Thermal enhanced oil recovery in deep heavy oil carbonates: Experimental and numerical study on a hot water injection performance

Askarova, Aysylu; Turakhanov, Aman; Markovic, Strahinja; Popov, Evgeny; Maksakov, Kirill; Usachev, G.A.; Karpov, Valery Borisovich

doi:10.1016/j.petrol.2020.107456

Cited by 54 publications

(18 citation statements)

References 25 publications

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“…Pada kajiannya didapatkan nilai temperatur optimum injeksi [11]. Studi ekperimental dan komputasi dinamika fluida (CFD) pada proses termal EOR dilakukan oleh Askarova et al Pada hasil studinya didapatkan bahwa solusi numerik dapat melakukan validasi dan kajian parametrik untuk kasus fenomena termal-EOR [12]. Wu Sunghong dalam kajiannya menyatakan proses steam-flood yang sukses pada reservoir dengan karakter permabilitas rendah dan minyak ringan.…”

Section: Latar Belakangunclassified

Simulasi aliran dua fase pada campuran air-minyak di pipa horizontal dengan parameter termal

Jalaali¹,

Kumolosari²

2021

Angkasa

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A CFD study of Water-Oil flow in the horizontal pipe was conducted using the Volume-of-Fluid (VoF) multiphase model coupled with the SST turbulence model scheme. This study aimed to simulate the mixture flow characteristic by takes account temperature parameter. It was numerically solved using a finite-volume model utilized in Fluent software. The simulation results compared towards experimental showed good prediction on the particular flow pattern. In this study, the thermal parameter was then solved by utilizing energy equation coupled by multiphase model. The water flow temperatures were varied in ranged of 300-340K. The results showed that temperature affected reducing the viscosity of the fluid as well as the density. Furthermore, the flow pattern changed whereby oil was above the water due to its lower viscosity and density. This study is beneficial for accessing the temperature effect on the water-oil flow as represented in the applied petroleum industry of oil-lifting.

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Section: Latar Belakangunclassified

Simulasi aliran dua fase pada campuran air-minyak di pipa horizontal dengan parameter termal

Jalaali¹,

Kumolosari²

2021

Angkasa

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“…At present, the recovery methods for heavy oil primarily include steam driving and oil layer burning (Pang et al, 2018;Strelets and Ilyin, 2021). Burning oil layer is the first thermal oil recovery technology used to develop heavy oil (Askarova et al, 2020). Compared with other heavy oil development technologies, this method has unique hightemperature operation characteristics.…”

Section: Introductionmentioning

confidence: 99%

Effect of CO2 on the Hydration of Aluminate Cement Under Conditions of Burning Reservoir in Heavy Oil Thermal Recovery

Wu¹,

Wu²,

Xing³

et al. 2022

Front. Mater.

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Under conditions of heavy oil thermal recovery, cement sheaths often suffer high-temperature performance degradation and CO2 corrosion. The performance of Class G oil well cement commonly used for cementing, deteriorates significantly at high temperatures and in CO2 environments, which can easily cause accidents. By contrast aluminate cement (CAC), at the same time, has good high-temperature resistance and corrosion resistance. Therefore, this study explored the mechanical properties and permeability of CAC with a high-temperature stabiliser cement slurry system (C1), pure CAC slurry system (C2) and Portland cement with sand cement slurry system (C3) before and after corrosion at 50, 300, 400, 500, and 600°C. The micromorphology, hydration products and pore structure of the cement paste before and after corrosion were analyzed using scanning electron microscopy, X-ray diffraction, thermogravimetry and nitrogen adsorption specific surface area and pore diameter analysis; additionally, the hydration mechanism of CAC under high temperatures and in CO2 environments was explored. The results show that the degree of degradation of the mechanical properties of C1 cement slurry system at high temperatures and under CO2 corrosive environments is significantly lower than that of the C3 cement slurry system. At a curing high temperature of 400°C, the maximum strength of the C1 cement paste reached 36.39 ± 0.37 MPa. The addition of a high-temperature stabiliser improved the mechanical properties of CAC at low temperatures, reduced the formation of C3ASH4 in the cement paste at high temperatures, and improved the strength of the cement paste after high-temperature curing. Compared with the C3 cement slurry system, the C1 cement slurry system had better high-temperature resistance and corrosion resistance and was more suitable for application under conditions of a burning reservoir in heavy oil thermal recovery.

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“…Hence, water flooding is more suitable for light or less viscous oil flooding than for heavy oil. In order to recover more heavy oil after conventional water flooding, different enhanced oil recovery (EOR) techniques including thermal oil recovery techniques and nonthermal techniques have been investigated [6][7][8][9][10][11]. The EOR processes focus on the reduction of oil viscosity or improvement of injection water viscosity, which can improve the mobility ratio of injection water and crude oil and enlarge sweep efficiency.…”

Section: Introductionmentioning

confidence: 99%

Insights into Enhanced Oil Recovery by Polymer-Viscosity Reducing Surfactant Combination Flooding in Conventional Heavy Oil Reservoir

Chen

et al. 2021

Geofluids

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Polymer flooding has a significant potential to enhance oil recovery in a light oil reservoir. However, for polymer flooding in a conventional heavy oil reservoir, due to unfavorable mobility ratio between water and oil, the improvement of sweep efficiency is limited, resulting in a low incremental oil recovery and failure to achieve high-efficiency development for polymer flooding in a conventional heavy oil reservoir. Inspired by the EOR mechanisms of the surfactant-polymer (SP) flooding process, the polymer-viscosity reducing surfactant flooding (P-VRSF) system was proposed to enhance conventional heavy oil recovery. Thus, to gain an insight into enhancing oil recovery by P-VRSF in a conventional heavy oil reservoir, the viscosity property, oil-water interfacial tension property, and oil viscosity reduction property were investigated. A series of parallel sand pack experiments were conducted to investigate enhanced oil recovery ability of polymer flooding and P-VRSF in a heterogeneous reservoir. Then, the 2D micromodel flooding experiments were conducted to investigate the EOR mechanism from porous media to pore level. Results demonstrated that polymer could increase the viscosity of injection water and improve the sweep efficiency. The emulsifying stability of surfactant with ultralow IFT (10-3 mN/m) was worse than that of the surfactant with higher IFT (10-2 mN/m). The viscosity reduction rate of the surfactant with higher IFT was higher than 80% at different oil-water volume ratios. The incremental oi recovery of P-VRSF was higher than that of polymer flooding. Moreover, the polymer-viscosity reducing surfactant with higher IFT could have higher incremental oil recovery. The 2D micromodel flooding results showed that the swept area of polymer flooding and P-VRSF was larger than that of water flooding. Moreover, the swept area of the surfactant with good emulsifying stability was larger than that of the surfactant with ultralow IFT. These findings could provide insights into enhancing oil recovery by P-VRSF in the conventional heavy oil reservoir.

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Thermal enhanced oil recovery in deep heavy oil carbonates: Experimental and numerical study on a hot water injection performance

Cited by 54 publications

References 25 publications

Simulasi aliran dua fase pada campuran air-minyak di pipa horizontal dengan parameter termal

Simulasi aliran dua fase pada campuran air-minyak di pipa horizontal dengan parameter termal

Effect of CO2 on the Hydration of Aluminate Cement Under Conditions of Burning Reservoir in Heavy Oil Thermal Recovery

Insights into Enhanced Oil Recovery by Polymer-Viscosity Reducing Surfactant Combination Flooding in Conventional Heavy Oil Reservoir

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