Articoli di riviste: "Wettability"

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Ramanamane, N. J., P. B. Sob, A. A. Alugongo e T. B. Tengen. "Integrated Membrane System Wettability – A Review". International Journal of Emerging Technology and Advanced Engineering 12, n. 9 (1 settembre 2022): 83–93. http://dx.doi.org/10.46338/ijetae0922_09.

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Integrated membrane system is one of the current leading techniques repoprted for oil-water separation in current years. These combination of different filtration membranes offered the improved separation efficiency of the integrated membrane system during oil-water separation. Although the integrated membrane system is hilighted as the promissing method for oil-water separtion in various industries, the poor membrane wettability was reported which hampers the performance of the membrane. The poor estimation of the membrane wettability in the integrated membrane feed stream leads to the pores blockages, decline oil-water efficiecy and pooor oil/water rejection ratio. The integrated membrane feed stream is prone to membrane fouling during oil-water sepration due to poor membrane wattability. To improve the performance of the integrated membrane system this review covers the membrane wettability during oil-water separation, the techniques used to improve the membrane wettability during oil-water separtion and mathematical models developed to enhance the fundermental understanding of the membrane wettability during oil-water separation. Even though the integrated membrane feed stream has been reported to be having the limitation due to the poor membrane wettabillity, the integrated membrane system is still considered to be the better technique which separates the oil-water emulsions compared to the traditional methods.

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Graue, A., E. Aspenes, T. Bognø, R. W. Moe e J. Ramsdal. "Alteration of wettability and wettability heterogeneity". Journal of Petroleum Science and Engineering 33, n. 1-3 (aprile 2002): 3–17. http://dx.doi.org/10.1016/s0920-4105(01)00171-1.

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Chantaramanee, Suchart, Sirikul Wisutmethangoon, Lek Sikong e Thawatchai Plookphol. "Wettability of Carbon Nanotubes with Molten Sn-Ag-Cu Solder Alloy". Applied Mechanics and Materials 372 (agosto 2013): 136–42. http://dx.doi.org/10.4028/www.scientific.net/amm.372.136.

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The purpose of this work was to study the wettability of single-walled carbon nanotube (SWCNTs) and molten 96.5Sn-3.0Ag-0.5Cu (SAC305) lead-free solder alloy. The SWCNTs was coated with silver (Ag) by using an electroless plating method in order to enhance its wettability. The wetting behavior of molten SAC305 alloy on three different substrates, alumina, un-coated SWCNTs and Ag-coated SWCNTs was investigated by employing a modified sessile drop technique. The wetting angle between the molten SAC305 and the three substrates was measured at temperature range of 250-550 °C. The average wetting angles between the molten SAC305 and the alumina, the un-coated SWCNTs and the Ag-coated SWCNTs substrates were 130.7±1.3°, 128.4±4.2° and 120.1±3.5°, respectively. The wettabilty of the SWCNTs was improved by coating it with silver. The wetting angle of the Ag-coated SWCNTs was decreased approx. 9° compared to that of the un-coated. Increasing temperature has slightly affected on the wettability of SWCNTs and the molten SAC305.

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Anderson, William. "Wettability Literature Survey- Part 2: Wettability Measurement". Journal of Petroleum Technology 38, n. 11 (1 novembre 1986): 1246–62. http://dx.doi.org/10.2118/13933-pa.

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Shimizu, Jun, Li Bo Zhou, Kaoru Takamori, Hirotaka Ojima, Takeyuki Yamamoto e Han Huang. "Enhancement of Photocatalytic Reaction of Titanium Dioxide Film by Surface Texturing". Materials Science Forum 654-656 (giugno 2010): 1784–87. http://dx.doi.org/10.4028/www.scientific.net/msf.654-656.1784.

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This study aims to study the influence of surface topography on the photocatalytic reaction of TiO2 film surfaces. In this work, a textured TiO2 film surface was fabricated by anodic oxidizing a titanium plate with micro grooves, and its wettabilty was evaluated. Micro grooves were machined on a 3-axis NC control precision machine tool using a single point diamond cutter with a tip radius of several hundred nanometers. Anodic oxidation experiments were conducted by using the self-developed equipment with diluted acetic acid as the electrolyte. It was found that the wettability of the TiO2 film surface textured by microcutting was superior to that textured by polishing under the irradiation environment of ultraviolet rays. The wettability of photocatalytic film surfaces could be improved by increasing the surface area.

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Dick, M. J., D. Veselinovic e D. Green. "Spatially resolved wettability measurements using nmr wettability index". E3S Web of Conferences 89 (2019): 03001. http://dx.doi.org/10.1051/e3sconf/20198903001.

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Wettability is a crucial petrophysical parameter for determining accurate production rates in oil and gas reservoirs. However, industry standard wettability measurements (Amott Test and USBM) are expensive and time consuming. It is known that NMR response varies as a function of wettability change in rock core plug samples. This information was used to develop an NMR wettability index (NWI) based on T2 distributions. This NWI is capable of measuring changes in wettability as a function of oil/water saturations unlike traditional methods which are based on measurements at Swi and Sor only. In addition, these oil/water saturations are determined without the aid of any special oil or brine, such as D2O. This allows the NMR method to nondestructively monitor changes in wettability in real time (i.e. during a flooding experiment or an aging procedure). In this work, we have coupled this T2-based NWI to spatially resolved T2 NMR measurements to monitor changes in wettability and saturation along rock core plugs. In order to derive an NMR wettability index, NMR T2 spectra of 100% brine saturated, 100% oil saturated, bulk oil and bulk brine are needed. These spectra are then mixed to give a predicted T2 spectrum which is compared (via a least squares fit) to a T2 spectrum recorded from a sample partially saturated with both water and oil and whose wettability is to be determined. For initial testing, three sandstone samples were employed along with 2% KCl brine and dodecane. To achieve sample states of mixed wettability, 100% brine saturated samples had dodecane pushed into them via centrifugation. Centrifugation at different speeds resulted in samples of varying bulk and spatial wettabilities from which NWI parameters and oil/water saturations were determined. The bulk wettabilities were compared to measurements done using the standard Amott test and oil/water saturations were confirmed by repeating experiments using NMR invisible D2O.

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Sauli, Zaliman, Vithyacharan Retnasamy, Aaron Koay Terr Yeow, Goh Siew Chui, K. Anwar e Nooraihan Abdullah. "Surface Roughness and Wettability Correlation on Etched Platinum Using Reactive Ion Ecthing". Applied Mechanics and Materials 487 (gennaio 2014): 263–66. http://dx.doi.org/10.4028/www.scientific.net/amm.487.263.

