Post on 15-Jul-2015
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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
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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
CO2 flooding
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Compositional Simulator
Equation of state (EOS) for CO2-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 reservoir simulator
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Schematic of Slim-tube Experiment Apparatus
C O 2
s o u r c e
Milton Roy
pump
Effluent
N2 s o ur c
e
C O 2
O i l
T
TT
ISCOpump
ISCO
pump
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 1.2
CO2 injection (HCPV)
O i l p r o d u c e d ( H C P V )
1305 psia
1015 psia
Temp: 105 °F
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MMPMeasurements 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 )
Experiment
Simulation_bip0.05
Simulation_bip0.0735
Pressure = 1305 psia
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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
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Critical Issues to theM
easurements
Measurement needs to account for
± Well defined development of miscibility
± Representative fluid and rock
properties
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Schematic of ResidualOil Saturation
Measurement Apparatus
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Characteristics of Slim-tube and
Core Sample
Slim-tube Core sample
Length (inch) 459.48 1.9205
I.D. (inch) 0.2425 0.9845
Bulk volume (cc) 347.80 23.96
Pore volume (cc) 127.76 5.26
Porosity (%) 36.73 21.95
Permeability (md) 4900 453.73
Porous media Glass bead Berea sandstone
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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
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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
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MMPMeasurements of Peavey #B1Oil
(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 around
500 psia, which is not high enough for
CO2 miscible displacement
Reservoir must be pressurized
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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)
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Grid Cell System Used in theModel
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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
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 enough
energy 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-year¶s Pressurization
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Summary of Pressurization Process
The magnitude of pressure increase
within a pattern depends on the size of
the 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 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
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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