Experimental study on the key influencing factors of phase inversion and stability of heavy oil emulsion: Asphaltene, resin and petroleum acid

Pu, Wanfen; He, Meiming; Yang, Xuerui; Li, Rui; Shen, Chao

doi:10.1016/j.fuel.2021.122631

Cited by 51 publications

(24 citation statements)

References 69 publications

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“…With an increase in depth, the formation temperature also increases. It can also be verified from Figure that with an increase in depth, the colloid and asphaltene content is reduced, and the density and viscosity also decrease. , Furthermore, the figure illustrates how temperature/depth controls the degree of biodegradation. Water environment: Some research results show that the Western Sag has the characteristics of vertical flow. When near the surface, the surface water is continuously injected, mixing with formation water. , Other findings suggest that fault and fracture are the direct passage between surface water and groundwater, which results in high oxygen content in the water environment and promotes the growth and reproduction of a large number of aerobic microorganisms .…”

Section: Resultsmentioning

confidence: 64%

“…It can also be verified from Figure 2 that with an increase in depth, the colloid and asphaltene content is reduced, and the density and viscosity also decrease. 45 , 48 Furthermore, the figure illustrates how temperature/depth controls the degree of biodegradation. Water 51 environment: Some research results show that the Western Sag has the characteristics of vertical flow.…”

Section: Resultsmentioning

confidence: 99%

“…Therefore, the root of these formation mechanisms is biodegradation. Most of the heavy oil in the Western Sag has endured biodegradation to varying degrees. , The concentration of saturated hydrocarbons decreases due to biodegradation. This results in an increase in the colloid and asphaltene content, as well as an increase in its density and viscosity.…”

Section: Resultsmentioning

confidence: 99%

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Characterization and Origin Analysis of Heavy Oil in the Western Sag of the Liaohe Basin

Hu²,

Liu³

et al. 2022

ACS Omega

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This article systematically examines the physical characteristics, group composition characteristics, and geochemical characteristics of heavy oil in the Western Sag of the Liaohe Basin. The examination is based on the separation and quantitative analysis of crude oil and rock samples, as well as the analysis of test results from gas chromatography with saturated hydrocarbons and aromatic hydrocarbons. It also analyzes the generation mechanism and main controlling factors of heavy oil. The results show that heavy oil has low wax content (1.8–9.2%), a low freezing point (−19–38 °C), low sulfur content (0.28–0.5%), high colloid and asphaltene content, high density (0.926–1.008 g/cm 3 ), and high viscosity (328–231910 mPa·s). The physical properties of the heavy oil in the same formation decrease from the depression’s edge toward its center and within the same area, and the physical properties in different formations also have an inverse relationship with burial depth. Biodegradation is the main reason for the formation of heavy oil. Based on the biodegradation degree, there are four types of heavy oil: undegraded, weakly degraded, moderately degraded, and severely degraded. The main controlling factors of biodegradation are temperature and the water environment. This study provides a method for studying the genetic mechanism of heavy oil, an approach for discovering similar genetic oil and gas, and a basis for the transformation of heavy oil field development.

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Section: Resultsmentioning

confidence: 64%

Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%

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Characterization and Origin Analysis of Heavy Oil in the Western Sag of the Liaohe Basin

Hu²,

Liu³

et al. 2022

ACS Omega

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“…Naphthenic acids (NAs) are structured with acidic oxygenated functionalities, and their chemical formula is represented as C n H 2n+z O 2 . 22−24 Wanfen Pu 25 confirmed that the presence of petroleum acid does not favor oil−water emulsification. Although petroleum acid possesses an amphiphilic structure as a surface-active substance, the composition of naphthenic acid, fatty acid, and aromatic acid within petroleum acid can influence its hydrophilicity and lipophilicity.…”

Section: Introductionmentioning

confidence: 93%

Analysis of the Contribution of Petroleum Acid Components to the Viscosity of Heavy Oils with High TAN

