Carbon Dioxide Demonstration Project -Jyun-Syung

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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)

Laboratory experiments

± Slim-tube displacement

± Residual oil measurement



Simulation

Reservoir simulator

± VIP black oil simulator

Primary production, waterflooding

± VIP compositional simulator

CO2 flooding



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

C7+ characterization (sub-grouping

heavy end)

Pseudoization (grouping)

Phase behavior calculation (swelling

test)

Slim-tube displacement



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



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



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



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



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



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 theM

easurements

Measurement needs to account for

± Well defined development of miscibility

± Representative fluid and rock

properties



Schematic of ResidualOil Saturation

Measurement Apparatus



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



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 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



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



Current Reservoir Condition

Average reservoir pressure is around

500 psia, which is not high enough for

CO2 miscible displacement

Reservoir must be pressurized



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)



Grid Cell System Used in theModel



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'



Satisfactory Match

Simulation results were to match

± Reservoir average pressure

± Cumulative oil and water production

± Current oil and water production rate



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



Pressure Distribution at the End of Primary Production

(Beginning of Pressurization)



Simulation Tests to Pressurize a Project Area

5 spot pattern (10 acres) with 6confining injectors (within 120 acres)



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



Pressure Distribution After 3-year¶s Pressurization



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.



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

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

Documents

Carbon Dioxide Demonstration Project -Jyun-Syung