Geologic Carbon Storage: Pore Scale Reactive Transport & Inverse Modeling of a CO2 Pilot Test at Cranfield MS.
Abstract not provided.
Yoon, Hongkyu↗
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Cranfield Results Update - Denbury Staff Briefing
Southeast Regional Carbon Sequestration Partnership (SECARB): CCS in the US
Hovorka, Susan↗
SECARB "Early Test: at Cranfield
Southeast Regional Carbon Sequestration Partnership (SECARB): CCS in the US
Hovorka, Susan↗
Present Early Test Results at SECARB Industry Briefing [Slides]
Contents include the following presentations: 1) SECARB Phase III Early Test Cranfield, MS; 2) SECARB Phase III Early Test at Cranfield, March 9, 2010; 3) Update on Results of SECARB "Early" Test of Monitoring Large Volume Injection at Cranfield; 4) Progress Update SECARB "Early" Test Monitoring 3.5 Million Tons at Cranfield, March 7, 2012; 5) Cranfield Geophysical Monitoring Status and Results, March 8, 2012; 6) Large Volume CO 2 Injection at Cranfield, Early Field Test of the SECARB Phase III–Near-Surface Monitoring, March 7, 2012; 7) Shallow Groundwater Study at the Cranfield Site, March 12, 2013; 8) Subsurface Monitoring Studies–Results and Integration, March 12, 2013; 9) Review of the Petrophysics for the Cranfield Phase III Project, March 12, 2013; 10) Geomechanics at Cranfield, March 5, 2014; 11) Gulf Coast Carbon Center Near-Surface Update, March 4-5, 2014; 12) Monitoring Design Best Practices, March 5, 2014; 13) Assessing Impacts of CO 2 Leakage on Groundwater Quality and Monitoring Network Efficiency–Case Study at a CO 2 -EOR site, March 11, 2013; 14) Near-surface Stratigraphy and Geophysics, March 11, 2015; 15) Update on Reservoir Modeling and Final Testing and P&A Underway, March 11, 2013; 16) SECARB Early Test Retrospective; 17) Fluid Source Attribution at CCS and CO 2 -EOR Sites, March 8, 2016; 18) SECARB "Early Test" at Cranfield, March 8-9, 2017; 19) Analysis of Seismic Time-Lapse Observations at Cranfield; 20) SECARB Phase III Cranfield Project (Early Test), March 8, 2018; 21) Enhanced Analytical Simulation Tool (EASiTool) Dynamic Capacity Estimation; 22) Net Carbon Negative Oil Mass Accounting–Cranfield Case Study; 23) Knowledge Sharing; 24) Advancing Toward Commercialization Final Stages of the Early Test; 25) CO 2 EOR Feasibility in SECARB Region Limited by CH 4 ; 26) Understanding of CO2 Migration and Entrapment–Cranfield Site
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SECARB Semi-Annual Field Review Reports - Early Test
The Southern States Energy Board (SSEB) managed the overall Southeast Regional Carbon Sequestration Partnership (SECARB) Phase III project and The Bureau of Economic Geology (BEG), at the University of Texas at Austin, managed all activities associated with the Early Test field site near Cranfield, Mississippi (the Early Test or Cranfield Project). BEG was assisted in the management of site activities by Sandia Technologies (Sandia). BEG and Sandia implemented reporting procedures that included monthly and quarterly technical progress reports, as well as periodic reporting on key field activities. Subsequent sections of this report catalog the field activities and are organized in a semiannual chronology. The Cranfield Project was located approximately 12 miles east of Natchez, Mississippi. Denbury Onshore, LLC, began operating a commercial CO 2 flood of the field (using the subsurface injection of CO 2 for EOR) in June 2008. Carbon dioxide from the Jackson Dome, a natural source near Jackson, Mississippi, was delivered to the Cranfield oilfield via pipeline. Beginning in October 2008, the SECARB Early Test team characterized the surface and subsurface of the Cranfield site. During the field test CO 2 was injected into the lower Tuscaloosa Formation, a regionally extensive saline formation with the potential to hold millions of tons of CO 2 emissions. By January 2015, the team injected more than 11 million metric tons of CO 2 and monitored a total stored CO 2 mass of 5,326,975 metric tons. SECARB’s study operations occurred in four integrated research program areas within Cranfield field: (1) the High Volume Injection Test area (HiVIT); (2) the Detailed Area of Study (DAS); (3) the Geomechanical area; and (4) the near-surface observatory, also called the “P-site.” Carbon dioxide injection activities were conducted at the HiVIT and the DAS. Figure 1.1-1 provides a depiction of the DAS.
