CO2/brine interfacial tension and rock wettability at reservoir conditions: A critical review of previous studies and case study of black shale from Malaysian formation

Yekeen, Nurudeen; Padmanabhan, Eswaran; Abdulelah, Hesham; Irfan, Sayed Ameenuddin; Okunade, Oluwagade Adenike; Khan, Javed Akbar; Negash, Berihun Mamo

doi:10.1016/j.petrol.2020.107673

Cited by 88 publications

(47 citation statements)

References 85 publications

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“…Interfacial tension measurements were conducted using a view chamber drop shape analyzer (model: DSA-100, Kruss). The pendant drop method 34 was followed to evaluate CH 4 /aqueous solution IFT. The required pressure and temperature at the view chamber were first attained.…”

Section: Shale Samplementioning

confidence: 99%

Mechanism of CH₄ Sorption onto a Shale Surface in the Presence of Cationic Surfactant

et al. 2021

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A substantial amount of water used for fracking shale formations is trapped by capillary and interfacial forces. Such trapped water is detrimental to gas production because of its potential to obstruct gas’s desorption and, subsequently, its flow path. Surfactants are proposed to alleviate the problem; however, further insight is required to understand the underlying mechanism. In this study, a cationic surfactant, namely, cetyltrimethylammonium bromide (CTAB), and a clay-rich Marcellus shale are used to investigate and explain the mechanism. The study encompasses a series of systematic experiments and molecular simulations. First, laboratory measurements of CH4–brine interfacial tension, CH4 surface excess, and zeta potential at different CTAB concentrations were conducted. Then, we evaluated CH4 adsorption in Marcellus shale before and after treatment with CTAB. Second, a molecular dynamics simulation by GROMACS software was used to explain the phenomenon at the molecular level. Experimental results indicated that CTAB reduced the CH4–brine interfacial tension by up to 80%. The zeta potential data showed that shale’s dominant surface charge was altered from negative to positive after treatment with CTAB. Furthermore, the presence of CTAB has significantly influenced the distribution of CH4 in the aqueous phase as indicated by the changes in the CH4 surface excess concentration. Moreover, the adsorbed CH4 amount decreased with increasing CTAB concentration when the CTAB concentration was kept below the critical micelle concentration (CMC). The reduction in adsorbed CH4 was explained by the molecular dynamics simulation results, which revealed a 62% shrinkage in vertical distances between CH4 molecules and clays after introducing CTAB. Simulation findings also unfold that CTAB has reduced the density distribution of CH4 molecules along with clay layers by 64%. One of the more significant result of this study is that surfactants injected at above CMC values can lessen fracking water trapping by reducing CH4 brine interfacial tension, changing surface charges, and reducing molecular distances between CH4 and hydrophilic clays.

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Section: Shale Samplementioning

confidence: 99%

Mechanism of CH₄ Sorption onto a Shale Surface in the Presence of Cationic Surfactant

et al. 2021

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“…Thus, it is clear that a precise evaluation of shale wettability is extremely important for successful hydrocarbon exploitation from shale reservoirs. Currently, the contact angle method is frequently used to measure shale wettability under different operating conditions, ,− while spontaneous imbibition has also been extensively studied recently, − and some NMR investigations have been conducted. , However, only a few studies have used molecular dynamics simulations to examine shale wettability. , One key factor that limits the understanding of shale rocks is their complex microstructure, ,− including organic matter, minerals, and microfractures. ,, Consequently, a precise shale wettability characterization may not be possible without a detailed understanding of the associated shale microstructure. Furthermore, no single imaging technique is capable to capture the shale rock microstructure fully and accurately, rather a multiscale correlative imaging approach is required. ,, …”

Section: Introductionmentioning

confidence: 99%

“…The current literature suggests that shale rocks demonstrate a mixed-wet behavior where the inorganic mineral matter is hydrophilic, while the organic matter is hydrophobic, and this hydrophobicity increases with shale total organic carbon (TOC). , However, there are other observations too where shales were found to be water-wet, and the associated wetting behavior was not influenced by shale TOC, thus suggesting a complex wetting behvaior of shales. On the contrary, the wettability of conventional geomaterials, for example, sandstones, and pure minerals are relatively better understood and evaluated. − For instance, a wide body of literature agrees that pure clean quartz surfaces are strongly water-wet, − while pure calcite is relatively less water-wet (at ambient conditions), and the water-wetness is typically reduced at elevated CO 2 injection pressures. ,− …”

