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MRCSP - Large-Scale CO2-Enhanced Oil Recovery and Geologic Storage Test in Mid t USAMidwestern USA
Presented by:
Carbon Sequestration Leadership ForumTechnical Group MeetingWashington, DCNovember 4, 2013
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Presented by:Neeraj Gupta, Ph.D. Senior Research Leader , Battelle, Columbus, [email protected]
DOE/NETL Cooperative Agreement # DE-FC26-0NT42589
MRCSP – cornerstone of the Battelle’s program on the CCUS technology development
AEP Mountaineer Projects • Site Characterization, Design• Permitting, Construction• Operations, workover
Regional Carbon Partnership
Wellbore Integrity
Simplified Modeling
FutureGen Program
• Post-Injection Monitoring• >150,000 hours of safe drilling Storage Feasibility in
Sichuan Basin China
• Regional Mapping• Policy & Regulation• Small-Scale Tests
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FutureGen Program• 1 MT/yr scale• Design/costing• Class VI permitting
Ohio Valley Characterization, Basin-Scale Modeling
• Large-Scale Test• EOR and Storage• Exploration
Private Client Studies – Domestic and Global
Emerging Program in Brine Disposal, EOR, Shale Gas
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The MRCSP assesses viability of carbon sequestration
• Established in 2003 by Battelle with DOE-NETLBattelle with DOE-NETL funds – Currently in Phase III
• Led by Battelle, there are 40 organizations from non-profit, government, and commercial entities
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• Mission – The premier resource for CO2 storage and utilization expertise in the region
MRCSP region: Many CO2 emission sources with dependence on coal
• CO2 storage/utilization technologies key to g yaffordable energy supplies
• Environmental/climate issues and shale gas, are leading to energy supply transition
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• Coal continues to be dominant fuel source, but will be impacted due to emission limits
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Overall schedule for MRCSP – 10 Years of achievements and more to come!
2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018
Phase I
Phase IIILarge Scale Field Validation
Phase IISmall Scale Validation
Characterization
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g
Site Selection, Permitting, Site Characterization, Site Preparation, and Baseline Monitoring
MI Injection Operations(Multiple Reefs)
Post Injection Monitoring
OH Site MI SalineMI EOR Fields
MRCSP region has many large historic oil and gas producing areas
• ~ 8,500 million metric tons of CO2 could be t d ithi d l t d
Oil and gas fields map for region*
stored within depleted O&G fields (~10 years worth of regional emissions)*
• Using CO2 for EOR could lead to the production of an
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production of an additional ~1.2 billion barrels* of oil
• However, EOR needs to be proven in the region
* Source: Estimates developed by the Geological Surveys within the MRCSP
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MRCSP large-scale test site —only CO2–EOR site in the Midwest
Location: Otsego County, Michigang y, g
Host Company: Core Energy LLC
Reservoir Type: Closely-spaced, highly compartmentalized oil & gas fields located in the Northern Michigan Niagaran Reef Trend
Source of CO2: N t l G P i Pl t
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Natural Gas Processing Plant
Injection Goal: At least 1 million metric tons of CO2 over ~four years
MRCSP study fields are in multiple oil production stages
Oil fields are in various production life-cycle stages
• Late Stage EOR Reefs• Late-Stage EOR ReefsUndergone extensive primary and CO2-EOR – highly depleted
• Active EOR ReefsCompleted primary oil recovery and CO2-EOR is under way
• Pre-EOR Reefs – New CO2 EOR
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Undergone primary oil recovery but no CO2-EOR yet Reef Surface
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Existing EOR infrastructure enables cost effective research for MRCSP tests• Infrastructure:
• CO2 uptake from capture
• Compression and d h d ti t