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SECARB Regional Project Assessment
The SECARB Cranfield Early Test Project was designed to safely demonstrate large-scale, long-term CO 2 injection and storage in a CO 2 -enhanced oil recovery (EOR) operation and associated saline reservoir. Storage during EOR operations has the potential to offset commercial costs, holding a significant promise for future large-scale deployment in the southeastern United States. Denbury Onshore LLC began CO 2 -EOR operations in July 2008 at the Cranfield oilfield located east of Natchez, Mississippi (Figure 1). The location offered an ideal setting to investigate storage monitoring at a commercial CO 2 -EOR operation. The field team, led by the Gulf Coast Carbon Center of the Bureau of Economic Geology at the University of Texas at Austin, deployed the largest suite of monitoring, verification, accounting (MVA) technologies to collect data to assess long-term CO 2 utilization and storage. The CO 2 injection interval is within the 3,000-meter-deep fluvial lower Tuscaloosa Formation, a large and regionally extensive saline reservoir, at a broad four-way structural closure that defines the Cranfield oilfield. Tests were conducted in the oil-producing area as well as in the non-oil-producing brine aquifer. The CO 2 used during EOR operation was transported via pipeline from the Jackson Dome, a natural source of CO 2 . The study focused on four integrated research areas: (1) the High-Volume Injection Test area (HiVIT); (2) the Detailed Area of Study (DAS); (3) the Geomechanical area; and (4) the near-surface observatory, also called the “P-site.” CO 2 injection occurred at the HiVIT and the DAS (Figure 2 and Figure 3). The DAS was located down-dip of the oil-water interface of the Cranfield oilfield. The well layout included one injection well and two down-dip observation wells. The team was the first of the regional partnerships to monitor more than 1 million metric tons of CO 2 . At the end of the project, the team monitored more than 11 million metric tons of CO 2 injected and 5 million metric tons of CO 2 stored. The Cranfield Project was the fifth project worldwide, and the first such project in the United States, to reach this CO 2 injection volume while being monitored to demonstrate storage effectiveness.
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Information Products & Communications Materials for COR and Contractors' Meetings [Slides]
Contents include the following: 1) Large Scale CO 2 Storage in the Lower Tuscaloosa Massive Sand Formation, December 12, 2007; 2) CoalFleet Program Update and Workshops, July 26-28, 2005; 3) Regional Carbon Sequestration Partnership Annual Review Meeting, November 18, 2009; 4) SECARB U. S. Regional Partnerships from Pilot to Demonstration, November 5, 2009; 5) The SECARB Anthropogenic Test–CO 2 Capture/Transportation/Storage, August 21-23, 2012; 6) Citronelle Project–Experiences With Permitting and Regulations on CCS, August 21, 2013; 7) Partnering With Industry for Large Scale CCS Projects, August 22, 2013; 8) Plant Barry-Citronelle Field Project, August 13, 2104; 9) SECARB's Early Test at Cranfield, Mississippi; 10) SECARB Partnership Early Test at Cranfield Status, August 18-20, 2015; 11) Citronelle Project, August 18, 2015; 12) Plant Barry 25 MW Demo; 13) SECARB Phase III Citronelle Project (Anthropogenic Test) in Alabama, August 18, 2015; 14) SECARB Early Test Retrospective; 15) SECARB Anthropogenic Test Lessons Learned, August 16-18, 2016; 16) SECARB Early Test at Cranfield, August 1-3, 2017; 17) Carbon Storage and Oil and Natural Gas Technologies Review Meeting, August 1-3, 2017; 18) SECARB Partnership Early Test at Cranfield, August 13-16, 2018; 19) SECARB Anthropogenic Test Update, August 13-16, 2018; 20) SECARB Partnership Early Test at Cranfield, August 26-30, 2019; 21) SECARB (Citronelle) Phase III, August 27, 2019.
