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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

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
Supporting Research Activities
  • Simulation
    • Hall-Gurney field (LKC formation)
    • Bemis-Shutts field (Arbuckle formation)
  • Laboratory experiments
    • Slim-tube displacement
    • Residual oil measurement
  • Reservoir simulator
    • VIP black oil simulator
      • Primary production, waterflooding
    • VIP compositional simulator
      • CO2 flooding
compositional simulator
Compositional Simulator
  • Equation of state (EOS) for CO2-oil phase behavior characterization and properties calculation
  • Peng-Robinson 3-parameter EOS model
typical data preparation for compositional simulation
Typical Data Preparation for Compositional Simulation
  • C7+ characterization (sub-grouping heavy end)
  • Pseudoization (grouping)
  • Phase behavior calculation (swelling test)
  • Slim-tube displacement
laboratory displacement data to fine tune reservoir simulator
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
schematic of slim tube experiment apparatus





Milton Roy pump

CO2 source



N2 source



ISCO pump

ISCO pump

Schematic of Slim-tube Experiment Apparatus
determination of residual oil saturation to carbon dioxide
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
critical issues to the measurements
Critical Issues to the Measurements
  • Measurement needs to account for
    • Well defined development of miscibility
    • Representative fluid and rock properties
future tasks
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
evaluation of arbuckle crude oil for oil recovery by co 2 displacement
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

MMP Measurements of Peavey #B1 Oil

(Bemis-Shutts field)

Temp: 108 °F

current reservoir condition
Current Reservoir Condition
  • Average reservoir pressure is around 500 psia, which is not high enough for CO2 miscible displacement
  • Reservoir must be pressurized
  • 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)
cross section of the reservoir formation


86 ft




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

simulation tests to pressurize a project area
Simulation Tests to Pressurize a Project Area
  • 5 spot pattern (10 acres) with 6 confining injectors (within 120 acres)
well condition parameters during the pressurization
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
summary of pressurization process
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.
preliminary results
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
current status
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