Dover 35 Dover 36 dehydration systems
• Pipelines for transport
• Central processing facility (Dover 36)
• Injection and production-monitoring wells (7 fields)
• Monitoring and
Core Energy Existing Pipeline
Charlton 6
Charlton 30/31Dover 33
Dover 35
Chester 5
Chester 2
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gmeasurement systems
• Total system capacity is >1200 tonnes/day (10-15% of 500MW coal-based plant)
Core Energy Compressor
Dover 36 Processing Facility – central hub for fluids and data flow
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Geologic Setting – Complex Reef Structures
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Highly depleted field provides a test bed for advanced monitoring technologies
Reservoir TestingInSAR
Total Test
850
900
950
1000
1050
1100
Pre
ssu
re (psi
(a))
-16
-12
-8
-4
0
Gas R
ate (M
Mscfd
)
pdata
pmodel
qgas
pi (syn) 800.0 psi(a)
p*model 809.2 psi(a)
Cumwater 0.00 Mbbl
Cumgas -18.852 MMscf
kh 3750.00 md.ft
h 150.000 ft
k 25.0000 md
sd 5.000
Xe 1559.000 ft
Ye 2430.000 ft
Xw 779.500 ft
Yw 1215.000 ft
Dover 33
Na
90
10
80
20
70
30
60
40
50
50
40
60
30
70
20
80
10
90
Geochemistry
Wireline Logging
Gravity Survey
8000 10 20 30 40 50 60 70 80 90 100 110 120 130
Time (h)
Pressure & Temperature
1460
1480
1500
1520
1540
1560
1580
1600
1620
0 10 20 30 40 50 60 70
Days
Pre
ssu
re (
PS
I)
Press ure1
Press ure2
Press ure3
Press ure4
60
65
70
75
80
85
90
95
0 10 20 30 40 50 60 70
Days
Te
mp
era
ture
(F
)
Temp1
Temp2
Temp3
Temp4
Pressure Temperature
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Monitoring options under testing at Dover 33 field
Vertical Seismic
Ca K90 80 70 60 50 40 30 20 10
Microseismic
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MRCSP Phase III Field Activities – Dover 332012 2013
Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sept Oct Nov Dec
Baseline Characterization Long‐Term Injection Operations
Baseline Geochemical Sampling
Vertical Seismic Profiling
Reservoir Testing and Microseismic Testing
Gravity Survey
Well Workovers and Wireline Logging
p g
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Repeat Geochemical Sampling
Start of Long-Term Injection – April 23
Repeat Geochemical Sampling
Pressure Fall Off Testing
Pressure response in 3 wells in late-stage reef
All 3 wells show progressive
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All 3 wells show progressive increase in pressure following each CO2 injection event, indicating the reservoir is behaving as a closed system
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Developing detailed geologic model work for MRCSP based on seismic and well log data
Log and core correlationSeismic Interpretation Geologic Framework Model
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The modeling integrates seismic and well log dataProvides basis for fluids flow models
Final Geologic Model
Porosity
MRCSP Dynamic reservoir simulationsExpected Outcome:
• Full accounting for (1) reservoir geologyand (2) compositional phase behavior
Strategy:
Dover-33 pressure predictions using IMEX13n17May13\Dover33_CO2injsch_krmani_25mD_BHP300_current.irf
R (
psi
)
day
)3,000
4,000
3.00e+6
4.00e+6
Strategy:
• CO2-Prophet for initial simulations
• GEM (Computer Modeling Group) to model multiphase flows for CO2-EOR
• Requires detailed information about (1) rock / fluid properties and (2) production history
C b d f ll h f hi t
Ave Pres HC POVO SCTR Entire Field Solvent Rate SC CO2inj
Time (Date)
Av
e P
res
HC
PO
VO
SC
TR
So
lven
t R
ate
SC
(b
bl/
d
2013-4 2013-7 2013-10 2014-1 2014-4 2014-7 2014-10 2015-10
1,000
2,000
0.00e+0
1.00e+6
2.00e+6
2e+9
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• Can be used for all phases of history matching (primary, CO2-EOR, depleted), flood design and production forecasting
• Possible partial or full coupling of flow, geochemistry, and geomechanics
Time (Date)
Cu
mu
lati
ve
Gas
SC
(ft
3)
1980 1985 1990 19950e+0
5e+8
1e+9
2e+9
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2013 YTD (end August) Production by Reefs
MRCSP – Understanding CO2-EOR System-wide operations• Data collection and reporting from all fields
• Compilation and review of historic operations data