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SECARB Pressure Monitoring Data
Bottom-hole, above zone monitoring interval, and injection zone pressure data collected during the SECARB project in Cranfield, Mississippi to assess the relationship between pressure field and multiphase field. Submission includes 10-second interval data from Detailed Area of Study wells: CFU31-F1 (injector), CFU31-F2 (observation), CFU31-F3 (observation) and Ella G Lees no. 7 (observation) well located west of the DAS. Associated Publications: Joy, C. A., 2011, The effects of pressure variation and chemical reactions on the elasticity of the lower Tuscaloosa sandstone of the Cranfield Field Mississippi, The University of Texas at Austin, Master’s thesis, 97 p. Kim, S., and Hosseini, S. A., 2013, Above-zone pressure monitoring and geomechanical analysis of a field scale CO2 injection, Cranfield Mississippi, Greenhouse Gases: Science and Technology, doi:10.1002/ghg.1388. Kim, S., and Hosseini, S. A., 2017, Study on the ratio of pore-pressure/stress changes during fluid injection and its implications for CO2 geologic storage: Journal of Petroleum Science and Engineering, v. 149, p. 138-150, doi:10.1016/j.petrol.2016.10.037. Mathias, S. A., Gluyas, J. G., Gonzalez Martinez de Miguel, G. J., and Hosseini, S. A., 2011, Role of partial miscibility on pressure buildup due to constant rate injection of CO2 into closed and open brine aquifers: Water Resources Research, v. 47, W12525, 11 p., doi:10.1029/2011WR011051. Meckel, T. A., Zeidouni, M., Hovorka, S. D., and Hosseini, S.A., 2013, Assessing sensitivity to well leakage from three years of continuous reservoir pressure monitoring during CO2 injection at Cranfield, MS, USA: International Journal of Greenhouse Gas Control, [insert volume no., page numbers], doi:10.1016/j.ijggc.2013.01.019. Nicot, J.-P., Oldenburg, C. M., Bryant, S. L., and Hovorka, S. D., 2009, Pressure perturbations from geologic carbon sequestration: area-of-review boundaries and borehole leakage driving forces, in Energy Procedia (v. 1, no.1), Proceedings of 9th International Conference on Greenhouse Gas Control Technologies, GHGT9, 16–20 November, Washington DC, p. 47–54. Tao, Q., Bryant, S. L., and Meckel, T. A., 2013, Modeling above-zone measurements of pressure and temperature for monitoring CCS sites: International Journal of Greenhouse Gas Control, v. 18, p. 523–530, doi:10.1016/j.ijggc.2012.08.011.
above zone monitoring interval↗
SECARB Bottom Hole Gravity Data
Borehole gravity measurements obtained during the SECARB project at the Cranfield oil site in Mississippi from CFU31-F2 and CFU31-F3 wells. Data was used to calculate density changes within the Cranfield reservoir and to test borehole gravity performance compared to a variety of other methods for monitoring the injected CO2 plume. Associated Publications: Dodds, K., Krahenbuhl, R., Reitz, A., Li, Y., Hovorka, S. D., 2013, Evaluation of time lapse borehole gravity for CO2 plume detection SECARB Cranfield: International Journal of Greenhouse Gas Control.
