a systematic assessment of enhanced oil recovery …
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A SYSTEMATIC ASSESSMENT OF ENHANCED OIL RECOVERY AND CO-SEQUESTRATION POTENTIAL FOR CO2IN OHIO’S DEPLETED OILFIELDSS. MISHRA, C. MCNEIL, J. HAWKINS, E. HOWAT, A. HAAGSMA, M. YUGULIS,
I. FUKAI, A. PASUMARTI AND T. BARCLAY
Carbon Management Technology Conference 2015
Sugar Land, TX, November 17th – 19th, 2015
AbstractThe goal of this study is to develop process understanding and evaluate technical and economic feasibility of
CO2 utilization foe enhanced oil recovery (EOR) and geologic storage in Ohio. Our focus is on depleted oil fields
in the Clinton sandstone (Eastern Ohio) and the Knox Dolomite Group (North-Central Ohio). These fields are
promising candidates for CO2-assisted EOR because of poor primary recovery efficiency that leaves behind
approximately 80–90% of the original oil in place. A systematic assessment of EOR and co-sequestration
potential for CO2in these depleted oil fields has not been undertaken to date – which is the objective of this
research project. In this paper, we will describe our findings related to:
• Source-sink matching for characterizing potential stationary sources of CO2 with respect to their location and
size, and comparing that to the distribution of depleted oil fields using pipeline routing tools,
• Production history assessment for evaluating CO2 sequestration potential based on production-based
voidage replacement calculations,
• Reservoir characterization for developing geologic framework models for “reference” reservoirs in the Clinton
and Knox formations via integration of well-log and core analysis data,
• Fluid property characterization for evaluating empirical correlations to predict oil, gas, water, and
CO2 pressure-volume-temperature (PVT) relationships,
• Reservoir simulation studies based on the geologic framework models to better understand field-scale areal
and vertical sweep efficiencies for both continuous and water-alternating-gas CO2-EOR processes, and
• Economic analyses including compilation of capital and operating expenses representative of field conditions
in Ohio; and cost-benefit analysis for CCUS operations.
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Project Goals
• Develop a rigorous framework for fully evaluating the
potential for CO2-assisted EOR and geologic storage in
Ohio’s depleted oil fields,
• Develop process understanding and evaluate technical
and economic feasibility of CCUS in the region,
• Focus on Clinton Sandstone and Knox Group Dolomite
formations (under-pressured, low permeability reservoirs
with poor primary recovery), and
• Provide systematic assessment of CO2-EOR and geologic
storage potential in these reservoirs.
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Storage Capacity Estimation Method
CO2 storage capacity was calculated using a production-based equation,
which uses actual oil and gas production to evaluate storage.
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Reservoir
Barrels
MCF CO2
CO2 Formation
Volume Factor
Reservoir
Barrels Stock Tank
Barrels
Oil Formation
Volume Factor
x +Reservoir
Barrels
Gas Formation
Volume Factor
MCF Gas
x
Oil Production Gas Production
Storage Capacity Estimation Results
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CO2 Storage Capacity
(Production Method)
Million Metric Tons (MMT)
72 - 154
0.004 - 25
25 - 72
The 30 major oilfields had a combined
total of 878 million metric tons of CO2
storage capacity.
Geologic Model Development
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• Integration of data from
geologic analysis and
reservoir characterization
• Building “static earth model”
for each oilfield of interest
▪ Create a 3D grid incorporating
porosity and water saturation
• Export developed model as
input to dynamic reservoir
modeling effort
Geologic Model Building and Results
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• Challenges
▪ lack of information on
distribution of natural
fractures,
▪ sparse advanced log
coverage in study
areas, and
▪ minimal availability of
core samples for
developing porosity-
perm relationship.
Reservoir Fluid Properties Study
• An Excel-based toolbox for predicting fluid properties of oil, gas, brine and CO2
has been developed using literature-based and newly developed correlations
▪ Formation volume factor
▪ Solution-gas liquid ratio (gas in oil, CO2 in water)
▪ Density
• These correlations are primarily a function of pressure, temperature, oil gravity,
gas gravity and salinity (as appropriate)
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▪ Isothermal compressibility
▪ Viscosity
▪ Gas deviation factor
Reservoir Simulation
• Goal Evaluate the feasibility of CO2-EOR for reference
Ohio reservoirs in terms of reservoir performance
following CO2 injection
• Develop reservoir model(s) to integrate known geologic,
fluid and production data
• Calibrate models to observed production history
• Quantify incremental oil recovery following CO2 injection
and amount of CO2 stored
• Examine sensitivity of injection scenarios to geologic and
engineering factors
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Reservoir Simulation Results - ECOF
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Cumulative Oil vs Time
Cumulative Stored CO2 vs Time
Strategy Performance at End of EOR Period
Reservoir Simulation Results - MCOF
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Cumulative Oil vs Time
Cumulative Stored CO2 vs Time
Strategy Performance at End of EOR Period
Oilfield Sink Capacity vs Emission Source Volume – Source-Sink Matching
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• Buffer maps were generated to determine the emission sources in close proximity
to ECOF and MCOF.
• A pipeline routing analysis was carried out to determine the optimal routes from
the top 45 emission sources to ECOF and MCOF.
Cost-Benefit Analysis Methodology
• CO2-PROPHET reservoir
performance model
• Ohio-specific well cost data
+ cost models established
in previous studies.
• Results include: NPV (net
present value), IRR (internal
rate of return), and a break-
even cost of CO2.
• Applied to ECOF and MCOF
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Cost-Benefit Analysis Results
• Example calculations
▪ For both ECOF and MCOF
▪ With representative pattern elements
▪ Using Oil price = [40, 70, 100] $/bbl
▪ Using CO2 cost = [40, 80, 100] $/ton
• NPV analysis shows good project
economics at $100/bbl oil for most
CO2 price scenarios
• Breakeven analysis suggests that
for every dollar increase in oil price,
corresponding increase in break-
even cost of CO2 is ~$4 per ton
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Project Key Findings
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Incremental oil
recovery as a % of
primary production
with CO2-EOR for
ECOF & MCOF
70 - 120 %
Tons of CO2 stored
for every 100
barrels of oil
produced
5 - 12
Change in breakeven
CO2 cost per $
change in the
oil price
~4x
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Depleted Oil
Fields
Original Oil in
Place [MMbbls]
8,851
Cumulative
Production
[MMbbls]
1,274
CO2 Storage
Capacity [MMt]
878
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Stationary
Sources
Million Metric Tons
CO2 Emitted Per
Year
129
Sources are Coal-
Fired Plants
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CO2 Emissions
Come From Coal-
Fired Power Plants
63%
800.201.2011 | [email protected] | www.battelle.org
Collaborators: Neeraj Gupta, Mark Kelley,
Amber Conner, Ola Babarinde, Jackie Gerst, Mark Moody,
Rick Peterson, Samin Raziperchikolaee, Priya Ravi Ganesh,
Jacob Markiewicz, Natalie Zeleznik, Jared Schuetter,
Ashley Kubatko and Jacob Markiewicz.
Funding for this study was provided by Ohio Development
Services Agency’s Ohio Coal Development Office (OCDO) grant
agreement OOE-CDO-D-13-24 in conjunction with the Midwest
Regional Carbon Sequestration Partnership (MRCSP) grant
agreement number DE-FC26-05NT42589.
Acknowledgments