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Transcript of MRCSP and Regional CCUS – Accomplishments and Outlook · 11/8/2017 1 DOE/NETL Cooperative Agr...
11/8/2017
1
DOE/NETL Cooperative Agreement # DE-FC26-0NT42589
Annual MRCSP Partners Meeting November 2, 2017
Washington DC
Neeraj GuptaBattelle
MRCSP and Regional CCUS –Accomplishments and Outlook
Outline – CCUS Building Blocks
• MRCSP large-scale test status
• AEP Mountaineer completion
• Understanding and Mitigating Risks
CCUS Resource Assessment
Well integrity
Geomechanics
• International Capacity Building
• MRCSP Outreach
• Summary
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MRCSP is Part of the Regional Carbon Sequestration Partnership Initiative
Objectives are to advance operational, monitoring, and modeling techniques needed to:
Develop and validate reservoir models useful for commercial scale applications
Address public concerns such as leakage and long-term storage security
Address other topics such as cost effectiveness and CCUS practicability
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Primary goal: To execute a large-scale scale CO2 injection test to evaluate best practices and technologies required to implement carbon sequestration
Over 10 million metric tons stored
Historical Snapshot of MRCSP –14 Years of Progress
• One of seven DOE-funded regional partnerships to develop infrastructure for wide-scale CO2 sequestration deployment
Late‐stage EOR reef
Operational EOR reef
Newly targeted reef
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MRCSP Basin Large-Scale Injection
• Objective – Inject/monitor 1 million metric tons of CO2 in collaboration with EOR operations.
• Evaluate CO2 injectivity, migration, containment
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MRCSP Michigan Basin Test Site
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Late-stage
Active
Main Test Bed
Active
Pre EOR
Active
Active (new)
Active (new)
Active
Active
Active
EOR Facilities owned and operated by Core Energy
Natural gas processing is the source of the CO2
• Complete CCUS value chain
• >20 years EOR ops.
• Expand research withnew reefs
• Flexible researchportfolio
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139341 357 374
597
974
1,466
2,074
0
500
1,000
1,500
2,000
2,500
Net
in R
eef
CO
2 (M
T)
Th
ou
san
ds
Net in Reef CO2 (Thousand MT)
Total EOR Net In Reef CO2 (MT)
Injection Test Status – Cumulative Storage• Accounting for Associated storage over EOR lifetime since 1996
• >800,000 net storage under MRCSP monitoring
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Late Stage Reef – Testing Post-EOR Storage Potential
Main CO2 Injection Period ~250,000 tonnes CO2 injected
Original discovery pressure is ~2,900 psi
Microseismic Monitoring Test
~15,000 tonnes CO2
injected
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Evaluating Injection – Working with Complex EOR System• Added monitoring in more complex reefs with 2 to 3 partly
connected lobes, multiple injection wells
New EOR reef- drilling of two new wells• New injection and monitoring
wells drilled
• Core, wireline logging, and monitoring completed
• Advanced monitoring
Distributed Acoustic, Temp.
Multi-level pressure
• Injection started in Jan 2017
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Advanced Monitoring- Distributed Fiber Optic Systems
Regional Characterization – A Geologic Storage Mapping Collaboration
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State geological surveys are:
• Compiling/interpreting data
• Developing common terminology for formations across state boundaries
• Creating maps andother tools MRCSP's
Geology Team
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• AEP-1 Stratigraphic Test Well was drilled in 2002
• Project included extensive data collection and community outreach
• Feasibility – Wildcat Well Drilling • Construction & Commissioning
AEP Mountaineer Project Spanning 15 years of CCS Experience
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Injection and Operations Monitoring
• A network of five wells, two injection wells and three monitoring wells was constructed (drilling and completion) in 2008-2009.
• The wells were integrated with the capture system on-site
• A pressure maintenance and monitoring system was installed
• ~37,000 tons of CO2 was injected and stored over 18 months from 2009 to 2011
• Monitoring included monitoring of reservoir pressure, groundwater chemistry, CO2 injectate, and soil gas.
Post-Injection and Site Closure• Post-injection monitoring
includes pressure monitoring to feed plume modeling
• Post-injection period was reduced from 20 years to 5 years by working with regulators and proving all permit requirements had been met.
The AEP Mountaineer Project Began by Drilling a Characterization Well in 2003 Extensive data was collected as part of the
project.
− Wireline logs, whole core, seismic
The wildcat well, AEP-1, was constructed such that it could be converted to an injection well should the project move forward.
