Effects of brine valency and concentration on oil displacement by spontaneous imbibition: An interplay between wettability alteration and reduction in the oil-brine interfacial tension

Sukee, Anupong; Nunta, Tanakon; Nawamin, Fongkham,; Yoosook, Hutthapong; Jeennakorn, Montri; Harbottle, David; Santha, Nipada; Tangparitkul, Suparit

doi:10.1016/j.molliq.2022.120089

Cited by 14 publications

(16 citation statements)

References 43 publications

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“…At the same ethanol–water ratios, the tube wettability also demonstrated its influence on the displacement dynamics. Less hydrophilic system (Package II – hydrophobic cases) retarded the v and the dynamics process terminated at longer time ( t ∼ 10 s → t ∼ 100 s for 60% ethanol mixture), as it contributed to a decrease in a driving capillary force, , assuming an increase in the θ. The hydrophilicity influence observed is similar to that of previous work by Lee et al Uneven or fluctuate-like plots in hydrophobic are thought to be due to chemical heterogeneity on the hydrophobized tube surface, where crude oil components were adsorbed, as confirmed by surface imaging using atomic force microscopy (Figure S1).…”

Section: Resultsmentioning

confidence: 99%

“…To elucidate such a fluid displacement, many physical and interfacial properties are considered, e.g., fluid viscosity (μ), fluid density, fluid–fluid interfacial tension (σ), and fluid–fluid–solid wettability. Since Bell and Cameron, a fundamental and yet simple experiment on a 1D capillary tube has long been investigated to observe the fluid displacement behaviors with associated interfacial phenomena. − This kind of study allows opaque and highly complex fluid flows in subsurface to be elucidated through visualization, although more elaborate examinations at higher dimensions and scales have to be conducted to better understand the flows. − Recent studies on influences of the σ and μ were investigated, of which the findings are that dynamic fluid displacement is accordingly enhanced by the former but decelerated by the latter. , One crucial factor that has always been considered is wettability, ,, which are of interest in several studies.…”

Section: Introductionmentioning

confidence: 99%

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Predicting Dynamic Contact Angle in Immiscible Fluid Displacement: A Machine Learning Approach for Subsurface Flow Applications

Suetrong,

Tosuai,

Vo Thanh

et al. 2024

Energy Fuels

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Immiscible fluid−fluid displacement dynamics is a crucial element to understanding and engineering many subsurface flow applications, including enhanced oil recovery and carbon dioxide geological sequestration. Although there are several interfacial properties that govern such a displacement dynamic, the wettability has been considered a dominant factor. Owing to its complex coaffinity among the three phases (i.e., solid−fluid−fluid) and difficulty to be characterized accurately and efficiently, the wettability (defined as the contact angle: θ) determination is of interest in the current study with aim toward machine learning (ML) approach.In the current research, four experimental packages of fluid displacement at 1D capillary scale served as data sets for ML examination on the θ predictability. Via digital image processing, fluid traveling length at a given time was extracted, and the theoretical θ was calculated as ground truth for the modeling, with input features being fluid traveling length, displacing velocity, and the interfacial tension. Random forest (RF) and multilayer perception (MLP) were selected for the modeling due to their appropriate characteristics to the investigated data (being nonlinear relation). The prediction results showed that RF apparently outperformed MLP on the θ prediction, reflecting its best ability to manage missing values and outliers. Although more input features analyzed (from two to three features) did yield a better prediction, the best model remains RF. Sensitivity on the key parameters of displacing velocity and the interfacial tension was also analyzed, where the results confirm the model prediction agreement with theories. The study demonstrated how ML model can be an alternative tool to elucidate the fluid displacement in subsurface, with additional potential for autonomously improving the deep underground flows, converging a new concept of "augmented" artificial intelligence.

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Section: Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Predicting Dynamic Contact Angle in Immiscible Fluid Displacement: A Machine Learning Approach for Subsurface Flow Applications

Suetrong,

Tosuai,

Vo Thanh

et al. 2024

Energy Fuels

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“…Efficiently exploiting such unconventional, poor properties of reservoir characteristics (e.g., low porosity and low permeability , ) is normally realized with advanced production techniques deployed. Owing to the “tight” character of unconventional oils, the confined and connected pore-throat networks in reservoir formation are undoubtedly controlled by a capillarity, of which the reservoir fluids flow under a primary influence of capillary pressure acting upon due to the nature of the rock–fluid–fluid interactions. − Most efforts therefore focus on how to manipulate such a capillary pressure to improve the oil flow and lead to enhanced oil recovery, while the production technique of interest is the widely implemented “huff-n-puff” technique . The huff-n-puff technique is a process to stimulate tight reservoirs in cycles by using only a signal well for both fluid-injecting (hence “huff”) and oil-producing (hence “puff”) purposes.…”

Section: Introductionmentioning

confidence: 99%

Relative Permeability-Dictated Huff-n-Puff Technique in Tight Reservoirs: Suitability and Limitation toward Field Implementation

