Non-Isothermal Injectivity Considerations for Effective Geological Storage of CO2 at the Aquistore Site, Saskatchewan, Canada
- Alireza Rangriz Shokri (University of Alberta) | Rick J. Chalaturnyk (University of Alberta) | Erik Nickel (Petroleum Technology Research Centre)
- Document ID
- Society of Petroleum Engineers
- SPE Annual Technical Conference and Exhibition, 30 September - 2 October, Calgary, Alberta, Canada
- Publication Date
- Document Type
- Conference Paper
- 2019. Society of Petroleum Engineers
- CCS, Injectivity, Non-isothermal, Aquistore, CO2 Injection
- 12 in the last 30 days
- 427 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 9.50|
|SPE Non-Member Price:||USD 28.00|
Monitoring data of episodic transient heat and flow conditions, caused by intermittent cold CO2 injection in Aquistore, has shown a linkage between injectivity index and downhole injection temperature. Taking leverage access to invaluable field performance data collected from this highly instrumented Canadian CCS demonstration project, the focus of this paper is to understand and quantify the potential non-isothermal mechanisms involved in cold CO2 injection. Understanding this phenomenon is important as it has serious implications on containment, conformance, and injectivity technologies for effective geological CO2 storage.
To account for transient heat and fluid transport during cold CO2 injection in Aquistore, a non-isothermal EOS-based fluid flow simulation, of a high-resolution detailed geological model built based on an extensive characterization program, was calibrated with periodic monitoring data of downhole pressure, temperature, and injected mass rate. Due to the possibility of non-isothermal effects on near-wellbore stress fields, local induced fractures, and permeability alterations, in addition to dynamics of CO2-brine interactions, coupled reservoir geomechanical modeling techniques were then employed for further calibration. The uncertainties associated with the subsurface geological modeling, leaking aquifer boundaries, reservoir heterogeneity, rock thermal, petrophysical, and geomechanical properties were considered for both isothermal and non-isothermal conditions.
Processing of DTS (Distributed Temperature Sensing) data from both injection and observation wells indicated dynamic perturbations in subsurface temperature due to injection operations. Geological characterization, performed through high-resolution 3D seismic images, core, and log data, and the existence of a leaking aquifer, were found to have significant impacts on CO2 plume evolution. Through history matching process of non-isothermal flow simulation, for both injector and observation wells, the extent of the cold region was estimated, and found to be mainly controlled by rock thermal properties, permeability, and injection rate. Our analysis suggested that cold temperature front was limited to near-wellbore region due to substantial heat loss by conduction, besides radial decay of convective flow.
Further non-isothermal coupled simulations indicated a large, but near-wellbore-limited reduction in effective horizontal stresses, induced by cold CO2 injection. Employing different values of thermal expansion coefficients, local potential open-mode fractures were observed; however, fracturing of entire formation was not experienced. This phenomenon was associated with local permeability enhancement, and potential improvement in CO2 injectivity. A comparison of isothermal and non-isothermal analyses on reservoir performance during CO2 injection was lastly provided.
Our analysis of subsurface injection and coupled processes in relation to geologic CO2 sequestration delivers critical insights on how and under what conditions these non-isothermal effects are generated. This ultimately provides a predictive tool to better characterize the reservoir behaviour, injectivity issues, and spatial location of a subsurface CO2 plume.
|File Size||3 MB||Number of Pages||32|
Bell, J.S., Grasby, S.E. (2012) The Stress Regime of the Western Canadian Sedimentary Basin. Geofluids 12, 150-165. 10.1111/j.1468-8123.2011.00349.x
Bell, J.S., Price, P.R., McLellan, P.J. (1994) In situ Stress in the Western Canada Sedimentary Basin, Chapter 29 - Geological Atlas of the Western Canada Sedimentary Basin, comp. G.D. Mossop and I. Shetsen, Canadian Society of Petroleum Geologists and Alberta Research Council, Calgary, Canada: 439-446.
Kurz, M., Heebink, L., Smith, S., Zacher, E. (2014) Petrophysical Evaluation of Core from the Aquistore CO2 Injection Site. Plains CO2 Reduction (PCOR) Partnership value-added report for U.S. Department of Energy National Energy Technology Laboratory Cooperative Agreement No. DE-FC26-05NT42592, EERC Publication 2014-EERC-07-16, Grand Forks, North Dakota, Energy & Environmental Research Center, March.
Rangriz Shokri, A., Chalaturnyk, R.J., Bearinger, D., Virues, C., Lehmann, J. (2017) Constraining the Complexity of Stimulated Reservoir Volume during Multi-Stage Hydraulic Fracturing of Horizontal Wells through Inter-Well Pressure Hit Modeling. Society of Petroleum Engineers. doi:10.2118/187188-MS
Vilarrasa, V., Rutqvist, J. (2017) Thermal effects on geologic carbon storage, Earth-Science Reviews, 165: 245-256 10.1016/j.earscirev.2016.12.011.