Effect of pressure, temperature, and mass fraction of CO<sub>2</sub> on the stability of the asphaltene constituents in crude oil

Wang, Zhengku; Xu, Jianian; Liu, Hongli; Hou, Jiadan; Zhang, Yu

doi:10.1080/10916466.2017.1384838

Cited by 11 publications

(5 citation statements)

References 20 publications

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“…Also, using this technique, phase boundaries are identified and compared to the data obtained in the bulk fluid. Several authors have used microscopy analysis to propose aggregation and redissolution mechanisms of asphaltenes in reservoir fluids. − Mohammadi et al have shown that aggregation and asphaltene precipitation kinetics depend upon crude oil solvency for asphaltenes, reporting a slight increment of asphaltene aggregates and rapid redissolution for stable oils . The same approach has been used for the study of asphaltene precipitation mechanisms on live crude oils .…”

Section: Introductionmentioning

confidence: 99%

Phase Behavior for Crude Oil and Methane Mixtures: Crude Oil Property Comparison

et al. 2019

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A wide variation in composition and thermodynamic properties is expected for different reservoir fluids, from the simplest one containing only methane and light compounds to those with high compositional complexity. In this work, phase behavior of six different reservoir fluids recombined with methane was compared and contrasted. From our past work (Experimental Study of the Phase Behavior of Methane and Crude Oil MixturesRomero YanesJ. F.FeitosaF. X.FlemingF. P.de Sant’AnaH. B. Romero Yanes, J. F. Feitosa, F. X. Fleming, F. P. de Sant’Ana, H. B. Fuel2019255115850), a low asphaltene crude oil [28.0° American Petroleum Institute (API) gravity, 0.68 wt % n-C7 asphaltenes], referred to here as BRO, has presented a complex phase behavior when mixed with methane, especially when the methane content is around 75.0 mol %. On the basis of these results, the phase behavior of six different crude oils mixed with 75.0 mol % methane was studied in this work. The main characteristics of samples can be summarized as follows: a light condensate fluid (P1, 44.0° API gravity, and no detected n-C7 asphaltenes), three medium crude oils [(P2, 30.8° API gravity, and 0.09 wt % n-C7 asphaltenes), (P3, 26.0° API gravity, and 0.54 wt % n-C7 asphaltenes), and (P4, 25.1° API gravity, and 0.12 wt % n-C7 asphaltenes)], and two heavier crude oils [(P5, 19.5° API gravity, and 2.69 wt % n-C7 asphaltenes) and (P6, 18.7° API gravity, and 2.09 wt % n-C7 asphaltenes)]. From these fluids, mixtures with methane were prepared and their phase behavior was evaluated using a constant composition expansion test, coupled with a near-infrared solid detection system and high-pressure microscopy. For P1 and P4 systems, a unique phase transition at the bubble point was detected. On the other hand, for P2 and P3 systems, non-typical multiphase equilibria were observed associated with asphaltene precipitation, similar to that described for the BRO mixture. Phase segregation with no fractal geometry was observed from the phase transition onset pressure to the bubble pressure for P2, BRO, and P3 crude oils. Additionally, BRO and P3 show minor aggregation at pressures above the bubble pressure, with rapid redissolution when gas evolves at saturation pressures. P5 and P6 systems have phase transitions at a higher pressure because of their high asphaltene content. Phase transitions and related characteristics were associated with crude oil solvency for heavy compounds and their stability.

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Section: Introductionmentioning

confidence: 99%

Phase Behavior for Crude Oil and Methane Mixtures: Crude Oil Property Comparison

et al. 2019

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“…During CO 2 flooding, with the increase in concentration of CO 2 in crude oil, the surface of the asphaltene molecule can be gradually occupied by a large number of CO 2 with a small molecular size, so that the content of colloid solvents on asphaltene molecules is gradually decreased, and the stability of the asphaltene micelle is destroyed, leading to the precipitation of the asphaltene. 31 Asphaltene precipitation may cause produced crude oil to be deasphalted, becoming lighter and less viscous in comparison with the original crude oil. In addition, asphaltene deposition on the rock surface may cause reservoir plugging and wettability alteration, which might eventually lead to a reduction of enhanced oil recovery performance.…”

