A wellbore fluid performance parameters–temperature–pressure coupling prediction model during the managed pressure cementing injection stage,Energy Science & Engineering

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A wellbore fluid performance parameters–temperature–pressure coupling prediction model during the managed pressure cementing injection stage
Energy Science & Engineering ( IF 3.5 ) Pub Date : 2023-12-05 , DOI: 10.1002/ese3.1632
Jinlu Liu ₁ , Li Jun _{1,

2} , Hongwei Yang ₁ , Hui Li ₁ , Gonghui Liu ₁

Affiliation

Managed pressure cementing (MPC) is a new technology based on managed pressure drilling, which has a greater advantage in facing narrow density window formations. However, the existing pressure prediction models during MPC injection stage consider fewer factors and have lower accuracy. To this end, combined with the characteristics of the injection stage, a predictive model of the distribution of annular fluid type was first proposed. Then, based on the experimental results, fluid density and rheology as a function of temperature and pressure were fitted. The governing equation of temperature-pressure field was established. Eventually the fluid performance parameters–temperature–pressure coupling prediction model was developed in this paper. By comparing the predicted pump pressure with the measured pump pressure, the maximum relative error is not more than 10%. Using this model, the fluid type distribution, temperature field distribution, and pressure field distribution were investigated. The results indicated that the distribution of fluid types in the wellbore presented a complex variation, with up to 10 fluids in the casing and up to five fluids in the annulus. The trend of temperature field is complex, with three turning points. The larger the formation temperature gradient, the higher the fluid temperature in the annulus. The influence law of fluid heat conduction coefficient is reversed at 6750 m. Decreasing drilling fluid density will trigger gas channeling, while increasing drilling fluid density will increase the risk of fracturing formation, and safe operation can be realized by MPC. The variation of the static pressure in the casing is more complicated than in the annulus and the annular circulation pressure in the eccentric casing is smaller than that of the concentric casing, which is due to the smaller annular friction pressure. This study can provide a theoretical basis for the prediction of hydrodynamic parameters during the MPC injection stage.

中文翻译：

控压固井注入阶段井筒流体性能参数-温度-压力耦合预测模型

控压固井（MPC）是一种基于控压钻井的新技术，在面对窄密度窗口地层时具有更大的优势。然而，现有的MPC注入阶段压力预测模型考虑因素较少，精度较低。为此，结合注入阶段的特点，首次提出了环空流体类型分布的预测模型。然后，根据实验结果，拟合了流体密度和流变性作为温度和压力的函数。建立了温度-压力场控制方程。最终本文建立了流体性能参数-温度-压力耦合预测模型。通过将预测泵压力与实测泵压力进行比较，最大相对误差不大于10%。利用该模型，研究了流体类型分布、温度场分布和压力场分布。结果表明，井筒内流体类型分布呈现复杂变化，套管内流体种类多达10种，环空流体种类多达5种。温度场变化趋势复杂，存在3个转折点。地层温度梯度越大，环空中的流体温度越高。流体导热系数的影响规律在6750 m处发生逆转。钻井液密度降低会引发气窜，而钻井液密度增大会增加压裂地层风险，通过MPC可以实现安全作业。套管内静压的变化比环空复杂，偏心套管环空循环压力比同心套管小，这是由于环空摩擦压力较小。该研究可为MPC注入阶段水动力参数的预测提供理论依据。

更新日期：2023-12-05

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