Simulation of Water and Condensate Blockage and Solvent Treatments in Tight Formations Using Coupled Three-Phase Flash and Capillary Pressure Models
- Sajjad S. Neshat (The University of Texas at Austin) | Ryosuke Okuno (The University of Texas at Austin) | Gary A. Pope (The University of Texas at Austin)
- Document ID
- Society of Petroleum Engineers
- SPE Improved Oil Recovery Conference, 14-18 April, Tulsa, Oklahoma, USA
- Publication Date
- Document Type
- Conference Paper
- 2018. Society of Petroleum Engineers
- 5.1 Reservoir Characterisation, 4 Facilities Design, Construction and Operation, 5.1 Reservoir Characterisation, 5.2.2 Fluid Modeling, Equations of State, 5.2.1 Phase Behavior and PVT Measurements, 4.1 Processing Systems and Design, 5.5 Reservoir Simulation, 5 Reservoir Desciption & Dynamics, 4.1.2 Separation and Treating, 5.2 Fluid Characterization
- phase behavior, Heterogeneity, capillary pressure, unconventional, compositional simulation
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- 286 since 2007
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Water and condensate blockage near production wells in unconventional reservoirs can significantly reduce oil and gas production rates. This paper presents a new approach for more accurate modelling of liquid blockage in tight oil and gas reservoirs and investigates the use of solvents for blockage removal. A cubic equation of state is used to model the phase behavior of three-phase mixtures of solvent, hydrocarbons and water. The three-phase flash model is coupled with a rigorous three-phase capillary pressure model to account for the effect of capillary pressure. The capillary pressure function includes the impact of several important petrophysical properties such as pore size distribution and wettability. A compositional simulator is used to simulate the effectiveness of using methanol, dimethyl ether or CO2 to remove liquid blockage and increase production rate.
|File Size||1 MB||Number of Pages||14|
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