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As the world of semiconductor is moving towards smaller and high-end applications, the quality of the bonding adhesion for wire bonding is very critical. Although aluminium has been the metallization of choice in integrated circuits, it can be easily oxidized during high temperature and pressure. On the other hand, Platinum metallization layer has high thermal coefficient resistance and inert to oxygen. This paper reports the correlation between surface roughness and the wettability in the form of contact angle for Platinum deposited wafer etched using Inductively Couple Plasma-Reactive Ion Etching (ICP-RIE). Surface roughness was measured using AFM while contact angle was obtained via droplet test. The results clearly suggested that both surface roughness and wettabily, calculated by its contact angle value has the same trend. Surface roughness is directly proportional to the contact angle. This indicates that surface roughness have great influence on the surface wettability. Therefore, the adhesion for wire bonding process on platinum metallization which can be used in high end applications can be controlled by its surface roughness and wettability.

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Jurak, Małgorzata, e Agnieszka Wiącek. "WETTABILITY OF HYBRID CHITOSAN/PHOSPHOLIPID COATINGS". Progress on Chemistry and Application of Chitin and its Derivatives XXII (30 settembre 2017): 66–76. http://dx.doi.org/10.15259/pcacd.22.06.

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Sugihardjo, Sugihardjo. "Surfactant-Induced Wettability Alteration". Scientific Contributions Oil and Gas 32, n. 1 (17 marzo 2022): 56–63. http://dx.doi.org/10.29017/scog.32.1.834.

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Contact of surfactant solution onto rock surface has an important impact on the wettability alteration of the rock. This phenomenon has widely received attention of researchers on the field of EOR (enhanced oil recovery), at which surfactant solution basically has been used as the main injection fluid. However, there has not yet come up with conclusive findings, which is due to the unique characteristics of surfactant used at the oil fields. Therefore, every surfactant needs a particular laboratory evaluation before injected into a reservoir. We have evaluated surfactant-induced wettability alteration by means of contact angle measurement. Three kinds of surfactant have been used in this experiment, namely: TFSA (thin film spreading agent), IFT-R (interfacial tension reduction), and Well Stimulator type of surfactants. Two kinds of rocks namely LS (limestone) and SL (sandy limestone) have also been prepared. Both rocks are originally oil wet. TFSA-LS interaction tend to decrease the oil preferences with time, the contact angle increased 30 degrees after 8 weeks. Whereas TFSA-SL experienced only a little change of contact angle. Contact IFT-R and LS has changed significantly the contact angle to around 51degrees indicating less oil preference. Whereas, IFT-R and SL only changed a bit to less oil wet. The stimulator type of surfactant obviously lessen the oil wet tendency for the both rocks, the contact angles increase from initially around 15 to 35 degrees. In this experiment we found out that all the three surfactants generally tend to change the wettabillity to less oil wet.

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Punase, Abhishek, Amy Zou e Riza Elputranto. "How Do Thermal Recovery Methods Affect Wettability Alteration?" Journal of Petroleum Engineering 2014 (19 ottobre 2014): 1–9. http://dx.doi.org/10.1155/2014/538021.

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We will investigate the effect of temperature on wettability. First, we will list and summarize the different schools of thoughts from previous literature describing wettability changes for sandstone and carbonate reservoirs at elevated temperature. Next, we will describe the properties that affect wettability: how they alter wettability and how they are affected by temperature. After that, we will present indications of wettability changes and current wettability measurement techniques. Following this, case studies describing how wettability change influences reservoir characteristics and field performance during thermal recovery processes will be discussed. The thermal recovery methods included in the case studies were steam flooding, cyclic steam injection, hot water flooding, and in situ combustion. The main and very important take away from this study is that temperature induced wettability change is determined by many possible mechanisms combined together and not by just one or two phenomena occurring simultaneously. Finally, we will propose a reasonable scheme for wettability alteration during dry forward combustion, which needs further investigation.

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Wang, Yan, Binbin Li, Peipei Bao, Ronghua Wang, Aoyun Min e Peifeng Xiong. "A Case Study of Leaf Wettability Variability and the Relations with Leaf Traits and Surface Water Storage for Urban Landscape Plants". Water 15, n. 12 (7 giugno 2023): 2152. http://dx.doi.org/10.3390/w15122152.

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Leaf wettability, the affinity of a leaf surface to water droplets, affects the interactions between leaves and external environments. This study aimed to determine the interspecific and seasonal variabilities of leaf wettability across 30 common landscape plants, and their relationships with leaf functional traits, surface micromorphology and rainfall interception in Hefei city, China. Results indicated that leaf wettability was species-specific, and the adaxial and abaxial contact angles ranged from 63° to 134° and 66° to 134°, respectively, with the adaxial surface proving more wettable. Leaf wettability gradually increased from spring to winter. Classification of life forms revealed that there were no significant wettability differences among trees, shrubs and herbs, and between evergreen and deciduous plants, but deciduous plants’ wettability increased more significantly in winter. Leaf wettability was not significantly correlated with any leaf functional traits. Single surface microscopic parameters also had low correlations with leaf wettability. Instead, the low-wettability species were found to possess more prominent epidermis cells, dense waxy layers or trichomes on leaf surfaces. Leaf wettability was the best predictor of surface rainwater storage within all functional traits. Our results highlighted that leaf wettability was variable between different species and growth periods due to micromorphological differences, and significantly affected rainfall interception at the leaf scale, which may have great significance for evaluating plant hydrological function in urban areas.

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WATANABE, Toshiya. "Wettability of ceramic surfaces -A wide range control of surface wettability from super hydrophilicity to super hydrophobicity, from static wettability to dynamic wettability". Journal of the Ceramic Society of Japan 117, n. 1372 (2009): 1285–92. http://dx.doi.org/10.2109/jcersj2.117.1285.

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Sachdeva, Jaspreet S., Edison A. Sripal, Anders Nermoen, Reidar I. Korsnes, Merete V. Madland e Lesley A. James. "A laboratory scale approach to wettability restoration in chalk core samples". E3S Web of Conferences 89 (2019): 03003. http://dx.doi.org/10.1051/e3sconf/20198903003.

