4 research outputs found
The codes and data generated in this study.
The codes and data generated in this study.</p
Experimental Observation of Permeability Changes In Dolomite at CO<sub>2</sub> Sequestration Conditions
Injection
of cool CO<sub>2</sub> into geothermally warm carbonate
reservoirs for storage or geothermal energy production may lower near-well
temperature and lead to mass transfer along flow paths leading away
from the well. To investigate this process, a dolomite core was subjected
to a 650 h, high pressure, CO<sub>2</sub> saturated, flow-through
experiment. Permeability increased from 10<sup>–15.9</sup> to
10<sup>–15.2</sup> m<sup>2</sup> over the initial 216 h at
21 °C, decreased to 10<sup>–16.2</sup> m<sup>2</sup> over
289 h at 50 °C, largely due to thermally driven CO<sub>2</sub> exsolution, and reached a final value of 10<sup>–16.4</sup> m<sup>2</sup> after 145 h at 100 °C due to continued exsolution
and the onset of dolomite precipitation. Theoretical calculations
show that CO<sub>2</sub> exsolution results in a maximum pore space
CO<sub>2</sub> saturation of 0.5, and steady state relative permeabilities
of CO<sub>2</sub> and water on the order of 0.0065 and 0.1, respectively.
Post-experiment imagery reveals matrix dissolution at low temperatures,
and subsequent filling-in of flow passages at elevated temperature.
Geochemical calculations indicate that reservoir fluids subjected
to a thermal gradient may exsolve and precipitate up to 200 cm<sup>3</sup> CO<sub>2</sub> and 1.5 cm<sup>3</sup> dolomite per kg of
water, respectively, resulting in substantial porosity and permeability
redistribution
Experimental Observation of Permeability Changes In Dolomite at CO<sub>2</sub> Sequestration Conditions
Injection
of cool CO<sub>2</sub> into geothermally warm carbonate
reservoirs for storage or geothermal energy production may lower near-well
temperature and lead to mass transfer along flow paths leading away
from the well. To investigate this process, a dolomite core was subjected
to a 650 h, high pressure, CO<sub>2</sub> saturated, flow-through
experiment. Permeability increased from 10<sup>–15.9</sup> to
10<sup>–15.2</sup> m<sup>2</sup> over the initial 216 h at
21 °C, decreased to 10<sup>–16.2</sup> m<sup>2</sup> over
289 h at 50 °C, largely due to thermally driven CO<sub>2</sub> exsolution, and reached a final value of 10<sup>–16.4</sup> m<sup>2</sup> after 145 h at 100 °C due to continued exsolution
and the onset of dolomite precipitation. Theoretical calculations
show that CO<sub>2</sub> exsolution results in a maximum pore space
CO<sub>2</sub> saturation of 0.5, and steady state relative permeabilities
of CO<sub>2</sub> and water on the order of 0.0065 and 0.1, respectively.
Post-experiment imagery reveals matrix dissolution at low temperatures,
and subsequent filling-in of flow passages at elevated temperature.
Geochemical calculations indicate that reservoir fluids subjected
to a thermal gradient may exsolve and precipitate up to 200 cm<sup>3</sup> CO<sub>2</sub> and 1.5 cm<sup>3</sup> dolomite per kg of
water, respectively, resulting in substantial porosity and permeability
redistribution
Permeability Reduction Produced by Grain Reorganization and Accumulation of Exsolved CO<sub>2</sub> during Geologic Carbon Sequestration: A New CO<sub>2</sub> Trapping Mechanism
Carbon sequestration experiments were conducted on uncemented
sediment
and lithified rock from the Eau Claire Formation, which consisted
primarily of K-feldspar and quartz. Cores were heated to accentuate
reactivity between fluid and mineral grains and to force CO<sub>2</sub> exsolution. Measured permeability of one sediment core ultimately
reduced by 4 orders of magnitude as it was incrementally heated from
21 to 150 °C. Water-rock interaction produced some alteration,
yielding sub-μm clay precipitation on K-feldspar grains in the
core’s upstream end. Experimental results also revealed abundant
newly formed pore space in regions of the core, and in some cases
pores that were several times larger than the average grain size of
the sediment. These large pores likely formed from elevated localized
pressure caused by rapid CO<sub>2</sub> exsolution within the core
and/or an accumulating CO<sub>2</sub> phase capable of pushing out
surrounding sediment. CO<sub>2</sub> filled the pores and blocked
flow pathways. Comparison with a similar experiment using a solid
arkose core indicates that CO<sub>2</sub> accumulation and grain reorganization
mainly contributed to permeability reduction during the heated sediment
core experiment. This suggests that CO<sub>2</sub> injection into
sediments may store more CO<sub>2</sub> and cause additional permeability
reduction than is possible in lithified rock due to grain reorganization