World Class CO 2 Sequestration Potential in Saline Formations, Oil and Gas Fields, Coal and Shale: The U.S. Southeast Regional Sequestration Partnership has it All! SPE 126619 Authors: Robin Petrusak, David Riestenberg, Patricia Goad, Karine Schepers, Advanced Resources International; Jack Pashin, Geological Survey of Alabama; Robert Trautz, Electric Power Research Institute; Richard Esposito, Southern Company
Acknowledgements Geological Survey of Alabama Electric Power Research Institute Southern Company and Mississippi Power Southern States Energy Board U.S. Department of Energy, National Energy Technology Laboratory, DE-FC26-04NT42590 Disclaimer : This material is based upon work supported by the Department of Energy National Energy Technology Laboratory under DE-FC26-04NT42590. This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference herein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or otherwise does not necessarily constitute or imply its endorsement, recommendation, or favoring by the United States Government or any agency thereof. The views and opinions of authors expressed herein do not necessarily state or reflect those of the United States Government or any agency thereof. 2 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Overview of Presentation Potential CO 2 storage capacity assessed to date: Oil and gas fields Saline reservoirs Coal seams and shale For saline reservoirs: Reservoir characterization and field validation of CO 2 injection and storage for the Lower Tuscaloosa -- a regional, large capacity, saline formation Summary CO 2 Injection wellhead at Mississippi Saline Formation Injection Test Site 3 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
CO 2 Sources of the SECARB Region Annual CO 2 emissions = 1045 million metric tons (1.05 Gt) Electric power generation: 860 million metric tons (82 %) Remaining 185 million metric tons (16%) from: Refineries, Gas processing, Chemical plants, Cement & fertilizer plants Other industrial production Most large CO 2 emission sources in the SECARB region are situated near multiple geologic storage options (Source: US DOE, 2008 Carbon Sequestration Atlas) 4 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
The SECARB Region has Multiple Large- Capacity Geologic Storage Options for CO 2 CO 2 Storage Reservoir Type Depleted Oil and Gas Fields CO 2 -EOR Saline Aquifer: Lower Tuscaloosa/ Woodbine Saline Aquifer: All other saline formations Gulf Coast Tertiary Coal: Wilcox Other Coal: Central Appalachian & Black Warrior Basins Barnett Shale Fayetteville Shale Billion metric tons, Gt Low High (P85) (P15) 29.7 5.0 19.4 2,261 19.7 1.2 19 14 29.7 5.0 77.9 9,044 28.2 2.1 27 20 Trillion cubic ft., Tcf Low High (P85) (P15) 560.4 95.1 368 40,906 378.6 23 356 266 560.4 95.1 1,471 170,934 540.8 39 508 380 Total 2,369.0 9,233.9 42,953 174,528 5 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Oil and Gas Fields 6 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Oil and Gas Fields: Storage Capacity Methodology 3,549 SECARB oil and gas reservoirs assessed for conventional CO 2 storage and CO 2 -EOR potential. Screened for: Appropriate depth for miscible CO 2 Appropriate reservoir pressure depletion Absence of significant faults and fracturing CO 2 storage replaces produced oil and gas Injected CO 2 displaces water and low pressure gas occupying pore space that previously contained oil/ natural gas Additional CO 2 storage from CO 2 -EOR; 4 Mcf of CO 2 stored for each incremental barrel of technically recoverable oil CO 2 miscible in residual oil and dissolves in residual water, Pressure decline from enhanced oil production yields more pore space for CO 2 Mineral trapping 7 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Estimated CO 2 Storage Capacity: Oil and Gas Fields of the SECARB Region Units = Gt TX = 4.0 + 2.3 AR = 0.25 + 0.1 LA = 6.8 + 1.2 MS = 0.4 + 0.18 Offshore = 17.8 + 1.1 (Figure modified from US DOE, 2008 Carbon Sequestration Atlas) Production to date: TN = 0 AL= 0.3 + 0.05 VA =0.01 + 0 FL= 0.11 + 0.07 44 Billion barrels oil; 332 Trillion cubic ft. gas Map shows estimated CO 2 storage capacity by state from replacement of oil and gas production. Plus, additional capacity from integrated CO 2 -EOR with storage Total conventional CO 2 storage capacity = 29.7 Gt Additional capacity from integrated CO 2 storage with EOR = 5 Gt 8 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Saline Reservoirs 9 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
