The role of matching relationship between polymer injection parameters and reservoirs in enhanced oil recovery

Wang, Zhihua; Le, Xinpeng; Feng, Yaoguo; Zhang, Chengxin

doi:10.1016/j.petrol.2013.07.011

Cited by 37 publications

(25 citation statements)

References 11 publications

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“…The evaluation of the adsorption and retention behavior, which are related to a successful polymer flooding project from both perspectives of technical and economic feasibility, is essential. These results are in agreement with previous studies regarding the effect of polymer adsorption on permeability reduction in EOR [23,[38][39][40].…”

Section: Adsorption Behavior Under Various Polymer Injection Parameterssupporting

confidence: 93%

“…The result is also in agreement with the aforementioned RRF measured results and indicates that formation damage, primarily from polymer adsorption, cannot be ignored in polymer EOR of type II reservoirs. The identification and partition of the blockage risk will help to select the best plan to obtain the highest oil recovery in a type II reservoir system, and this was not involved in the similar work which targeted type I reservoirs reported by Wang et al [23]. select the best plan to obtain the highest oil recovery in a type II reservoir system, and this was not involved in the similar work which targeted type I reservoirs reported by Wang et al [23].…”

Section: Injection Performance Evaluation Of Various Polymer Solutionsmentioning

confidence: 99%

“…The identification and partition of the blockage risk will help to select the best plan to obtain the highest oil recovery in a type II reservoir system, and this was not involved in the similar work which targeted type I reservoirs reported by Wang et al [23]. select the best plan to obtain the highest oil recovery in a type II reservoir system, and this was not involved in the similar work which targeted type I reservoirs reported by Wang et al [23]. Flow rate (10 Flow rate (10 Relative permeability data are essential petrophysical data required for characterization of multiphase flow and polymer adsorption in type II reservoirs.…”

Section: Injection Performance Evaluation Of Various Polymer Solutionsmentioning

confidence: 99%

“…This indicates that the injection performance of the polymer solution is still strongly related to the matching relationship between the polymer concentration and permeability in two-phase flow of type II reservoirs and reveals the permeability level and polymer properties would produce evident differences in two-phase flow behavior. select the best plan to obtain the highest oil recovery in a type II reservoir system, and this was not involved in the similar work which targeted type I reservoirs reported by Wang et al [23]. Flow rate (10 Flow rate (10 Relative permeability data are essential petrophysical data required for characterization of multiphase flow and polymer adsorption in type II reservoirs.…”

Section: Injection Performance Evaluation Of Various Polymer Solutionsmentioning

confidence: 99%

“…Several experimental studies have investigated the resulting effect of polymer adsorption during polymer flooding [19][20][21][22]. The previous study carried out by Wang et al [23] identified the polymer injection ability on type I reservoirs with different water-wash degree, and the feasibility of reducing residual oil after water flooding in strong water-wash degree reservoirs by polymer solutions with high molecular weight and high concentration was evaluated. However, the residual resistance measurements were merely operated in single-phase flow and whether the adsorption behavior could be alleviated with the existence of oil was not mentioned in their work, and the results were not validated by the field data as well.…”

Section: Introductionmentioning

confidence: 99%

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The Performance of Polymer Flooding in Heterogeneous Type II Reservoirs—An Experimental and Field Investigation

Zhong

Zhang

et al. 2017

Energies

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Abstract:The polymer flooding process has already been applied to the medium permeability type II reservoirs of the Daqing Oilfield (China) to enhance oil recovery. However, this process faces a number of challenges, such as the flooding efficiency, high injection pressure, formation blockage and damage, unbalanced absorption ratio, and economical justification. In this study, single-phase and two-phase flow experiments are performed to investigate polymer injection adaptability with natural cores of type II reservoirs. The enhanced oil recovery (EOR) effects of the polymer are studied by physical simulation experiments, and the results of application in an actual field are also presented. The results indicate that the flow characteristics and injection capability are dominated by the reservoir permeability in polymer flooding. Moreover, the adsorption of polymer molecules and the injection pressure gradient, which reflect formation damage, are affected more significantly by the concentration than by the molecular weight in type II reservoirs. Using the matching relationship, the injection-production process is stable, and additional oil recoveries of 10%-15% can be obtained in heterogeneous type II reservoirs with a high water saturation. This work is significant in that it further accelerates the application of polymer flooding EOR in medium permeability heterogeneous oilfields with high water saturation.

