CO<sub>2</sub>/brine/rock interactions in Lower Tuscaloosa formation

Soong, Yee; Howard, Bret H.; Dilmore, Robert; Haljasmaa, Igor; Crandall, Dustin; Zhang, Liwei; Zhang, Wu; Lin, Ronghong; Irdi, Gino A.; Romanov, Vyacheslav; McLendon, T. Robert

doi:10.1002/ghg.31611

Cited by 6 publications

(25 citation statements)

References 23 publications

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“…The experimental results of core HU24-1 indicate that the injection flow rate do not induce velocity sensitivity, and the brine do not cause the expansion of clay minerals under the experimental conditions, eliminating the interference of brine on the experimental results during the flooding process. The permeability of the cores HU24-2 and HU24-3 decrease after flooding, but the porosity is unchanged, which is similar to the results of previous experiments [9,15,19,[35][36][37][38]. Those studies believe that CO 2 is injected into the core and dissolved into brine to form carbonic acid, which triggers CO 2 -brine-rock interactions.…”

Section: Permeability Decline and Fines Migrationsupporting

confidence: 88%

“…Physical property changes in rocks caused by above factors damage the injection capacity of CO 2 and brine, changing the concentrations and types of ions contained in fluids. Due to these interactions, the released fines migrate to the distant reservoir with the flow of fluid, which will cause serious damage to the reservoir and ultimately affect the efficiency of EOR and CO 2 storage [16][17][18][19][20]. On the other hand, the in-situ multiphase flow characteristics in rocks under different CO 2 displacement methods are different, and these also have different effects on physical properties changes.…”

Section: Introductionmentioning

confidence: 99%

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Experimental Investigation on the Effects of CO2 Displacement Methods on Petrophysical Property Changes of Ultra-Low Permeability Sandstone Reservoirs Near Injection Wells

Wang

Yang

Han³

et al. 2019

Energies

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The petrophysical properties of ultra-low permeability sandstone reservoirs near the injection wells change significantly after CO2 injection for enhanced oil recovery (EOR) and CO2 storage, and different CO2 displacement methods have different effects on these changes. In order to provide the basis for selecting a reasonable displacement method to reduce the damage to these high water cut reservoirs near the injection wells during CO2 injection, CO2-formation water alternate (CO2-WAG) flooding and CO2 flooding experiments were carried out on the fully saturated formation water cores of reservoirs with similar physical properties at in-situ reservoir conditions (78 °, 18 MPa), the similarities and differences of the changes in physical properties of the cores before and after flooding were compared and analyzed. The measurement results of the permeability, porosity, nuclear magnetic resonance (NMR) transversal relaxation time (T2) spectrum and scanning electron microscopy (SEM) of the cores show that the decrease of core permeability after CO2 flooding is smaller than that after CO2-WAG flooding, with almost unchanged porosity in both cores. The proportion of large pores decreases while the proportion of medium pores increases, the proportion of small pores remains almost unchanged, the distribution of pore size of the cores concentrates in the middle. The changes in range and amplitude of the pore size distribution in the core after CO2 flooding are less than those after CO2-WAG flooding. After flooding experiments, clay mineral, clastic fines and salt crystals adhere to some large pores or accumulate at throats, blocking the pores. The changes in core physical properties are the results of mineral dissolution and fines migration, and the differences in these changes under the two displacement methods are caused by the differences in three aspects: the degree of CO2-brine-rock interaction, the radius range of pores where fine migration occurs, the power of fine migration.

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Section: Permeability Decline and Fines Migrationsupporting

confidence: 88%

Section: Introductionmentioning

confidence: 99%

Experimental Investigation on the Effects of CO2 Displacement Methods on Petrophysical Property Changes of Ultra-Low Permeability Sandstone Reservoirs Near Injection Wells

Wang

Yang

Han³

et al. 2019

Energies

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“…). This stacked‐layer scenario was designed to mimic multi‐layer geological structures at real CO 2 storage testing sites like Illinois Basin –Decatur site in Illinois, USA and Plant Daniel CO 2 storage testing site in Mississippi, USA . A very large model domain and infinite volume boundary cells were used in this study to minimize boundary effects on pressure and CO 2 saturation results from TOUGH2, as suggested by Zhang et al .…”

Section: Methodsmentioning

confidence: 99%

Application of a new reduced‐complexity assessment tool to estimate CO₂ and brine leakage from reservoir and above‐zone monitoring interval (AZMI) through an abandoned well under geologic carbon storage conditions

et al. 2018

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This study employs a combination of detailed simulations and reduced‐complexity models in the Well Leakage Analysis Tool (WLAT), developed by the National Risk Assessment Partnership (NRAP), US Department of Energy, to investigate how the rates of CO2 and brine leakage through an abandoned well under geologic CO2 storage conditions are affected by various factors. The factors considered in this study include depth of well penetration into the storage system, location relative to the point of injection, and effective permeability of the abandoned well. Location is the primary factor used to identify high‐ and low‐risk abandoned wells. For the typical CO2 injection scenario considered in this study, the potential impact of CO2 and brine leakage through an abandoned well is very low if the abandoned well is 6.2 km or further away from the CO2 injector. Due to the buoyancy of CO2 relative to formation brine, wells intersecting (i.e., accepting flow from) the top of the above‐zone monitoring interval (AZMI), which is the interval immediately above the seal, have a higher chance to become a pathway for CO2 than wells intersecting the bottom of the AZMI. If the permeability of an abandoned well is 10−14 m2 or less, the risk of CO2 and brine leakage through the well becomes very low. Due to the combined effect of pressure increase and buoyancy, the CO2 leakage rate is higher than brine leakage rate within the CO2 plume extent. Specific values reported in this study are site‐specific results and cannot be regarded as general findings. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd.