Tapanya,

Fongkham,

Ramadhan

et al. 2024

Energy Fuels

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Exploiting unconventional petroleum is needed in this era, and thus more enhancement has been introduced including chemical additives to manipulate the fluid flow characteristics. Although most of the examinations were at the laboratory scale, the scaling-up to reservoir applicability is in question and needs further studies. The current study examined laboratory-derived relative permeability (k r ) at various wettabilities and the oil−water interfacial tension on reservoir-scale numerical simulation, utilizing a huff-n-puff technique, aiming to emphasize suitability and limitations of k r . The simulated results emphasized the important character of k r , which dictates the oil recovery in tight reservoirs where the huff-n-puff technique is normally implemented. Although derived from laboratory tests, such a k r character has to be taken caution when considering EOR design in field deployment at the reservoir scale since there are suitability and limitations to be concerned for each k r character as well as the economic aspect. Not all reservoir parameters or producing factors could practically induce substantial changes in oil production; hence, further techno-economic study should be executed prior to implementation toward field implementation of tight reservoirs. Simulations of primary oil production agreed with those of the experiment, confirming the model validity. Following the secondary six-cycle huff-n-puff process also yielded the same trend of oil production performances, dictated by k r as a primary fluid flow characteristic. Four influencing factors of reservoir properties and producing design were further investigated for their sensitivity to the oil production performances. At various k r investigated in the current study, the porosity factor was distinctively found to have limited suitability to low values if high oil production is anticipated, owing to the nature of tight reservoirs pe se. On the contrary, reservoir permeability likely did not have much influence since more oil was produced with higher value of permeability, albeit no sensitivity at much higher values. The shut-in period for the huff-n-puff process was not sensitive to the oil production of all fluids. Interestingly, the critical water saturation where the water phase starts to flow (k rw > 0) had a strong influence on the oil production in two approaches, either demoting the oil production or having no contribution, depending on the k rw −S w character. Although derived from laboratory tests, such a k r character has to be taken caution when considering enhanced oil recovery design in reservoir-scale deployment since there are suitability and limitations to be concerned for each k r character.

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“…In an oil-wet system, the capillary force between the oil and the porous rock matrix is stronger, compared to those in a water-wet system. This mean that the oil is held more tightly within the rock’s pores, due to capillary pressure . As the IFT between the oil and the displacing fluid is reduced, it weakens the capillary forces, allowing the oil to be displaced more easily, which leads to an increase in oil recovery factor.…”

Section: Introductionmentioning

confidence: 99%

“…This mean that the oil is held more tightly within the rock's pores, due to capillary pressure. 19 As the IFT between the oil and the displacing fluid is reduced, it weakens the capillary forces, allowing the oil to be displaced more easily, which leads to an increase in oil recovery factor. In addition, in an oil-wet system, the rock surface has a greater affinity for oil, compared to water.…”

Section: Introductionmentioning

confidence: 99%

Review of the Application of Natural Surfactants in Enhanced Oil Recovery: State-of-the-Art and Perspectives

2023

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Injecting surfactant by means of chemical enhanced oil recovery (cEOR) has acquired predominant attention in improving oil recovery by changing either fluid/rock and/or fluid/fluid interaction due to ion-pair forming and/or surfactant adsorption on the rock surface. As the main surfactant role in EOR, IFT reduction refers to adsorbing of surfactant molecules on the residual oil/water interface, which causes an increase in capillary number; as a result, trapped oil drops in porous media get free and start to move through the pore space toward the production well. The toxic nature, excessive cost, and environmental issues are the obvious limitations in applying the chemical surfactants in EOR, hence, looking for a less-expensive and eco-friendly type of surfactant has become a significant task to researchers to study the natural surfactant as an alternative to chemical surfactants. A deep understanding about the classification of natural surfactants, fabrication methods, and the difference between each class is crucial to propose a new plant-derived natural surfactant. This study tried to review up-to-date published studies related to the natural surfactant types and prepare a comprehensive catalog respective to natural surfactant that helps researchers with regard to future work in natural surfactant application in EOR. In addition, comparisons of each class performance and the impact of nanoparticles and the salinity on them in reducing IFT, altering wettability, and improving the recovery factor have been investigated. It had been concluded that natural surfactant can be produced from different plant parts (leaf, root, steam, fruit, and seed) based on the fabrication method. Natural surfactants synthesized from seed oil are stronger, compared with those extracted from the plant part (i.e., IFT reduction by 98%). Generally, injecting natural surfactants expressed low to high performance in improving the ultimate oil recovery from 2% to 40% original oil in place (OOIP).

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Effects of brine valency and concentration on oil displacement by spontaneous imbibition: An interplay between wettability alteration and reduction in the oil-brine interfacial tension

Cited by 14 publications

References 43 publications

Predicting Dynamic Contact Angle in Immiscible Fluid Displacement: A Machine Learning Approach for Subsurface Flow Applications

Predicting Dynamic Contact Angle in Immiscible Fluid Displacement: A Machine Learning Approach for Subsurface Flow Applications

Relative Permeability-Dictated Huff-n-Puff Technique in Tight Reservoirs: Suitability and Limitation toward Field Implementation

Review of the Application of Natural Surfactants in Enhanced Oil Recovery: State-of-the-Art and Perspectives

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