XG潜山油藏结垢影响因素室内实验研究

Experimental study on influence factors of XG buried hill reservoir scaling

 黄广庆¹ 范洪富² 吴超³ 王兴伟²

中国石油集团长城钻探工程有限公司，北京100101 中国地质大学（北京）能源学院，北京 100083 北京四维动向能源科技有限公司，北京 100083

Great Wall Drilling Co. Ltd., CNPC, Beijing 100101, China School of Energy Resources, China University of Geosciences, Beijing 100083, China Beijing Four?鄄dimensional Dynamic Energy Technology Co. Ltd., Beijing 100083, China

 XG潜山油藏注水开发生产过程中，结垢情况严重，需分析结垢的影响因素，控制结垢的发生。文中利用正交试验设计，分析了影响XG潜山油藏注水开发油藏结垢的因素。实验结果表明：XG潜山油藏注水开发中，随着注入水pH值升高，油藏结垢量逐渐增大；随着地层压力增大，沉淀结垢量逐渐减小；随着注入水混合比例增大，沉淀结垢量缓慢增大，达到峰值后又逐渐减小，注入水混合比例为50%时沉淀结垢量最大；随着体系温度升高，沉淀结垢量逐渐增大。对XG潜山油藏结垢影响最大的因素是注入水pH值，油藏压力次之，注水量与油藏温度影响较弱。当pH值控制在6.5以下，油藏压力保持在20 MPa以上，就能有效避免XG潜山油藏在注水开发过程中出现大量结垢。

 Serious scaling will happen when XG buried hill reservoir is developed by water flooding, in order to prohibit this scaling, the reason must be found out. Based on the principle of orthogonal experimental analysis, taking the HPHT reaction kettle experiment to simulate the reservoir scaling, the influence factors of XG buried hill reservoir scaling are analyzed. The result shows that the scaling amount of XG buried hill reservoir increases with the pH value increasing of injected water; decreases gradually with the increasing of formation pressure; the amount increases slowly with the increasing amount of injection water in the mixing proportion and then decreases gradually after reaching the peak and the precipitation scaling maximum appears when the injected water mixing ratio is 50%; increases with the increasing of temperature. The experimental results show that the main influence factor to the scaling of XG buried hill reservoir during water flooding is pH value and the second factor is reservoir pressure, volume of water and reservoir temperature are weak. Controlling pH value below 6.5 and reservoir pressure above 20 MPa can effectively prevent the emergence of a large amount of scaling of XG buried hill reservoir during water flooding.

10.6056/dkyqt201505020