jyun syung
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Carbon Dioxide Demonstration ProjectSupporting Research at KU
Jyun-Syung Tsau presented for
Tertiary Oil Recovery ProjectAdvisory Board Meeting
October 19-20, 2001
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Supporting Research Activities
Simulation Hall-Gurney field (LKC formation) Bemis-Shutts field (Arbuckle formation)
Laboratory experiments Slim-tube displacement Residual oil measurement
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Simulation
Reservoir simulator VIP black oil simulator
Primary production, waterflooding VIP compositional simulator
CO 2 flooding
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Compositional Simulator
Equation of state (EOS) for CO 2-oil phase behavior characterization and properties calculation
Peng-Robinson 3-parameter EOS model
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Typical Data Preparation for
Compositional Simulation C7+ characterization (sub-grouping
heavy end) Pseudoization (grouping) Phase behavior calculation (swelling
test) Slim-tube displacement
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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 developmultiple-contact miscibility
Fine tune EOS parameters in reservoirsimulator
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Schematic of Slim-tube Experiment Apparatus
C O
2
s o u r c e
Milton Roypump
Effluent
N2 s o
ur c e
C O
2
O i l
T
TT
ISCOpump
ISCOpump
BPR
T
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Oil Recovery Performance in Slim-tube Experiment(Letsch #7 oil)
0
0.2
0.4
0.6
0.8
1
0.0 0.2 0.4 0.6 0.8 1.0 1.2CO2 injection (HCPV)
O i l p r o
d u c e
d ( H C P V )
1305 psia1015 psia
Temp: 105 F
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MMP Measurements of Letsch #7 Oil
40
50
60
70
80
90
100
800 900 1000 1100 1200 1300 1400
Pressure (psia)
R e c o v e r y
( % )
Recovery at 1.0 HCPV CO2 injection
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Oil Recovery Performance Match
0
0.2
0.4
0.6
0.8
1
1.2
0.0 0.5 1.0 1.5 2.0
CO2 injection (HCPV)
O i l p r o
d u c e
d ( H C P V )
ExperimentSimulation_bip0.05Simulation_bip0.0735
Pressure = 1305 psia
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Determination of Residual Oil Saturation
to Carbon DioxideWhy it is important? Miscibility developed by multiple
contact results in variable amount ofoil left behind in CO 2-swept zone
Uncertainty in projection of oilrecovery by the simulator
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Critical Issues to the Measurements
Measurement needs to account for Well defined development of
miscibility Representative fluid and rock
properties
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Schematic of Residual Oil SaturationMeasurement Apparatus
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Characteristics of Slim-tube and
Core SampleSlim-tube Core sample
Length (inch) 459.48 1.9205
I.D. (inch) 0.2425 0.9845Bulk volume (cc) 347.80 23.96
Pore volume (cc) 127.76 5.26
Porosity (%) 36.73 21.95Permeability (md) 4900 453.73
Porous media Glass bead Berea sandstone
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Future Tasks
Investigate the effect of displacementrate, core length and structure on
residual oil saturation determination Investigate the effect of water saturation
on the residual oil saturation to CO 2
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Evaluation of Arbuckle Crude Oil for Oil
Recovery by CO 2 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
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MMP Measurements of Peavey #B1 Oil(Bemis-Shutts field)
40
50
60
70
80
90
100
800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800
Pressure (psia)
O i l r e c o v e r y
( % O
O I P )
Temp: 108 F
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Current Reservoir Condition
Average reservoir pressure is around500 psia, which is not high enough for
CO 2 miscible displacement Reservoir must be pressurized
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Approaches
Construct a generic model tosimulate the process of Primary production Pressurization
Model contains 126 active production wells in a 2 by 2
square miles area (2560 acres)
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Grid Cell System Used in the Model
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Cross Section of the Reservoir Formation
11 layers with permeability rangingbetween 0.2 ~5 md in aquitard and 50~1500 md in production zones
86 ft
2 miles
a q u
i f e r
3486'
3400'
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Satisfactory Match
Simulation results were to match Reservoir average pressure Cumulative oil and water production Current oil and water production rate
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Observations
Reservoir is a layered reservoir with high permeability contrast between layers
Bottom water drive Edge water drive does not provide enoughenergy to support the average reservoir
pressure and production performance
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Pressure Distribution at the End of Primary Production(Beginning of Pressurization)
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Simulation Tests to Pressurize a Project Area
5 spot pattern (10 acres) with 6confining injectors (within 120 acres)
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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
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Pressure Distribution After 3- years Pressurization
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Summary of Pressurization Process
The magnitude of pressure increasewithin a pattern depends on the size ofthe pattern, confining area, and bottomhole pressure control of injectors and
producers. The ultimate pressures within the
pattern varied from 1200 psia to 1500 psia.
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Preliminary Results
Attainable reservoir pressure mightslightly below the MMP as required for a
miscible CO 2 displacement Oil recovery remains relatively high (70
~85%) for a few hundred psi below MMP
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Current Status
Oil and gas samples collected from thewellhead and separator were analyzed byCore-Lab
High nitrogen content was found on someof the separator samples through the qualitycheck, which suggests the needs to measureMMP and oil recovery using a live oilsample
Detailed PVT test and swelling test would be conducted by Core-Lab, and data would be used for compositional simulation
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