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The Monitoring Program at the AEP PVF Site was a Comprehensive, Integrated Program
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The PVF project at the AEP Mountaineer Power Plant consisted of a 20 MW CO2 Capture and Storage System
CO2 Capture and Injection took place from October 2009 - May 2011
Injection into two reservoirs, the Rose Run Sandstone and the Copper Ridge Dolomite
Well network of 2 injection wells and 3 reservoir monitoring wells
Protection and monitoring of the USDW
Differential reservoir pressure monitoring
CO2 plume assessment through modeling
Well network mechanical integrity and well condition maintenance
Monitoring Goals & Requirements
Program Approach
Local groundwater sampling and analysis
Downhole pressure / temp. data collection
Reservoir pressure data analysis
Frequent well observation/ maintenance surface & well
The AEP PVF Project has Completed All Site Closure Operations; Awaiting Final Regulatory Concurrence
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• The two CO2 plumes are stable and modeling shows that they extend approximately 990 to 1050 ft. for the Copper Ridge formation and approximately 510 to 600 ft. for the Rose Run formation
The program at AEP during the post-injection monitoring phase was successful.
• Differential pressure has return to pre-injection or near pre-injection levels
• Injected CO2 poses no threat to the USDW
• All regulatory and operational program requirements and goals have been met
• Due to the success of the site care and monitoring program, three of the wells were plugged in 2014
• Following a two phased schedule, the remaining two monitoring wells were plugged in 2017
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Calculation of Prospective Stacked CO2 Storage Resource
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Regional Assessment In Eastern Ohio
Co-Funded by ODSA/OCDO Project D-13-22
Permeability (mD)
Ohio’s Oilfields of Interest
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30Depleted Oil
Fields
Original Oil in Place [MMbbls]
8,851
Cumulative Production [MMbbls]
1,274
CO2 Storage Capacity [MMt]
878
Co-Funded by ODSA/OCDO Project D-13-24, D-15-08
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Geological Analysis in Data-Limited Areas
Minimum Miscibility Pressure Estimation
Effects of Fractures on CO2-EOR/Storage
Source-Sink Pairing for Economic Analysis
Risk Assessment for Wellbore Integrity Loss
CO2 Huff’n’Puff Injectivity Testing
CO2 Utilization for EOR and Geologic Storage in Ohio’s Depleted Oilfields
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• Find and fix a leak• Environmental
remediation• Injection interruption• Technical remedies• Legal costs• Business disruption to
others• Labor burden to
others
A. Leakage
C. Encounters groundwater
D. Escapes to surface
B. Interferes with surface activities
Develop Low‐ and High‐Cost Storylines
Quantify Scenario Costs
Identify Leakage Outcomes Identify Costs
• Find and fix a leak• Environmental
remediation• Injection interruption• Technical remedies• Legal costs• Business disruption to
others• Labor burden to
others
A. Leakage
C. Encounters groundwater
D. Escapes to surface
B. Interferes with surface activities
Develop Low‐ and High‐Cost Storylines
Quantify Scenario Costs
Identify Leakage Outcomes Identify Costs
Mid-Atlantic U.S. Offshore Carbon Storage Resource Assessment
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BCT Baltimore Canyon Trough GBB Georges Bank Basin
Stationary Sources of CO2 (U.S. DOE-NETL NATCARB v. 1502)
0 225 km
WellIndustry Seismic LineUSGS Seismic Line
75 km
LAMONT-DOHERTYEARTH OBSERVATORY
• Potentially only CCS option for eastern US
• Storage resource assessment using legacy wells and seismic data
~171,000 lm2 on continental shelf
Three key sub-regions
44 legacy wells
Reprocessing 4,000 miles of seismic
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CarbonSAFE Phase I: Integrated Pre-Feasibility
FE0029219 Columbia University‐Offshore
Washington, British Columbia
FE0029276 BattelleNorthern Michigan Basin
FE0029466 BattelleCentral Appalachian Basin
FE0029186 North DakotaBeneath Gerald Gentleman Station, Sutherland, NE
FE0029264 Battelle
Columbus, NE/Red Willow County, NE
FE0029474 University of
KansasGarden City, KS
FE0029302 University of WyomingRock Springs Uplift
FE0029375 University of WyomingDry Fork Station
FE0029489 EPRIBakersfield, CA
FE0029280 University of Utah Rocky Mountains
FE0029280 University of Texas at AustinNorthwest Gulf of
Mexico
FE0029274 Louisiana State University
Louisiana Chemical Corridor
FE0029445 University of IllinoisIllinois East Basin
Evaluating Geomechanical Risks for CO2 Storage
• Realistic analysis of geomechanical risk factors related to CO2 storage:
Which reservoir rock formations are more fractured in the region?
Which caprocks have larger risk factors related to fracturing?
What are the key methods and tools for evaluating fractured zones in deep layers?
How can we better understand basin-scale stress-strain regime to more accurately define stress magnitude at depth?
