solution of benchmark problems for co 2 storage min jin, gillian pickup and eric mackay heriot-watt...
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![Page 1: Solution of Benchmark Problems for CO 2 Storage Min Jin, Gillian Pickup and Eric Mackay Heriot-Watt University Institute of Petroleum Engineering](https://reader035.vdocuments.us/reader035/viewer/2022062511/5515f29f550346cf6f8b54bf/html5/thumbnails/1.jpg)
Solution of Benchmark
Problems for CO2 Storage
Min Jin, Gillian Pickup and Eric MackayHeriot-Watt University
Institute of Petroleum Engineering
![Page 2: Solution of Benchmark Problems for CO 2 Storage Min Jin, Gillian Pickup and Eric Mackay Heriot-Watt University Institute of Petroleum Engineering](https://reader035.vdocuments.us/reader035/viewer/2022062511/5515f29f550346cf6f8b54bf/html5/thumbnails/2.jpg)
Outline
• Introduction
• Problem 1– Leakage through an abandoned well
• Problem 2– Enhanced methane recovery
• Problem 3– Storage capacity in a geological formation
• Conclusions
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Numerical Simulation
• Simulation is a very important tool for CO2 storage
• Can give estimates of– migration of CO2 gas
– dissolution in brine– build-up of pressure around injection
well– etc
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Reliability
• Depends on– Input data
• geological structure• rock permeability/porosity measurements• laboratory measurements
• Also depends– Adequate computer models
• flow equations• representation of physical processes
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Reservoir Simulation
• Codes are complex• Various different versions available
for– gridding model– calculating fluid properties– solving equations
• May get slightly different answers
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Benchmark Problems
• Compare solutions using different codes
• If results are the same– gives confidence in simulation results
• If they are different– indicates where more work is needed
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Stuttgart Workshop, April 2008
• Aim– Discuss current capabilities of
mathematical and numerical models for CO2 storage
• Compare results of 3 benchmark problems
• Focus model development on open questions and challenges
• 12 groups participatingweb site: http://www.iws.uni-stuttgart.de/co2-workshop/
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Heriot-Watt Entry
• Solutions to all 3 problems
• Eclipse 300– Reservoir simulation software package– Compositional simulation– Schlumberger
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Outline
• Introduction
• Problem 1– Leakage through an abandoned well
• Problem 2– Enhanced methane recovery
• Problem 3– Storage capacity in a geological formation
• Conclusions
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Problem 1
• CO2 plume evolution and leakage through an abandoned well
aquifer
aquifer
aquitard
leaky well
1000 m
k = 0 mD,= 0.0
k = 200 mD,= 0.15
k = 200 mD,= 0.15
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Problem 1
• CO2 plume evolution and leakage through an abandoned well
aquifer
aquifer
CO2 injector
aquitard
leaky well
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Problem 1
• CO2 plume evolution and leakage through an abandoned well
aquifer
aquifer
CO2 injector
aquitard
?leaky well
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Model Details
• Lateral extent of model: 1000 m x 1000 m
• Separation of wells: 100 m• Aquifer thickness: 30 m
– perm: 200 mD, poro = 0.15
• Aquitard thickness: 100 m– impermeable
• Abandoned well– model as thin column of 1000 mD, poro =
0.15
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Details of Fluid Properties
• Problem 1.1– Reservoir is very deep, ~3000 m– Simplified fluid properties
• constant with P and T
• Problem 1.2– Shallower reservoir, <800 m
– CO2 can change state when rising
– More complex fluid properties
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Other Inputs to Simulation
• Constant injection rate– 8.87 kg/s
• Pressure should stay constant at the edges of the model
• No-flow boundaries top and bottom
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Challenges
• Gridding– Coarse over most of model– Fine near wells
x
y
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Close-up of Grid Centre
leaky wellinjector
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Challenges
• Modelling of abandoned wella) Model as high perm columnb) Model as closed well
• output potential production
high perm cells closed well
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Challenges
• Maintaining pressure constant at boundaries
• Eclipse designed for oil reservoirs– assumes sealed boundaries
• leads to build up of pressure
• We added aquifers to sides of the model
– fluids could move into the aquifer– prevented build up of pressure
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Challenges
• Fluid properties in Problem 1.2a) User-definedb) Specified as functions of pressure and
temperature
• We used constant T = 34 oC– Tuned equations
• density and pressure similar to specified values
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CO2 Distribution after 100 Days, Problem 1.2
InjectorLeaky well
Gas Sat
0.0 0.2 0.4 0.6 0.8
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CO2 Distribution after 2000 Days, Problem 1.2
Gas Sat
0.0 0.2 0.4 0.6 0.8
Inj leaky well
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Results
• Leakage rate for Problem 1.2
0.00
0.02
0.04
0.06
0.08
0.10
0.12
0.14
0 500 1000 1500 2000 2500
time (day)
leak
age
volu
me/
inje
ctio
n v
olu
me
(%)
leaky well modelled as high perm cells
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Summary of Problem 1
• Successfully predicted well rate– Using high perm cells for leaky well
• well model overestimated leakage
– Our results similar to others
• Leakage rate ~ 0.1% injected volume
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Outline
• Introduction
• Problem 1– Leakage through an abandoned well
• Problem 2– Enhanced methane recovery