Liu

et al. 2023

ACS Omega

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The viscosity of heavy oil hinders its cold production, posing a major challenge to its exploitation. The high viscosity of heavy oil can be attributed to the content of asphaltene. However, during the collection of heavy oil samples from various regions in China, we observed that heavy oils with high total acid number (TAN) but low asphaltene content also exhibit relatively high viscosity. Hence, the viscosity mechanism of high-acid crude oil, the influence of petroleum acid on heavy oil viscosity, should be investigated. In this study, Xinjiang Chunfeng heavy oil was selected for analysis, possessing a viscosity of 16,886 mPa•s at 50 °C and a high total acid number (TAN) of 17.72 mg KOH/g. Separation was performed on the deacidified oil and the acid component using an alkali-modified silica gel column. The viscosity changes of the deacidified oil and its blends with varying proportions of the acid component were determined, along with the viscosity changes of the deacidified oil and acid components in a toluene solution. The molecular composition was analyzed using a Fourier transform ion cyclotron resonance mass spectrometer (FT-ICR MS). The findings indicated successful separation of petroleum acid from the heavy oil, the acid component yield being 16.65 wt %. Furthermore, the viscosity of the petroleum acid was significantly higher than that of the deacidified oil. The rate of viscosity change of the acid component in the toluene solvent exceeded that of the deacidified oil, and the viscosity of the deacidified oil notably increased upon the addition of acid. In conjunction with the viscosity data, it was observed that the deacidified oil exhibited the removal of O2 and O4 compounds, resulting in a 43.11% viscosity reduction at 30 °C compared with crude oil. Thus, the monoacid and diacid components considerably affected the viscosity of heavy oil.

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“…The value of the PIP of the COE is closely related to the crude oil physical properties (COPPs). Generally, the higher content of interfacial active components in crude oil, the stronger the emulsifying ability of crude oil, leading to a larger PIP of the COE. ,− At present, the PIP of an COE is usually determined using experiments according to actual production needs. However, there is no universal prediction model for the PIP of a COE that has been published that is applicable to different crude oil–water systems.…”

Section: Introductionmentioning

confidence: 99%

Modeling of the Phase Inversion Point of Crude Oil Emulsion by Characterization of Crude Oil Physical Properties

et al. 2022

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Accurate prediction of the phase inversion point (PIP) of crude oil emulsion (COE) will give important guiding significance to the mixed transportation technology during the crude oil mining process. The influence of water cut of a system on viscosity characteristics of the COE was studied by emulsification experiments with 16 kinds of crude oils having significant differences in physical properties. The results showed that under the condition of low water cut of a system, the crude oils can emulsify all the water to form stable W/O emulsions with apparent viscosities much higher than those of pure crude oils. When the water cut of a system exceeds a certain critical value, the crude oils have no ability to emulsify all water; instead, they are wrapped by a water phase and form unstable O/W emulsions, and their apparent viscosities decrease sharply compared with those of pure crude oils. The critical water cut of a system corresponding to the abrupt change of apparent viscosity of the COE is the PIP of the COE changing from the type of W/O to O/W. Furthermore, the apparent viscosities of stable W/O emulsions decrease with increasing shear rate and temperature and meanwhile increase dramatically with the increasing water cut of a system. The apparent viscosities of unstable O/W emulsions decrease with increasing shear rate, water cut of a system, and temperature and are far lower than those of pure crude oils. Four typical parameters were chose as the representation to describe the crude oil physical properties (COPPs), that is, the content of saturates, the content of aromatics, the content of surfactants, and the crude oil acid number. On the basis of the quantitative description of COPPs, a prediction model for the PIP of the COE was established. The results of model verification showed that the mean relative deviation of prediction results was 2.9%.

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Experimental study on the key influencing factors of phase inversion and stability of heavy oil emulsion: Asphaltene, resin and petroleum acid

Cited by 51 publications

References 69 publications

Characterization and Origin Analysis of Heavy Oil in the Western Sag of the Liaohe Basin

Characterization and Origin Analysis of Heavy Oil in the Western Sag of the Liaohe Basin

Analysis of the Contribution of Petroleum Acid Components to the Viscosity of Heavy Oils with High TAN

Modeling of the Phase Inversion Point of Crude Oil Emulsion by Characterization of Crude Oil Physical Properties

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