reservoir modeling for eor associated storage in closed
TRANSCRIPT
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Reservoir Modeling for EOR Associated Storage in Closed Carbonate Reef Oilfields (MRCSP)
Priya Ravi Ganesh and Dr. Neeraj GuptaBattelle, Columbus, Ohio
IEAGHG Modeling and Monitoring Workshop
Morgantown, WV
August 6, 2014
DOE/NETL Cooperative Agreement # DE-FC26-0NT42589
MRCSP‘s 10 years of achievements!
2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018
Phase IIILarge Scale Field Validation
Site Selection, Permitting, Site Characterization, Site Preparation,
and Baseline Monitoring
MI Injection Operations
(Multiple Reefs)
Post Injection
Monitoring
Phase IISmall Scale Validation
Phase ICharacterization
2 IEAGHG Modeling and Monitoring Workshop, Morgantown, WV
OH Site MI Saline MI EOR Fields
0
200
400
600
800
1000
1200
1.0E-10 1.0E-08 1.0E-06 1.0E-04 1.0E-02 1.0E+00 1.0E+02
pre
ssu
re b
uil
du
p (p
si)
r^2/t (m^2/s)
M2Φ,w - Eq. 21
M2Φ, eff - Eq. 25
STOMP
MBL - Eq. 9
MRCSP is part of a portfolio of Battelle
projects to enable CCS deployment
3
Field tests for MRCSP Geologic storage lead for
FutureGen 2.0
Post monitoring at
AEP Mountaineer
Developing simplified
models for DOE-Industry
R&D assessment of
wellbore integrity
Assessing CCUS
Options in Ohio
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV
Pinnacle reefs formed
in a shallow shelf of an
ancient ocean.
Closed carbonate reservoirs
surrounded by evaporite layers
General model of study area Depositional System
Core Energy’s EOR infrastructure used for
testing geologic storage of CO2
Core Energy
Compressor
Core Energy
Existing Pipeline
Charlton 6
Charlton 30/31
Dover 33
Dover 35
Chester 5
Dover 36
Chester 2
Dover 33 is the
main test bed
Active reefs also
being monitored
Natural gas processing
provides the CO2
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Pre-EOR reef TBD
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV
Dover 33 Reef EOR Operations
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0
200,000
400,000
600,000
800,000
1,000,000
1,200,000
1,400,000
1,600,000
0
50,000
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500,0004/1
/96
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Cu
mu
lati
ve C
O2 (
MT
)
Cu
mu
lati
ve O
il (
BB
L)
Dover 33 - Cumulative Production/Injection
Cumulative Oil (BBL) Cumulative CO2 Injected (MT) Cumulative CO2 Produced (MT) Net CO2 in Reef (MT)
Phase III Injection
139,037
236,063
334,826340,767356,027356,015356,680368,265372,994374,494
462,256476,335
596,930653,435
807,672
974,134
1,133,991
1,321,633
1,378,224
0
200,000
400,000
600,000
800,000
1,000,000
1,200,000
1,400,000
1,600,000
1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014
Net
in R
eef
CO
2 (
MT
)
Net in Reef CO2 (MT)
Dover 33 EOR Unit Dover 36 EOR Unit Dover 35 EOR Unit
Charlton 30/31 EOR Unit Charlton 6 EOR Unit Chester 2 EOR Unit
Chester 5 EOR Unit Total EOR Net In Reef CO2 (MT)
Net CO2 in reefs increases over time
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV7
• Late stage, Dover 33, serves as main
test bed for monitoring techniques
• Instrumented wells and pipelines in active fields to track CO2 injection and CO2, brine, and oil production
• Lessons learned to applied for MVA in for newly targeted field for EOR
Borehole gravity meter
being assembled
Model assessing feasibility of the borehole gravity
meter to measure changes in formation density in
response to CO2
MRCSP Dover 33 field monitoring
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Modeling objective is to emulate actual
reservoir behavior
To build a representative model of the depleted Dover-33
reef (reservoir) that can help us predict/ validate reservoir
response to current CO2 injection.
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV9
Sensitivity of dynamic reservoir behavior
to alternate geologic models is studied
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Static Earth Model
(SEM) Level 1
Property distributions
constrained by geologic
formation surfaces.
Property distributions
constrained by
lithofacies.
Static Earth Model
(SEM) Level 2
Geologic surfaces based on 3D seismic and well data.
Dover-33 (carbonate reef) represented in
various levels of geologic detail
SEM1 Porosity Model
SEM2 Porosity Model
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Main dynamic modeling steps
2. System / reservoir specification
BLACK OIL MODEL
COMPOSITIONAL
MODEL
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV12
3. Model performance calibration to historical data
1. Fluids definition/ treatment
4. Injection response validation
Determining total compressibility in the absence of fluid saturation distribution from field.
Initialization of SEM1 in black oil simulator
1-3329565 55942
2,011,000 2,012,000 2,013,000
2,011,000 2,012,000 2,013,000
4,1
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4,2
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3,9
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4,1
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4,3
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4,4
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4,5
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4,6
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4,7
000.00 355.00 710.00 feet
0.00 110.00 220.00 meters
File: l1_prim_kmulti_2x_omegaco2 - copy.irf
User: RAVIGANESHP
Date: 7/30/2014
Scale: 1:5558
Z/X: 3.00:1
Axis Units: ft
0.00
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1.00
Water Saturation 1975-01-01 J layer: 17
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV13
Initial water
saturation
Successful replication of historical production
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(a) (b)
(d)(c)
Gas injection Avg. pressure
(a) (b)
(d)(c)
Oil production Gas production
Black-oil model under-predicts reservoir
pressure during CO2 injection
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV15
Pressure under-predicted possibly due to
Reservoir dimensions
CO2
Solubility
Compositional model
Initialization of the revised compositional
SEM1 model
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV16
Model revised to stay within lease boundaries.
Initial water
saturation
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV17
Preliminary history-match for compositional
model of Dover-33
Oil Production
Average reservoir pressure
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV18
Total compressibility, calculated from material
balance, varies for each injection period
∆𝑷 =𝑸
𝑨𝒉∅𝑪𝒕
Complex CO2 phase behavior influences
reservoir response
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV19
V V LL SL
V
L
S
Vapor
Liquid
Supercritical
Pressure response in the 3 wells provide
input indicators to reservoir analysis
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV20
All 3 wells show progressive
increase in pressure
following each CO2 injection
event, indicating the
reservoir is behaving as a
closed system
Summary and next steps
• Transition to compositional model.
• Link with analytical modeling to predict CO2
injectivity in other reefs.
• Extract single-well simulation model to match
injection-falloff periods.
• Incorporate geochemical and geomechanical
aspects in reservoir models.
• Compare modeling with other monitoring results.
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV21
Acknowledgements
• MRCSP is funded by DOE/NETL under Cooperative
Agreement # DE-FC26-0NT42589 with Andrea McNemar
as the DOE Project Manager
• Battelle’s MRCSP team
• Core Energy LLC, including Bob Mannes and Rick
Pardini
• Western Michigan University
IEAGHG Modeling and Monitoring Workshop, Morgantown, WV22