The Feasibility Studies of Polymer Foam Flooding in Gudao Oilfield

Li, Zhenquan; Zhou, Guohua; Zhou, Zhongze

doi:10.2118/101189-ms

Cited by 18 publications

(15 citation statements)

References 3 publications

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“…Due to the poor stability of conventional foam, polymer is added to improve foam stability [Shen et al, 2006;Li et al, 2006;Kang et al, 2010]. Enhanced foam system is a system by mixing some polymer into foam.…”

Section: Effect Of Oil Viscosity On Enhanced Foam Floodingmentioning

confidence: 99%

“…It can be seen that large amounts of injected gas are needed for the conventional foam flooding. And the same problem also occurred in polymer enhanced nitrogen foam injection for EOR in well group GD2-28-8 of Gudao, Shengli oilfield [Li et al, 2006]. Although the domestic implementations of foam flooding in the filed test are often used liquid alternating with gas injection (LAG) [Li et al, 2006], the problems of high injection pressure occurred frequently.…”

Section: Introductionmentioning

confidence: 98%

“…However, for the conventional foam flooding, the gas/liquid ratio is often required to be larger than 1:1 [Lin et al, 2006;Li et al, 2009]. Although the domestic implementations of foam flooding in the filed test are often used liquid alternating with gas injection (LAG) [Li et al, 2006], the problems of high injection pressure occurred frequently. It can be seen that large amounts of injected gas are needed for the conventional foam flooding.…”

Section: Introductionmentioning

confidence: 99%

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Investigation of Polymer-Enhanced Foam Flooding With Low Gas/Liquid Ratio for Improving Heavy Oil Recovery

Pei

Zhang

et al. 2010

All Days

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Severe viscous fingering during water flooding of heavy oil leaves a large amount of oil untouched in the reservoir. Improving sweep efficiency is vital for increasing heavy oil recovery. Previous researches have proved that foam flooding can increase the sweep efficiency and control gas mobility, and thus increase oil recovery. However, researches on foam flooding were always focusing on the effect of high gas/liquid ratio (The gas/liquid ratio is usually larger than 1:1). Little research was conducted on foam flooding with low gas/liquid ratio. This paper presents the results of a laboratory study of polymer enhanced foam flooding with low gas/liquid ratio for heavy oil in Shengli oilfield. For polymer enhanced foam (PEF), the displacement medium is N 2 mixed with surfactant as foaming agent and HPAM. The experimental investigation evaluated the performance of foaming agent and studied the use of polymer to enhance foam properties. Polymer enhanced foam flooding were performed in cores, sandpacks and 3D physical model to study the factors affecting displacement efficiency such as gas/liquid ratio, injection slug size, and the viscosity of crude oil. The results of sandpack flood tests showed that the tertiary oil recovery of polymer enhanced foam flooding with the gas/liquid ratio of 0.2:1 could reach 39% IOIP for heavy oil with the viscosity of 325mPa·s at 55 , which was 11% higher than the alkali/surfactant/polymer flooding by injecting a 0.3 pore volume (PV) of the same chemical slug. However, the tertiary oil recovery decreased with the increasing viscosity of crude oil. The result obtained in 3D physical simulation indicated that polymer enhanced foam system had excellent profile modification effect to increase sweep area and thus increase oil recovery. The above results demonstrate that polymer enhanced foam flooding with low gas/liquid ratio is a promising economical method for improving heavy oil recovery after water flooding.