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Wettability in chalk has been studied comprehensively to understand fluid flow mechanisms impacting coreflooding experiments. Wettability becomes paramount in understanding the parameters influencing chalk-fluid interactions. The main objective of this work is to evaluate as to which degree the wettability in chalk core samples can be controlled in the laboratory. Kansas chalk samples saturated with brine (1.1 M/64284 ppm NaCl) and an oil mixture (60% - 40% by volume of Heidrun oil and heptane) were aged at a constant temperature of 90oC with aging time as the laboratory control variable. A multimodal method incorporating contact angle measurements, wettability index via USBM test, and SEM-MLA analysis was applied in evaluating wettability. A systematic approach was applied with the three different methods to quantify the degree of uncertainty linked to a) wettability estimation and b) the aging procedure to control wettability alteration of Kansas chalk. With a comprehensive suite of samples, we were successfully able to alter the wettability of chalk cores.

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R, Kharrat. "Experimental Investigation of Reservoir Rock Wettability Alteration by Matricaria Chamomilla Extract". Petroleum & Petrochemical Engineering Journal 6, n. 3 (29 luglio 2022): 1–7. http://dx.doi.org/10.23880/ppej-16000308.

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Residual oil can be mobilized by reducing the interfacial tension between oil and water and/or by altering the wettability of the rock through surfactant flooding. Recently natural surfactants have been considered as opposite to synthetic surfactants due to environmental problems associated with synthetic surfactants. This work introduces a plant-based natural surfactant named Matricaria Chamomilla as an agent of reservoir rock wettability alteration. Qualitative and quantitative methods were used to measure rock samples' wettability. For this purpose, flotation wettability, separation wettability, and the pendant drop method were used. The results show that Matricaria Chamomilla extract (MCE) changes the reservoir rock wettability to some degree equivalent to other natural surfactants. The highest wettability variation was observed at 12%wt MCE concentration with 28% change and 21% for critical micelle concentration (CMC) of 5.5%wt.

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Wang, Xianchen, e Qin Zhang. "Insight into the Influence of Surface Roughness on the Wettability of Apatite and Dolomite". Minerals 10, n. 2 (28 gennaio 2020): 114. http://dx.doi.org/10.3390/min10020114.

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Surface roughness has an important influence on the wettability of particles. This paper is an innovative exploration to control the surface wettability of apatite and dolomite from the perspective of roughness in the background of phosphate flotation. Roughness characteristics of apatite and dolomite particles and its effects on wettability were investigated with surface roughness, contact angle measurements, and SEM analysis. The relationship between surface energy and wettability of different roughness surfaces was also discussed. The results indicated that the influence of roughness on apatite and dolomite particles showed the same regularity, and wettability increased with the increasing roughness for hydrophilic surfaces, while the wettability decreased for hydrophobic surfaces. The influence of roughness on wettability can be well explained by Wenzel and Cassie models, and the surface energy of different rough surfaces had a strong correlation with their wettability. When sodium oleate was added after acid treatment, the apatite was hydrophilic, while the dolomite was hydrophobic; the difference in wettability between them became greater as surface roughness increased. Thus, it can be predicted that the selective separation of dolomite and apatite under acid reverse flotation conditions can be strengthened by increasing the mineral surface roughness during comminution.

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Mitiurev, Nikolai A., Michael Verrall, Anastasia A. Ivanova, Alireza Keshavarz e Stefan Iglauer. "Sample preparation for rock wettability studies via atomic force microscopy". APPEA Journal 61, n. 1 (2021): 216. http://dx.doi.org/10.1071/aj20083.

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The wettability of a reservoir rock is one of the most essential parameters in oil and gas recovery applications and gas storage schemes. However, bulk techniques, which are commonly used to analyse rock wettability, for example the United States Bureau of Mines test, are not sensitive enough to probe mixed-wettability scenarios. Furthermore, these measurements are conducted at millimetre–centimetre scale, while wettability is determined at the atomic scale, and some rocks (e.g. shale) have a very fine structure even at nanoscale. Additionally, in the case of shale rocks, standard wettability measurements cannot be applied due to their extremely low permeability. To overcome these limitations, wettability can be directly measured at the nanoscale with advanced analytical methods, such as scanning electron microscopy (SEM) and atomic force microscopy (AFM). While such techniques are well-established in various disciplines, there exists no standard procedure for rock wettability analysis at nanoscale. Thus, this study elaborates on the optimal methods that can be used for the preparation of an AFM-cantilever-rock grain sample, with which the rock wettability can be measured at atomic scale. Therefore, this work aids in the wider-scale implementation of AFM as a rock wettability measurement tool.

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Yang, Jin-Long, Xuan Zhou, Yi-Feng Li, Xing-Pan Guo, Xiao Liang e Jia-Le Li. "Plantigrade settlement of the musselMytilus coruscusin response to natural biofilms on different surfaces". Journal of the Marine Biological Association of the United Kingdom 94, n. 8 (30 luglio 2014): 1639–49. http://dx.doi.org/10.1017/s0025315414001039.

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Surface properties affect the attachment of micro- and macroscopic marine organisms. The current study examined the settlement response of the musselMytilus coruscusplantigrades to natural biofilms formed on surfaces of different wettability. The percentages of plantigrade settlement were not influenced by the biofilms formed on variously wettable surfaces in the short term, but after 10 days, the plantigrade settlement rates decreased on biofilms formed on lower wettability surfaces. In general, lower wettability of the surfaces resulted in the decrease of the dry weight, bacterial and diatom density and the thickness of natural biofilms when compared to high wettability surfaces. In contrast, chlorophyll-aconcentration in biofilms was independent of the initial wettability of the surfaces. Comparative cluster analysis of bacterial denaturing gradient gel electrophoresis patterns revealed that high variability existed between the bacterial community on high wettability surfaces and that on low wettability surfaces. Thus, surface wettability affects the formation of natural biofilms, and this variation in biofilms developed on different wettability surfaces may explain the discrepancy in their corresponding inducing activities onM. coruscusplantigrade settlement. This finding provides new insight into interactions between mussel settlement, biofilm characteristics and surface properties.

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Yong, Jiale, Feng Chen, Qing Yang e Xun Hou. "Femtosecond laser controlled wettability of solid surfaces". Soft Matter 11, n. 46 (2015): 8897–906. http://dx.doi.org/10.1039/c5sm02153g.

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Li, Kexing, Bowen Chen, Wanfen Pu, Xueqi Jing, Chengdong Yuan e Mikhail Varfolomeev. "Characteristics of Viscoelastic-Surfactant-Induced Wettability Alteration in Porous Media". Energies 14, n. 24 (14 dicembre 2021): 8454. http://dx.doi.org/10.3390/en14248454.

