Central Appalachian Basin Unconventional Reservoir Small Scale CO Injection Tests Coalbed ...

43 Pages·2017·8.42 MB·English

Central Appalachian Basin Unconventional
Reservoir Small Scale CO Injection Tests
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Coalbed Methane and Shale

Nino Ripepi, Michael Karmis, Ellen Gilliland, Charles Schlosser
Virginia Center for Coal and Energy Research at Virginia Tech
SSEB Annual Stakeholders Briefing
March 8, 2018
Acknowledgments
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•  Acknowledgments

•  Financial assistance for this work was provided by the U.S. Department of

Energy through the National Energy Technology Laboratory’s Program under

Contract No. DE-FE0006827.

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Motivation for Test
¬  Carbon Capture, Utilization and Storage (CCUS)
§  Utilization is key to make the business case make sense for carbon capture
¬ Previous funded Tests
¬ Russell County, VA – 1,000 ton test
¬ Central Appalachian Geologic Characterization
¬ Black Warrior Basin, Alabama
¬ Regional need for CO2 Sink in Appalachia focused on Utilization
¬ Coal and Shale
§  Adsorption of CO2 on the organic surface – safe and secure
§  CO2 can displace unrecovered methane and enhance recovery
§  Infrastructure in place
§  Low pressure
SECARB Phase II
Previous Experience in Huff and Puff Test
in Russell County, Virginia (2009)
Production curve for huff-and-puff test well,
•  1000-ton CO injection
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Russell County, Virginia, 2009

•  Stacked coal reservoir

•  Evidence of preferential
adsorption: elevated N and
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CH
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•  Enhanced CH recovery at
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two offset wells, no CO
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breakthrough

•  EUR of test well has
increased by 85 percent
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65% of CO2 Retained in Russell County Test
SECARB Phase II – Black Warrior Basin Test
Current Project Overview:
Goals and Objectives
¬  Objectives:
§  Inject up to 20,000 metric tons of CO2 into 3 vertical CBM wells over a one-year period in
Central Appalachia
§  Perform a small (approximately 400-500 metric tons) Huff and Puff test in a horizontal
shale gas well
¬ Goals
§  Test the storage potential of unmineable coal seams and shale reservoirs
§  Learn about adsorption and swelling behaviors (methane vs. CO2)
§  Test the potential for enhanced coalbed methane (ECBM) and enhanced gas (EGR) production and recovery
¬ Major tasks:
§  Phase I: site characterization, well coring, injection design
§  Phase II: site preparation, injection operations
§  Phase III: post-injection monitoring, data analysis, reservoir modeling
Research Partners
•  Virginia Center for Coal and Energy Research (Virginia Tech) 1,2,3,4,5
•  Marshall Miller & Associates 2,3
•  Gerald Hill, Ph.D. 1,4
•  Southern States Energy Board 1,5
•  Virginia Dept. of Mines, Minerals and Energy 3 1 Project management
2 Operations
•  Geological Survey of Alabama 3
3 Research
•  Sandia Technologies 3
4 Risk management
•  Det Norske Veritas (DNV) 4
5 Outreach
•  Consol Energy (Research Group) 2,3
Industrial Partners
Collaborators
•  Schlumberger
•  Consol Energy (CNX Gas)
•  Global Geophysical Services
•  Harrison-Wyatt, LLC
•  Oak Ridge National Laboratory
•  Emory River, LLC
•  University of Nottingham / British Geological Survey,
•  Dominion Energy
University of Tennessee, University of Virginia,
•  Alpha Natural Resources
•  Southern Illinois University, Oklahoma State University
•  Flo-CO2; Praxair; Trimeric
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Shale CO Injection Test (510 tons)
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Morgan County, Tennessee
•  Horizontal well in Chattanooga Shale formation, drilled in 2009

•  Legacy producing gas well permitted under TDEC

•  510 tons for “huff and puff” injection test

•  Injection period: March 18-31, 2014 (14 days)

•  Shut-in period: March 31- July 29, 2014 (~4 months)

•  Flowback period: July 29, 2014- present (~24 months)

•  Current status: site closed

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Shale CO Injection Test in Morgan County, Tennessee
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Operations Overview
Storage
Vessel
Injection
Skid
Propane Heater
HW-1003
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