Optimization of polymer flooding design in conglomerate reservoirs

Liu, Zheyu; Li, Yiqiang; Lv, Jitao; Li, Binhui; Chen, Yihang

doi:10.1016/j.petrol.2017.03.010

Cited by 41 publications

(13 citation statements)

References 18 publications

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“…Emulsions aside, there are a plethora of studies worked on various selective plugging agents such as gels, cement and polymers to control water cut in production wells (Bai and Zhang 2011;Breston 1957;Liu et al 2017;Stavland et al 2006;Wang et al 2003). Among these, although emulsion is not capable as much as the others in permeability reduction of formations, it has its unique distinctions (Seright and Liang 1995).…”

Section: Introductionmentioning

confidence: 99%

An experimental investigation on enhancing water flooding performance using oil-in-water emulsions in an Iranian oil reservoir

Sadati

Sahraei

2019

J Petrol Explor Prod Technol

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Emulsions are extensively prevalent in the oil industry in both advantageous and disadvantageous ways. In the literature, conventional water flooding in high permeability oil reservoirs has confronted with water channeling and poor sweep efficiency. In this paper, the remedial application of O/W emulsions as an EOR method in improving water performance is discussed. To this purpose, a series of flooding experiments were carried out in one of the Iranian oil reservoirs in reservoir condition of 75 C and 2000 psi. Then, visual stability measurements were conducted to inspect the stability characterization of the emulsion. Sodium dodecyl sulfate was applied helping simple dispersion of the gasoil into the water phase, and emulsions with water percentage of 90, 80, 70 and 60 were developed to introduce into the porous media. It was found out from flooding experiments that emulsion injection after conventional water flooding can lead to additional oil recovery (up to 20%). Besides, the emulsion with 80% water cut was determined as the optimum emulsion for injection in this reservoir considering financial aspects. Moreover, results of the stability test revealed that the aqueous phase with one wt% surfactant or higher had formed emulsions which have been stable during a long period of 6 months.

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Section: Introductionmentioning

confidence: 99%

An experimental investigation on enhancing water flooding performance using oil-in-water emulsions in an Iranian oil reservoir

Sadati

Sahraei

2019

J Petrol Explor Prod Technol

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“…Polymer flooding improves the water injection profile in heterogeneous reservoirs by reducing the efficiency of fluid viscosity fingering between layers and the permeability contrast in order to enable the relative permeability of water phase greater than that of the oil phase [26]. The study on rheological properties of polymer solution injected into oil layers is an important step to increase displacement efficiency [27].…”

Section: Mathematical Model Of the Polymer Flow In The Different-mmentioning

confidence: 99%

Study Rheological Behavior of Polymer Solution in Different-Medium-Injection-Tools

Huang

et al. 2019

Polymers

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Previous studies showed the difficulty during polymer flooding and the low producing degree for the low permeability layer. To solve the problem, Daqing, the first oil company, puts forward the polymer-separate-layer-injection-technology which separates mass and pressure in a single pipe. This technology mainly increases the control range of injection pressure of fluid by using the annular de-pressure tool, and reasonably distributes the molecular weight of the polymer injected into the thin and poor layers through the shearing of the different-medium-injection-tools. This occurs, in order to take advantage of the shearing thinning property of polymer solution and avoid the energy loss caused by the turbulent flow of polymer solution due to excessive injection rate in different injection tools. Combining rheological property of polymer and local perturbation theory, a rheological model of polymer solution in different-medium-injection-tools is derived and the maximum injection velocity is determined. The ranges of polymer viscosity in different injection tools are mainly determined by the structures of the different injection tools. However, the value of polymer viscosity is mainly determined by the concentration of polymer solution. So, the relation between the molecular weight of polymer and the permeability of layers should be firstly determined, and then the structural parameter combination of the different-medium-injection-tool should be optimized. The results of the study are important for regulating polymer injection parameters in the oilfield which enhances the oil recovery with reduced the cost.

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“…The unique properties of polymer solutions enable their widespread use in enhanced oil recovery (EOR) technology in the field of oil development, especially in oil fields in China. 1,2 This technology exploits the mobility control ability of polymers to offset the adverse water drive development effect in order to further improve the crude oil productivity of water drive development reservoirs. 3,4 In practical application, the performance parameters of polymer solution are the first to be considered.…”

Section: Introductionmentioning

confidence: 99%

Effect of micro‐aggregation behavior on the salt tolerance of polymer solutions

Zhu

Shi

et al. 2020

J of Applied Polymer Sci

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Polymer solution for oil displacement is mostly used in the middle and late stage of water flooding reservoir development, and reservoir groundwater conditions are often one of the main conditions restricting polymer application. Therefore, it is necessary to develop salt tolerance of polymer solutions with different aggregation behaviors, so as to facilitate the synthesis and optimization of suitable polymer systems. The differences in the micro‐aggregation behavior of three polymers with different molecular structures were explored. On this basis, the effects of divalent metal cations on the properties of the polymer solutions were analyzed by assessing the micro‐aggregation behavior, apparent viscosity, hydrodynamic size, and shear rheological characteristics. The results showed that the linear partially hydrolyzed polyacrylamide (HPAM) was seriously affected by divalent cations, and the viscosity decreased obviously. The aggregation behavior of the polymer changed by hydrophobic association can enhance the salt tolerance of the solution. The hydrophobically modified partially hydrolyzed polyacrylamide (HMPAM) with “chain beam” aggregation behavior has strong intermolecular connection, which enables it to withstand the content of calcium and magnesium ions of 1100 mg l−1. When the content of calcium and magnesium ions exceeds 600 mg l−1, dendritic hydrophobically associating polymer (DHAP) will destroy the interaction between molecular chains, resulting in the decrease of apparent viscosity and hydrodynamic size. For polymer flooding in high‐salinity reservoir, salt tolerant polymer system can be constructed by optimizing molecular weight and hydrophobic group content.

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Optimization of polymer flooding design in conglomerate reservoirs

Cited by 41 publications

References 18 publications

An experimental investigation on enhancing water flooding performance using oil-in-water emulsions in an Iranian oil reservoir

An experimental investigation on enhancing water flooding performance using oil-in-water emulsions in an Iranian oil reservoir

Study Rheological Behavior of Polymer Solution in Different-Medium-Injection-Tools

Effect of micro‐aggregation behavior on the salt tolerance of polymer solutions

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