Optimized Surfactant IFT and Polymer Viscosity for Surfactant-Polymer Flooding in Heterogeneous Formations

Wang, Yefei; Zhao, Fulin; Bai, Baojun

doi:10.2523/127391-ms

Cited by 18 publications

(21 citation statements)

References 13 publications

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“…Highest oil recovery can be achieved under optimum IFT and not under the lowest IFT of the binary system. However, this concept (Wang et al 2010) is based on light oil reservoir with high permeability and low temperature. Dagang Oilfield is a reservoir with mediumlow permeability characterized by high temperature, significant heterogeneity, and high brine salinity.…”

mentioning

confidence: 99%

Effect of viscosity and interfacial tension of surfactant–polymer flooding on oil recovery in high-temperature and high-salinity reservoirs

Yue

Cheng³

et al. 2013

J Petrol Explor Prod Technol

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This study aims to analyze the influence of viscosity and interfacial tension (IFT) on oil displacement efficiency in heterogeneous reservoirs. Measurement of changes in polymer viscosity and IFT indicates that viscosity is influenced by brine salinity and shearing of pore media and that IFT is influenced by salinity and the interaction between the polymer and surfactant. High concentrations (2,500 and 3,000 mg/L) of polymer GLP-85 are utilized to reduce the effect of salinity and maintain high viscosity (24 mPa s) in formation water. After shearing of pore media, polymer viscosity is still high (17 mPaÁs). The same polymer viscosity (17 mPaÁs) is utilized to displace oil, whose viscosity is 68 mPaÁs, at high temperature and high pressure. The IFTs between surfactant DWS of 0.2 % in the reservoir water of different salinities and crude oil droplet are all below 10 -2 mN/m, with only a slight difference. Surfactant DWS exhibits good salt tolerance. In the surfactant-polymer (SP) system, the polymer solution prolongs the time to reach ultra-low IFT. However, the surfactant only has a slight effect on the viscosity of the SP system. SP slugs are injected after water flooding in the heterogeneous core flooding experiments. Recovery is improved by 4.93-21.02 % of the original oil in place. Furthermore, the core flooding experiments show that the pole of lowering the mobility ratio is more significant than decreasing the IFT of the displacing agent; both of them must be optimized by considering the injectivity of the polymer molecular, emulsification of oil, and the economic cost. This study provides technical support in selecting and optimizing SP systems for chemical flooding.

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confidence: 99%

Effect of viscosity and interfacial tension of surfactant–polymer flooding on oil recovery in high-temperature and high-salinity reservoirs

Yue

Cheng³

et al. 2013

J Petrol Explor Prod Technol

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“…studied the rheological characteristics of ternary multisystem in porous media through the laboratory experiment [4]; There are researches on solution of partially hydrolyzed polyacrylamide passed through the core, the viscosity of produced fluid at different time and pressure difference of polymer solution passing through core [5]. There are also a lot of researches, through the core experiment, analyzed the actual viscosity and viscosity loss factor of polymer solution in porous media in polymer flooding [6][7]. Although there is the study on surfactant adsorption of chemical flooding [8] and the study on interfacial tension of surfactant [9], but study on changing patterns of interfacial tension and adsorption properties of binary multisystem in porous media is less [10].…”

Section: Introductionmentioning

confidence: 99%

Study on Variation of Physicochemical Parameters of the Polymer/Surfactant Binary Multisystem in Porous Media

Liu

Dong

Yang

2018

IOP Conf. Ser.: Earth Environ. Sci.

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Abstract. The sulfonate Gemini surfactant and hydrophobic associating polymers were prepared with different ratio in multisystem, and we measured viscosity and interfacial tension of the solution before pour it into the core. The multisystem with different ratio was poured into the core, we measured the produced liquid viscosity, interfacial tension, the concentration of polymer and surfactant at core outlet with different injection stage and at different locations after stable, calculated the dynamic adsorption capacity of the binary multisystem, and measured the static adsorption capacity of binary multisystem with different ratio on natural oil sand in Suizhong 36-1 Oilfield. Experimental results show that the stable viscosity of the produced liquid of multisystem increased with increase of polymer concentration, and decreased with the increase of the distance flowed through the core, and these changes concentrated on the first 1/3 of core; the interfacial tension decreased with the increase of mass fraction of surfactant, the stable interfacial tension value after passed through the core was about 7-10 times before solution injected; Multisystem has the chromatographic fractionation in rock.

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“…It will result in the reservoir damage, difficulty demulsification, and the reduction of the ASP system viscosity [10]. As a new flooding method, the SP system without alkali can solve the above problems [11]. As the system is free of alkali, it can play the viscoelasticity of polymers to the maximum degree and erase the corrosion and scaling caused by alkali.…”

Section: Introductionmentioning

confidence: 99%

Main Controlling Factor of Polymer-Surfactant Flooding to Improve Recovery in Heterogeneous Reservoir

Yin

Zhao

2017

Advances in Materials Science and Engineering

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This study aims to analyze the influence of viscosity and interfacial tension (IFT) on the recovery in heterogeneous reservoir and determines the main controlling factors of the polymer-surfactant (SP) flooding. The influence of the salinity and shearing action on the polymer viscosity and effects of the surfactant concentration on the IFT and emulsion behavior between chemical agent and oil were studied through the static and flooding experiments. The results show that increasing the concentration of polymer GF-11 (HPAM) can reduce the influence of the salinity and GF-11 has high shear-resistance property. In the condition of the Jilin Oilfield, the oil/water IFT can reach 10 −3 mN/m when the surfactant concentration is 0.3 wt%. The lower the IFT is, the easier the emulsion of SP and oil is formed. Seven flooding experiments are conducted with the SP system. The results show that the recovery can be improved for 5.02%-15.98% under the synergistic effect of the polymer and surfactant. In the heterogeneous reservoir, the contribution of oil recovery is less than that of the sweep volume.

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Optimized Surfactant IFT and Polymer Viscosity for Surfactant-Polymer Flooding in Heterogeneous Formations

Cited by 18 publications

References 13 publications

Effect of viscosity and interfacial tension of surfactant–polymer flooding on oil recovery in high-temperature and high-salinity reservoirs

Effect of viscosity and interfacial tension of surfactant–polymer flooding on oil recovery in high-temperature and high-salinity reservoirs

Study on Variation of Physicochemical Parameters of the Polymer/Surfactant Binary Multisystem in Porous Media

Main Controlling Factor of Polymer-Surfactant Flooding to Improve Recovery in Heterogeneous Reservoir

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