Pore-Scale Experimental Investigation of the Effect of Supercritical CO2 Injection Rate and Surface Wettability on Salt Precipitation

2019 ◽  
Vol 53 (24) ◽  
pp. 14744-14751
Author(s):  
Di He ◽  
Peixue Jiang ◽  
Ruina Xu
Keyword(s):  
Experimental Investigation ◽  
Supercritical Co2 ◽  
Injection Rate ◽  
Surface Wettability ◽  
Co2 Injection ◽  
Pore Scale ◽  
Salt Precipitation ◽  
Supercritical Co2 Injection

Microfluidics Underground: A Micro-Core Method for Pore Scale Analysis of Supercritical CO2 Reactive Transport in Saline Aquifers

2013 ◽  
Vol 135 (2) ◽  
Author(s):  
Phong Nguyen ◽  
Hossein Fadaei ◽  
David Sinton
Keyword(s):  
Carbon Sequestration ◽  
Chemical Analysis ◽  
Supercritical Co2 ◽  
Small Sample ◽  
Co2 Injection ◽  
Micro Ct ◽  
Pore Scale ◽  
Core Method ◽  
Porosity And Permeability ◽  
Supercritical Co2 Injection

Carbon sequestration in microporous geological formations is an emerging strategy for mitigating CO2 emissions from fossil fuel consumption. Injection of CO2 in carbonate reservoirs can change the porosity and permeability of the reservoir regions, along the CO2 plume migration path, due to CO2-brine-rock interactions. Carbon sequestration is effectively a microfluidic process over large scales, and can readily benefit from microfluidic tools and analysis methods. In this study, a micro-core method was developed to investigate the effect of CO2 saturated brine and supercritical CO2 injection, under reservoir temperature and pressure conditions of 8.4 MPa and 40 °C, on the microstructure of limestone core samples. Specifically, carbonate dissolution results in pore structure, porosity, and permeability changes. These changes were measured by X-ray microtomography (micro-CT), liquid permeability measurements, and chemical analysis. Chemical composition of the produced liquid analyzed by inductively coupled plasma-atomic emission spectrometer (ICP-AES) shows concentrations of magnesium and calcium in the produced liquid. Chemical analysis results are consistent with the micro-CT imaging and permeability measurements which all show high dissolution for CO2 saturated brine injection and very minor dissolution under supercritical CO2 injection. This work leverages established advantages of microfluidics in the new context of core-sample analysis, providing a simple core sealing method, small sample size, small volumes of injection fluids, fast characterization times, and pore scale resolution.

4D surface seismic tracks small supercritical CO2 injection into the subsurface: CO2CRC Otway Project

2017 ◽  
Vol 63 ◽  
pp. 150-157 ◽  
Author(s):  
Roman Pevzner ◽  
Milovan Urosevic ◽  
Dmitry Popik ◽  
Valeriya Shulakova ◽  
Konstantin Tertyshnikov ◽  
...  
Keyword(s):  
Supercritical Co2 ◽  
Co2 Injection ◽  
Supercritical Co2 Injection

scholarly journals Changes in Permeability of Kimachi Sandstone and Iidate Granite with Supercritical CO2 Injection

2013 ◽  
Vol 129 (12) ◽  
pp. 701-706
Author(s):  
Takashi FUJII ◽  
Yuichi SUGAI ◽  
Kyuro SASAKI ◽  
Toshiyuki HASHIDA ◽  
Toshiyuki TOSHA ◽  
...  
Keyword(s):  
Supercritical Co2 ◽  
Co2 Injection ◽  
Supercritical Co2 Injection

scholarly journals Capillary processes increase salt precipitation during CO2 injection in saline formations

2018 ◽  
Vol 852 ◽  
pp. 398-421
Author(s):  
Helena L. Kelly ◽  
Simon A. Mathias
Keyword(s):  
High Salinity ◽  
Volume Fraction ◽  
Injection Rate ◽  
Injection Well ◽  
Co2 Injection ◽  
Salt Precipitation ◽  
Injection Wells ◽  
Tenfold Increase ◽  
Entry Pressure ◽  
Injection Rates

An important attraction of saline formations for CO2 storage is that their high salinity renders their associated brine unlikely to be identified as a potential water resource in the future. However, high salinity can lead to dissolved salt precipitating around injection wells, resulting in loss of injectivity and well deterioration. Earlier numerical simulations have revealed that salt precipitation becomes more problematic at lower injection rates. This article presents a new similarity solution, which is used to study the relationship between capillary pressure and salt precipitation around CO2 injection wells in saline formations. Mathematical analysis reveals that the process is strongly controlled by a dimensionless capillary number, which represents the ratio of the CO2 injection rate to the product of the CO2 mobility and air-entry pressure of the porous medium. Low injection rates lead to low capillary numbers, which in turn are found to lead to large volume fractions of precipitated salt around the injection well. For one example studied, reducing the CO2 injection rate by 94 % led to a tenfold increase in the volume fraction of precipitated salt around the injection well.

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