in a quarter five-spot well pattern under favorable field conditions. The field-scale simulations show that a viscoelastic polymer flood can recover significantly more oil (12% OOIP for the base case simulation) compared to an inelastic polymer flood of the same polymer viscosity. A sensitivity analysis shows that polymer concentration, salinity, well spacing, permeability, heterogeneity and injection rate affect the incremental oil recovery due to elasticity. The results suggest that the use of viscoelastic polymers could be a beneficial enhanced oil recovery strategy at the field scale under favorable conditions.