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Section: Adsorption Behavior Under Various Polymer Injection Parameterssupporting

confidence: 93%

Section: Injection Performance Evaluation Of Various Polymer Solutionsmentioning

confidence: 99%

Section: Injection Performance Evaluation Of Various Polymer Solutionsmentioning

confidence: 99%

Section: Injection Performance Evaluation Of Various Polymer Solutionsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 3 more Smart Citations

The Performance of Polymer Flooding in Heterogeneous Type II Reservoirs—An Experimental and Field Investigation

Zhong

Zhang

et al. 2017

Energies

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Static adsorption and dynamic retention of an anti‐salinity polymer in low permeability sandstone core

Wei

et al. 2016

J of Applied Polymer Sci

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The technical viability of enhancing oil recovery (EOR) using polymer flooding has been verified. Through correcting the unfavorable mobility ratio, polymer flooding could significantly improve the macroscopic sweep efficiency of waterflooding, which makes it attractive in middle to high permeability reservoirs. However, as the depletion of these easy-to-produce resources, the interests of oil industry will be diverted to low permeability reservoirs and polymer flooding is believed to be one of the key methods for this type of reservoir. To meet this technological tendency, the current work investigated the applicability of an anti-salinity polymer (KYPAM) in low permeability sandstone reservoirs. The interactions between polymer and sandstone surface including static adsorption and dynamic retention were addressed. Static adsorption data proved that the adsorptive behavior of this anti-salinity polymer was closely related to molecular weight and concentration. The quantity of the detained KYPAM polymer in the sandstone core rapidly increased once the permeability dropped below 38 mD. High molecular weight KYPAM experienced noticeable retention compared with low molecular weight polymers resulting from the large hydrodynamic size. Due to polymer retention, the permeability of the sandstone core was significantly influenced particularly for the low permeability cores.

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Effects of residual resistance factor in the mobility control of the polymer flooding

Cao

Zhu

Zheng

et al. 2022

J of Applied Polymer Sci

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To broaden the application of the polymer flooding in complex reservoirs, the residual resistance factor (RRF) is sought to make up for the limitations of high‐viscosity polymer flooding. First, the polymer solution rheology, adsorption and retention behaviors were mathematically characterized, and subsequently substituted into the equation of motion of the aqueous phase to build a mathematical model of the polymer flooding percolation. Second, based on the built numerical model, the formation process of seepage resistance and pressure propagation characteristics of polymers with a high RRF in the porous media were investigated. Lastly, the effects arising from viscosity and RRF on the flow control of the polymer flooding were explored by comparing the injection capacity, crude oil utilization and profile control capacity of different permeable formations at different development stages. As revealed by the results, the RRF was found to be more favorable than the “viscosity” parameter in improving the injection capacity at the polymer flooding stage. Moreover, it was found to slow down the water‐cut increase at the subsequent water flooding stage and reduce the difference between the oil recovery rate and injection pressure at different stages. Furthermore, the viscosity was primarily adopted to facilitate oil recovery of medium and high‐permeability formations by increasing the oil replacement efficiency, while the RRF was primarily dependent on the regulation of interlayer water absorption differences, thus mobilizing the remaining oil under the low‐permeability formations.

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The role of matching relationship between polymer injection parameters and reservoirs in enhanced oil recovery

Cited by 37 publications

References 11 publications

The Performance of Polymer Flooding in Heterogeneous Type II Reservoirs—An Experimental and Field Investigation

The Performance of Polymer Flooding in Heterogeneous Type II Reservoirs—An Experimental and Field Investigation

Static adsorption and dynamic retention of an anti‐salinity polymer in low permeability sandstone core

Effects of residual resistance factor in the mobility control of the polymer flooding

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