scholarly journals Experimental Research on Profile Control for Oil Displacement by Functional Polymer in Low Permeability Fractured Reservoir

2012 ◽  
Vol 25 ◽  
pp. 1292-1300 ◽  
Author(s):  
Li Li ◽  
Han Xiuting ◽  
Meng Lin
Keyword(s):  
Experimental Research ◽  
Low Permeability ◽  
Fractured Reservoir ◽  
Functional Polymer ◽  
Oil Displacement ◽  
Profile Control

scholarly journals Experimental Research on the Optimization and Evaluation of the Polymer/Chromium-Ion Deep Profile Control System for the Fractured Low-Permeability Reservoirs

Processes ◽  
2020 ◽  
Vol 8 (9) ◽  
pp. 1021
Author(s):  
Daiyin Yin ◽  
Shuang Song ◽  
Qi Xu ◽  
Kai Liu
Keyword(s):  
Molecular Weight ◽  
Control System ◽  
High Molecular Weight ◽  
Low Molecular Weight ◽  
Low Permeability ◽  
Chromium Ion ◽  
Oil Displacement ◽  
Profile Control ◽  
Deep Profile ◽  
Plugging Performance

The matrix/fracture conductivity of a fractured low-permeability reservoir is variable, and its heterogeneity is serious. When carrying out deep profile control measures, it is difficult to inject under the premise of ensuring the plugging effect. According to the characteristics of the fractured low-permeability reservoir in Chaoyanggou Oilfield, the polymer/chromium ion deep profile control system was optimized via a viscosity evaluation experiment, liquidity experiment and oil displacement experiment. The experimental results show that the high molecular weight main agent/low concentration system and low molecular weight main agent/high concentration system can meet the gel strength requirement. The evaluation results of the injection ability and plugging performance of the fractured low-permeability core show that a high molecular weight profile control system is difficult to inject, while a low molecular weight profile control system has a poor plugging performance and high cost after simulated shear. Therefore, the formulation of the profile control system was determined to be a polymer with a molecular weight of 16 million g·mol−1 as the main agent with a concentration of 1000–1500 mg·L−1. As assisting agents, the concentrations of thiourea, NaCl and NaHCO3 were 900 mg·L−1, 800 mg·L−1 and 700 mg·L−1, respectively. The plugging rate of the system was 87.6%, and the resistance coefficient was 19.2. Finally, a fractured low-permeability core model with parallel long cores was designed, and the optimal profile control system was used for the core oil-displacement experiment. Compared with the water-flooding experiment, the plugging rate can be increased by 6.9–8.0%.

Chemical Agents Formula of Deep Profile Controlling for Niuxintuo Fractured Reservoir

2014 ◽  
Vol 1008-1009 ◽  
pp. 281-284
Author(s):  
Xiao Juan Liu ◽  
Guang Sheng Cao ◽  
Ben Cheng Gao ◽  
Hua Yin ◽  
Tong Li
Keyword(s):  
Salt Tolerance ◽  
Pour Point ◽  
Control Agent ◽  
Low Permeability ◽  
Fractured Reservoir ◽  
High Permeability ◽  
Blocking High ◽  
Chemical Agents ◽  
Profile Control ◽  
Deep Profile

Niuxintuo reservoir is a low permeability fractured reservoir with high pour point oil reservoir.control agent formula obtained via laboratory test can effectively improve iulection profile, which can be evaluated by performance of salt tolerance, Core plugging experiments shows that this profile control agent has achieved a success rate of 97%,the purpose of blocking high permeability formation is achieved.

scholarly journals Profile control performance and field application of preformed particle gel in low-permeability fractured reservoir

2020 ◽  
Author(s):  
Bin Xu ◽  
Yan Wang
Keyword(s):  
Fractured Reservoirs ◽  
Field Tests ◽  
Field Application ◽  
Low Permeability ◽  
Fractured Reservoir ◽  
Synthesis Conditions ◽  
Preformed Particle Gel ◽  
Profile Control ◽  
Deep Profile ◽  
Preformed Particle Gels

AbstractWater well profile control is the main way to control water channeling in low-permeability fractured reservoirs, and preformed particle gels (PPGs) are commonly used. A preformed particle gel was prepared and the synthesis conditions were optimized. The temperature and salt resistant performance, plugging performance were investigated and the field application was tested. The results showed PPGs exhibited good temperature and salt resistant performance. PPGs with larger particle size showed greater plugging strength but shorter valid period. Field tests suggested that multiple rounds of profile control should be employed using PPGs with different particle sizes to achieve deep profile control.

