Integrated Analysis of Geomechanical Factors for Geologic CO2 Storage in the Midwestern United States

Sminchak, Joel; Babarinde, Ola; Gupta, Neeraj

doi:10.1016/j.egypro.2017.03.1458

Cited by 2 publications

(2 citation statements)

References 7 publications

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“…The technique of injecting CO 2 into deep saline aquifers and oil and gas reservoirs have the potential for alternative methods for reducing CO 2 emissions (Vilcáez, 2015). Studies (Allen et al, 2017;Bennaceur, 2013;Riis and Halland, 2014;Sanguinito et al, 2018;Sminchak et al, 2017) have shown that deep saline aquifers have the advantage of more storage capacity as a result of different storage mechanisms over oil and gas reservoirs. However, incentives in the form of additional hydrocarbon resources (through Enhanced Oil/Gas Recovery techniques) come from using oil and gas reservoirs as storage sites which will, invariably, offset some of the cost of the sequestration process (Kalra and Wu, 2014).…”

Section: Introductionmentioning

confidence: 99%

Experimental investigation on the impact of connate water salinity on dispersion coefficient in consolidated rocks cores during Enhanced Gas Recovery by CO2 injection

Abba

Al-Othaibi

Abbas

et al. 2018

Journal of Natural Gas Science and Engineering

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Connate water salinity is a vital property of the reservoir and its influence on the displacement efficiency cannot be overemphasised. Despite the numerous analytical literatures on the dispersion behaviour of CO 2 in CH 4 at different parametric conditions, studies have so far been limited to systematic effects of the process while parameters such as connate water salinity of the reservoir has not been given much attention and this could redefine the CO 2 -CH 4 interactions in the reservoir. This study aims to experimentally determine the effect of connate water salinity on the dispersion coefficient in consolidated porous media under reservoir conditions. A laboratory core flooding experiment depicting the detailed process of the CO 2 -CH 4 displacement using Grey Berea sandstone core sample at a temperature of 50 o C and at a pressure of 1300 psig was carried out to determine the optimum injection rate, from 0.2-0.5 ml/min, for the experimentation based on dispersion coefficients and methane recovery in the horizontal orientation. This was established to be 0.3 ml/min. At the same conditions, the effects of connate water saturation of 10% and a salinity of 0 (distilled water), 5, and 10% wt. with a CO 2 injection rate of 0.3 ml/min on the dispersion coefficients was investigated. The results from the core flooding process indicated that the dispersion coefficient decreases with increasing salinity, hence the higher the density of the immobile phase (connate water) the lower the dispersion of CO 2 into CH 4 . This is a significant finding given that the inclusion of the connate water and its salinity have an effect on the mixing of the gases in the core sample and should be given importance and included during simulation studies for field scale applications of Enhanced Gas Recovery (EGR). This is the first experimental investigation into the relationship between the connate water salinity and the dispersion coefficient in consolidated porous media.

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Section: Introductionmentioning

confidence: 99%

Experimental investigation on the impact of connate water salinity on dispersion coefficient in consolidated rocks cores during Enhanced Gas Recovery by CO2 injection

Abba

Al-Othaibi

Abbas

et al. 2018

Journal of Natural Gas Science and Engineering

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“…Accordingly, conventional natural gas reservoirs have a storage capacity limitation compared to the most ideal choice i.e. deep saline aquifers (Sminchak et al, 2017) for CO2 sequestration. Deep saline aquifer utilises a combination of different trapping mechanisms (structural and stratigraphic, solubility, residual, mineral) to store the injected CO2 and as such increases, significantly, its storage potential.…”

Section: Introductionmentioning

confidence: 99%

Solubility trapping as a potential secondary mechanism for CO2 sequestration during enhanced gas recovery by CO2 injection in conventional natural gas reservoirs: An experimental approach

Abba

Abbas

Nasr

et al. 2019

Journal of Natural Gas Science and Engineering

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This study aims to experimentally investigate the potential of solubility trapping mechanism in increasing CO2 storage during EGR by CO2 injection and sequestration in conventional natural gas reservoirs. A laboratory core flooding process was carried out to simulate EGR on a sandstone core at 0, 5, 10wt% NaCl formation water salinity at 1300 psig, 50 o C and 0.3ml/min injection rate. The results show that CO2 storage capacity was improved significantly when solubility trapping was considered. Lower connate water salinities (0 and 5 wt%) showed higher CO2 solubility from IFT measurements. With 10% connate water salinity, the highest accumulation of the CO2 in the reservoir was realised with about 70% of the total CO2 injected stored; an indication of improved storage capacity. Therefore, solubility trapping can potentially increase the CO2 storage capacity of the gas reservoir by serving as a secondary trapping mechanism in addition to the primary structural and stratigraphic trapping and improving CH4 recovery.

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Integrated Analysis of Geomechanical Factors for Geologic CO2 Storage in the Midwestern United States

Cited by 2 publications

References 7 publications

Experimental investigation on the impact of connate water salinity on dispersion coefficient in consolidated rocks cores during Enhanced Gas Recovery by CO2 injection

Experimental investigation on the impact of connate water salinity on dispersion coefficient in consolidated rocks cores during Enhanced Gas Recovery by CO2 injection

Solubility trapping as a potential secondary mechanism for CO2 sequestration during enhanced gas recovery by CO2 injection in conventional natural gas reservoirs: An experimental approach

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