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, Muhammad Kabir; Abbas, AJ; Nasr, G. G.; Al-Otaibi, A.; Burby, Martin; Saidu, B; Suleiman, Salihu M.

doi:10.1016/j.jngse.2019.103002

Cited by 28 publications

(14 citation statements)

References 35 publications

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“…The setup of the core flooding equipment and operating principle and procedure was adopted from our previous works (Abba et al, 2019a;Abba et al, 2018b). The setup is shown in Figure 2 has a combined uncertainty in measurement of 2% and designed and operated based on the API standard.…”

Section: Core Floodingmentioning

confidence: 99%

“…One of the scenarios that have not been investigated widely is the presence of connate water. It has been established that this property has significant influence on the dispersion coefficient of CO2 injectivity (Abba et al, 2018b;Honari et al, 2016) and storability of the CO2 for EGR process (Abba et al, 2019a). The nature of the connate water is also fundamental, in that, different species of salts exist in the connate water brine and have different properties and effects on the interacting fluids at reservoir conditions.…”

Section: Introductionmentioning

confidence: 99%

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Enhanced gas recovery by CO2 injection: Influence of monovalent and divalent brines and their concentrations on CO2 dispersion in porous media

Abba

2020

Journal of Natural Gas Science and Engineering

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This study aims to experimentally investigate the roles of different brine types and concentrations on the longitudinal dispersion coefficient (KL) during enhanced gas recovery by CO2 injection. Core flooding process was used to simulate the displacement of CH4 by supercritical CO2 in a Buff Berea core sample at a pressure and temperature of 1400 psig and 50 o C respectively, and a CO2 injection rate of 0.3 ml/min. Individual NaCl, KCl, CaCl2 and MgCl2 solutions were prepared as test brines with ionic strengths (IS) of 1M, 2M, and 3M. The results revealed that, at lower IS of 1M, MgCl2 and CaCl2 brines had the lowest KL while the monovalent brines showed relatively higher KL. Divalent brines showed a higher degree of salting out effects at higher concentrations resulting in higher KL. The salting and drying out effects of divalent brines were responsible for higher CH4 recovery at 2M IS as CH4 comes out of solution. A hyperbolic-type relationship exists between the two properties (KL and IS), where KL decreases from 0 to 1M IS, and then increases sharply at IS >1Mthis behaviour is most pronounced in the divalent brines. Lowest contamination of the recovered CH4 was found to be between formation water salinities of 5-15 wt.%, regardless of salt type, during EGR by CO2 injection and sequestration. This study will not only present new knowledge on EGR process but will also provide an avenue for establishing a screening criterion based on formation water salinity for effective EGR process. This is a first experimental investigation which establishes the relationship between salt types and concentration and the KL in porous media.

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Section: Core Floodingmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Enhanced gas recovery by CO2 injection: Influence of monovalent and divalent brines and their concentrations on CO2 dispersion in porous media

Abba

2020

Journal of Natural Gas Science and Engineering

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“…The medium Péclet number (Pe m ) was determined using Eq. (2), in that the characteristic length scale of mixing, d (µm), was obtained from the work of Abba et al (2019). This value was found to be 57.15 µm for Bandera grey, such value was used in Eq.…”

Section: Dispersion Coefficient and Dispersivitymentioning

confidence: 99%

“…They reveal that injection of N 2 -rich mixtures contributes to preventing the nascent early breakthrough of injected CO 2 and safely stored large volumes of CO 2 into the shale sediment over the long term. Abba et al (2019) achieved a high percentage of total CO 2 injected stored at 10 wt.% salinity using solubility trapping mechanism, but with least CH 4 recovery resulted from the density of connate water sealing off the narrow pore spaces within the pore matrix.…”

Section: Introductionmentioning

confidence: 99%

Alternating N2 gas injection as a potential technique for enhanced gas recovery and CO2 storage in consolidated rocks: an experimental study

Mohammed

Abbas

Enyi

et al. 2020

J Petrol Explor Prod Technol

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The promotion of enhanced gas recovery (EGR) and CO2 storage is still shrouded in contention and is not well accepted, due to the excessive in situ CO2 mixing with the nascent natural gas. This adulterates the recovered CH4 and thus results in a high sweetening process cost thereby making the technique impractical. This has not only limited the field application of EGR in actual projects to a few trails but renders it uneconomical. This study aims to present, experimentally, alternating N2 injection as a potential technique for EGR and CO2 storage in sandstone rock cores. A laboratory core flooding experiment was carried out to simulate a detailed process of unsteady-state methane (CH4) displacement using Bandera grey core plug. This was carried out at 40 °C, 1500 psig, and 0.4 ml/min injection rate by alternative injection of N2 and CO2 in succession designed to suit the application based on optimum operating conditions. The results show that both CO2 storage capacity and CH4 recovery improved significantly when gas alternating gas (GAG) injection was considered. The best results were observed at lower N2 cushion volumes (1 and 2 PV). Therefore, the GAG injection method with N2 as cushion gas can potentially increase both CO2 storage and CH4 recovery of the gas reservoir. This technique if employed will assert the current position and provide vital information for further researches aimed at promoting environmental sustainability and economic viability of the EGR and CO2 sequestration processes.

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“…In recent times, research on solubility trapping has been carried out to study the influences of parameters like brine salinity, pH, microbial activity, and reservoir conditions on the solubility trapping efficiency. Abba et al [26] conducted experiments on the solubility trapping mechanism to examine its influences on the salinity in the gas reservoir. In the gas reservoir, even at higher salinity of 10% weight percentage of NaCl, the trapped efficiency of solubility trapping was observed 63% [26].…”

Section: Introductionmentioning

confidence: 99%

Influence of Caprock Morphology on Solubility Trapping during CO2 Geological Sequestration

2022

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Carbon capture and sequestration (CCS) technology is one of the indispensable alternatives to reduce carbon dioxide (CO2) emissions. In this technology, carbon capture and transport grid will send CO2 to the storage facilities that are using various storage techniques. Geologic carbon sequestration (GCS) is one such storage technique where CO2 is injected into a deep geological subsurface formation. The injected CO2 is permanently stored in the formation due to structural, residual, solubility, and mineral trapping phenomena. Among different trapping mechanisms, solubility trapping plays a significant role in the safe operation of GCS. In this work, the study is conducted to elucidate the influence of top surface caprock morphology on the solubility trapping mechanism. The simulation results show that the naturally available heterogeneous formations with anticline and without anticline structure influence the solubility fingering phenomena and solubility entrapment percentage over a geological time scale. The lateral migration and sweeping efficiency results of both the synthetic domains for the injected CO2 have shown the importance of caprock morphology on solubility trapping and selection of injection rate. Quantification of solubility trapping in two morphological structures revealed that the synthetic domain without anticline morphology had shown higher solubility trapping. In the future, the simulation data using Artificial Neural Networks can be applied to predict the structural and solubility trapping of geological formations. This analysis further helps incorporating the interaction of CO2 with porous media leading to a mineral trapping mechanism.

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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

Cited by 28 publications

References 35 publications

Enhanced gas recovery by CO2 injection: Influence of monovalent and divalent brines and their concentrations on CO2 dispersion in porous media

Enhanced gas recovery by CO2 injection: Influence of monovalent and divalent brines and their concentrations on CO2 dispersion in porous media

Alternating N2 gas injection as a potential technique for enhanced gas recovery and CO2 storage in consolidated rocks: an experimental study

Influence of Caprock Morphology on Solubility Trapping during CO2 Geological Sequestration

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