An Experimental Study on the Flood Characteristic and Fluid Rock Interactions of a Supercritical CO<sub>2</sub>, Brine, Rock System

Saeedi, Ali; Piane, Claudio Delle; Esteban, Lionel; Stalker, Linda

doi:10.1190/ice2015-2210011

Cited by 3 publications

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“…A synthetic brine was prepared by dissolving 40 g of NaCl and 20 g of KCl in ultrapure deionized (DI) water. It is worth noting that in this work, to eliminate or reduce two-way mass transfer (immiscible coreflooding), the brine and scCO 2 were mutually pre-equilibrated using a stirred reactor (autoclave reactor) following a technique similar to that described by Saeedi et al 47 All of the chemicals were used as received.…”

Section: Materials Sample Preparation and Test Proceduresmentioning

confidence: 99%

“…(2) The pore pressure was increased to the experimental value by injecting degassed brine, and the sample was left to age and saturate with the brine for 24 h. To eliminate two-way mass transfer during CO 2 injection and achieve immiscible displacement, five pore volumes (PV) of the brine which was pre-equilibrated with CO 2 was injected to displace the degassed brine. 22,47 (3) The absolute permeability of the rock sample was measured using a multirates (1, 2, 4 cc/min) injection procedure.…”

Section: Materials Sample Preparation and Test Proceduresmentioning

confidence: 99%

“…The respective relative permeability data were calculated using a numerical history matching technique 64,65 for which Sendra software from PRORES AS was used. Full details of the history matching technique applied through Sendra software are described by Saeedi et al; 47 nevertheless, the history matched curves for GB.2 (pre-and post-treatment differential pressure and brine recovery) are presented in Figures 5 and 7 (refer to Supporting Information figures for GB.1, GB.3, and GB.4 history match data). The values for the empirical parameters which produced the best match of experimental data are presented in Supporting Information Table S1.…”

Section: Energy and Fuelsmentioning

confidence: 99%

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Modifying the Wettability of Sandstones Using Nonfluorinated Silylation: To Minimize the Water Blockage Effect

et al. 2019

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Multiphase fluid flow characteristics of a reservoir rock, such as capillary pressure, displacement efficiency, relative permeability, and saturation distribution are substantially influenced by the wettability state of the rock. Being able to change the affinity of the rock toward different fluid phases present in the formation has implications in various petroleum applications (e.g., CO 2 geo-sequestration, EOR, gas production). In this study, silylation of sandstone core samples using nonfluorinated compounds is accomplished using supercritical CO 2 as a solvent and carrier. This approach is cost-effective and less environmentally sensitive compared to other approaches which use fluorinated silylation reagents. By using small molecules to only change the wettability characteristics of core samples without altering other parameters (e.g., rock pore structure) noticeably, the effects of wettability alteration alone on multiphase flow (i.e., relative permeability) can be identified. Spontaneous imbibition tests were conducted on Gray Berea sandstone before and after silylation treatment, which showed a diminished rate of water uptake in the post-treatment sample. The wettability alteration caused by this functionalization and its impact on multiphase flow characteristics were analyzed using core flooding tests. The experimental results show that supercritical CO 2 -based (scCO 2 -based) silylation changes the wettability of the formation from strongly water-wet to intermediate gas-wet. Core flooding tests showed that the effective permeability for the water phase was significantly increased, resulting in higher water removal from the rock matrix. Furthermore, the relative permeability for the gas phase (in this study, CO 2 ) at residual water saturation is higher after treatment. Such an outcome confirms that the change in wettability could be beneficial in geological CO 2 storage as well as gas production.

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Section: Materials Sample Preparation and Test Proceduresmentioning

confidence: 99%

Section: Materials Sample Preparation and Test Proceduresmentioning

confidence: 99%

Section: Energy and Fuelsmentioning

confidence: 99%

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Modifying the Wettability of Sandstones Using Nonfluorinated Silylation: To Minimize the Water Blockage Effect

et al. 2019

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“…Queensland (e.g. the CTSCo Surat CCS project) (Dawson et al, 2015a;Harkin et al, 2017;79 Hodgkinson and Grigorescu, 2012; Saeedi et al, 2016). The Precipice Sandstone is a low 80 salinity fresh to brackish aquifer with a predicted high prospectivity for CO2 storage (Farquhar et 81 al., 2013;Horner et al, 2014).…”

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confidence: 99%

A combined geochemical and μCT study on the CO2 reactivity of Surat Basin reservoir and cap-rock cores: Porosity changes, mineral dissolution and fines migration