• Systematic calibration of flow meters
1000
1500
2000
2500
10 000
15,000
20,000
25,000
30,000
cte
d/P
rod
uc
ed
(M
MC
F)
Oil
(BB
L)
2013 YTD (end August) Production by Reefs
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Charlton 30/31 EOR
Unit
Charlton 6 EOR Unit
Chester 2 EOR Unit
Chester 5 EOR Unit
Dover 33 EOR Unit
Dover 35 EOR Unit
Dover 36 EOR Unit
Gross Oil (BBL) 20,037 5,836 28,166 4,997 45 17,706 23,982
CO2 Injected (MMCF) 738 488 765 587 1960 204 1004
CO2 Produced (MMCF) 863 583 631 149 3 168 1029
0
500
0
5,000
10,000
CO
2 In
jeMonitoring in Active EOR Reefs
• Work plan approved by DOE – Review historical operations
– Selected piggyback monitoring
– Model one reef in detail
– Evaluate mass balance and retention
5000
6000
7000
8000
9000
10000
80000
100000
120000
140000
160000
180000
e C
O2
(MM
CF
)
ve O
il (
BB
L)
Charlton 30/31EOR flood began in 2006
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0
1000
2000
3000
4000
0
20000
40000
60000
80000
1/1/
05
6/1/
05
11/1
/05
4/1/
06
9/1/
06
2/1/
07
7/1/
07
12/1
/07
5/1/
08
10/1
/08
3/1/
09
8/1/
09
1/1/
10
6/1/
10
11/1
/10
4/1/
11
9/1/
11
2/1/
12
7/1/
12
12/1
/12
5/1/
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Cu
mu
lati
ve
Cu
mu
lati
v
Cumulative Oil (BBL) Cumulative CO2 Injected (MMCF)
Cumulative CO2 Produced (MMCF) Net CO2 in Reef (MMCF)
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MRCSP Outreach Goals
Support the large volume injection test
Updated communication plan for restructured project
Maintain reputation of MRCSP as a neutral and credibleMaintain reputation of MRCSP as a neutral and credible source of scientific information on CCS
Over 20 Topical Reports available
Over 30 Presentations and Briefings available on MRCSP Website
Improve public understanding and acceptance of CCS
Synthesizing project results into key findings and messages for stakeholders.
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for stakeholders.
Increase public understanding of EOR, subsurface activities, and their role in the larger energy mix
Speaking at conferences and meeting with trade associations
Western Michigan
Geology Teams From Nine States Part of MRCSP to Conduct Regional Characterization and Implementation Plans
New York State M
gUniversity
Indiana University
Rutgers University
Museum
Ohio Geo Survey
Pennsylvania Geo Survey
2020
University of Kentucky
West Virginia Geo Survey
Maryland Geo Survey
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Finding storage options in Appalachian Basin• Battelle is working with oil/gas operators to obtain crucial geologic data
for mapping storage zones
• Funded by Ohio Coal Development Office as a joint effort with MRCSP
OCDO piggyback wells
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4
(1) Lee Family Trust
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11
12
13
14
p ggyOther wells in database
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(1) Lee Family Trust(2) McCoy(3) Dager(4) Ohio #1 CO2(5) Devco(6) Miley(7) AEP #1(8) McKelvey(9) Raynor D #1(10) #1 Jarrell(11) Georgetown
Marine(12) #1 Northstar(13) Adams(14) Silcor(15) Frankovitch(16) Burger
7 8
910
Copper Ridge vuggy Dolomite Core 8370’
MRCSP status and plans
• MRCSP Phase III injection began Feb. 2013 –
• ~350K tonnes till Oct. 2013 in Dover 33 and other active reefs
• Up to 500,000 tonnes of CO2 injection planned in Dover 33 depleted reef
• Additional fields for new CO2-EOR tests with ~500,000 tonnes planned
• >200,000 tonnes injection monitored in active reefs by Oct. 2013
• A period of monitoring after completion of injection
• Wells to be returned for normal operations by Core Energy at the end
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Work presented here has been conducted by Battelle Geosciences team, our collaborators, and field services providers
Acknowledgements
N j G t Ph D
providers
Projects have been sponsored by The US DOE, The Ohio Coal Development Office, and several companies
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Neeraj Gupta, Ph.D. Senior Research Leader, Battelle, Columbus, Ohio
[email protected] 614-424-3820
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