CO 2 Storage Capacity for Selected Saline Reservoirs of the SECARB Region 1-4 13-51 43-171 2,063 8,254 1-5 20-79 (Figure modified from US DOE, 2008 Carbon Sequestration Atlas) Units = Gt 8-32 28-111 4-18 8-31 89-356 Estimated CO 2 storage capacity assessed to date = 2,280 9,122 Gt Storage mechanisms: Formation water displaced by immiscible CO 2 CO 2 dissolution Residual trapping (capillary trapping) Mineralization Storage efficiency: Compute total storage reservoir pore volume Apply storage efficiency factor to total reservoir pore volume 1 % (High confidence, P 85 ) 4 % (Low confidence, P 15 ) 10 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Conceptual Model of CO 2 Storage in Saline Reservoirs of the SECARB Region Multiple region-scale confining units Favorable reservoir architecture Thick sedimentary section of high porosity high permeability sandstones interbedded with low permeability barriers: (Source: Pashin and others, 2008, Geological Survey of Alabama) Limits vertical CO 2 movement Facilitates efficient use of pore volume and reduces plume Enhances dissolution and mineralization 11 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Tertiary and Cretaceous Saline Formations and Regional Confining Units - Examples (Source: Pashin and others, 2008, Geological Survey of Alabama) Significant Cretaceous saline formations in southeast MS and southwest AL Multiple potential CO 2 storage reservoirs distributed across a 5,000 + stratigraphic section. Significant confining units: Midway Group, Selma Group, Tuscaloosa Marine Shale 12 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Mississippi Saline Formation Injection Test Objective: Demonstrate safe, CO 2 injection and long-term storage in a large-capacity, regional saline reservoir. 13 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Lower Tuscaloosa CO 2 Storage Capacity Lower Tuscaloosa Group sandstones comprise one of several region-scale, large-capacity saline formations in the SECARB region. Current assessment of total storage CO2 storage capacity = 17 68.4 Gt Computed total storage reservoir pore volume and applied storage efficiency factors of 1% (Low Case) and 4% (High Case) to total reservoir volume. Woodbine Fm in East Texas Basin (equivalent to Lower Tuscaloosa) could provide additional 2.4 9.5 Gt capacity. Mississippi Saline Formation Injection Test validates favorable injectivity and efficient CO 2 storage. Test volume of 3000 tons natural-source CO 2 injected during October 2008 14 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
SECARB Phase II Mississippi Saline Formation Injection Test Site Location Map of Mississippi Power Co. Plant Daniel, Jackson Co., MS. Stratigraphic correlation chart showing Lower Tuscaloosa storage reservoir and confining units 15 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Lower Tuscaloosa Geologic Characterization SP, gamma ray, resistivity logs of Lower Tuscaloosa Massive sand in the observation and injection wells at the Mississippi Saline Formation Test Site Core images show upper storage reservoir sandstone and intersand lithology consisting of low permeability shale, siltstone and sandstone. injection zone Core permeability and porosity Representative thin-section of Lower Tuscaloosa Massive sandstone, 8539.5 ; Mag. = 50x; Blue epoxy shows porosity; Core porosity = 24.1%; Air permeability = 1850 md injection zone 16 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Reservoir Simulation of CO 2 Storage Simulation of the test injection volume of 3,000 tons shows that low permeability flow barriers increase reservoir volume contacted by CO 2, thus reducing plume footprint and enhancing dissolution and mineralization. After 1500 years; No Dissolution Case (plume dimensions of 1300 x 300 ; area = 14 acres) End of Injection After 1500 Years; Dissolution Case After 1500 Years; Mineralization Case Maximum plume extent occurs in Upper Sand Flow Barrier Upper Sand Flow Barrier Upper Sand Flow Barrier Upper Sand Flow Barrier Vertical