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“…The Lower Tuscaloosa Formation in the southeast region of the USA is recognized as a promising candidate reservoir for carbon sequestration. Furthermore, the Lower Tuscaloosa Formation is proximal to CO 2 sources, and has favorable depth, thickness, permeability, porosity, and the presence of overlying low permeability formations to seal unwanted vertical migration of CO 2 into overlying formations . One of the formations overlying the Lower Tuscaloosa Formation is a carbonate rock formation (Selma Chalk Formation), which has relatively low vertical permeability, enabling the formation to serve as a potential seal to constrain vertical migration of injected CO 2 .…”

Section: Introductionmentioning

confidence: 99%

Numerical investigation of Lower Tuscaloosa Sandstone and Selma Chalk caprock under geological CO₂ sequestration conditions: mineral precipitation and permeability evolution

2017

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A numerical model was developed using CrunchFlow to simulate reactive transport and porosity and permeability changes of sandstone and carbonate rock samples taken from the Lower Tuscaloosa Formation and the Selma Chalk Formation, Jackson County, MS, USA. The model predicted a permeability decrease from 2190 mD to 2038 mD for the Lower Tuscaloosa Sandstone sample in a static batch reactor after 180 days of exposure to CO2‐saturated brine, which is consistent with measured permeability results. The model predicted a negligible permeability change from 2.00 mD to 2.08 mD for the Selma Chalk carbonate sample after 180 days of exposure to CO2‐saturated brine. Based on model prediction, key mineral dissolution and precipitation reactions in the Lower Tuscaloosa Sandstone sample include dissolution of quartz, chlorite, and feldspar, as well as precipitation of amorphous silica and kaolinite. For the Selma Chalk carbonate sample, key predicted reactions include dissolution of calcite, quartz and chlorite, and precipitation of kaolinite and amorphous silica. Initial porosity, initial feldspar content and the exponent n value (related to pore structure and tortuosity) used in permeability calculations were three important factors affecting permeability evolution of sandstone samples under CO2 sequestration conditions. The small permeability change predicted for both the Lower Tuscaloosa Sandstone and the Selma Chalk caprock after exposure to CO2‐saturated brine suggests that poro‐permeability changes during CO2 injection into the Lower Tuscaloosa Formation are not likely to significantly affect reservoir and seal quality. © 2017 Society of Chemical Industry and John Wiley & Sons, Ltd.

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CO₂/brine/rock interactions in Lower Tuscaloosa formation

Cited by 6 publications

References 23 publications

Experimental Investigation on the Effects of CO2 Displacement Methods on Petrophysical Property Changes of Ultra-Low Permeability Sandstone Reservoirs Near Injection Wells

Experimental Investigation on the Effects of CO2 Displacement Methods on Petrophysical Property Changes of Ultra-Low Permeability Sandstone Reservoirs Near Injection Wells

Application of a new reduced‐complexity assessment tool to estimate CO₂ and brine leakage from reservoir and above‐zone monitoring interval (AZMI) through an abandoned well under geologic carbon storage conditions

Numerical investigation of Lower Tuscaloosa Sandstone and Selma Chalk caprock under geological CO₂ sequestration conditions: mineral precipitation and permeability evolution

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CO2/brine/rock interactions in Lower Tuscaloosa formation

Cited by 6 publications

References 23 publications

Experimental Investigation on the Effects of CO2 Displacement Methods on Petrophysical Property Changes of Ultra-Low Permeability Sandstone Reservoirs Near Injection Wells

Experimental Investigation on the Effects of CO2 Displacement Methods on Petrophysical Property Changes of Ultra-Low Permeability Sandstone Reservoirs Near Injection Wells

Application of a new reduced‐complexity assessment tool to estimate CO2 and brine leakage from reservoir and above‐zone monitoring interval (AZMI) through an abandoned well under geologic carbon storage conditions

Numerical investigation of Lower Tuscaloosa Sandstone and Selma Chalk caprock under geological CO2 sequestration conditions: mineral precipitation and permeability evolution

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Resources

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CO₂/brine/rock interactions in Lower Tuscaloosa formation

Application of a new reduced‐complexity assessment tool to estimate CO₂ and brine leakage from reservoir and above‐zone monitoring interval (AZMI) through an abandoned well under geologic carbon storage conditions

Numerical investigation of Lower Tuscaloosa Sandstone and Selma Chalk caprock under geological CO₂ sequestration conditions: mineral precipitation and permeability evolution