Compatibility evaluation of in-depth profile control agents in dominant channels of low-permeability reservoirs

2020 ◽  
Vol 194 ◽  
pp. 107529 ◽  
Author(s):  
Junjian Li ◽  
Ze Wang ◽  
Hanxu Yang ◽  
Hai'en Yang ◽  
Tianjiang Wu ◽  
...  
Keyword(s):  
Depth Profile ◽  
Low Permeability ◽  
Profile Control ◽  
Low Permeability Reservoirs

Effect of profile-control oil-displacement agent on increasing oil recovery and its mechanism

Fuel ◽  
2019 ◽  
Vol 237 ◽  
pp. 1151-1160 ◽  
Author(s):  
Weijia Cao ◽  
Kun Xie ◽  
Xiangguo Lu ◽  
Yigang Liu ◽  
Yunbao Zhang
Keyword(s):  
Oil Recovery ◽  
Oil Displacement ◽  
Profile Control

scholarly journals Formulation Development of High Strength Gel System and Evaluation on Profile Control Performance for High Salinity and Low Permeability Fractured Reservoir

2017 ◽  
Vol 2017 ◽  
pp. 1-9 ◽  
Author(s):  
Chengli Zhang ◽  
Guodong Qu ◽  
Guoliang Song
Keyword(s):  
High Salinity ◽  
Crosslinking Agent ◽  
High Strength ◽  
Gel Strength ◽  
Water Flooding ◽  
Low Permeability ◽  
Control Performance ◽  
Formulation Development ◽  
Profile Control ◽  
Gel System

For the large pores and cracks of reservoirs with low temperatures, high salinity, and low permeability, a new type of high strength gel ABP system is developed in this paper. The defects of conventional gels such as weak gel strength, no gelling, and easy dehydration are overcome under the conditions of low temperature and high salinity. The temperature and salt resistance, plugging characteristics, and EOR of the gel system are studied. Under the condition of 32°C and 29500 mg/L salinity, the ABP system formulation is for 0.3% crosslinking agent A + 0.09% coagulant B + 3500 mg/L polymer solution P. The results show that when the temperature was increased, the delayed crosslinking time of the system was shortened and the gel strength was increased. The good plugging characteristics of the ABP system were reached, and the plugging rate was greater than 99% in cores with different permeability. A good profile control performance was achieved, and the recovery rate was improved by 19.27% on the basis of water flooding. In the practical application of the gel system, the salinity of formation water and the permeability of fractures are necessary to determine the appropriate formulation.

An Experimental Research on Enhanced Oil Recovery Using Local Polymers

2021 ◽  
Author(s):  
Abiola Oyatobo ◽  
Amalachukwu Muoghalu ◽  
Chinaza Ikeokwu ◽  
Wilson Ekpotu
Keyword(s):  
Enhanced Oil Recovery ◽  
Experimental Research ◽  
Oil Recovery ◽  
Capital Investment ◽  
Oil And Gas ◽  
Produced Water ◽  
Water Injection ◽  
Gum Arabic ◽  
Oil And Gas Industry ◽  
Profile Control

Abstract Ineffective methods of increasing oil recovery have been one of the challenges, whose solutions are constantly sought after in the oil and gas industry as the number of under-produced reservoirs increases daily. Water injection is the most extended technology to increase oil recovery, although excessive water production can pose huge damage ranging from the loss of the well to an increase in cost and capital investment requirement of surface facilities to handle the produced water. To mitigate these challenges and encourage the utilization of local contents, locally produced polymers were used in polymer flooding as an Enhanced Oil Recovery approach to increase the viscosity of the injected fluids for better profile control and reduce cost when compared with foreign polymers as floppan. Hence this experimental research was geared towards increasing the efficiency of oil displacement in sandstone reservoirs using locally sourced polymers in Nigeria and also compared the various polymers for optimum efficiency. Starch, Ewedu, and Gum Arabic were used in flooding an already obtained core samples and comparative analysis of this shows that starch yielded the highest recovery due to higher viscosity value as compared to Ewedu with the lowest mobility ratio to Gum Arabic. Finally, the concentration of Starch or Gum Arabic should be increased for optimum recovery.

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