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Section: Effect Of Oil Viscosity On Enhanced Foam Floodingmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 98%

Section: Introductionmentioning

confidence: 99%

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Investigation of Polymer-Enhanced Foam Flooding With Low Gas/Liquid Ratio for Improving Heavy Oil Recovery

Pei

Zhang

et al. 2010

All Days

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“…Hou, et al [3] compared three main injection modes, including co-injection of gas and solution, alternative injection of gas and solution, and direct injection of foam and pointed that the direct injection of foam was the most effective mode and the alternative injection of gas and solution is the poorest. Li, et al [4] experimentally studied the use of additives to enhance foam properties and the factors affecting blocking performance such as injection model, gas liquid ratio, and alternate slug, etc. Harsenhorst, et al [5] illustrated with a model fit by Rossen, et al [6] to data of Persoff, et al [7], a fit specifically designed for a hypothetical surfactant-alternating-gas (SAG) application.…”

Section: Introductionmentioning

confidence: 99%

Polymer Foam Flow in Porous Media under Different Injection Modes

Zhao¹,

Cui²,

Wang³

2015

EPE

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The mathematical models of the flow of polymer foam in porous media under three injection modes are established and the relevant numerical calculation methods are given. The profiles of the liquid phase saturation, the pressure drop and the number density of the flowing HPAM foam in artificial sandstone cores with the dimensionless distance under three injection modes are numerically calculated and analyzed. The results show that, compared with the injection mode 2 and 3, HPAM foam flows in a piston-like fashion in the artificial sandstone core under the injection mode 1 and produces the biggest pressure drop. Obviously, the flood efficiency is the highest under the injection mode 1.

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“…It is well-known that foam has been widely used for mobility control in EOR [Rossen, 1995], acid diversion in well stimulation [Gdanski, 1993;Rossen et al, 1999] and recovery of wastes in environmental remediation [Dicksen Tanzil et al, 2000;Mamun et al, 2002]. Because foam is a thermodynamic unstable system and has a limited lifetime, a relatively new method is the addition of polymers to improve foam stability [Li et al, 2006;Shalaby et al, 1991;Ming et al, 2004]. Water soluble polymers can stabilize foam by increasing either the surface or bulk viscosity of the film, thereby increasing the film elasticity and decreasing the film drainage rate [Shen et al, 2006].…”

Section: Introductionmentioning

confidence: 99%

A Novel Ultra-low Interfacial Tension Foam Flooding Agent to Enhance Heavy Oil Recovery

Kang

Meng

et al. 2010

SPE Improved Oil Recovery Symposium

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Foam as a mobility control agent in enhanced oil recovery is becoming more and more attractive. Recently, ASP foam flooding method was proposed, which was based on the mechanism of both lowering interfacial tension to an ultra-low value (10 -3 mN/m grade) and improving sweep efficiency of displacing fluid. However, the alkali (NaOH or Na 2 CO 3 ) in the ASP system will bring about scaling in the reservoir and pipelines if the formation water contains a large number of divalent cations such as Ca 2+ and Mg 2+ . Therefore，it is necessary to develop a non-alkali foam flooding system to improve oil recovery.A novel ultra-low interfacial tension foam agent is developed by the combination of surfactant and additives to lower oil-water interfacial tension and the addition of polymer to improve foam stability. Firstly, the concentration of surfactant and non-alkali additives used as the foam agent was determined by interfacial tension contour diagram. Then, the molecular weight and concentration of HPAM to enhance foam stability in the reservoir was screened. The foamability of the formula was measured using airflow method. Furthermore, the effects of temperature, salinity and shearing on the interfacial property and foamability were investigated to know the adaptability of this method to different oilfields. The heavy oil displacement experiments showed that the final oil recovery could be improved approximately 23% initial-oil-in place over waterflood recovery for the heterogenous core model of which permeability variation coefficient is 0.65, more than that of alkalinesurfactant-polymer flooding.

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The Feasibility Studies of Polymer Foam Flooding in Gudao Oilfield

Cited by 18 publications

References 3 publications

Investigation of Polymer-Enhanced Foam Flooding With Low Gas/Liquid Ratio for Improving Heavy Oil Recovery

Investigation of Polymer-Enhanced Foam Flooding With Low Gas/Liquid Ratio for Improving Heavy Oil Recovery

Polymer Foam Flow in Porous Media under Different Injection Modes

A Novel Ultra-low Interfacial Tension Foam Flooding Agent to Enhance Heavy Oil Recovery

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