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Keywords: reservoir geomechanics, carbon capture and storage, experimental geomechanics, risk assessment
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Non-Isothermal Reservoir Geomechanical Modeling at Aquistore Poster Presentation at the March 14th Future Energy System Research SymposiumT02-P04 University of Alberta Activity 2018-03-14 Seungjoo Lee, Alireza Rangriz Shokri, Nathan Lee Deisman, Stephen James Talman,
Chalaturnyk, R. T02-P04 Advances in Non-Isothermal Reservoir Geomechanical Coupled Simulations at Aquistore PosterT02-P04 University of Alberta Activity 2018-10-03 Alireza Rangriz Shokri, Nathan Lee Deisman, Stephen James Talman, Seungjoo Lee,
Chalaturnyk, R. T02-P04 Advances in Reservoir Geomechanical Testing Program at High Temperatures PosterT02-C02 University of Alberta Activity 2018-10-03 T02-C02 Salt Precipitation at an Active CO2 Injection Site The Aquistore research is part of SaskPower’s Boundary Dam Integrated Carbon Capture and Storage (CCS) Demonstration project. Carbon dioxide, captured from the flue gas of Unit Three of the Boundary Dam coal-fired power generation station, is injected into a 3400 m deep injection well drilled specifically for CO2 injection. The target aquifer is highly saline (TDS 330 g/L) with injection through four distinct perforation zones extending over about 200 m.
Drying-induced salt precipitation within the target reservoir has been identified as having the potential to cause formation damage in CO2 injection operations. Key parameters in assessing the possible severity are the initial salinity of the formation water and the residual water saturation under drainage. However, a second mechanism for reducing CO2 injectivity was observed at the Aquistore site. Downhole images from the injection well, together with recovered samples reveal that scales of simple salts have formed on the inside of a CO2 injection well. These are developed by evaporation of formation water to near complete dryness in the CO2 dominated wellbore fluids. The timing of the water backflow into the well and the mechanism driving it are uncertain, but the very high salinity of the formation water means that the total volume of scale observed could be due to minor volumes of flow back fluid. Since large salt build-ups are associated with what is very likely small volumes of inflow, the salts precipitated in the wellbore may threaten to CO2 injectivity. This observation suggests that an effort should be made prior to the onset of CO2 injection to reduce the likelihood of such a scale development. This requires a better understanding of the conditions responsible for any flow-back of water into the injection well.
Images and other descriptions of the salt deposits will be presented along with an interpretation of their mechanisms of formation and preservation.
T02-P04, T02-C02, T02-T02 University of Alberta Publication 2019-09-25 Stephen James Talman, Alireza Rangriz Shokri,
Chalaturnyk, R. ,
" Erik Nickel
" T02-P04, T02-C02, T02-T02 Salt Precipitation at an Active CO2 Injection Site T02-C02 University of Alberta Publication 2020-08-05 Stephen James Talman, Alireza Rangriz Shokri,
Chalaturnyk, R. ,
" Erik Nickel
" T02-C02 CO2 Injection Modeling Expertise from 7 Years of Operation at Aquistore T02-P04 University of Alberta Activity 2022-10-04 T02-P04 Integrated Analysis of Downhole Camera Videos, Salt Precipitation and Geochemistry at Aquistore T02-P04, T02-C02 University of Alberta Activity 2022-10-04 T02-P04, T02-C02 Anomalous Start-Up Pressure Signals of a Bubble-Tube System for Downhole Pressure Determination at the Aquistore CO2 Injection Site T02-P04 University of Alberta Publication 2022-10-23 T02-P04 On the Temporal Evolution of Non-Isothermal Injectivity Behaviour at an Active CO2 Injection Site T02-P04 University of Alberta Publication 2021-06-25 Alireza Rangriz Shokri, Stephen James Talman,
Chalaturnyk, R. ,
" Nickel, E.
" T02-P04 Physical and Chemical Characteristics of Salts Recovered from an Active CO2 Injection Well T02-P04 University of Alberta Publication 2021-09-15 Stephen James Talman, Alireza Rangriz Shokri,
Chalaturnyk, R. ,
" Nickel, E.
" T02-P04 Downhole Pressure and Temperature Observations at a CO2 Injector under Differing Injection Conditions T02-P04 University of Alberta Publication 2023-05-25 Stephen James Talman, Alireza Rangriz Shokri, Nathan Lee Deisman,
Chalaturnyk, R. T02-P04 Advanced Linear Dynamic Gas Phase Bottomhole Pressure Measurement System University of Alberta Activity 2024-01-05 Chalaturnyk, R. ,
" Zambrano G.