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Wettability alteration is one of the most important mechanisms of surfactant flooding. In this work, the combined Amott/USBM (United States Bureau of Mines) method was applied to study the average wettability alteration of initially neutral cores after viscoelastic-surfactant (VES) filtration. The effects of static aging, dynamic aging, VES concentration, filtration flow rate, and pore radius on the alteration of a core’s average wettability were studied. The wettability-alteration trends measured by Amott and USBM were consistent, demonstrating that the overall hydrophilicity of the core was enhanced after VES filtration. The wettability alterations of the core brought about by dynamic aging were more significant than by static aging. The viscoelastic properties of the VES played an important role in altering the wettability. In addition, the ability of the VES to affect the core’s wettability was significantly enhanced when the VES concentration was increased, which was beneficial in increasing VES adsorption on the pore-wall surface, thus altering the overall wettability of the core. Increasing filtration flow rates can destroy those high-viscosity VES aggregates via the higher shear rate. A higher retention of VES makes the core more hydrophilic. The difference in the wettability of cores with different pore radius after VES filtration was not significant. The alteration of average wettability caused by VES in porous media provides a new vision for studying the EOR mechanism of VES.

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Sasaki, Nobuhiro. "Wettability of Solder." HYBRIDS 8, n. 2 (1992): 21–27. http://dx.doi.org/10.5104/jiep1985.8.2_21.

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Xin, Bingwei, e Jingcheng Hao. "Reversibly switchable wettability". Chem. Soc. Rev. 39, n. 2 (2010): 769–82. http://dx.doi.org/10.1039/b913622c.

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Parobek, David, e Haitao Liu. "Wettability of graphene". 2D Materials 2, n. 3 (23 giugno 2015): 032001. http://dx.doi.org/10.1088/2053-1583/2/3/032001.

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ROVNER, SOPHIE. "AT-WILL WETTABILITY". Chemical & Engineering News 86, n. 1 (7 gennaio 2008): 10. http://dx.doi.org/10.1021/cen-v086n001.p010a.

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Belyaeva, Liubov A., e Grégory F. Schneider. "Wettability of graphene". Surface Science Reports 75, n. 2 (maggio 2020): 100482. http://dx.doi.org/10.1016/j.surfrep.2020.100482.

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Raj, Rishi, Shalabh C. Maroo e Evelyn N. Wang. "Wettability of Graphene". Nano Letters 13, n. 4 (7 marzo 2013): 1509–15. http://dx.doi.org/10.1021/nl304647t.

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Wang, Liming, Bo Peng e Zhaohui Su. "Tunable Wettability and Rewritable Wettability Gradient from Superhydrophilicity to Superhydrophobicity". Langmuir 26, n. 14 (20 luglio 2010): 12203–8. http://dx.doi.org/10.1021/la101064c.

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Deng, Xiao, Muhammad Shahzad Kamal, Shirish Patil, Syed Muhammad Shakil Hussain e Xianmin Zhou. "A Review on Wettability Alteration in Carbonate Rocks: Wettability Modifiers". Energy & Fuels 34, n. 1 (4 dicembre 2019): 31–54. http://dx.doi.org/10.1021/acs.energyfuels.9b03409.

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Sun, Ling Hui, Wei Dong Liu e Chun Liu Sun. "The Adsorption Property of Wettability Reversal Surfactant". Advanced Materials Research 233-235 (maggio 2011): 2051–55. http://dx.doi.org/10.4028/www.scientific.net/amr.233-235.2051.

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In order to understand the adsorption property of wettability reversal surfactant, the adsorption rule of the wettability reversal surfactant on hydrophilic surface and lipophilic surface was studied, and the adsorption behavior of the wettability reversal surfactant on hydrophilic surface and lipophilic surface was studied by Atomic Force Microscope (AFM). The results show that there is a saturated adsorption capacity of all the wettability reversal surfactants on sandstone surface, and the adsorption quantity on lipophilic surface is bigger than that on hydrophilic surface. The AFM study show that the wettability reversal surfactant tends to distribute where is close to the oil droplet. Consequently, the wettability reversal surfactant is favorable for using in lipophilic surface.

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Widarsono, Bambang. "An Investigation Over Rock Wettability And Its Alteration On Some Indonesian Sandstones". Scientific Contributions Oil and Gas 33, n. 3 (22 febbraio 2022): 165–79. http://dx.doi.org/10.29017/scog.33.3.820.

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Wettability is a reservoir rock property that is not easy to measure and quantify but has a crucial effect on other rock properties such as relative permeability, capillary pressure, and electrical properties. Problem that may occur with regard to this matter is that those properties are often measured on already cleansed core samples as part of the standard procedure. Having undergone the normally utilized heated cleansing process alteration in the rock’s original wettability was often reported. Under such condition, unrepresentative wettability certainly leads to unrepresentative measured data with all of consequences. This article presents a study that uses 363 sandstone samples retrieved from 28 oil and gas fields in Indonesia. The study consists of two stages of analysis. First analysis is performed on data obtained from three wettability tests results while the second one is made with using water-oil relative permeability data, that is usually measured on cleansed core samples. Original wettability data shows that the sandstones varry in wettability from water-wet to oil-wet (48.2% and 30.2% of total samples, respectively). Comparison between data of the two analyses shows that original wettability tends to degrade in strength after cleaning down to neutral wettability, among which neutral wettability appears to be the largest in number (49.1% of total sample). Results also show that weak wettability tends to endure more than stronger ones. The overall results have demonstrated the need for caution in core handling and for measures that can minimize the risk.

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Gong, Wenbo, e Jinhui Liu. "Effect of Wettability Heterogeneity on Water-Gas Two-Phase Displacement Behavior in a Complex Pore Structure by Phase-Field Model". Energies 15, n. 20 (17 ottobre 2022): 7658. http://dx.doi.org/10.3390/en15207658.

