Development of a New High-Temperature-Resistant Plugging Agent for Heavy Oil Recovery by Steam Flooding of Resevoirs

Sun, Qiji; Wang, Chunsheng; Dong, Biao

doi:10.1007/s10553-016-0730-1

Cited by 3 publications

(1 citation statement)

References 8 publications

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“…The results show that the higher the degree of reservoir heterogeneity, the higher the viscosity ratio of the optimal displacement fluid to reservoir fluid required for profile adjustment [21][22][23]. When the viscosity ratio of polymer system to underground crude oil reaches 3.0 or more, the polymer system has a stronger ability to expand the swept volume and improve the oil displacement efficiency [24][25][26].…”

Section: Introductionmentioning

confidence: 99%

Experimental Study on Optimization of Polymer Preslug Viscosity of ASP Flooding in Interlayer Heterogeneous Well Group Artificial Sandstone Core

Sun

Ke-sen

et al. 2021

Geofluids

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An artificial sandstone core model of large well group of positive rhythmic heterogeneous reservoir was designed and made for the simulation of ASP flooding experiment in the moderate heterogeneous reservoir. The well layout of one injection and one production was employed for the core model, to simulate the influence of polymer preslugs with different viscosity on ASP flooding effect. The experimental results show that the injectability of the polymer preslug and the effect of relieving the conflict of remaining oil production in each layer are related to the viscosity of the system. In the heterogeneous core model with the coefficient of variation of 0.65, under the constraint of the same amount of polymer agent, the ASP flooding effect of the 0.075 PV, 60 mPa·s polymer preslug was better than that of the 0.093 PV, 40 mPa·s and 0.064 PV, 80 mPa·s polymer preslugs. The change in the viscosity of the polymer preslug did not enable the ASP system to effectively exploit the low-permeability layer though. As the viscosity increased, the pressure difference between injection and production increased; the remaining oil could be exploited effectively at the bottom of the high-permeability layer and the medium-permeability layer as well as the injection end of the medium-permeability layer. If the viscosity is too small, the high-permeability area cannot be effectively blocked by the injected chemical agent, and if the viscosity is too large, the injected chemical agent cannot produce good elastic displacement relationship, which will lead to ineffective chemical agent flow. Therefore, the polymer preslug viscosity of the ASP flooding system should be moderate, and cores with different heterogeneity should have a reasonable viscosity matching range.

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Section: Introductionmentioning

confidence: 99%

Experimental Study on Optimization of Polymer Preslug Viscosity of ASP Flooding in Interlayer Heterogeneous Well Group Artificial Sandstone Core

Sun

Ke-sen

et al. 2021

Geofluids

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High-temperature resistant drilling fluid of Sodium-based rectorite modified by organic laponite

et al. 2023

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Preparation and Evaluation of Thermo- and Salinity-Responsive Hydrogel as Intelligent Plugging Agent

Xue

Wang

Zhang

et al. 2017

Day 3 Wed, April 05, 2017

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The swellable hydrogel particles have been developed as effective plugging agents. However, the harsh conditions would significantly detract the performance of conventional plugging agents. To address the problem, an amphoteric hydrogel (IHPA) modified by zwitterionic groups was successfully developed, which presented distinctive thermo- and salt-responsiveness. Environment Scanning Electron Microscopy (ESEM) images of swollen IHPA showed its multiporous structure contributing to its water absorptivity. The water absorption and swelling capacity of IHPA were systematically studied at various temperatures using water and different salines. The sudden increase of the swelling capacity of the hydrogels upon temperature and/or salinity, caused by the alteration of zwitterionic self-association, promised them as intelligent plugging agents. The plugging simulating tests indicated that IHPA possessed excellent plugging performance at 80°C with a plugging efficiency of 93.8% compared with the efficiency of only 33.3% at 20°C

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Development of a New High-Temperature-Resistant Plugging Agent for Heavy Oil Recovery by Steam Flooding of Resevoirs

Cited by 3 publications

References 8 publications

Experimental Study on Optimization of Polymer Preslug Viscosity of ASP Flooding in Interlayer Heterogeneous Well Group Artificial Sandstone Core

Experimental Study on Optimization of Polymer Preslug Viscosity of ASP Flooding in Interlayer Heterogeneous Well Group Artificial Sandstone Core

High-temperature resistant drilling fluid of Sodium-based rectorite modified by organic laponite

Preparation and Evaluation of Thermo- and Salinity-Responsive Hydrogel as Intelligent Plugging Agent

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