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Wellbore Integrity – CCUS in Oil/Gas Rich Regions• Old wells seen as a risk for CO2 storage
• Regional status of oil and gas wells, cement bond logs, field monitoring of sustained casing pressure, spatial analysis of wellbore integrity indicators, 6 test study areas
• Results provide better understanding of implications of wellbore integrity issues for CO2
storage projects in the region
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MaghrebMaghreb
KosovoKosovoJordanJordan
EgyptEgypt
BotswanaBotswanaIndonesiaIndonesia
ChinaChina
MexicoMexico
South AfricaSouth Africa
International Capacity Building –Extending MRCSP’s Value
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• MRCSP experience used for international CCS projects with multilateral funding
• Projects in China, Mexico, and South Africa
• Significant emphasis on local capacity building
World Bank CCS Trust Fund Phase I and Phase II Countries
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Regional Structure and Faults
Source: China Geological SurveySeismic Setting
China Sichuan Basin Pre-Feasibility
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• Site Screening Using Geological Setting – Sichuan Basin Example
Regional Structure and Faults
• Plan/execute a pilot-scale CO2 storage testin onshore Zululand Basin with concurrent capacity building
• 10,000 to 50,000 MT injection in saline reservoir
South Africa Pilot CO2 Storage Program• Six tasks in Planning Phase:
Setting Project Management Framework
Project Management Services
Integrated Capacity Building
Data Acquisition, Examination and Archiving
Geological Modeling
Plan for Zululand Basin Exploration
• Continuation to Phase II for pilot test execution under discussion
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South Africa Pilot Test – Storage Complex Assessment
• Legacy well and seismic data evaluated and modeled
• New seismic surveys and slim hole characterization planned for two sub-areas
MRCSP Outreach – Sharing Lessons Learned to Foster CCUS Development
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www.mrcsp.org Message Mapping
Stakeholder Meetings
Factsheets and BPMs
Conferences and Papers
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MRCSP Outreach – Enhanced Technical Dissemination
• IEAGHG Monitoring Workshop
• GHGT-13 papers
• CCUS Conference
• North American Trilateral Meetings
• Mission Innovation
• Peer-reviewed papers
• SPE Grand Challenges
• SPE SRMS Document
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Michigan is Tech Savvy Training, 2017
IEAGHG Workshop, Traverse City, 2017
Related Technical Outreach – CCUS and Beyond
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Large-Scale Test - Sustained Progress
• >800,000 metric tons net stored under MRCSP monitoring
• >2 M metric tons stored since start of EOR in 1996
• Completed injection at main test bed in late-stage reef
Performed microseismic monitoring in final injection stage
Post-injection PNC, microgravity, and VSP completed
Post-injection test well drilled and characterized
Returned to normal EOR operations, with continued accounting and pressure monitoring
• Added new EOR reefs with complex geology to monitoring
• Drilled new wells and initiated advanced fiber-optic monitoring
• Advancements in static and numeric modeling processes
• Developed performance metrics to assess storage capacity
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All Critical Milestones and Objectives On Track
Summary of Lessons Learned
• CO2 measurement/accounting can be performed with high level of confidence in an inter-connected multi-field EOR complex
• Storage potential in closed reservoirs evaluated, after active EOR ends
• Geologic complexity within and across reefs affects CO2injection, migration, and storage
• Pressure monitoring remains the mainstay for managing injection operations and monitoring reservoir response
• Advanced monitoring technologies still require testing/validation for confident assessment of plume development
• Characterization-monitoring-modeling loop requires more research for cross-validation over the life-cycle
• A well developed CO2-EOR regulatory/policy framework with financial incentives essential for enhanced associated storage
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Regional Partnerships Essential For Advancing CCUS - Locally, Regionally, and Globally
• Partnerships have contributed significantly towards CCUS development in the US and globally
• The program has been highly recognized under several peer-reviews
• The overall program has excelled in meeting key objectives
• Partnerships remain a major resource in their study regions
• Significant work still remains to be done to advance CCUS and share knowledge from the programs
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Acknowledgements
Battelle’s MRCSP Current Contributors – Mark Kelley, Srikanta Mishra, Matt Place, Lydia Cumming, Sanjay Mawalkar, Charlotte Sullivan, Priya Ravi Ganesh, Autumn Haagsma, Samin Raziperchikolaee, Amber Conner, Glen Larsen, Caitlin Holley, Joel Main, Jacob Markiewicz, Isis Fukai, Ashwin Pasumarti, Jackie Gerst, Rod Osborne, and others
DOE/NETL – Agreement # DE-FC26-0NT42589, Andrea McNemar (PM)
Core Energy, LLC – Bob Mannes, Rick Pardini, Allen Modroo, Bob Tipsword, Kim Sanders, Kathy Dungey, and several others
Ohio Development Services Agency’s Ohio Coal Development Office
MRCSP’s technical partners, sponsors, and host sites since 2003
The MRCSP Region’s State Geology Survey and University team members
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