Fifty Years of Wettability Measurements in the Arab-D Carbonate
Reservoir

Okasha, Taha; Funk, James E.; Rashidi, Hamid

doi:10.2523/105114-ms

Cited by 11 publications

(9 citation statements)

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“…Traditional lab-scale flooding experiments have used a cylindrical core from a sample reservoir rock collected during drilling to estimate the oil recovery data, through what is known as a core-flooding experiment. However, the fluid transport processes in a reservoir rock occur at a pore-scale on the order of nano- to millimeters, − and the conventional core-flooding tests are not able to provide structural information at such a scale. In order to develop efficient methods for oil recovery, we need to understand the underlying physical processes which occur at the pore scale.…”

Section: Introductionmentioning

confidence: 99%

“…In order to develop efficient methods for oil recovery, we need to understand the underlying physical processes which occur at the pore scale. For example, in the Ghawar Arab-D reservoir in Saudi Arabia, the largest collection of carbonate reservoirs in the world, the microporosity (pore throats and channels <10 μm) constitutes up to 50% of the total porosity in the carbonate rock. ,, A significant proportion of the world’s oil reserves are found in carbonate reservoirs. For example, it is estimated that around 70% of oil and 90% of gas reserves are held in carbonate reservoirs in the Middle East.…”

Section: Introductionmentioning

confidence: 99%

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Toward Reservoir-on-a-Chip: Fabricating Reservoir Micromodels by in Situ Growing Calcium Carbonate Nanocrystals in Microfluidic Channels

Wang

Chang

Gizzatov

2017

ACS Appl. Mater. Interfaces

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We introduce a novel and simple method to fabricate calcium carbonate (CaCO) micromodels by in situ growing a thin layer of CaCO nanocrystals with a thickness of 1-2 μm in microfluidic channels. This approach enables us to fabricate synthetic CaCO reservoir micromodels having surfaces fully covered with calcite, while the dimensions and geometries of the micromodels are controllable on the basis of the original microfluidic channels. We have tuned the wettability of the CaCO-coated microchannels at simulated oil reservoir conditions without introducing any chemical additives to the system; thus the resulting oil-wet surface makes the micromodel more faithfully resemble a natural carbonate reservoir rock. With the advantage of its excellent optical transparency, the micromodel allows us to directly visualize the complex multiphase flows and geochemical fluid-calcite interactions by spectroscopic and microscopic imaging techniques. The CaCO-coated microfluidic channels provide new capabilities as a micromodel system to mimic real carbonate reservoir properties, which would allow us to perform a water-oil displacement experiment in small-volume samples for the rapid screening of candidate fluids for enhanced oil recovery (EOR). The immiscible fluid displacement process within carbonate micromodels has been demonstrated showing the water-oil-carbonate interactions at pore-scale in real time by fluorescence microscopic imaging.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Toward Reservoir-on-a-Chip: Fabricating Reservoir Micromodels by in Situ Growing Calcium Carbonate Nanocrystals in Microfluidic Channels

Wang

Chang

Gizzatov

2017

ACS Appl. Mater. Interfaces

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“…They stated that carbonate reservoir rocks analyzed in their study were generally ranged from slightly water-wet to slightly oil-wet. Okasha et al [57] found that the results of the Amott and USBM methods were similar indicating that the Arab-D carbonate reservoir was slightly oil-wet. In another study, Al-Attar et al [58] evaluated the Bu Hasa reservoir by measuring the contact angle by image analysis and showed the reservoir had slightly water-wet responses.…”

Section: Introductionmentioning

confidence: 97%

Wettability of Carbonate Reservoir Rocks: A Comparative Analysis

et al. 2021

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Various methods have been proposed for the evaluation of reservoir rock wettability. Among them, Amott–Harvey and USBM are the most commonly used approaches in industry. Some other methods, such as the Lak and modified Lak indices, the normalized water fractional flow curve, Craig’s triple rules of thumb, and the modified Craig’s second rule are based on relative permeability data. In this study, a set of capillary pressure curves and relative permeability experiments was conducted on 19 core plug samples from a carbonate reservoir to evaluate and compare different quantitative and qualitative wettability indicators. We found that the results of relative permeability-based approaches were consistent with those of Amott–Harvey and USBM methods. We also investigated the relationship between wettability indices and rock quality indicators RQI, FZI, and Winland R35. Results showed that as the rock quality indicators increased, the samples became more oil-wet.

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“…[ 46 ] The descending trend of IFT along with salinity reduction has also been observed in studies of live oil. [ 47–49 ] On the other hand, in a study by Chen et al, in most salts tested, IFT decreased with increasing salinity. [ 50 ]…”

Section: Introductionmentioning

confidence: 97%

Synergistic effect of salt ions and water‐soluble amphiphilic compounds of acidic crude oil on surface and interfacial tension

et al. 2021

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This study investigated the effect of solubility of amphiphilic compounds of acidic crude oil in water on the surface and interfacial tension (IFT) with NaCl, MgCl2, CaCl2, and Na2SO4 salts. Accordingly, distilled water, along with the salts mentioned in zero ionic strength up to 2 mol were put in contact with crude oil to become saturated with amphiphilic compounds. The effects of these compounds were investigated on the properties of contact water by pH, total organic carbon (TOC), FTIR (Fourier transform infrared spectroscopy), water‐air surface tension (ST), and water‐n‐decane IFT tests. The results showed that some of the organic components of crude oil, especially acidic and basic compounds, are present or soluble in water, which have a significant effect on reducing the surface and IFT. The IFT reduction of water‐n‐decane was greater than the water‐air ST system. Also, the observations showed that for both NaCl and Na2SO4 salt water, with increasing ionic strength of water, there was an optimum salinity within the range of 0.1‐0.25 mol/L for both salts with the amount of surface and IFT minimized at this point. In the other two salts, this point was delayed upon elevation of ionic strength and was observed at high salinity. In this case, divalent cations reduce tension rate compared to monovalent cations. Due to solubility of acidic and basic groups in water, pH of salt water illustrates an acidic trend. Results of the FTIR test confirmed solubility of these compounds as well.

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Fifty Years of Wettability Measurements in the Arab-D Carbonate Reservoir

Cited by 11 publications

References 0 publications

Toward Reservoir-on-a-Chip: Fabricating Reservoir Micromodels by in Situ Growing Calcium Carbonate Nanocrystals in Microfluidic Channels

Toward Reservoir-on-a-Chip: Fabricating Reservoir Micromodels by in Situ Growing Calcium Carbonate Nanocrystals in Microfluidic Channels

Wettability of Carbonate Reservoir Rocks: A Comparative Analysis

Synergistic effect of salt ions and water‐soluble amphiphilic compounds of acidic crude oil on surface and interfacial tension

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