Injection of supercritical CO2 in brine saturated sandstone: Pattern formation during salt precipitation

Energy Procedia

Volumn 4, Issue , 2011, Pages 4425-4432

  Ott, H ^a   De Kloe, K D ^a   Marcelis, F ^a   Makurat, A ^a  

^a SHELL GLOBAL SOLUTIONS INTERNATIONAL B V   (United States)

Author keywords

Near well bore; Permeability impairment; Salt precipitation

Indexed keywords

CARBON DIOXIDE; COMPUTERIZED TOMOGRAPHY; GREENHOUSE GASES; INJECTION (OIL WELLS); SANDSTONE;

ABSOLUTE PERMEABILITY; CROSS-SECTIONAL PATTERNS; PERMEABILITY IMPAIRMENTS; PRECIPITATION OF SALTS; PRECIPITATION PATTERNS; SALT PRECIPITATION; SATURATED SANDSTONES; WELL BORE;

PRECIPITATION (CHEMICAL);

EID: 79955453497     PISSN: 18766102     EISSN: None     Source Type: Conference Proceeding    
DOI: 10.1016/j.egypro.2011.02.396     Document Type: Conference Paper

References (20)

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16. Fluid densities were calculated with STFlash (Shell Global Solutions, 2003); the obtained densities were compatible with literature data and online-measured fluid densities.
17. The density of the precipitated salt was determined from the densities of the single components (http://www.WebElements.org/); complex solid solutions were not taken into account.
18. The brine contained two salts, NaCl and CsCl, with CsCl more soluble than NaCl. Therefore, the composition of the precipitating salt depends on water advection vs. evaporation, which changes the brine composition to higher CsCl concentrations with time. The CsCl/NaCl ratio of the precipitated phase has been determined by ToughReact simulations (data not shown here) to 0.08 (compared to 0.1 in the original brine), corresponding to a scaling factor of α= 0.2.
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20. -3).