" , Alireza Rangriz Shokri, Stephen James Talman
Stress-Dependent Pore Deformation Effects on Multiphase Flow Properties of Porous Media T02-C02 University of Alberta Publication 2019-10-18 T02-C02 Updates on Non-Isothermal Coupled Simulations at Aquistore PresentationT02-P04 University of Alberta Activity 2018-10-05 T02-P04 An update on Thermal Impacts for Geological Storage of CO2 PresentationT02-C02 University of Alberta Activity 2019-03-21 T02-C02 Petrophysical and Thermo-Hydro-Mechanical Study of a deep hypersaline CO2 reservoir T02-P04, T02-C02 University of Alberta Publication 2022-11-22 T02-P04, T02-C02 Depositional models for the Basal Deadwood Sandstone T02-P04 University of Alberta Activity 2022-10-05 T02-P04 Advances in Non-Isothermal Reservoir Geomechanical Coupled Simulations at Aquistore Participation in the Aquistore Annual General Meeting T02-P04 University of Alberta Activity 2018-09-12 T02-P04 Thermal Reservoir Geomechanical Coupled Simulations at Aquistore Poster Presentation at 20th Anniversary Celebration of PTRCT02-P04 University of Alberta Activity 2018-09-13 T02-P04 Collaboration Opportunities for CO2 Storage and EOR in Canada PresentationT02-P04 University of Alberta Activity 2018-09-20 T02-P04 Innovation Overview of Canadian CO2 Storage and EOR Activities PresentationT02-P04 University of Alberta Activity 2018-09-20 T02-P04 Canadian Experience in CO2-EOR WebinarT02-P04 University of Alberta Activity 2018-09-21 T02-P04 Geomechanical Modeling and Non-Isothermal Coupled Reservoir Simulations at the Aquistore Injection Site, Saskatchewan Interim ReportT02-P04 University of Alberta Publication 2019-02-17 T02-P04 Non-isothermal Injectivity Considerations for Effective Geological Storage of CO2 at the Aquistore Site, Saskatchewan, Canada 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.T02-P04, T02-C02 University of Alberta Publication 2019-10-01 T02-P04, T02-C02 Measurement, Monitoring, Verification and Modelling at the Aquistore CO2 Storage Site T02-P04, T02-C02 University of Alberta Publication 2021-05-26 " Zeinab Movahedzadeh
" , Alireza Rangriz Shokri,
Chalaturnyk, R. ,
" Erik Nickel
" ,
" Norm Sacuta
" T02-P04, T02-C02 Suitability of the Aquistore CCS-site for a CO2-Circulation Test: Towards CO2-Plume Geothermal (CPG) Power Plant Implementations T02-P04 University of Alberta Publication 2021-05-26 T02-P04 Early Stage and Full-Scale CCUS Feasibility Studies T02-P04 University of Alberta Publication 2022-09-19 T02-P04 Carbon to Electrons: A CO2 Circulation Feasibility Study for Sustainable Geothermal Power Generation at the Aquistore CO2 Storage Site T02-P04 University of Alberta Publication 2022-05-17 Alireza Rangriz Shokri,
Chalaturnyk, R. ,
" Kevin Hau
" ,
" Martin Saar
" ,
" Erik Nickel
" T02-P04 Overview of Measurement, Monitoring and Verification Program at the Aquistore CO2 Storage Site T02-P04 University of Alberta Activity 2022-07-17 T02-P04 Modeling Expertise Developed during 7 Years of CO2 Injection at Aquistore T02-P04 University of Alberta Activity 2022-11-22 T02-P04 Modeling CO 2 Circulation Test for Sustainable Geothermal Power Generation at the Aquistore CO2 Storage Site, Saskatchewan, Canada T02-P04 University of Alberta Publication 2021-01-01 Alireza Rangriz Shokri, K P Hau, M O Saar, D White, E Nickel, G Siddiqi,
Chalaturnyk, R. T02-P04 Modeling CO2 Circulation Test, as a Key Element of CO2 Plume Geothermal (CPG), at An Active CO2 Storage Site T02-P04 University of Alberta Publication 2021-09-15 " Hau, K.
" , Alireza Rangriz Shokri,
" Nickel, E.
" ,
Chalaturnyk, R. ,
" Saar, M.
