Shale Caprock/Acidic Brine Interaction in Underground CO2 Storage

Olabode, Abiola; Radonjic, Mileva

doi:10.1115/1.4027567

Cited by 29 publications

(9 citation statements)

References 25 publications

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“…Another advantage of dense CO2 as a displacement fluid is its extremely low solubility in formation water, preventing an excessive amount of the CO2 from being lost when CO2 flooding is performed in water-flooded reservoirs. Moreover, capturing and injecting CO2 into the petroleum-bearing underground will greatly reduce the greenhouse gas (GHG) effect as well as produce oil, which also makes the CO2 flooding a compelling enhanced oil recovery (EOR) strategy [8][9][10].…”

Section: Introductionmentioning

confidence: 99%

Experimental Study on a Novel Foaming Formula for CO2 Foam Flooding

Saeedi

Liu

2016

Journal of Energy Resources Technology

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This research developed a viable and economical foaming formula (AOS/AVS/N70K-T) which is capable of creating ample and robust CO2 foams. Its foaming ability and displacement performance in a porous medium were investigated and compared with the two conventional formulations (AOS alone and AOS/HPAM). The results showed that the proposed formula could significantly improve the foam stability without greatly affecting the foaming ability, with a salinity level of 20,000 ppm and a temperature of 323 K. Furthermore, AOS/AVS/N70K-T foams exhibited thickening advantages over the other formulations, especially where the foam quality was located around the transition zone. This novel formulation also showed remarkable blocking ability in the resistance factor (RF) test, which was attributed to the pronounced synergy between AVS and N70K-T. Last but not the least, it was found that the tertiary oil recovery of the CO2 foams induced by AOS/AVS/N70K-T was 12.5% higher than that of AOS foams and 6.8% higher than that of AOS/HPAM foams at 323 K and 1500 psi, thus indicating its huge enhanced oil recovery (EOR) potential. Through systematic research, it is felt that the novel foaming formulation might be considered as a promising and practical candidate for CO2 foam flooding in the future.

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Section: Introductionmentioning

confidence: 99%

Experimental Study on a Novel Foaming Formula for CO2 Foam Flooding

Saeedi

Liu

2016

Journal of Energy Resources Technology

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“…In addition, reactions that cause immobilisation of CO 2 and the ability of caprock to withstand pressures resulting from CO 2 plume beneath are directly related to the amounts and types of clay minerals in the formation [21,22]. Many studies have thus been conducted to investigate clay-fluid interaction in the context of understanding their implications on combined enhanced hydrocarbon recovery and CO 2 storage projects [23][24][25][26][27][28][29].…”

Section: Geological Co 2 Storagementioning

confidence: 99%

Review of Geochemical and Geo-Mechanical Impact of Clay-Fluid Interactions Relevant to Hydraulic Fracturing

Awejori¹,

Radonjic²

2022

Emerging Technologies in Hydraulic Fracturing and Gas Flow Modelling

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Shale rocks are an integral part of petroleum systems. Though, originally viewed primarily as source and seal rocks, introduction of horizontal drilling and hydraulic fracturing technologies have essentially redefined the role of shale rocks in unconventional reservoirs. In the geological setting, the deposition, formation and transformation of sedimentary rocks are characterised by interactions between their clay components and formation fluids at subsurface elevated temperatures and pressures. The main driving forces in evolution of any sedimentary rock formation are geochemistry (chemistry of solids and fluids) and geomechanics (earth stresses). During oil and gas production, clay minerals are exposed to engineered fluids, which initiate further reactions with significant implications. Application of hydraulic fracturing in shale formations also means exposure and reaction between shale clay minerals and hydraulic fracturing fluids. This chapter presents an overview of currently available published literature on interactions between formation clay minerals and fluids in the subsurface. The overview is particularly focused on the geochemical and geomechanical impacts of interactions between formation clays and hydraulic fracturing fluids, with the goal to identify knowledge gaps and new research questions on the subject.

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“…But the overall response of caprocks depends on the rock type. While certain caprocks undergo permeability increase due to interaction with CO 2 (Olabode and Radonjic, 2014), others present a self-sealing response to CO 2 flow due to porosity decrease (Espinoza and Santamarina, 2012) or fracture clogging (Noiriel et al, 2007). Nevertheless, CO 2 is only expected to penetrate a short distance, if any, into the caprock because of its high entry pressure, which prevents upwards CO 2 flow (Busch et al, 2008).…”

Section: Geochemical Effects On Geomechanical Propertiesmentioning

confidence: 99%

Induced seismicity in geologic carbon storage

et al. 2019

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Abstract. Geologic carbon storage, as well as other geo-energy applications, such as geothermal energy, seasonal natural gas storage and subsurface energy storage imply fluid injection and/or extraction that causes changes in rock stress field and may induce (micro)seismicity. If felt, seismicity has a negative effect on public perception and may jeopardize wellbore stability and damage infrastructure. Thus, induced earthquakes should be minimized to successfully deploy geo-energies. However, numerous processes may trigger induced seismicity, which contribute to making it complex and translates into a limited forecast ability of current predictive models. We review the triggering mechanisms of induced seismicity. Specifically, we analyze (1) the impact of pore pressure evolution and the effect that properties of the injected fluid have on fracture and/or fault stability; (2) non-isothermal effects caused by the fact that the injected fluid usually reaches the injection formation at a lower temperature than that of the rock, inducing rock contraction, thermal stress reduction and stress redistribution around the cooled region; (3) local stress changes induced when low-permeability faults cross the injection formation, which may reduce their stability and eventually cause fault reactivation; (4) stress transfer caused by seismic or aseismic slip; and (5) geochemical effects, which may be especially relevant in carbonate-containing formations. We also review characterization techniques developed by the authors to reduce the uncertainty in rock properties and subsurface heterogeneity both for the screening of injection sites and for the operation of projects. Based on the review, we propose a methodology based on proper site characterization, monitoring and pressure management to minimize induced seismicity.

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Shale Caprock/Acidic Brine Interaction in Underground CO2 Storage

Cited by 29 publications

References 25 publications

Experimental Study on a Novel Foaming Formula for CO2 Foam Flooding

Experimental Study on a Novel Foaming Formula for CO2 Foam Flooding

Review of Geochemical and Geo-Mechanical Impact of Clay-Fluid Interactions Relevant to Hydraulic Fracturing

Induced seismicity in geologic carbon storage

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