No abstract

A critical component in the assessment of long-term risk from geologic sequestration of carbon dioxide (CO 2 ) is the ability to predict mineralogical and geochemical changes within storage reservoirs as a result of rock-brine-CO 2 reactions. Impurities and/or other constituents in CO 2 source streams selected for sequestration can affect both the chemical and physical (e.g., density, viscosity, interfacial tension) properties of CO 2 in the deep subsurface. The nature and concentrations of these impurities are a function of both the industrial source(s) of CO 2 , as well as the carbon capture technology used to extract the CO 2 and produce a concentrated stream for subsurface injection and geologic sequestration.This report summarizes the relative concentrations of CO 2 and other constituents in exhaust gases from major non-energy-related industrial sources of CO 2 . Assuming that carbon capture technology would remove most of the incondensable gases N 2 , O 2 , and Ar, leaving SO 2 and NO x as the main impurities, the authors of this report selected four test fluid compositions for use in geochemical experiments. These included the following: 1) a pure CO 2 stream representative of food-grade CO 2 used in most enhanced oil recovery projects; 2) a test fluid composition containing low concentrations (0.5 mole %) SO 2 and NO x (representative of that generated from cement production); 3) a test fluid composition with higher concentrations (2.5 mole %) of SO 2 ; and 4) test fluid composition containing 3 mole % H 2 S. v