Borehole↗
SECARB Soil-Gas Monitoring Data
Soil-Gas monitoring data collected at the P-site and DAS study locations during SECARB project at Cranfield oil site in Mississippi. Data was used to study influence of gravel pad, pit, plants, and plugged and abandoned (P&A) oil well on near-surface soil-gas compositions. Associated Publications: Anderson, J. S., Romanak, K. D., Yang, C., Lu, J., Hovorka, S. D., and Young, M. H., 2017, Gas source attribution techniques for assessing leakage at geologic CO 2 storage sites: Evaluating a CO 2 and CH 4 soil gas anomaly at the Cranfield CO 2 -EOR site: Chemical Geology, v. 454, p. 93-104, doi:10.1016/j.chemgeo.2017.02.024 Hingst, M. C., 2013. Geochemical effects of elevated methane and carbon dioxide in near-surface sediments above an EOR/CCUS site, The University of Texas at Austin, Master’s thesis. http://hdl.handle.net/2152/21836 Lu, J., Kharaka, Y. K., Thordsen, J. J., Horita, J., Karamalidis, A., Griffith, C., Hakala, J. A., Ambats, G., Cole, D. R., Phelps, T. J., Manning, M. A., Cook, P. J., and Hovorka, S. D., 2012, CO 2 -rock-brine interactions in Lower Tuscaloosa Formation at Cranfield CO2 sequestration site, Mississippi, U.S.A.: Chemical Geology, v. 291, p. 269-277. Yang, C., Jamison, K., Xue, L., Dai, Z., Hovorka, S. D., Fredin, L., and Treviño, R. H., 2017, Quantitative assessment of soil CO 2 concentration and stable carbon isotope for leakage detection at geological carbon sequestration sites: Greenhouse Gases: Science and Technology, v. 7, no. 4, p. 680-691, doi:10.1002/ghg.1679. Yang, C., Romanak, K. D., Reedy, R. C., Hovorka, S. D., and Treviño, R. H., 2017, Soil gas dynamics monitoring at a CO2-EOR site for leakage detection: Geomechanics and Geophysics for Geo-Energy and Geo-Resources, v. 3, p. 351-364, doi:10.1007/s40948-017-0053-7
capture↗
How to sustain a CO 2 -thermosiphon in a partially saturated geothermal reservoir: Lessons learned from field experiment and numerical modeling
CO 2 has been proposed as a working fluid for geothermal energy production because of its ability to establish a self-sustaining CO 2 thermosiphon, taking advantage of the strong temperature dependence of CO 2 density. To test the concept of CO 2 heat extraction, in January 2015 a CO 2 thermosiphon was operated at the SECARB Cranfield Site, Cranfield, Mississippi, where a brine-saturated sand at a depth of 3.2 km has been under near continuous CO 2 flood since December 2009 as part of a U.S. Department of Energy demonstration of CO 2 sequestration, resulting in a partially saturated reservoir surrounding a well pair. The lateral distance between the producer and injector was 112 m at reservoir depth, a distance considered pre-commercial in scale, but great enough that thermal breakthrough was still not significant after several years of injection. Instead of producing power with a turbine, heat was extracted heat from recirculated fluid using a heat exchanger and portable chiller. The well field and surface equipment were instrumented to compare field observations with predicted responses from numerical models. Thermosiphon flow could be initiated by venting, but thereafter flow rate steadily declined, indicating that the thermosiphon was not sustainable. To model the system, the capability of T2Well, a fully coupled wellbore/reservoir numerical simulator, was expanded to enable simulation of the entire loop of fluid circulation in the fully-coupled system consisting of the injection/production wells, the reservoir, and the surface devices (heat exchanger, flow-rate regulator etc.). Combined with the newly developed TOUGH2 equation of state module called EOS7CMA, the enhanced T2 Well was used prior to the field experiment to simulate the circulation of a CO 2 -H 2 O-CH 4 mixture in a model geothermal system patterned after the Cranfield demonstration test. The model predicted that a sustainable thermosiphon could be achieved. After the field thermosiphon did not achieve the pre-test prediction of flow rates and thermosiphon sustainability, the numerical model was modified to improve realism and calibrate certain processes; it was then able to reproduce the major phenomena observed in the field. In a series of sensitivity studies, many factors were found that could potentially contribute to the failing of a sustainable thermosiphon. These factors could be categorized as two types: factors that increase the resistance to flow and factors that increase heat loss of the working fluid. In conclusion, the lessons learned can be applied to both future modeling and to achieving CO 2 -based geothermal reservoir exploitation.
