杏子川油田王家湾区注水管线结垢预测  

Scale prediction of water injection pipeline in Wangjiawan Dwastrict of Xingzichuan Oilfield

作　　者：王苗苗 韩龙飞 王祎璠 张倩[1] 艾先婷 兰晓龙 WANG Miaomiao;HAN Longfei;WANG Yifan;ZHANG Qian;AI Xianting;LAN Xiaolong(Research Center of Exploration and Development Technology of Yanchang Oilfield Co.,Shaanxi Yan’an 716000,China)

机构地区：[1]延长油田股份有限公司勘探开发技术研究中心,陕西延安716000

出　　处：《非常规油气》2024年第5期114-121,共8页Unconventional Oil & Gas

基　　金：延长油田股份有限公司科技项目“杏子川王家湾区注水管线结垢及防治措施研究”(ycsy2021ky-B-15-19)。

摘　　要：为了便于油田地面注水管线的维护,有必要对管道内结垢情况作出符合实际的预测。针对王家湾区目前注水管线结垢严重而造成的管线更换频繁的问题,以该区块注水管线为研究对象,基于某一联合站沿程注入水离子浓度,利用结垢软件预测了注入水结垢趋势并通过室内静态实验进行了验证,分析了不同温度、pH值和压力对结垢垢型及结垢量变化趋势的影响。根据注水沿管线流动及沿程热损失过程,建立沿程水温变化数学模型,预测了管线沿程结垢厚度。结果表明:当温度从10℃升高到50℃时,理论预测下的结垢量增加了106.75 mg/L;当pH值从6增加到8时,结垢量增加了166.70 mg/L;随管输压力从0.5 MPa增加至10.5 MPa,结垢量下降了18.68 mg/L,说明pH值是影响管线结垢的主要因素,其次是温度的影响,压力对结垢影响很小。通过对比结垢软件预测值与实验数据,发现两者基本吻合,相对误差为5%~10%,说明结垢软件可实现管线结垢趋势及结垢厚度的预测,更能准确的模拟油田现场的结垢情况。热力学变化数学模型预测表明,随着注水时间的增加,管线结垢厚度3年后将达到20.8 mm,预测结果与现场实际相符,表明该预测模型也符合现场要求,具有一定的适用性。结垢趋势的准确预测有利于减缓管线结垢,提高注水质量,对后续采取有效的清防垢方法以及工艺的选取具有重要的指导意义。In order to facilitate the maintenance of oilfield surface water injection pipelines,it is necessary to make realistic predictions about the scaling inside the pipelines.In response to the serious scaling of water injection pipelines in Wangjiawan District and the frequent replacement of pipelines due to scaling,the water injection pipeline in this block was taken as the research object.Based on the ion concentration of the injected water along a certain joint station,scaling software was used to predict the scaling trend of the injected water,and which was validated through indoor static experiments.The effects of different temperatures,pH values,and pressures on the scaling type and the trend of scaling amount were analyzed.Based on the water injection flow and the heat loss process along the pipeline,a mathematical model for the variation of water temperature along the pipeline was established to predict the thickness of scaling along the pipeline.The results show that the theoretically predicted scaling amount increases by 106.75 mg/L when the temperature increases from 10℃to 50℃.The amount of scaling increases by 166.7 mg/L when the pH value increases from 6 to 8.As the pipeline pressure increased from 0.5 MPa to 10.5 MPa,the amount of scaling decreased by 18.68 mg/L,indicating that pH value is the main factor affecting pipeline scaling,followed by temperature,and pressure has little effect on scaling.By comparing the predicted values of scaling software with experimental data,it was found that the two were basically consistent,with a relative error of 5%~10%.This indicates that the software can predict the trend and thickness of pipeline scaling and can more accurately simulate the scaling situation in the oil field.The mathematical model prediction of thermodynamic changes shows that the thickness of pipeline scaling increases with the increase of water injection time,and the scaling thickness reaches 20.8 mm after 3 years.The predicted results are consistent with the actual on-site conditions,indicati

关 键 词：注入水 地面管线 结垢预测 热传导 结垢厚度 

分 类 号：TE358.5[石油与天然气工程—油气田开发工程]