" T02-P04 Saline Reservoir Monitoring at an Active CO2 Storage Site T02-P04 University of Alberta Publication 2021-03-25 T02-P04 Closing the Loop: 4D Seismic Constraints on CO2 Flow Simulations from the Aquistore CO2 Storage Site T02-P04 University of Alberta Publication 2021-09-15 T02-P04 Advancing Canadian Experience and Best Practices in Containment, Conformance, and Injectivity of Deep Subsurface CO2 Storage, CO2 EOR, and CO2 Geothermal T02-P04 University of Alberta Publication 2021-09-15 T02-P04 Improving the Competitiveness of Geothermal Energy Exploitation through Integrated CO2 Storage in the Western Canadian Sedimentary Basin University of Alberta Publication 2022-12-31 Alireza Rangriz Shokri, Noga Vaisblat,
" Wigston, A
" ,
" Champollion, Y
" ,
" Hickson, C
" ,
Chalaturnyk, R. Estimating Sustainable Long-Term Fluid Disposal Rates in the Alberta Basin University of Alberta Publication 2023-03-07 Relative Permeability Measurements within Reservoir Geomechanics Framework University of Alberta Activity 2018-09-12 Pressure Surveillance Monitoring at the Aquistore Site University of Alberta Activity 2019-10-09 Temperature Dependency of Multiphase Flow Properties of Rock University of Alberta Activity 2021-10-06 Rock Mechanics in the Geological Storage of CO2 through the lens of the Aquistore CO2 Storage Project T02-C02 University of Alberta Activity 2022-08-10 T02-C02 Geological Storage of CO2 T02-C02 University of Alberta Activity 2018-04-05 T02-C02 Geothermal reservoir modeling and calibration in a coupled thermo-hydro-mechanical perspective-a case study for DEEP Geothermal Project in Saskatchewan, Canada Geothermal offers a low-emission, reliable and sustainable source of base-load energy, yet efficient reservoir management is challenging. Understanding the Thermo (T), Hydro (H) and Mechanical (M) interactions can help create sustainable strategies and ease energy extraction. In this study, a geological regional-scale THM model is created using PETREL, based on geological data from 11 wells close to the DEEP geothermal project. Geostatistical modelling was challenging as only 11 wells are available for such a large area. The depositional directions are used as secondary data for stratigraphic modeling. The permeability was populated using Machine Learning techniques based on 9 well logs as input data and calibrated with pulse-decay tests. A Mechanical Earth Model (MEM) was set up using a combination of empirical equations and calibrated using laboratory and field data. The minimum horizontal stress in the sandstone reservoir was found to be lower (~41 MPa) compared with caprock shale. Two open geothermal loop tests were history matched using INTERSECT which confirm fractures are induced for improved transmissibility in the sandstone reservoir without causing caprock failures.
T02-A03 University of Alberta Publication 2025-06-08 Arqam Muqtadir,
Zhang, B. , Walid Ben Saleh,
Chalaturnyk, R. , Noga Vaisblat,
" Andrew Wigston
" ,
" Ashley Drobot
" , Leo Groenewoud Groenewoud Leo,
" Kristen Marcia
" T02-A03 Using Coupled Thermal-Hydraulic-Mechanical Simulation to Evaluate the Geothermal Power Extraction and CO2 Storage Capacity for Hybrid CO2-Water Geothermal System Hybrid CO2-water geothermal systems offer a pathway to simultaneously extract geothermal energy and store CO2 in deep saline aquifers. However, their performance depends strongly on reservoir heterogeneity, CO2 breakthrough and plume development, and pressure evolution, all of which influence thermal output, flow sustainability, and geomechanical safety. Compared with conventional water-based geothermal systems, supercritical CO2 has lower viscosity, lower density, and stronger buoyancy forces, which may lead to higher production rates and less parasitic power required to pump the fluid to surface facility; however, the lower heat capacity of CO2 may also result in decreased thermal power production compared to water-based system.In this study, a hybrid CO2-water geothermal concept is evaluated using coupled thermal-hydraulic-mechanical (THM) simulations. Supercritical CO2 is injected to maintain reservoir pressure while enabling partial sequestration through structural, residual and solubility trapping. Production initially consists of brine and gradually transitions to a CO2-water mixture following CO2 breakthrough. The objective is to quantify the impact of CO2 breakthrough timing, fluid property contrasts, and reservoir heterogeneity on thermal power extraction, pressure management, and long-term system performance, and to compare the hybrid system against a conventional water-based geothermal configuration. Based on the THM simulation results, the hybrid CO?-water system produces comparable gross thermal power compared to water-based system after reasonable optimizations; however, CO2 benefits from strong buoyancy-driven circulation, which can significantly reduce parasitic pumping power. Over the 30-year operational period, 89 million tonnes of CO2 are stored in the saline aquifer.T02-A03 University of Alberta Activity 2026-05-11 T02-A03