Section: Introductionmentioning

confidence: 99%

Shale Wettability: Data Sets, Challenges, and Outlook

2021

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The wetting characteristics of shale rocks at representative subsurface conditions remain an area of active debate. A precise characterization of shale wettability is essential for enhanced oil and gas recovery, containment security during CO 2 geo-storage, and flow back efficiency during hydraulic fracturing. While several methods were utilized in the literature to evaluate shale wettability (e.g., contact angle measurements, spontaneous imbibition method ,and NMR method), we here review the recently published data sets on shale contact angle measurements. The objectives of this review are to (a) develop a repository of the recent shale wettability data sets using contact angle measurements at high pressure and temperature (HPHT) conditions, (b) explore the factors influencing shale wettability, (c) identify potential limitations associated with contact angle methods, and (d) provide a research outlook for this area. On the basis of the data reviewed here, we conclude the following: (1) Shale/oil/brine systems demonstrate water-wet to strongly oil-wet wetting behaviors. (2) Shale/CO 2 /brine systems are usually weakly water-wet to CO 2 -wet. (3) Shale/CH 4 /brine systems are weakly water-wet. The key contributing factors that underpin this high shale wettability variability include, but are not limited to, operating pressure and temperature conditions, total organic content (TOC), mineral matter, and thermal maturity conditions. Thus, this review provides a succinct analysis of the shale wettability contact angle data sets and affords an overview of the current state of the art technology and possible future developments in this area to enhance the understanding of shale wettability.

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“…Data were collected over a 2θ range of 2-90° at a scan rate of 0.02°/2 s. TOC was determined using the TOC device (Multi N/C 3100 Analytic Jena, Germany). BET surface was measured using surface area instrument (Tristar II Series, Micromeritics, USA), with N2 as the adsorbate gas at 77 K [19][20][21][22][23][24].…”

Section: Methodsmentioning

confidence: 99%

Artificial neural network (ANN) modeling for CO2 adsorption on Marcellus Shale

Irfan

Abdulkareem

Radman

et al. 2022

IOP Conf. Ser.: Earth Environ. Sci.

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In this work, artificial neural network modeling for CO2 adsorption on various types of Marcellus shale samples is studied. The eight shale geometries are investigated for their CO2 adsorption at 298k and up to 50bar pressure utilizing a gravimetric technique and magnetic suspension balance. ANN modelling was applied to investigate three main objectives which are the impact of various training algorithms, various data initiation points, and altered training/validating ratios and number of neurons required for ANN model. The work can provide insightful knowledge linked to the impact of each of the studied parameters which play an important role in ANN modeling and training algorithms. The outcomes can provide an optimized matrix for unconventional resources, enhanced gas and oil recovery applications intend to apply the artificial intelligence modeling in their assessments.

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CO2/brine interfacial tension and rock wettability at reservoir conditions: A critical review of previous studies and case study of black shale from Malaysian formation

Cited by 88 publications

References 85 publications

Mechanism of CH₄ Sorption onto a Shale Surface in the Presence of Cationic Surfactant

Mechanism of CH₄ Sorption onto a Shale Surface in the Presence of Cationic Surfactant

Shale Wettability: Data Sets, Challenges, and Outlook

Artificial neural network (ANN) modeling for CO2 adsorption on Marcellus Shale

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CO2/brine interfacial tension and rock wettability at reservoir conditions: A critical review of previous studies and case study of black shale from Malaysian formation

Cited by 88 publications

References 85 publications

Mechanism of CH4 Sorption onto a Shale Surface in the Presence of Cationic Surfactant

Mechanism of CH4 Sorption onto a Shale Surface in the Presence of Cationic Surfactant

Shale Wettability: Data Sets, Challenges, and Outlook

Artificial neural network (ANN) modeling for CO2 adsorption on Marcellus Shale

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Product

Resources

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Mechanism of CH₄ Sorption onto a Shale Surface in the Presence of Cationic Surfactant

Mechanism of CH₄ Sorption onto a Shale Surface in the Presence of Cationic Surfactant