The Research on Cross-linking Polymer Gel as In-depth Profile Control Agent

2009 ◽  
Vol 27 (12) ◽  
pp. 1300-1311 ◽  
Author(s):  
Y. He ◽  
S. Xiong ◽  
Z. Yang ◽  
X. Ruan ◽  
Y. Gong
Keyword(s):  
Depth Profile ◽  
Control Agent ◽  
Cross Linking ◽  
Polymer Gel ◽  
Profile Control

scholarly journals Development and Performance Evaluation of Steam Channeling Plugging Agent of Thermal Oil Recovery

2015 ◽  
Vol 8 (1) ◽  
pp. 58-63
Author(s):  
Wang Chunsheng ◽  
Sun Yingfan ◽  
He Chenglin ◽  
Zhang Haipeng ◽  
Du Qiuying
Keyword(s):  
Thermal Stability ◽  
High Temperature ◽  
Oil Recovery ◽  
Ph Value ◽  
Control Agent ◽  
Formation Condition ◽  
Cross Linking ◽  
Profile Control ◽  
High Efficient ◽  
And Performance

Under the constraints of high temperature and heterogeneity, the common profile control agent can not effectively plug the steam channeling. To address this issue, it is necessary to develop the high temperature resistance steam channeling plugging agent to improve the steam suction profile in the heavy oil reservoir. This paper used Simple Variable Method to optimize the content of the components of the high temperature resistant plugging agent. Static performances evaluation aims to study the influence rules of the formation condition (temperature, salinity and pH value). Dynamic evaluation is used to study its performance (plugging ratio, residual resistance factor, scouring resistance and thermal stability) in the sand-filled pipe to testify its applicability. The ratio of the component and the injection sequence are shown as follows: 0.03% coagulant +2.2% cross-linking agent I + 1.2% cross-linking II + 6% high efficient main agent. The evaluation experiment results show that the gel can resist at least 280ºC, the plugging ratio is above 93.1%. The plugging ratio only have a 8.43% reduction after scoured by 15 PV steam (280ºC). After a 10-day thermal stability experiment (280 ºC), the plugging ratio is still above 80%. The result indicated that the plugging agent is suitable for the improvement of steam suction profile. The suggested way of injection is also provided.

Development and Evaluation of Salt-Resisting Polymer Gel Profile Control Agent

2013 ◽  
Vol 781-784 ◽  
pp. 426-430 ◽  
Author(s):  
Guang Yang ◽  
Jian Zhang ◽  
Xin Sheng Xue ◽  
Ying Xian Cui ◽  
Wen Sen Zhao
Keyword(s):  
High Temperature ◽  
Storage Modulus ◽  
Water Erosion ◽  
Control Agent ◽  
Polymer Gel ◽  
Laboratory Findings ◽  
Water Shutoff ◽  
Profile Control ◽  
Weak Gel

Be aimed at the characteristics of high temperature-salinity and severe heterogeneity of Bohai oilfield. This paper studies three different strength kinds of polymer gel profile control agents. Use storage modulus evaluates strength of polymer gel. the result indicate that the storage modulus of weak gel is between0.1 Pa and 1.0 Pa, the storage modulus of moderate gel is between1.0 Pa and 3.1 Pa, the maximal value of powerful gels storage modulus is11.9 Pa during 90 days. Core laboratory findings indicate that these different strength kinds of polymer gel have well formation sealing quality and endure washing out quality,40PV by water erosion , the formation sealing rate is up 90%.the experiment result of water shutoff and flooding oil indicate that the EOR is13.44% in heterogeneity core.

scholarly journals Evaluation and Injection Parameter Optimization for Polymer Flooding with Different Kinds of Profile Control Agents

2013 ◽  
Vol 2013 ◽  
pp. 1-4 ◽  
Author(s):  
Yikun Liu ◽  
Qingjun Deng ◽  
Gang Chen ◽  
Shuang Liang ◽  
Lingyun Chen
Keyword(s):  
Parameter Optimization ◽  
Control Agent ◽  
Injection Rate ◽  
Polymer Flooding ◽  
Economic Effects ◽  
Cross Linking ◽  
Injection Parameter ◽  
Profile Control ◽  
Deep Reservoir ◽  
Better Than

Injecting profile control agent (PCA) into deep reservoir can decrease the inefficient circulation of injected water effectively, which is critical to improve polymer flooding in heterogeneous reservoir. Polymer flooding contrast experiments were carried out with three PCAs, respectively; the influence of different injection times on recovery is analyzed, and the best injection rate of PCA is determined. The result shows that the effect of compound ion PCA, anionic delay-action cross-linking PCA, and luminum citrate cross-linking PCA gets worse in turn. The effect of injecting PCA before polymer flooding is better than that of injecting it during and after the procedure. As the PCA rate increases, the recovery increment raises, but the increasing ranges decrease. The best rate of PCA is 0.10PV, considering technical and economic effects.

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