Prediction Model of Wellbore Temperature Field during Deepwater Cementing Circulation Stage
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摘要:
准确预测固井循环阶段井筒温度场有助于水泥浆性能参数的设计和井筒压力的计算，为此，基于井筒流动机理和传热学理论，考虑不同区域差异对传热过程的影响和不同流体热力学参数差异及其随井深变化的特点，结合流体界面位置描述方程，建立了适用于深水固井循环阶段的井筒温度场预测模型。利用2口井的实测数据对模型进行了验证，并进行了关键因素的影响规律分析。结果表明：注入水泥浆之前，钻井液应循环2～4周，以降低注入过程中循环时间改变对井底循环温度的影响；注入水泥浆过程中，排量越大，周围环境的升温或降温作用越不明显；计算过程中，若不考虑温度对比热容的影响，则预测的井底循环温度会偏高2～4 ℃；水泥浆密度对温度的影响规律与传热方向有关。研究结果对深水固井具有一定的指导作用。
Abstract:Accurate prediction of the wellbore temperature field during the cementing circulation stage contributes to the design of cement slurry performance parameters and the calculation of wellbore pressure. Therefore, based on the wellbore flow mechanism and heat transfer theory, the influence of different regional differences on the heat transfer process was considered, and the discrepancy of different fluid thermodynamic parameters and their characteristics of variation with well depth were analyzed. Combined with the fluid interface position description equation, a set of wellbore temperature field prediction models suitable for the deepwater cementing circulation stage was established. The model was verified by the measured data from two wells, and the key influencing factors were analyzed. The results show that the drilling fluid should be circulated for 2~4 cycles prior to cement slurry injection, so as to reduce the impact of circulation time changes on the bottom hole circulating temperature (BHCT) during the injection. During the cement slurry injection process, larger flow rate causes less obvious warming or cooling of the surrounding environment. If the influence of temperature on specific heat capacity is not considered in the calculation process, it is predicted that the BHCT will be 2~4 °C higher. The influence of cement slurry density on temperature is related to the direction of heat transfer. The research results can be used to guide deepwater cementing.
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图 1 钻井液循环阶段井筒流动物理模型
Figure 1. Physical model of wellbore flow during drilling fluid circulation stage
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图 2 水泥浆注入阶段井筒流动物理模型
Figure 2. Physical model of wellbore flow during cement slurry injection stage
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图 6 B井不同模型预测的井筒温度分布
Figure 6. Wellbore temperature distribution predicted by different models for Well B
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图 7 不同钻井液循环时刻的井筒温度剖面
Figure 7. Wellbore temperature profile at different drilling fluid circulation times
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图 8 井底循环温度随钻井液循环周数的变化
Figure 8. Variation of BHCT with number of drilling fluid circulation cycles
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图 9 不同注入排量下水泥浆温度随界面位置的变化
Figure 9. Variation of cement slurry temperature with interface position under different injection rates
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图 10 不同比热容下水泥浆温度随界面位置的变化
Figure 10. Variation of cement slurry temperature with interface position under different specific heat capacity conditions
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图 11 注入不同密度水泥浆时井筒温度剖面
Figure 11. Wellbore temperature profile when injecting cement slurry with different density
表 1 不同类型流体比热容与温度关系式的回归系数
Table 1 Regression coefficient of specific heat capacity variation with temperature for different types of fluid
流体类型 回归系数 A B C 前置液 0.0227 19.985 0 2675.5 钻井液 0.0224 8.4234 2275.9 水泥浆 0.3242 −18.199 0 1824.6 
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表 2 固井工作液基础参数
Table 2 Basic parameters of cementing fluid
流体类型 体积/m3 密度/（kg·m−3） 排量（L·s−1） 隔离液 22.7 1 800 28.3 冲洗液 7.3 1 020 13.6 水泥浆 65.6 1 900 15.1 后置液 11.1 1 040 25.3 顶替液 30.5 1 000 10.1
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