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The Seismic Response to Injected Carbon Dioxide: Comparing Observations to Estimates Based Upon Fluid Flow Modeling
Time-lapse seismic amplitude differences and travel time shifts, obtained while monitoring enhanced oil recovery at Cranfield, Mississippi, reveal coherent changes that are associated with the injection of carbon dioxide. Rock physics modeling highlights the importance of the oil, brine, and gas content of pore fluids prior to the injection of carbon dioxide. For example, compressional velocity changes due to the injection of carbon dioxide can drop from 300 m/s to less than 100 m/s as the percentage of oil increases from 1% to 50%. Predictions based upon a new technique for modeling wave propagation in a poroelastic medium containing an arbitrary number of fluids, coupled with multicomponent numerical reservoir modeling at Cranfield, reproduce the general pattern of observed seismic amplitude changes and travel time shifts. In particular, time-lapse amplitude changes suggest a significant and widespread lowering of compressional velocities due to the injection of CO 2 into an aquifer bounding the oil rim of the reservoir. It appears that the large-scale variations in preexisting pore fluid content have a major influence on seismic velocity changes, even in the highly heterogeneous reservoir at Cranfield.
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SECARB Post Injection Assessment Report
The Southern States Energy Board (SSEB) managed the overall Southeast Regional Carbon Sequestration Partnership (SECARB) Phase III project and The Bureau of Economic Geology (BEG), at the University of Texas at Austin, managed all activities associated with the Early Test field site near Cranfield, Mississippi (the Early Test or Cranfield Project). The SECARB project at Cranfield was focused downdip of the oil rim and on demonstrating the stacked nature of the storage potential at this location: enhanced oil recovery (EOR) up-dip and saline downdip. Because the injection for EOR continued after the SECARB project ended, no actual post-injection period occurred. However, information collected during the SECARB-monitored injection period, including pressure and CO2 plume position, was utilized in an EOR carbon lifecycle assessment. The carbon lifecycle assessment provided insight on tracking injection fronts and production efficiencies across the field. To complete the post injection assessment, taking into account the continuing EOR period after closeout of SECARB field activities, this report provides data and analysis done under another DOE-funded project. The follow up project focused on the carbon lifecycle of EOR and included an assessment of EOR at as-operated and under possible future scenarios. This work was published by Hossieni et al. (2018) and Hosseininoosheri (2019).
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Wellbore injectivity response to step-rate CO 2 injection: Coupled thermo-poro-elastic analysis in a vertically heterogeneous formation
Safe and permanent carbon geological storages require an elaborate analysis of geomechanical stability. Subsurface injection of CO 2 changes the local temperature and pore pressure and, further, alters the stress due to thermo-poro-elastic responses. A permanent CO 2 storage testing was conducted in the water leg of Cranfield reservoir in Mississippi, USA, where hosted CO 2 enhanced-oil recovery activities. During CO 2 injection, the injection rate was ramped up twice but the bottom-hole pressure did not increase with the imposed injection rates as expected. This unexpected field observation suggests the possibility of an open-mode fracture development at the injector. However, the injector response and potential fracture development have not been rigorously interpreted with detailed near-wellbore temperature and pore pressure change upon the CO 2 injection. In this study, we performed history matching of CO 2 injection using coupled thermo-poro-elastic reservoir simulation to examine the possibility of fracturing. We built a reservoir model including vertical heterogeneity in both petrophysical and geomechanical properties estimated from well-logging analysis and laboratory experiments. The simulation results show that CO 2 injection changes stresses and support the hypothesis of development of an open-mode fracture at the injector during the Cranfield test. The near-injector region exhibits a large temperature reduction up to 55 °C with ensuing effective horizontal stress reduction up to 9.1 MPa. However, a caprock integrity issue is unlikely because of the horizontal stress contrast within layers and low hydraulic communication with the injection zone. This work indicates that the injectant temperature should be considered in the design of high-rate CO 2 injector.