Section: Resultsmentioning

confidence: 99%

“…It is well-known that the CO 2 injected into the heavy oil destabilizes the asphaltenes, which precipitate out of the oil. During CO 2 flooding, with the increase in concentration of CO 2 in crude oil, the surface of the asphaltene molecule can be gradually occupied by a large number of CO 2 with a small molecular size, so that the content of colloid solvents on asphaltene molecules is gradually decreased, and the stability of the asphaltene micelle is destroyed, leading to the precipitation of the asphaltene . Asphaltene precipitation may cause produced crude oil to be deasphalted, becoming lighter and less viscous in comparison with the original crude oil.…”

Section: Resultsmentioning

confidence: 99%

Evolution of the Properties and Composition of Heavy Oil by Injecting Dry Boiler Flue Gas

Dong

Wang

et al. 2021

ACS Omega

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As the increasing pressure to carbon peak and carbon neutral has brought carbon capture and storage (CCS) to the forefront as an emission mitigation tool, greater attention is being paid to the potential for injecting dry boiler flue gas (DBFG) into oil reservoirs. With the aim to directly inject DBFG with steam into heavy oil reservoirs, this study presents the results of a laboratory investigation of the effect of DBFG on the properties and composition of heavy oil by viscosity measurement, pressure–volume–temperature measurement, high-temperature and high-pressure experiment, and high-resolution mass spectrometry analysis. The results of the experiments show that adding 0.5 wt % particulate matter has no obvious influence on the viscosity of heavy oil. DBFG dissolved in heavy oil can reduce viscosity, increase the flow capability, and make the heavy oil volume swell. Heavy oil is oxidized with DBFG at 140 °C, which is mainly caused by the O 2 in the DBFG, and the oxidation product is alcohol. The findings of the beneficial effect of DBFG on viscosity and swelling factor and the negligible negative effect of the small amount of nitrogen oxides, sulfides, and particulate matter in DBFG are very encouraging. It is expected that DBFG can be directly injected into heavy oil, not only for enhanced oil recovery (EOR) but also for reducing the emissions of greenhouse gases and pollutants, as well as for saving costs.

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“…Direct analysis and use of these data are the basis for monitoring and ensuring normal crude oil production. Regarding the stability of the colloidal oil system, oil chemistry, pressure, and temperature are the main influencing factors. ,,, With the aid of the control valve, the drawdown pressure can be controlled, although distinguishing between the saturated gas solubility under reservoir conditions and gas production data is an imperative task.…”

Section: Introductionmentioning

confidence: 99%

Forecasting Asphaltene Deposition Zones at High Temperature and High Pressure via Bubble Point Pressure Analysis

Xiong,

Guo,

Kiyingi

et al. 2023

Ind. Eng. Chem. Res.

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A fast and reliable method to predict the zones of asphaltene deposition in oilfield wells is proposed. The study reveals that the critical colloidal instability index of crude oil during the production process increases, causing the crude oil colloidal system to be more prone to instability. The standing and Glaso models were used to identify the dissolved gas−oil ratio in order to predict the location of asphaltene deposition. Results show that the expected priority plugging removal region predicted by the model agrees with the actual plugging position observed in the field. The proposed model can guide the design of oil field plugging removal technology and chemical dosage.

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Effect of pressure, temperature, and mass fraction of CO₂ on the stability of the asphaltene constituents in crude oil

Cited by 11 publications

References 20 publications

Phase Behavior for Crude Oil and Methane Mixtures: Crude Oil Property Comparison

Phase Behavior for Crude Oil and Methane Mixtures: Crude Oil Property Comparison

Evolution of the Properties and Composition of Heavy Oil by Injecting Dry Boiler Flue Gas

Forecasting Asphaltene Deposition Zones at High Temperature and High Pressure via Bubble Point Pressure Analysis

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Effect of pressure, temperature, and mass fraction of CO2 on the stability of the asphaltene constituents in crude oil

Cited by 11 publications

References 20 publications

Phase Behavior for Crude Oil and Methane Mixtures: Crude Oil Property Comparison

Phase Behavior for Crude Oil and Methane Mixtures: Crude Oil Property Comparison

Evolution of the Properties and Composition of Heavy Oil by Injecting Dry Boiler Flue Gas

Forecasting Asphaltene Deposition Zones at High Temperature and High Pressure via Bubble Point Pressure Analysis

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Effect of pressure, temperature, and mass fraction of CO₂ on the stability of the asphaltene constituents in crude oil