CO2 foam flooding for improved oil recovery: Reservoir simulation models and influencing factors

Zhang, Yang; Wang, Yuting; Xue, Fangzheng; Wang, Yanqing; Ren, Bo; Zhang, Liang; Ren, Shaoran

doi:10.1016/j.petrol.2015.04.003

Cited by 77 publications

(23 citation statements)

References 38 publications

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“…However, the development of CO 2 flooding technology in China is relatively lacking, and this method has not been widely used. Most of the Chinese reservoirs in which CO 2 flooding has been implemented are homogeneous and low-permeability sandstone reservoirs, which are relatively simple [1][2][3][4][5][6] . In addition, studies have shown the feasibility of using CO 2 flooding in shale oil reservoirs or in the carbonate reservoirs 7,8 .…”

Section: Influencing Factors and Application Prospects Of Co 2 Floodimentioning

confidence: 99%

Influencing factors and application prospects of CO2 flooding in heterogeneous glutenite reservoirs

Wang

Zhang

Xie

2020

Sci Rep

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Section: Influencing Factors and Application Prospects Of Co 2 Floodimentioning

confidence: 99%

Influencing factors and application prospects of CO2 flooding in heterogeneous glutenite reservoirs

Wang

Zhang

Xie

2020

Sci Rep

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“…Well-known ionic surfactants have been introduced in detail from literature [26,29,[37][38][39][40][41]. Novel CO 2 soluble surfactants include the nonionic exthoxylated alcohols and switchable exthoxylated amines [27,40,[42][43][44][45][46][47][48][49]. The hydrophobic part can be either alkylphenol or branched/unbranched alkyl [45].…”

Section: Introductionmentioning

confidence: 99%

Exergy return on exergy investment analysis of natural-polymer (Guar-Arabic gum) enhanced oil recovery process

Hassan

Ayoub

Eissa

et al. 2019

Energy

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This paper probes the transport of CO 2 soluble surfactant for foaming in porous media. We numerically investigate the effect of surfactant partitioning between the aqueous phase and the gaseous phase on foam transport for subsurface applications when the surfactant is injected in the CO 2 phase. A 2-D reservoir simulation is developed to quantify the effect of surfactant partition coefficient on the displacement conformance and CO 2 sweep efficiency. A texture-implicit local-equilibrium foam model is embedded to describe how the partitioning of surfactant between water and CO 2 affects the CO 2 foam mobility control when surfactant is injected in the CO 2 phase. We conclude that when surfactant has approximately equal affinity to both the CO 2 and the water, the transport of surfactant is in line with the gas propagation and therefore the sweep efficiency is maximized. Too high affinity to water (small partition coefficient) results in surfactant retardation whereas too high affinity to CO 2 (large partition coefficient) leads to weak foam and insufficient mobility reduction. This work sheds light upon the design of water-alternating-gas-plus-surfactant-in-gas (WAG + S) process to improve the conventional foam process with surfactant-alternating-gas (SAG) injection mode during which significant amount of surfactant could possibly drain down by gravity before CO 2 slugs catch up to generate foam in situ the reservoir.

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“…Among the gas EOR methods, CO 2 flooding is the leading EOR technique for light and medium crude oil (Yongmao et al 2004;Gogoi 2013). Notwithstanding the successful application of CO 2 EOR in many laboratory-scale and field-scale tests, CO 2 cannot recover all of the oil in the formation because its low density and viscosity gives rise to a number of mobility and conformance issues (Enick and Olsen 2012;Farajzadeh et al 2012;Talebian et al 2013;Yang Zhang et al 2015). The low density of CO 2 gas relative to oil promotes gravity override, whereas low viscosity results in unfavorable mobility ratio leading to viscous fingering.…”

Section: Introductionmentioning

confidence: 99%

Enhanced oil recovery by alkaline-surfactant-alternated-gas/CO2 flooding

Phukan

Gogoi

Tiwari

2018

J Petrol Explor Prod Technol

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The volumetric sweep efficiencies of CO 2 flooding for enhanced oil recovery (EOR) are generally low due to problems of viscous fingering and gravity override. This paper attempts to study a relatively new and promising method to reduce the mobility of CO 2 flooding and increase oil recovery under reservoir conditions. Referred to as alkaline-surfactant-alternatedgas/CO 2 (ASAG) flooding, this method is essentially the synergic combination of chemical and immiscible CO 2 flooding. In this work, chemical formulations were identified through foam stability tests based on their foaming ability coefficients.The selected formulations were further tested for their capabilities to reduce oil-water interfacial tensions (IFT) to ultra-low value. With the best performing formulations, the laboratory-scale core flooding experiments were conducted to evaluate their EOR potential. The core flooding experiments were performed with sandstone reservoir core samples from two different depths of a major depleted oil field of Upper Assam Basin, India. This study reports the successful application of a natural anionic surfactant (black liquor) as a co-surfactant and foaming agent during ASAG flooding. It was observed that higher oil recovery of 14.26% original oil in place (OOIP) was obtained by surfactant-alternated-gas (SAG) flooding compared to 12.03% OOIP by immiscible CO 2 alternated with brine (WAG) flooding. The highest residual oil recovery of 20% OOIP was obtained for ASAG flooding with the alkali, surfactant and black liquor in the chemical slug. Oil recovery performances during SAG and ASAG flooding were found to be better for core samples with lower porosity-permeability due to stronger foam formation in lower permeability cores.

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CO2 foam flooding for improved oil recovery: Reservoir simulation models and influencing factors

Cited by 77 publications

References 38 publications

Influencing factors and application prospects of CO2 flooding in heterogeneous glutenite reservoirs

Influencing factors and application prospects of CO2 flooding in heterogeneous glutenite reservoirs

Exergy return on exergy investment analysis of natural-polymer (Guar-Arabic gum) enhanced oil recovery process

Enhanced oil recovery by alkaline-surfactant-alternated-gas/CO2 flooding

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