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Understanding the immiscible displacement mechanism in porous media is vital to enhancing the hydrocarbon resources in the oil and gas reservoir. Improving resource recovery requires quantitatively characterizing the effect of wettability heterogeneity on the immiscible displacement behaviors at the pore scale, which can be used to predict the displacement distribution of multiphase fluids and evaluate the optimal wettability strategy in porous media. The heterogeneity of fluid wettability in a natural rock makes it extremely hard to directly observe the fluid displacement behaviors in the reservoir rocks and quantify the sensitivity of preferential displacement path and displacement efficiency to wettability distribution. In this study, the phase-field model coupling wettability heterogeneity was established. The gas-water two-phase displacement process was simulated under various wettability distributions and injecting flux rates in a complex pore structure. The effect of wettability heterogeneity on immiscible displacement behavior was analyzed. The results indicated that wettability heterogeneity significantly affects the fluid displacement path and invasion patterns, while the injecting flux rate negatively influences the capillary–viscous crossover flow regime. The continuous wetting patches enhanced the preferential flow and hindered displacement, whereas the dalmatian wetting patches promoted a higher displacement efficiency. The results of the fractal dimensions and specific surface area also quantitatively show the effects of wettability distribution and heterogeneity on the complexity of the two-phase fluid distribution. The research provides the theoretical foundation and analysis approach for designing an optimal wettability strategy for injecting fluid into unconventional oil and gas reservoirs.

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Bolysbek, Darezhat, Kenbai Uzbekaliyev e Bakytzhan Assilbekov. "Rock Wettability Alteration Induced by the Injection of Various Fluids: A Review". Applied Sciences 14, n. 19 (26 settembre 2024): 8663. http://dx.doi.org/10.3390/app14198663.

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Wettability is a key parameter that determines the distribution and behavior of fluids in the porous media of oil reservoirs. Understanding and controlling wettability significantly impacts the effectiveness of various enhanced oil recovery (EOR) methods and CO2 sequestration. This review article provides a comprehensive analysis of various methods for measuring and altering wettability, classifying them by mechanisms and discussing their applications and limitations. The main methods for measuring wettability include spontaneous imbibition methods such as Amott–Harvey tests and USBM, contact angle measurement methods, and methods based on the characteristics of imbibed fluids such as infrared spectroscopy (IR) and nuclear magnetic resonance (NMR). These methods offer varying degrees of accuracy and applicability depending on the properties of rocks and fluids. Altering the wettability of rocks is crucial for enhancing oil recovery efficiency. The article discusses methods such as low-salinity water flooding (LSWF), the use of surfactants (SAAs), and carbonated water injection (CWI). LSWF has shown effectiveness in increasing water wettability and improving oil displacement. Surfactants alter interfacial tension and wettability, aiding in better oil displacement. CWI also contributes to altering the wettability of the rock surface to a more water-wet state. An important aspect is also the alteration of wettability through the dissolution and precipitation of minerals in rocks. The process of dissolution and precipitation affects pore structure, capillary pressure, and relative permeabilities, which in turn alters wettability and oil displacement efficiency.

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Skibitskaya, N. A., I. O. Burkhanova, M. N. Bolshakov, V. A. Kuzmin e O. O. Marutyan. "Carbonate oil and gas source rocks wettability alteration due to influence of polymer-colloidal drilling mud". SOCAR Proceedings, SI2 (30 dicembre 2021): 17–27. http://dx.doi.org/10.5510/ogp2021si200545.

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Evaluation of rock wettability is an important task, since this parameter determines the distribution of water and oil in the reservoirs and their relative and phase permeability. The reliability of evaluation the wettability of rock samples depends on the drilling-in conditions during core sampling and core sample preparation methods. The investigation of the surface properties of the core from the Orenburg oil and gas condensate field showed that using of polymer-colloidal drilling mud leads to hydrophilization of the samples' surface. To obtain information on the actual wettability values of rock samples taken from wells drilled with polymer-colloidal drilling mud a method for estimating the relative (predominant) wettability of rocks based on petrophysical and lithological studies data is proposed. The authors suggest that the extraction of oil and gas source rock samples leads to irreversible changes in surface properties that cannot be restored. Keywords: selective wettability; relative wettability; predominant wettability; polymer-colloidal drilling mud; residual gas saturation; trapped gas saturation; pore space structure; extraction.

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33

Feng, Xuegang, Xiang’an Yue, Weiqing An e Jirui Zou. "Experimental Study of Influence of Core Wettability on Imbibition Properties". Energies 15, n. 11 (28 maggio 2022): 3984. http://dx.doi.org/10.3390/en15113984.

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Through new core wettability simulation technology and the single-sided unidirectional imbibition experimental method, the influence of core wettability on oil imbibition characteristics was studied by using artificial cores with wettability index in the range of −0.9~0.95. Results show that for the cores with permeability from ultra-low to medium–high, the imbibition time shows a monotonically decreasing law with the increase in the wettability index. In the weak water-wet range, the imbibition time increases significantly with the weakening of water-wet. Oil imbibition rate goes up with the increase in wettability index. In the strong water-wet range, the imbibition rate will change significantly with wettability. In the water-wet zone, there is a positive correlation between imbibition oil limit recovery and wettability index, according to which a power exponent model of them is established. The imbibition–displacement ratio, which characterizes the contribution rate of oil recovery by imbibition to that by waterflooding, is also positively correlated with the wettability index. In addition, imbibition–displacement ratios of extra-low permeability cores are very close to that of medium–high permeability cores. According to the analysis of the research results, compared with the strongly water-wet oil layer, the weakly water-wet oil layer with a wettability index of 0–0.5 has a greater contribution to oil recovery by using the enhanced imbibition method.

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Brattekås, Bergit, Martine Folgerø Sandnes, Marianne Steinsbø e Jacquelin E. Cobos. "A Systematic Investigation of Polymer Influence on Core Scale Wettability Aided by Positron Emission Tomography Imaging". Polymers 14, n. 22 (21 novembre 2022): 5050. http://dx.doi.org/10.3390/polym14225050.

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Polymers have been used as viscosifying agents in enhanced oil recovery applications for decades, but their influence on rock surface wettability is rarely discussed relative to its importance: wettability largely controls fluid flow in porous media and changes in wettability may significantly influence subsequent system performance. This paper presents a two-part systematic investigation of wettability alteration during polymer injection into oil-wet limestone. The first part of the paper determines wettability and wetting stability on the core scale. The well-established Amott–Harvey method is used, and five full cycles performed with repeated spontaneous imbibition and forced displacements. Wettability alterations are measured in a polymer/oil system, to determine polymer influence on wettability, and evaluated towards simpler brine/oil and glycerol/oil systems, to determine reproducibility and uncertainty related to the method and fluid/rock system. Polymer injection into oil-wet limestone core plugs is shown to repeatedly and reproducibly reverse the core wettability towards water-wet. Wettability changed both quicker and towards stronger water-wet conditions with polymer solution as the aqueous phase compared to brine and glycerol. The second part of the paper attempts to explain the observed behavior; by utilizing in situ imaging by Positron Emission Tomography, an emerging imaging technology within the geosciences. High resolution imaging provides insight into fluid flow dynamics during water and polymer injections, identifying uneven displacement fronts and significant polymer adsorption.

