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Carbon Dioxide Demonstration Project Supporting Research at KU

Carbon Dioxide Demonstration Project Supporting Research at KU. Jyun-Syung Tsau presented for Tertiary Oil Recovery Project Advisory Board Meeting October 19-20, 2001. Supporting Research Activities. Simulation Hall-Gurney field (LKC formation) Bemis-Shutts field (Arbuckle formation)

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Carbon Dioxide Demonstration Project Supporting Research at KU

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  1. Carbon Dioxide Demonstration Project Supporting Research at KU Jyun-Syung Tsau presented for Tertiary Oil Recovery Project Advisory Board Meeting October 19-20, 2001

  2. Supporting Research Activities • Simulation • Hall-Gurney field (LKC formation) • Bemis-Shutts field (Arbuckle formation) • Laboratory experiments • Slim-tube displacement • Residual oil measurement

  3. Simulation • Reservoir simulator • VIP black oil simulator • Primary production, waterflooding • VIP compositional simulator • CO2 flooding

  4. Compositional Simulator • Equation of state (EOS) for CO2-oil phase behavior characterization and properties calculation • Peng-Robinson 3-parameter EOS model

  5. Typical Data Preparation for Compositional Simulation • C7+ characterization (sub-grouping heavy end) • Pseudoization (grouping) • Phase behavior calculation (swelling test) • Slim-tube displacement

  6. Laboratory Displacement Data to Fine Tune Reservoir Simulator • Slim-tube displacement experiment • Ideal porous media • Oil recovery attributed to phase behavior • MMP (minimum miscibility pressure) indicates the pressure required to develop multiple-contact miscibility • Fine tune EOS parameters in reservoir simulator

  7. T T T T Milton Roy pump CO2 source BPR CO2 N2 source Oil Effluent ISCO pump ISCO pump Schematic of Slim-tube Experiment Apparatus

  8. Oil Recovery Performance in Slim-tube Experiment(Letsch #7 oil) Temp: 105 °F

  9. MMP Measurements of Letsch #7 Oil

  10. Oil Recovery Performance Match

  11. Determination of Residual Oil Saturation to Carbon Dioxide Why it is important? • Miscibility developed by multiple contact results in variable amount of oil left behind in CO2-swept zone • Uncertainty in projection of oil recovery by the simulator

  12. Critical Issues to the Measurements • Measurement needs to account for • Well defined development of miscibility • Representative fluid and rock properties

  13. Schematic of Residual Oil Saturation Measurement Apparatus

  14. Characteristics of Slim-tube and Core Sample

  15. Future Tasks • Investigate the effect of displacement rate, core length and structure on residual oil saturation determination • Investigate the effect of water saturation on the residual oil saturation to CO2

  16. Evaluation of Arbuckle Crude Oil for Oil Recovery by CO2 Displacement • Conduct experiment to measure MMP of crude oil obtained from Arbuckle formation • Perform simulation to match current field condition and test the reservoir response to pressurization process

  17. MMP Measurements of Peavey #B1 Oil (Bemis-Shutts field) Temp: 108 °F

  18. Current Reservoir Condition • Average reservoir pressure is around 500 psia, which is not high enough for CO2 miscible displacement • Reservoir must be pressurized

  19. Approaches • Construct a generic model to simulate the process of • Primary production • Pressurization • Model contains • 126 active production wells in a 2 by 2 square miles area (2560 acres)

  20. Grid Cell System Used in the Model

  21. 3400' 86 ft 3486' aquitard aquifer 2 miles Cross Section of the Reservoir Formation • 11 layers with permeability ranging between 0.2 ~5 md in aquitard and 50 ~1500 md in production zones

  22. Satisfactory Match • Simulation results were to match • Reservoir average pressure • Cumulative oil and water production • Current oil and water production rate

  23. Observations • Reservoir is a layered reservoir with high permeability contrast between layers • Bottom water drive Edge water drive does not provide enough energy to support the average reservoir pressure and production performance

  24. Pressure Distribution at the End of Primary Production (Beginning of Pressurization)

  25. Simulation Tests to Pressurize a Project Area • 5 spot pattern (10 acres) with 6 confining injectors (within 120 acres)

  26. Well Condition Parameters During the Pressurization • Injector • 5-spot: BHP: 2000 psia, Qmax: 3000 bbl/day • Confining area: BHP: 2000 psia, Qmax: 3000 bbl/day • Producer • 5-spot: shut-in • Around confining area: BHP: 1100 psia, Qmax: 300 bbl/day • Other active producers : BHP: 300 psia, Qmax: 300 bbl/day

  27. Pressure Distribution After 3-year’s Pressurization

  28. Summary of Pressurization Process • The magnitude of pressure increase within a pattern depends on the size of the pattern, confining area, and bottom hole pressure control of injectors and producers. • The ultimate pressures within the pattern varied from 1200 psia to 1500 psia.

  29. Preliminary Results • Attainable reservoir pressure might slightly below the MMP as required for a miscible CO2 displacement • Oil recovery remains relatively high (70 ~85%) for a few hundred psi below MMP

  30. Current Status • Oil and gas samples collected from the wellhead and separator were analyzed by Core-Lab • High nitrogen content was found on some of the separator samples through the quality check, which suggests the needs to measure MMP and oil recovery using a live oil sample • Detailed PVT test and swelling test would be conducted by Core-Lab, and data would be used for compositional simulation

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