Testing the injection of air with methane as a new approach to reduce the cost of cold heavy oil recovery: An experimental analysis to determine optimal application conditions

Basilio, Enoc; Babadagli, Tayfun

doi:10.1016/j.fuel.2019.116954

Cited by 8 publications

(5 citation statements)

References 34 publications

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“…With the gas–liquid ratio increased, the foam seepage resistance increased. Basilio and Babadagli , adopted the idea of injecting flue gas and air and mixing heavy oil to form a foam oil system, which improved the flow property of heavy oil. Meanwhile, the foam in the system increased the displacement pressure and gave the heavy oil a whole viscoelasticity similar to that of foam.…”

Section: Introductionmentioning

confidence: 99%

Application of Flue Gas Foam-Assisted Steam Flooding in Complex and Difficult-to-Produce Heavy Oil Reservoirs

Min,

Zhang

2024

ACS Omega

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In order to study the mechanism of improving recovery efficiency of complex difficult-to-recover heavy oil reservoirs and explain the interaction and migration law of flue gas, foam, and steam, this paper designed the experiment of flue gas influence on heavy oil flow and the experiment of flue gas foam displacement in complex difficult-to-recover heavy oil model. The results show that the flue gas has expansion and an energy enhancement effect. Moreover, the interfacial tension of heavy oil can be reduced, and the higher the CO 2 content in flue gas, the more beneficial it is to reduce the interfacial tension. When there is an interlayer in the reservoir, the gas can form a "puncture" in the interlayer, which provides a channel for the subsequent upward expansion of steam, so that the upper part of the interlayer can be used to expand the steam sweep range. The main mechanism of improving heavy oil recovery with flue gas foam is that the foam regulates fluid mobility and improves the thermal sweep efficiency of steam. In addition, the injected foam can emulsify with heavy oil, reduce the viscosity of heavy oil, and improve the fluidity of heavy oil. Finally, the maximum oil production rate increased from 1.809 to 2.455 g/min, and the recovery rate increased from 44.3 to 68.8%.

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Section: Introductionmentioning

confidence: 99%

Application of Flue Gas Foam-Assisted Steam Flooding in Complex and Difficult-to-Produce Heavy Oil Reservoirs

Min,

Zhang

2024

ACS Omega

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“…Successful commercial heavy oil recovery technologies can be divided into thermal and cold recovery technologies 2 . At present, chemical flooding cold oil recovery technology has attracted wide attentions due to its simple operation, low energy consumption and low cost 3 – 7 . In this process, natural interfacial active ingredients and additional surfactants in heavy oil, will inevitably bring about oil emulsification in water in the formation 8 – 11 .…”

Section: Introductionmentioning

confidence: 99%

Study on the kinetics of formation process of emulsion of heavy oil and its functional group components

Liu,

Sun,

Lun

et al. 2024

Sci Rep

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Enhanced oil recovery (EOR) by in situ formation of oil-in-water emulsion in heavy oil cold production technology has received growing interest from the petroleum industry. We present an experimental study of emulsification of model oils prepared by heavy oil and its functional group compositions dissolved into toluene brought into contact with a surfactant solution. The effects of functional group composition, emulsifier concentration, temperature, pH and stirring speed on the emulsification rate of heavy oil was investigated. A second-order kinetic model characterizing the temporal variation of conductivity during the emulsification has been established. The results show that acidic and amphoteric fractions exhibit higher interfacial activity, larger emulsification rate constant and faster emulsification rate. With the increase of emulsifier concentration, the emulsification rate constant increase to the maximum value at a concentration of 0.05 mol/L before decreasing. Temperature increase benefits the emulsification rate and the activation energy of the emulsification process is 40.28 kJ/mol. Higher pH and stirring speed indicate faster emulsification rate. The heterogeneity of emulsions limits the accuracy of dynamic characterization of the emulsification process and the determination method of emulsification rate has always been controversial. The conductivity method we proposed can effectively evaluates the emulsification kinetics. This paper provides theoretical guidance for an in-depth understanding of the mechanism and application of cold recovery technology for heavy oil.

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“…The foamy oil flow stage of superheavy oil reservoir is considered as the stage of oil production with the long gas dispersion time and the large bubble quantities. Second, the main factors affecting the generation of foamy oil, such as heavy oil components, gas-oil ratio, viscosity, pressure and temperature, etc., have been researched (Abusahmin et al, 2017;Zhou et al, 2017c;Basilio and Babadagli, 2020;Jia et al, 2020). Aldea (1967) devised a sand filling experiment to investigate the impacts of pressure gradient on the mechanism of dissolved gas flooding and ultimate oil recovery to determine the flow characteristics of foamy oil.…”

Section: Introductionmentioning

confidence: 99%

Comparative analysis of different foamy oil flow characteristics and production performances of two similar super-heavy oil reservoirs using microscopic visual physical experiments

Xue,

Jia,

Wang

et al. 2023

Front. Earth Sci.

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Foamy oil flow is a potentially important reason for enhanced oil recovery (EOR) in super-heavy oil reservoirs during depressurized cold production (DCP). M oil reservoir and H oil reservoir located in Venezuela are typical super-heavy oil reservoirs with the foamy oil flow stage, and the properties of two reservoirs are similar. However, the production performances between two reservoirs in the stage foamy oil flow is quite different. In this paper, the novel microscopic visual physical experiments for foamy oil flow have been carried out to determine the flow characteristics of foamy oil and production performance. Three production stages of DCP are divided: stage I (the pressure greater than bubble point pressure), stage II (the pressure ranging from pseudo bubble point pressure to bubble point pressure), and stage III (the pressure lower than pseudo bubble point pressure). Then, the effects of different foamy oil flow characteristics in each production stage on production performances are investigated using comparative analysis method. The results show that the flow characteristics of the oil in the M and H oil reservoirs are both single-phase flow at stage I of DCP and two-phase flow at stage III of DCP. However, a phenomenon of strong foamy oil flow appeared in M oil reservoir while a phenomenon of weak foamy oil flow appeared in H oil reservoir at stage II of DCP. For the production performance, the oil rate, cumulative oil production and cumulative gas production of M oil reservoir increased obviously, while which of H oil reservoir increased slowly. The reason for the difference between the two oil reservoirs is that the super-heavy oil of M oil reservoir has more dissolved GOR and asphaltene content compared to H oil reservoir, and the pressure and temperature of M oil reservoir are more suitable for strong foamy oil flow.

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Testing the injection of air with methane as a new approach to reduce the cost of cold heavy oil recovery: An experimental analysis to determine optimal application conditions

Cited by 8 publications

References 34 publications

Application of Flue Gas Foam-Assisted Steam Flooding in Complex and Difficult-to-Produce Heavy Oil Reservoirs

Application of Flue Gas Foam-Assisted Steam Flooding in Complex and Difficult-to-Produce Heavy Oil Reservoirs

Study on the kinetics of formation process of emulsion of heavy oil and its functional group components

Comparative analysis of different foamy oil flow characteristics and production performances of two similar super-heavy oil reservoirs using microscopic visual physical experiments

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