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He, Yong, Shupei Xiao, Jianjian Wu e Hui Fang. "Influence of Multiple Factors on the Wettability and Surface Free Energy of Leaf Surface". Applied Sciences 9, n. 3 (11 febbraio 2019): 593. http://dx.doi.org/10.3390/app9030593.

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The wettability of plant leaves directly reflects leaf hydrophilicity, which is the key factor that influences the adhesion of liquid pesticide as well as affects plant protection products (PPP) efficacy. Generally, the wettability of leaf surface is quantified by the contact angle and surface free energy (SFE), which are mainly dependent on leaf surface properties, liquid properties and other spraying parameters. Therefore, the aim of this paper was to investigate the SFE of rice and rape leaves with the variation of leaf status, leaf surface, and probe liquid as well as the influence of droplet falling height, solid surface, and PPP concentration on the wettability. The results showed that: (1) the dispersive components of SFE of rice and rape account for a large proportion which are closely related to their hydrophobicity—the abaxial of rape new leaf and the adaxial of rape old leaf are easier to wet comparing with rice and rape leaves in other statuses; (2) the increase of droplet falling height had a significant effect on improving the wettability between wax surface and adjuvant solution, while it had little improving effect on the wettability between wax surface and water; (3) the wettability of different solid surface varied greatly, and the order of wettability from good to bad is water-sensitive paper (WSP), wax, rape leaf, and rice leaf; (4) the effect of PPP concentration on the leaf surface wettability is significant, the contact angle decreased with the increase of PPP concentration, and the wettability of microemulsion is better than that of suspending agent and wettable powder. In conclusion, the SFE and wettability of crop leaf surface determine the suitable type of PPP, studying the influence of multiple factors on leaf surface wettability can provide a reliable reference for providing scientific guidance as well as improving the effective utilization of PPP.

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36

Dick, Michael J., Dragan Veselinovic, Ron J. M. Bonnie e Shaina A. Kelly. "NMR-Based Wettability Index for Unconventional Rocks". Petrophysics – The SPWLA Journal of Formation Evaluation and Reservoir Description 63, n. 3 (1 giugno 2022): 418–41. http://dx.doi.org/10.30632/pjv63n3-2022a9.

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Standardized and benchmarked wettability characterization and quantification workflows are lacking in unconventional reservoir development. Quantification of in-situ wettability and changes due to wettability alteration efforts can assist with completions decisions, and economic oil production. This manuscript summarizes the establishment and validation of an NMR wettability index (NWI) for unconventional rocks. The method builds upon Looyestijn’s NMR wettability analysis methods for conventional rocks and has been tested on core plug samples from a variety of major producing unconventional reservoirs. It will be of interest to readers to note the marked range of wettability values quantified among the aforementioned tight formations. Our NWI model is well suited for data sets featuring complex oil and water T2 spectra with multiple peaks, common features of unconventional rock spectra. The results were subjected to comprehensive experimental and analytical validation, including complementary 3D NMR imaging and replication of the experiments with D2O. The validation procedure and advantages of the approach over other NMR wettability models are discussed in this review. Finally, best practices are detailed so that the SCAL methodology can be deployed on a larger scale.

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Seiedi, Omolbanin, Mohammad Zahedzadeh, Emad Roayaei, Morteza Aminnaji e Hossein Fazeli. "Experimental and modeling study of wettability alteration through seawater injection in limestone: a case study". Petroleum Science 17, n. 3 (9 gennaio 2020): 749–58. http://dx.doi.org/10.1007/s12182-019-00407-y.

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AbstractWater flooding is widely applied for pressure maintenance or increasing the oil recovery of reservoirs. The heterogeneity and wettability of formation rocks strongly affect the oil recovery efficiency in carbonate reservoirs. During seawater injection in carbonate formations, the interactions between potential seawater ions and the carbonate rock at a high temperature can alter the wettability to a more water-wet condition. This paper studies the wettability of one of the Iranian carbonate reservoirs which has been under Persian Gulf seawater injection for more than 10 years. The wettability of the rock is determined by indirect contact angle measurement using Rise in Core technique. Further, the characterization of the rock surface is evaluated by molecular kinetic theory (MKT) modeling. The data obtained from experiments show that rocks are undergoing neutral wetting after the aging process. While the wettability of low permeable samples changes to be slightly water-wet, the wettability of the samples with higher permeability remains unchanged after soaking in seawater. Experimental data and MKT analysis indicate that wettability alteration of these carbonate rocks through prolonged seawater injection might be insignificant.

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Nisogi, Kenta, Satoshi Okano, Sengo Kobayashi, Kensuke Kuroda e Takeaki Okamoto. "Effects of Titanium Surface Wettability on Osteoblast Behavior In Vitro". Materials Science Forum 985 (aprile 2020): 64–68. http://dx.doi.org/10.4028/www.scientific.net/msf.985.64.

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Surface wettability is thought to influence the osteoconductivity of bone-substituting materials; however, the effects of surface wettability on osteoblast behavior are not well understood. In this study, we prepared both an as-polished pure titanium with a water contact angle (WCA) of 57° and heat-treated pure titanium with more hydrophobic surface and WCAs of 68°-98°. The effects of the surface wettability of pure titanium on osteoblast behaviors were evaluated by in vitro assays. Compared with the as-polished titanium, the proliferation rate of osteoblast increased on heat-treated titanium. This suggested that surface wettability affects osteoblast behaviors, meaning osteoconductivity is influenced by surface wettability.

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Widarsono, Bambang. "Rock Wettability Characteristics Of Some Indonesian Limestones Case Study: Baturaja Formation". Scientific Contributions Oil and Gas 34, n. 2 (14 marzo 2022): 105–16. http://dx.doi.org/10.29017/scog.34.2.796.