Pearce

Dawson

Golab³

et al. 2019

International Journal of Greenhouse Gas Control

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16 17 Geological storage of CO2 generally involves injection of a CO2 stream into a high porosity and 18 permeability reservoir, contained by one or more overlying low permeability formations. 19Sandstone reservoirs and associated cap-rocks of targeted CO2 storage sites therefore have 20 distinct properties such as porosity and mineral contents. Their geochemical response or 21 reactivity to injected supercritical CO2 and associated changes in porosity, and permeability 22 trapping of CO2 as ferroan carbonates such as siderite, ankerite and dolomite over longer time 46 scales when pH is buffered. 47Changes to porosity, mineral content, and water chemistry after pure CO2 reaction observed here 48 and in other published studies were dependent on mineral content and fluid accessibility. These 49 results could be generalized to other sandstone reservoirs where it is expected to inject CO2. The 50 results can also be used to validate geochemical models to build longer term predictions. 51 52 Keywords 53 54 Surat Basin 55 Precipice Sandstone 56 Evergreen Formation 57 Hutton Sandstone 58 CO2 sequestration 59 60 25-60 %) after CO2 core-flooding at 60 -69°C and 19 -25 MPa pore pressure (Saeedi et al., 131 2016). Porosities however remained similar, with the permeability changes attributed to the 132 decreased pH destabilizing kaolinite which migrated plugging pore throats. 133While the above studies at high salinity conditions demonstrate generally higher reactivity of 134 calcite cements and potentially clay-rich cap-rocks that reservoir sandstone, changes in water 135 chemistry, porosity or permeability can be more complex. The different conditions used in each 136 study, especially temperature, and batch or flow conditions complicate direct comparisons 137

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Chemically Enhanced Carbon Dioxide Geosequestration Using Nanofluids

Jha,

Kitagawa,

Abe

et al. 2023

Day 3 Thu, October 12, 2023

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Carbon dioxide (CO2) sequestration in the subsurface porous geological media is the most favored large-scale climate change mitigation technique to achieve a net-zero target. The efficiency of CO2 subsurface storage depends on its rock's wetting ability, which affects its flow efficiency and residual or structural trapping. Reported laboratory investigations have shown that nanoparticle formulations have great potential for altering the wettability to more water-wet conditions favoring CO2 trapping potential. However, the compatible nanoparticles tailored for CO2 sequestration under temperature, pressure, and salinity conditions have not been reported, as per our knowledge. Therefore, this article demonstrates how modified silica nanoparticles affect the rock's surface and help enhance CO2 trapping potential under storage conditions using wettability, IFT, and CT coreflooding experiments. Several silica nanoparticles were fabricated for this purpose. The fabricated silica nanoparticles were modified, given the unfavorable formation brine salinity and ionic compositions affecting their stability. The resulting modified silica nanoparticles were diluted to 0.5 wt% with synthetic brine and observed for brine resistance at 50 °C for one month. They were further tested for wettability alteration of the organic acid-aged sandstone rock representative substrate in the presence of supercritical CO2 at 50 °C and 10 MPa by contact angle method. Furthermore, we evaluated their performance by computed tomography (CT) coreflooding experiments using Fontainebleau sandstone core plugs. These nanoparticles altered the wettability of the organic acid-aged sandstone rock representative substrate sample from intermediate wet (advancing brine contact angle - 90-108°) to strongly water wet (advancing brine contact angle - 33-49°). Modified silica nanoparticles also show high brine resistance. Therefore, up to 24.2% reductions in IFTs were observed using nanoparticles. Moreover, CT coreflooding test results shows good performance of novel nanofluids treatment on CO2 trapping potential through evaluation of initial and residual trapping. Therefore, up to 80.6 % and 55.8 % increments were observed using nanoparticles in initial and residual scCO2 saturations, respectively. We are reporting the use of novel modified silica nanoparticles for CO2 sequestration in sandstone formation for the first time, as per our knowledge. We expect these specialty nano-materials to enhance CO2 storage capacity through nanofluid injections as one of the emerging techniques for achieving net zero.

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An Experimental Study on the Flood Characteristic and Fluid Rock Interactions of a Supercritical CO₂, Brine, Rock System

Cited by 3 publications

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Modifying the Wettability of Sandstones Using Nonfluorinated Silylation: To Minimize the Water Blockage Effect

Modifying the Wettability of Sandstones Using Nonfluorinated Silylation: To Minimize the Water Blockage Effect

A combined geochemical and μCT study on the CO2 reactivity of Surat Basin reservoir and cap-rock cores: Porosity changes, mineral dissolution and fines migration

Chemically Enhanced Carbon Dioxide Geosequestration Using Nanofluids

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An Experimental Study on the Flood Characteristic and Fluid Rock Interactions of a Supercritical CO2, Brine, Rock System

Cited by 3 publications

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Modifying the Wettability of Sandstones Using Nonfluorinated Silylation: To Minimize the Water Blockage Effect

Modifying the Wettability of Sandstones Using Nonfluorinated Silylation: To Minimize the Water Blockage Effect

A combined geochemical and μCT study on the CO2 reactivity of Surat Basin reservoir and cap-rock cores: Porosity changes, mineral dissolution and fines migration

Chemically Enhanced Carbon Dioxide Geosequestration Using Nanofluids

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An Experimental Study on the Flood Characteristic and Fluid Rock Interactions of a Supercritical CO₂, Brine, Rock System