Computing the velocity field magnitude with prescribed velocities on the pressure and suction sides represents the most important step in the inverse design of transonic axial turbomachinery blade profiles. The objective is to develop a numerical method to solve the isentropic velocity field with prescribed velocities at the boundaries. We will present the computational methods developed to solve the potential flow equation leading to the isentropic velocity field, overcoming the problems linked to the presence of singularities at the leading and trailing edges. A combination of Picard and Newton iterative algorithms is used. The numerical algorithm is validated on subsonic and supersonic planar source flow test cases then used on real flow cases of subsonic compressors and transonic turbines. We are able to obtain fully converged isentropic velocity fields.
Carbon capture utilization and storage (CCUS) constitute promising underground storage techniques to address the challenge of climate change. Subsurface storage of carbon dioxide depends on several factors like injectivity, formation characteristics, sealing integrity etc. One critical parameter is the interfacial tension (IFT) of the fluid-fluid system in question e.g., CO2-brine IFT for CO2 geo-storage. Importantly, the IFT influences the capillary pressure of the seal, which, in turn, controls fluid leakage. In addition, different fluid-fluid IFTs give rise to distinct relative permeability curves and residual saturations of the fluids, thereby impacting residual trapping characteristics. Successful application of EOR techniques is also dependent on the IFT of the carbonated water (CO2+water/brine) and the oil in place given that the IFT controls fluid miscibility and flow. Numerous researchers investigated the IFT of fluid-fluid systems and its effect on capacity estimates for CO2/H2 storage as well as the expected performance EOR techniques. Associated trends, however, have not been critically analyzed before. Thus, this paper presents a critical review of published data sets on CO2-brine IFTs. The significance of IFT for underground gas storage and EOR applications is detailed. IFT depends primarily on pressure, temperature, and salinity. The influence of pressure, temperature, and salinity on IFT and associated trends are analyzed. In addition, latest developments pertaining IFT measurements for sequestration purposes are discussed from a risk managing perspective. Finally, this study elucidates research gaps and presents a future outlook.
During CO2 geo-storage, mineral dissolution is considered as the safest trapping technique however it is the longest and the most complicated trapping mechanism involving geo-chemical reactions and physical forces like diffusion and advection. Many factors also influence the mineral trapping capacity of the geological formation e.g., mineralogy, temperature, pH, CO2 fugacity, pressure of CO2, salinity and composition of the brine. The scope of this study is to investigate the mineral trapping of CO2 in Arabian carbonates reservoirs as a function of temperature, brine composition and pH of the subsurface systems. Numerical simulations are performed using the multi-phase simulator GEM-CMG. 2D and 3D models are developed to examine the mechanisms occurring during mineral trapping and how these affect its efficiency. The mineralogy of a carbonate field from an Arabian formation is used. Sensitivity analysis has been performed on the effect of temperature, pH and brine composition on CO2 mineralization tendency and porosity. The results suggest that dissolution and precipitation of minerals occurred during and post CO2 injection while pH had the major influence on mineral trapping. At basic pH conditions, pH=9, the highest amount of CO2 was mineralized while at mid pH, precipitation of carbonates decreased remarkably. Changing the brine composition also highly affected the storage capacity e.g., divalent salt accelerated CO2 mineralization. Moreover, temperature tends to promote the mineral activity during CO2 storage. While a score of publications investigated CO2 storage via structural, residual and dissolution trapping mechanisms, still the mineral trapping potential and its influencing factors have not been investigated much. This paper thus provides new insights into CO2 sequestration by mineral trapping pertinent to Arabian carbonate rocks.
During CO2 geo-storage, mineral dissolution is considered as the safest trapping technique however it is the longest and the most complicated trapping mechanism involving geo-chemical reactions and physical forces like diffusion and advection. Many factors also influence the mineral trapping capacity of the geological formation e.g., mineralogy, temperature, pH, CO2 fugacity, pressure of CO2, salinity and impurities. The scope of this study is to investigate the mineral trapping of CO2 in Arabian carbonates reservoirs as a function of CO2 pressure injection, presence of contaminants and well configuration. Numerical simulations were performed using the multi-phase simulator GEM-CMG. 2D and 3D models were developed to examine the mechanisms occurring during mineral trapping and how these affect its efficiency. The mineralogy of a carbonate field from an Arabian formation was used. Sensitivity analysis was performed on the above variables on CO2 mineralization tendency. The results suggest that dissolution and precipitation of minerals occurred during and post CO2 injection. Increasing pressure led to higher amount of CO2 trapped while the presence of impurities in the injected fluid reduced the potential of CO2 mineralization. Moreover, using horizontal well tends to promote the mineral activity during CO2 storage. While a score of publications investigated CO2 storage via structural, residual and dissolution trapping mechanisms, still the mineral trapping potential and its influencing factors have not been investigated much. This paper thus provides insights into CO2 sequestration by mineral trapping pertinent to Arabian carbonate rocks.
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