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Rock wettability plays a very important role in affecting various rock physical properties such as relative permeability and capillary pressure. Common practice at present is that carbonate rocks are assumed to be preferentially oil wet in nature. This assumption may prove fatal since the need of true knowledge over the real wettability for one’s carbonate reservoir is often neglected, and wettability aspect in reservoir modeling is in turn based on assumption. To prove over reliability of the assumption a study is carried out using information from 350 core samples taken from Baturaja Formation. The choice for the Baturaja limestone is basically based on the fact that it is a mature productive rock formation and its extensive spread into three of the most productive sedimentary basin in Indonesia, Northwest Java Basin, South Sumatra Basin, and Sunda Basin. The study proves that the assumption of the generally oil wet limestone does not apply for Baturaja limestone. The Baturaja limestone tend to exhibit, quantitatively, equality in their tendency towards oil wettability and water wettability and leave some proportion to neutral or mix wettability as well. However, when a more detailed comparison is made results show that qualitatively the limestone are indeed more inclined to oil wettability than water wettability even though this finding is insufficient to support a conclusion that the Baturaja limestone are specifically oil wet. Other finding from comparison with past studies also shows that limestone may behave in the way sandstones do. Both limestone and sandstones may vary in the same way and no assumption over their preferential wettability is justified without direct measurements. Wettability alteration as the result of hot core cleaning following the widely accepted standard procedure is also strongly indicated. It is therefore concluded that the practice has to be abandoned for a better and reliable laboratory testing results.

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40

Anderson, W. G. "Wettability Literature Survey-Part 6: The Effects of Wettability on Waterflooding". Journal of Petroleum Technology 39, n. 12 (1 dicembre 1987): 1605–22. http://dx.doi.org/10.2118/16471-pa.

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41

Chen, J., G. J. Hirasaki e M. Flaum. "NMR wettability indices: Effect of OBM on wettability and NMR responses". Journal of Petroleum Science and Engineering 52, n. 1-4 (giugno 2006): 161–71. http://dx.doi.org/10.1016/j.petrol.2006.03.007.

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42

Fujinami, Akinori, Daisuke Matsunaka e Yoji Shibutani. "Water wettability/non-wettability of polymer materials by molecular orbital studies". Polymer 50, n. 2 (gennaio 2009): 716–20. http://dx.doi.org/10.1016/j.polymer.2008.11.050.

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43

Anderson, W. G. "Wettability Literature Survey- Part 4: Effects of Wettability on Capillary Pressure". Journal of Petroleum Technology 39, n. 10 (1 ottobre 1987): 1283–300. http://dx.doi.org/10.2118/15271-pa.

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44

Leggate, William, Robert L. McGavin, Chuang Miao, Andrew Outhwaite, Kerri Chandra, Jack Dorries, Chandan Kumar e Mark Knackstedt. "The influence of mechanical surface preparation methods on southern pine and spotted gum wood properties: Wettability and permeability". BioResources 15, n. 4 (23 settembre 2020): 8554–76. http://dx.doi.org/10.15376/biores.15.4.8554-8576.

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The demand for engineered wood products (EWPs) continues to rise internationally. However, for some important Australian commercial timbers such as plantation grown southern pine and native forest sourced spotted gum, a major impediment to achieving commercially viable EWP production is difficulties experienced in gluing – particularly for sawn laminate based EWPs such as glulam. Wettability and permeability have a major influence on wood adhesion. This study investigated the efficacy of different surface machining preparations on the wettability and permeability of southern pine and spotted gum. For both species, planing resulted in poor wettability, whereas face milling and sanding treatments post-planing improved wettability. Wettability increased in southern pine earlywood compared to latewood; and wettability decreased for both species with increased time post-surface machining. Planing resulted in the highest permeability for southern pine but the lowest permeability for spotted gum. Face milling resulted in higher permeability compared to sanding treatments.

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Huang, Qiang, Jingzhi Zhou, Xiulan Huai e Feng Zhou. "Enhancing pool boiling heat transfer of modified surface by 3D Lattice Boltzmann method". Thermal Science, n. 00 (2023): 121. http://dx.doi.org/10.2298/tsci230114121h.

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In this study, pool boiling from micro-pillar modified surface has been simulated numerically by a 3D Lattice Boltzmann method(LBM). Effects of geometries and wettability of micro-pillaron boiling heat transfer performance were also systematically evaluated. Result showed that compared with in micro-pillar surface, heat flux of cubic micro-pillar surface was the highest with the lowest wall temperature. In addition, compared to hydrophilic condition, Heat flux of cubic micro-pillar surface with hydrophobic wettability increased by 98.3%. This is because hydrophobic wettability influenced nucleation site density, vapor-liquid flow field and heat transfer performance much more than cubic shaped geometry. Finally, heat flux of cubic micro-pillar surface with hybrid wettability increased by 430.7% compared to pure hydrophilic wettability. That is due to optimal hybrid wettability surface could control nucleate site location, restrict bubble growth, and increase obviously heat transfer performance.

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Mikhailov, N. N., O. M. Ermilov e L. S. Sechina. "Influence of asphaltenes on wettability of gas and oil saturated reservoir rock". Доклады Академии наук 486, n. 1 (10 maggio 2019): 65–68. http://dx.doi.org/10.31857/s0869-5652486165-68.

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The wettability of terrigenous and carbonate rock cores of oil and gas condensate fields extracted with n-hexane and chloroform by asphaltenes was studied. The obtained values of core wettability with asphaltenes show their contribution to the change of wettability of different rocks.

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Liu, Yifang, Junyu Chen e Gaofeng Zheng. "Study on the Wetting Mechanism between Hot-Melt Nano Glass Powder and Different Substrates". Micromachines 13, n. 10 (6 ottobre 2022): 1683. http://dx.doi.org/10.3390/mi13101683.

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The wettability of molten glass powder plays an essential role in the encapsulation of microelectromechanical system (MEMS) devices with glass paste as an intermediate layer. In this study, we first investigated the flow process of nano glass powder melted at a high temperature by simulation in COMSOL. Both the influence of the different viscosity of hot-melt glass on its wettability on SiO2 and the comparison of the wettability of hot-melt glass on Au metal lead and SiO2 were investigated by simulation. Then, in the experiment, the hot-melt glass flew and spread along the length of the Au electrode because of a good wettability, resulting in little coverage of the hot-melt glass on the Au electrode, with a height of only 500 nm. In order to reduce the wettability of the glass paste on the Au electrode, a SiO2 isolation layer was grown on the surface of golden lead by chemical vapor deposition. It successfully reduced the wettability, so the thickness of the hot-melt glass was increased to 1.95 μm. This proved once again that the wettability of hot-melt glass on Au was better.

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48

Toumelin, Emmanuel, Carlos Torres-Verdin, Boqin Sun e Keh-Jim Dunn. "Limits of 2D NMR Interpretation Techniques to Quantify Pore Size, Wettability, and Fluid Type: A Numerical Sensitivity Study". SPE Journal 11, n. 03 (1 settembre 2006): 354–63. http://dx.doi.org/10.2118/90539-pa.