migration of CO 2 Lower Sand Lower Sand Lower Sand Residual gas trapping Further simulation results suggest that the Lower Tuscaloosa Massive Sand at the Mississippi Test Site could accept commercial-scale quantities of CO 2 of more than 1 million tonnes per year (52 MMcfd) for 30 years 17 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Coal Seams and Gas Shale 18 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Coal Seams and Gas Shale: Storage Capacity Methodology CO 2 storage capacity is function of: Replacement of produced natural gas by CO 2 CO 2 adsorptive capacity Estimated CO 2 storage efficiency factor Production Replacement assumes 1:1 replacement of produced gas by CO 2 Mass of CO 2 stored by adsorption = (volume of coal/shale) x (concentration of CO 2 per unit volume) x (storage efficiency factor): G A h (100% ) Cg E CO 2 concentration per unit volume of coal/shale is obtained from adsorption isotherm data: VL p CgCO2 Storage Efficiency Factor, E ( PL p) 28 % (High confidence, P 85 ) 40 % (Low confidence, P 15 ) 19 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All; CO2 s
CO 2 Storage Capacity for Selected Coal and Shale Basins of the SECARB Region Fayetteville Shale 14-20 Barnett Shale 19-27 Units = Gt Black Warrior Basin Coal 0.9 1.3 Gulf Coast Tertiary Coal (Wilcox Fm.) 19.7 28.2 (Figure modified from US DOE, 2008 Carbon Sequestration Atlas) Central Appalachian Coal 0.3 0.8 53.9 77.3 Gt, Total CO 2 storage capacity appraised for 3 coal & 2 shale basins Total includes 468 Mt capacity appraised for commercial CBM fields. CO 2 storage has potential to increase CBM reserves by 30 %. Emerging gas shale plays offer additional potential capacity: Conasauga Fm. (Cambrian) Chattanooga Sh. (Devonian) Unnamed Devonian Shale Floyd Shale 20 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: (Mississippian) the U.S. SECARB Partnership has it All;
Capacity Assessment Example: Gulf Coast Tertiary Coal; Wilcox Group Play A Play B Play C Play C 5.7 8.2 Gt Play A 4.8 6.9 Gt Play B 9.2 13.1 Gt Figure modified from Barker and others, 2000, USGS) Figure modified from Barker and others, 2000, USGS) 21 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Capacity Assessment Example: Barnett Shale Ft. Worth Basin Showing Barnett Shale Thickness and Play Outlines for CO 2 Storage Capacity Calculation Emerging Play 5 7 Gt Primary ( Core ) Play 8 11 Gt Speculative Play 6 9 Gt (Figure modified after Pollastro and others, 2007 and Loucks and Ruppel, 2007) (Source: Koperna and others 2009; isopach modified from Jarvie and others, 2007) 22 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
Summary 23 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
World Class CO 2 Storage Potential in the SECARB Region Huge total capacity = 2,630 to 9,235 Gt; 96 % in saline formations Multiple saline formations offer potential for very efficient storage: High reservoir porosity and permeability provide good injectivity and pore volume Favorable reservoir architecture from multiple stacked storage reservoirs and interbedded flow barriers Fewer injection wells Smaller plume footprint The full range of CO 2 geologic storage options, including depleted oil and gas fields, CO 2 -EOR, coal seams and gas shale also contribute to the region s world-class potential. 24 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;
World Class CO 2 Storage Potential in the SECARB Region, cont. CO 2 -EOR a potential bridge technology to widespread deployment of commercial-scale CO 2 transport and storage. CO 2 storage capacity of coal seams and shale may offer important niche storage alternatives for remote, dispersed, or smallervolume CO 2 sources. Upside potential for CO 2 storage in coal and shale: Secure storage at shallow depths Enhanced coalbed methane production Enhanced shale gas production? Much uncertainty about effective CO 2 storage in coal and shale, especially with regard to injectivity. Two SECARB field validation tests in the central Appalachian and Black Warrior basins will help reduce uncertainty for coal seam storage. Equivalent tests have yet to be planned for shale. 25 SPE 126619 World Class CO 2 Sequestration in Saline Formations, Oil and Gas Fields, Coal and Shale: the U.S. SECARB Partnership has it All;