• Problem 3– Storage capacity in a geological formation
• Conclusions
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Problem 2
• Enhanced recovery of CH4 combined with CO2 storage
kh = 50 mDkv = 5mD = 0.23
CO2 injector
producer
200 m
45 m
200 m
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Model Details
• Two versions1. homogeneous2. layered
• Temperature = 66.7 oC• Depleted reservoir pressure = 35.5
bar• Molecular diffusion = 6 x 10-7 m2/s
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Model for Problem 2.2
P
x
z
I
0 10 20 30 40 50 60 70 80 90 100
Perm (mD)
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Other Inputs to Simulation
• Constant injection rate for CO2
– 0.1 kg/s– inject into lower layer– produce from upper layer
• Constant pressure at production well– P = 35.5 bar
• No-flow across model boundaries
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Challenges
• Mixing of gases
• Changes in physical properties of gas mixture with composition– can be modelled in Eclipse 300
• Numerical diffusion– will artificially increase the molecular
diffusion
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Result for Problem 2-1
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Results – Homogeneous Model
0.00
500.00
1000.00
1500.00
2000.00
2500.00
3000.00
0 200 400 600 800 1000 1200 1400 1600 1800 2000
time (day)
mas
s f
lux
(kg
/d)
CH4 CO2
• Mass Flux of CH4 and CO2
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Results – Layered Model
0
500
1000
1500
2000
2500
3000
0 200 400 600 800 1000 1200 1400 1600 1800 2000
time (day)
mas
s fl
ux
(kg
/d)
CH4 CO2
• Mass Flux of CH4 and CO2
![Page 34: Solution of Benchmark Problems for CO 2 Storage Min Jin, Gillian Pickup and Eric Mackay Heriot-Watt University Institute of Petroleum Engineering](https://reader035.vdocuments.us/reader035/viewer/2022062511/5515f29f550346cf6f8b54bf/html5/thumbnails/34.jpg)
Results and Summary
• Assume well is shut down when CO2 production reaches 20% by mass
• Relatively easy problem
Problem Model Shut-in time (days)
Recovery Efficiency (%)
2.1 homogeneous 1727 59
2.2 layered 1843 64
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Outline
• Introduction
• Problem 1– Leakage through an abandoned well
• Problem 2– Enhanced methane recovery
• Problem 3– Storage capacity in a geological formation
• Conclusions
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Problem 3
• Storage capacity in a geological model
Inj
x
y
z0.17 0.19 0.21 0.23 0.25
porosity
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Model Details
• Lateral dimensions– 9600 m x 8900 m
• Formation thickness– between 90 and 140 m
• Variable porosity and permeability
• Depth ~ 3000 m
• Temperature = 100 oC
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Challenges
• Simulation of system after injection has ceased– CO2 continues to rise due to buoyancy
– Brine moves into regions previously occupied by CO2
– Brine can occupy small pores, trapping CO2 in larger pores
• additional trapping mechanism• hysteresis
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Challenges
• Trapping of CO2 by hysteresis
after Doughty, 2007
Plume of rising CO2
CO2 displacing brine
brine displacing CO2
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CO2 Distribution after 25 Years
Gas Sat
0.0 0.2 0.5 0.8
Y
X
withhysteresisfault
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CO2 Distribution after 50 Years
Gas Sat
0.0 0.2 0.5 0.8
Y
X
withhysteresisfault
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Results
• Mass of CO2 in formation over time
0.0E+00
2.0E+09
4.0E+09
6.0E+09
8.0E+09
1.0E+10
1.2E+10
1.4E+10
0 5000 10000 15000 20000
Time (days)
Mas
s o
f C
O2
totalfreedissolved
(kg)
![Page 43: Solution of Benchmark Problems for CO 2 Storage Min Jin, Gillian Pickup and Eric Mackay Heriot-Watt University Institute of Petroleum Engineering](https://reader035.vdocuments.us/reader035/viewer/2022062511/5515f29f550346cf6f8b54bf/html5/thumbnails/43.jpg)
Results• Leakage of CO2 across the boundaries
CO2 inter-region mass flow rate for Problem 3
0
0.2
0.4
0.6
0.8
1
1.2
1.4
1.6
0 2000 4000 6000 8000 10000 12000 14000 16000 18000 20000
Time (day)
Mas
s F
low
rat
e (k
g/s)
P3-1
P3-2no hysteresis
with hysteresis
![Page 44: Solution of Benchmark Problems for CO 2 Storage Min Jin, Gillian Pickup and Eric Mackay Heriot-Watt University Institute of Petroleum Engineering](https://reader035.vdocuments.us/reader035/viewer/2022062511/5515f29f550346cf6f8b54bf/html5/thumbnails/44.jpg)
Summary of Problem 3
• CO2 did not move towards the fault– moved up-dip– leaked across model boundary
• Hysteresis did make difference, but not much difference in this example
• About 0.2 of the injected CO2 dissolved after 50 years
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Outline
• Introduction
• Problem 1– Leakage through an abandoned well
• Problem 2– Enhanced methane recovery
• Problem 3– Storage capacity in a geological formation
• Conclusions
![Page 46: Solution of Benchmark Problems for CO 2 Storage Min Jin, Gillian Pickup and Eric Mackay Heriot-Watt University Institute of Petroleum Engineering](https://reader035.vdocuments.us/reader035/viewer/2022062511/5515f29f550346cf6f8b54bf/html5/thumbnails/46.jpg)
Conclusions
• Benchmark solutions highlight difficulties– Adaptation of simulator for oil/gas
reservoirs to CO2 storage
– Difficulties are surmountable
– Schlumberger created new module for CO2 storage
• Participation in the workshop– Giving us confidence in simulations
![Page 47: Solution of Benchmark Problems for CO 2 Storage Min Jin, Gillian Pickup and Eric Mackay Heriot-Watt University Institute of Petroleum Engineering](https://reader035.vdocuments.us/reader035/viewer/2022062511/5515f29f550346cf6f8b54bf/html5/thumbnails/47.jpg)
Acknowledgements
• We thank Schlumberger for letting us use the Eclipse simulation software
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Solution of Benchmark
Problems for CO2 Storage
Min Jin, Gillian Pickup and Eric MackayHeriot-Watt University
Institute of Petroleum Engineering