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Summary Two-dimensional (2D) NMR techniques have been proposed as efficient methods to infer a variety of petrophysical parameters, including mixed fluid saturation, in-situ oil viscosity, wettability, and pore structure. However, no study has been presented to quantify the petrophysical limitations of such methods. We address this problem by introducing a pore-scale framework to accurately simulate suites of NMR measurements acquired in complex rock/fluid models. The general pore-scale framework considered in this paper is based on NMR random walks for multiphase fluid diffusion and relaxations, combined with Kovscek's pore-scale model for two-phase fluid saturation and wettability alteration. We use standard 2D NMR methods to interpret synthetic data sets for diverse petrophysical configurations, including two-phase saturations with different oil grades, mixed wettability, or carbonate pore heterogeneity. Results from our study indicate that for both water-wet and mixed-wet rocks, T2 (transverse relaxation)/D (diffusion) maps are reliable for fluid typing without the need for independently determined cutoffs. However, significant uncertainty exists in the estimation of fluid type, wettability, and pore structure with 2D NMR methods in cases of mixed-wettability states. Only light oil wettability can be reliably detected with 2D NMR interpretation methods. Diffusion coupling in carbonate rocks introduces additional problems that cannot be circumvented with current 2D NMR techniques. Introduction Wettability state and oil viscosity can play a significant role in the NMR response of saturated rocks. This property of NMR measurements has been discussed in recent papers (Freedman et al. 2003) for particular examples of rock systems. However, to date, no systematic study has been published of the reliability and accuracy of NMR methods to assess fluid viscosity and wettability, including cases of mixed wettability. This paper quantifies the sensitivity of 2D relaxation/diffusion NMR techniques to mixed wettability and fluid viscosity in generic rock models. Given that measurements are often made on rock samples with uncertain petrophysical properties and therefore uncertain corresponding measurement contributions, the work described in this paper is based on the numerical simulation of pore-scale systems. We introduce a general numerical model that simultaneously includes immiscible fluid viscosities, water or mixed wettability, variable fluid saturations and history, and disordered complexity of rock structure. Geometrical fluid distributions at the pore scale were considered a function of pore size, saturation history, and wettability following Kovscek et al.'s model of mixed-oil-wet rocks (1993). We simulated suites of NMR measurements with random walkers within these pore-scale geometries, and subsequently inverted into relaxation/diffusion NMR maps. The objective of this paper is to assess the accuracy of 2D NMR interpretation techniques to detect fluid and wettability types, and to quantify pore-size distributions. The first section of the paper summarizes the principles and limitations of current NMR petrophysical interpretation. We then summarize our pore-scale modeling procedure, its assumptions, and limitations. Subsequent sections analyze simulation results obtained for drainage and imbibition involving water-wettability and mixed-oil-wettability with partial saturations of water and different hydrocarbon types in a generic clay-free rock model. Next, we consider the case of coupled carbonate rocks with emphasis on the assessment of wettability and microporosity.

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Ren, Xiao Yuan, Zhi Yuan Yang, Shi Cun Qu e Jiang Long. "The Effect of Sodium Dodecyl Sulphate (SDS) on Wettability of Different Coals". Advanced Materials Research 734-737 (agosto 2013): 513–16. http://dx.doi.org/10.4028/www.scientific.net/amr.734-737.513.

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Three coals (Jincheng coal, Hancheng coal and Shan-bei coal) varying widely in coal type have been treated with anionic surfactant Sodium Dodecyl Sulphate (SDS). The effect of SDS on wettability of coals was explored by contact angles and zeta potentials characterisation techniques. Results obtained show that the addition of SDS can obviously improve the wettability of coals, and as the coal rank decreases, the wettability increases under investigation. Moreover, the wettability obviously increases with the significant decrease of particle size. The zeta potential for each coal, in the absence of surfactant, is negative, and the potential becomes more negative with the addition of SDS. Meanwhile, the FTIR spectrogram was used to test the changes of-COOH and-OH to analyze the reason for change of wettability, the results show that the wettability changes may be attributed to that the negative active ions of SDS are adsorbed on the coal surface, resulting in the increase of hydrophilic groups of the coal surface.

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Singh, Robin, e Kishore K. Mohanty. "Foams With Wettability-Altering Capabilities for Oil-Wet Carbonates: A Synergistic Approach". SPE Journal 21, n. 04 (15 agosto 2016): 1126–39. http://dx.doi.org/10.2118/175027-pa.

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Summary The goal of this work is to systematically study the effect of wettability alteration and foaming, either acting individually or synergistically, on tertiary oil recovery in oil-wet carbonate cores. Three types of anionic-surfactant formulations were used: alkyl propoxy sulfate (APS), which exhibited low interfacial tension (IFT), wettability alteration, and weak foaming; alpha-olefin sulfonate (AOS), which showed no wettability alteration but good foaming; and a blend of APS, AOS, and a zwitterionic-foam booster, which showed low IFT, wettability alteration, and good foaming. First, contact-angle experiments were conducted on oil-wet calcite plates to evaluate their wettability-altering capabilities. Second, spontaneous imbibitions in a microchannel were performed to study the role of IFT reduction and wettability alteration by these formulations. Third, static foam tests were conducted to evaluate their foaming performance in bulk. Fourth, foam-flow experiments were conducted in cores to evaluate potential synergism between the anionic-surfactant AOS and the zwitterionic surfactants in stabilizing foam in the absence of crude oil. Finally, oil-displacement experiments were performed by use of a vuggy, oil-wet, dolomite core saturated with a crude oil. After secondary waterfloods, surfactant solutions were coinjected with methane gas at a fixed foam quality (gas-volume fraction). Contact-angle and spontaneous-imbibition experiments showed that AOS can act as a wettability-altering surfactant in the presence of sodium carbonate, but not alone. No synergy was observed in foam stabilization by means of the blend of zwitterionic surfactant and AOS solution (1:1) in a water-wet carbonate core. Oil-displacement experiments in oil-wet carbonate core revealed that coinjection of wettability-altering surfactant and gas can recover a significant amount of oil [33% original oil in place (OOIP)] over waterflood. During foam flooding, with AOS as the foaming agent, only a weak foam was propagated in a carbonate core, irrespective of the core wettability. A blend of wettability-altering surfactant, AOS, and zwitterionic surfactant not only altered the wettability of carbonate core from oil-wet to water-wet, but also significantly increased the foam-pressure gradient in the presence of crude oil.

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