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SECARB Core Analysis Data and Photos
Core photos and analysis collected from Cranfield oilfield in southwest Mississippi as part of SECARB project. Cores are from CFU31F-1, CFU31F-2, and CFU31F-3 wells in the Detailed Area of Study. Data includes permeability and porosity measurements and gamma ray scans. Associated Publications: Kordi, M., 2013, Characterization and prediction of reservoir quality in chlorite-coated sandstones: evidence from the Late Cretaceous Lower Tuscaloosa Formation at Cranfield Field, Mississippi, U.S.A., The University of Texas at Austin, Ph.D. dissertation, 193 p.
carbon↗
SECARB Geochemical Data
Hydrotest, gas composition, injection fluid, mass spectrometer, and U-tube gas sample analysis data gathered during SECARB project at Cranfield oil site in Mississippi. Geochemical data collected as part of geologic characterization phase of SECARB. Associated Publications: Lu, J., Cook, P. J., Hosseini, S. A., Yang, C., Romanak, K. D., Zhang, T., Freifeld, B. M., Smyth, R. C., Zeng, H., and Hovorka, S. D., 2012, Complex fluid flow revealed by monitoring CO 2 injection in a fluvial formation: Journal of Geophysical Research, v. 117, B03208, doi:10.1029/2011JB008939. Lu, J., Kharaka, Y. K., Thordsen, J. J., Horita, J., Karamalidis, A., Griffith, C., Hakala, J. A., Ambats, G., Cole, D. R., Phelps, T. J., Manning, M. A., Cook, P. J., and Hovorka, S. D., 2012, CO 2 -rock-brine interactions in Lower Tuscaloosa Formation at Cranfield CO2 sequestration site, Mississippi, U.S.A.: Chemical Geology, v. 291, p. 269-277. Yang, C., Hovorka, S. D., Treviño, R. H., and Delgado-Alonso, J., 2015, Integrated framework for assessing impacts of CO 2 leakage on groundwater quality and monitoring-network efficiency: case study at a CO 2 enhanced oil recovery site: Environmental Science &Technology, v. 49, p. 8887–8898, doi:10.1021/acs.est.5b01574.
carbon capture and storage↗
SECARB 3D VSP Data
Vertical Seismic Profile data collected in 2009 and 2010 as part of SECARB Phase III Early Test at Cranfield oilfield in Mississippi to determine CO2 induced change from seismic response. Data divided into 3D VSP and Offset VSP folders. Associated Publications: Daley, T. M., Hendrickson, J., & Queen, J. H. (2014). Monitoring CO2 Storage at Cranfield, Mississippi with Time-Lapse Offset VSP – Using Integration and Modeling to Reduce Uncertainty. Energy Procedia, 63, 4240-4248. doi:10.1016/j.egypro.2014.11.459
3D VSP↗
SECARB Electrical Resistance Tomography Data
Electrical Resistance Tomography Data collected as part of SECARB project at Cranfield oil site in Mississippi. Associated Publications: Carrigan, C.R., Yang, X., LaBrecque, D.J., Larsen, D., Freeman, D., Ramirez, A.L., Daily, W., Aines, R., Newmark, R., Friedmann, S. J., Hovorka, S., 2013. Electrical resistivity tomographic monitoring of CO2 movement in deep geologic reservoirs. Int. J. of Greenhouse Gas Control, 18, 401-408. Yang, X., Chen, X., Carrigan, C.R. & Ramirez, A.L., 2014. Uncertainty quantification of CO2 saturation estimated from electrical resistance tomography data at the Cranfield site, Int J Greenh Gas Con, 27, 59-68.
carbon↗