Experimental investigation of carbonate wettability as a function of mineralogical and thermo-physical conditions

Arif, Muhammad; Abu-Khamsin, Sidqi A.; Zhang, Yihuai; Iglauer, Stefan

doi:10.1016/j.fuel.2019.116846

Cited by 55 publications

(36 citation statements)

References 61 publications

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“…For example, there is rock roughness in the reservoir that is eliminated in the contact angle tests. This roughness increases the effective surface area and adsorbs more oil onto the surface . On the other hand, in a chemical flood, this can increase the adsorption of additives.…”

Section: Results and Discussionmentioning

confidence: 99%

“…This roughness increases the effective surface area and adsorbs more oil onto the surface. 44 On the other hand, in a chemical flood, this can increase the adsorption of additives. Adsorption of petroleum components increases the hydrophobicity and adsorption of chemical additives such as surfactants in the optimal orientation of molecules can cause hydrophilicity.…”

Section: ■ Materials and Methodsmentioning

confidence: 99%

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Chemical Enhanced Oil Recovery by Different Scenarios of Slug Injection into Carbonate/Sandstone Composite Oil Reservoirs Using an Anionic Surfactant Derived from Rapeseed Oil

2021

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Surfactants are effective additives for interfacial tension (IFT) reduction. They can also improve the reservoir rock wettability and foam and emulsion formation. In this study, a Rapeseed oil-derived surfactant was first synthesized. The surfactant characteristics were determined by thermalgravimetric analysis, Fourier-transform infrared (FTIR) spectroscopy, and proton nuclear magnetic resonance ( 1 H NMR) spectroscopy. The experiments of IFT, sessile drop contact angle and chemical flooding in various scenarios such as integrated injection of the surfactant solution at critical micelle concentration (CMC) and optimal salinity, injection of 0.50 PV of the surfactant solution at CMC with optimal salinity and NaOH alkalinity (SA), injection of 0.50 PV of the surfactant solution at CMC with optimal salinity and 1000 ppm of partially hydrolyzed polyacrylamide (SP), injection of 0.25 PV of the surfactant solution at CMC with optimal salinity and NaOH alkalinity and 1000 ppm of PHPA polymer (ASP), and injection of 0.50 PV of the surfactant solution at CMC with optimal salinity and NaOH alkalinity and 1000 ppm of PHPA polymer (ASP) into carbonate/sandstone composite (CSC) plugs were performed to show the surfactant usage efficiency in enhanced oil recovery (EOR) process. Also, emulsion and foaming experiments were conducted to measure the capability of the surfactant under other EOR conditions. Based on the results, IFTs were obtained for the surfactant concentrations of 1500, 2500, 3500, 4500, 5500, and 6500 ppm equal to 3.157, 2.514, 1.089, 0.034, 0.071, and 0.095 mN/m, respectively. Accordingly, a low IFT of 3.4 × 10 −2 mN/m was obtained at CMC, which further decreased through optimization of the solution with optimal salinity and alkalinity. The CSC wettability altered to being hydrophilic, and the mean contact angles of 125.42, 105.53, 70.21, and 40.62°were obtained after 15, 30, 45, and 60 min, respectively. Oil production in various chemical injection scenarios increased by about 14.6−25.7%, depending on the type and amount of injection fluids. The novelty of this study is the introduction and application of a surfactant with a newly available herbal source.

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Section: Results and Discussionmentioning

confidence: 99%

Section: ■ Materials and Methodsmentioning

confidence: 99%

Chemical Enhanced Oil Recovery by Different Scenarios of Slug Injection into Carbonate/Sandstone Composite Oil Reservoirs Using an Anionic Surfactant Derived from Rapeseed Oil

2021

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“…Contact angle measurement is the most effective method which is widely used to quantify the wetting characteristics of reservoir rock in the presence of two fluids [21,24,25,[52][53][54]. This method can be performed in real reservoir conditions or ambient conditions.…”

Section: Contact Angle Measurement Systemmentioning

confidence: 99%

Effect of Environment-Friendly Non-Ionic Surfactant on Interfacial Tension Reduction and Wettability Alteration; Implications for Enhanced Oil Recovery

et al. 2020

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Production from mature oil reservoirs can be optimized by using the surfactant flooding technique. This can be achieved by reducing oil and water interfacial tension (IFT) and modifying wettability to hydrophilic conditions. In this study, a novel green non-ionic surfactant (dodecanoyl-glucosamine surfactant) was synthesized and used to modify the wettability of carbonate reservoirs to hydrophilic conditions as well as to decrease the IFT of hydrophobic oil–water systems. The synthesized non-ionic surfactant was characterized by Fourier transform infrared spectroscopy (FTIR) and chemical shift nuclear magnetic resonance (HNMR) analyses. Further pH, turbidity, density, and conductivity were investigated to measure the critical micelle concentration (CMC) of surfactant solutions. The result shows that this surfactant alters wettability from 148.93° to 65.54° and IFT from 30 to 14 dynes/cm. Core-flooding results have shown that oil recovery was increased from 40% (by water flooding) to 59% (by surfactant flooding). In addition, it is identified that this novel non-ionic surfactant can be used in CO2 storage applications due to its ability to alter the hydrophobicity into hydrophilicity of the reservoir rocks.

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“…Contact angle measurements are usually studied at reservoir conditions, where brine salinity, oil composition, rock mineralogy as well as pressure and temperature are the most investigated parameters [16][17][18][19][20][21]. While the aforementioned indeed influence the wettability, there exist other factors that impact the measurements and their interpretation from a methodological perspective.…”

Section: Introductionmentioning

confidence: 99%

Experimental determination of wetting behavior under non-atmospheric conditions relevant to reservoirs: a practical guide

Samara

Jaeger

2022

SN Appl. Sci.

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The wetting behavior in subsurface reservoirs plays a crucial role in storage, migration and liberation of fluid phases that are especially relevant to the energy sector. Further, the three-phase contact angle is important for implementing safe and successful subsurface storage of hydrogen and carbon dioxide. For reliable statements on the in situ wetting, it is important to be aware of the decisive factors of influence in order to design and perform the respective experiments in an appropriate way. This paper discusses the most important effects that shall be considered when determining contact angles experimentally, like drop size, surface roughness, aging process, dynamic behavior, and the pH, giving some valuable guidance to guarantee significant results. A drop base diameter of no less than 5 mm is found to be appropriate to minimize the impact of gravity on the contact angle under reservoir conditions. It is further confirmed that surface roughness contributes to better water wetting when the contact angles are below 90°. The versatility of contact angle measurements is shown through the dual-drop dual-crystal method that can be applied to estimate the adhesion forces present at the rock-brine interface and that need to be overcome by the flooding liquid to effectively displace hydrocarbons from the pores.

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Experimental investigation of carbonate wettability as a function of mineralogical and thermo-physical conditions

Cited by 55 publications

References 61 publications

Chemical Enhanced Oil Recovery by Different Scenarios of Slug Injection into Carbonate/Sandstone Composite Oil Reservoirs Using an Anionic Surfactant Derived from Rapeseed Oil

Chemical Enhanced Oil Recovery by Different Scenarios of Slug Injection into Carbonate/Sandstone Composite Oil Reservoirs Using an Anionic Surfactant Derived from Rapeseed Oil

Effect of Environment-Friendly Non-Ionic Surfactant on Interfacial Tension Reduction and Wettability Alteration; Implications for Enhanced Oil Recovery

Experimental determination of wetting behavior under non-atmospheric conditions relevant to reservoirs: a practical guide

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