高子璇1， 李扬1， 庞学玉1，2， 吕开河1，2， 孙金声1，2
1.中国石油大学（华东） 石油工程学院， 山东 青岛 266580； 2.中国石油大学（华东） 深层油气全国重点实验室， 山东 青岛
引用格式：
高子璇， 李扬， 庞学玉， 等. 外加剂对超高温加砂油井水泥长期性能的影响［J］. 中国粉体技术， 2026， 32（4）： 1-10.
Gao Zixuan， Li Yang， Pang Xueyu， et al. Effect of additives on long-term properties of silica-enriched oil well cement under ultra-high-temperature conditions［J］. China Powder Science and Technology， 2026， 32（4）： 1-10.
DOI：10.13732/j.issn.1008-5548.2026.04.008
收稿日期： 2025-12-15， 修回日期： 2026-05-28，上线日期： 2026-06-10。
基金项目：国家自然科学基金项目，编号：52288101；深层油气全国重点实验室自主研究课题，编号：SKLDOG2024-ZYTS-11。
第一作者：高子璇（2000—），男，博士研究生，研究方向为油气田化学与提高采收率技术。E-mail：BZ25020002@s.upc.edu.cn。
通信作者：庞学玉（1982—），男，教授，博士，博士生导师，研究方向为油气井固井工程。E-mail：x.pang@upc.edu.cn；孙金声（1965—），男，教授，博士，中国工程院院士，研究方向为油气井井筒工作液。E-mail：sunjinsheng@upc.edu.cn。
摘要：【目的】针对240 ℃超高温条件下加砂油井水泥仍存在强度衰退的问题，研究外加剂对其长期力学性能及微观结构演化的影响机制。【方法】在温度为240 ℃、养护压力为30 MPa的条件下，分别对含全套外加剂、缺失缓凝剂、不含外加剂的加砂油井水泥体系进行2 ~90 d养护，通过抗压强度测试、渗透率测试、压汞孔隙度和X射线衍射分析，结合高温高压稠化实验，研究不同加砂油井水泥体系的性能与水化特征。【结果】在240 ℃养护条件下，含全套外加剂，密度为1.9 g/cm3的加砂油井水泥体系2 d抗压强度最高，为44 MPa、渗透率低，但90 d抗压强度降至33 MPa， 渗透率上升，孔径粗化，水化产物分析表明，该体系水化硅酸钙凝胶含量降低，雪硅钙石几乎完全消失；相比之下，不含外加剂，密度为1.9 g/cm3的加砂油井水泥体系2 d抗压强度较低，为33 MPa，但90 d抗压强度增至40 MPa，渗透率下降，孔径细化，其水化产物中水化硅酸钙凝胶含量增加，硬硅钙石减少，微观结构趋于稳定；稠化时间测试显示，含全套外加剂体系可正常初凝于240 ℃，而不含外加剂体系在升温阶段即提前凝固。【结论】外加剂可以通过调控水泥浆凝固温度，显著影响加砂油井水泥在超高温条件下的水化过程与结构演化，是导致其长期力学性能差异的关键因素。
关键词：高温力学性能；强度衰退；加砂油井水泥；外加剂
Abstract
Objective In the cementing operation of ultra-high-temperature oil and gas wells， the cement stone of silica-enriched oil wells generally faces serious strength degradation problems， which directly affects the integrity of wellbores and the service life of oil and gas wells. Under high-temperature curing conditions， the compressive strength of cement stone decreases with the extension of curing time， and the degree of decline is closely related to the additive formulation， water-to-cement ratio， and curing temperature. In addition， oil well cement additives are a key technical means to ensure the stability of cement slurry performance and the long-term integrity of cement stone. As the well depth increases， the downhole temperature and pressure rise significantly. Pure cement systems are difficult to meet the comprehensive engineering requirements for thickening time， rheology， fluid loss agent， and compressive strength. Therefore， performance control must be achieved through additives. This study investigates the influence mechanism of additives on the long-term mechanical properties and microstructure evolution of silica-enriched oil well cement under ultra-high-temperature conditions of 240 ℃.
Methods Cement slurries with densities of 1.9 g/cm3 and 1.75 g/cm3 were prepared according to API standards. The compressive strength of cement stone was tested using a universal testing machine， and each group of cement stone samples had three replicates. The thickening performance of cement slurry was tested using a high-temperature and high-pressure thickener. The cement stone sample was placed in the core holder of an automatic permeability tester for permeability measurement. A high-pressure mercury intrusion porosimeter was used to test the pore structure of the cement stone， and the maximum applied pressure was set to 220 MPa. Phase analysis was performed on cement stone using an X-ray diffractometer.
Results and Discussion Under the high-temperature curing condition of 240 ℃， the H70 system containing additives showed excellent early performance. The compressive strength reached 44 MPa after 2 d of curing， the permeability was the lowest， and the median pore size was only 10 nm. However， as the curing time was extended to 90 d， its compressive strength decreased to 33 MPa， the permeability increased significantly （similar phenomenon was observed in the M70 system）， the median pore size coarsened to 20 nm， and the total porosity increased. The analysis of hydration products showed that the content of amorphous C-S-H in the H70 system gradually decreased， and the tobermorite almost completely disappeared after 90 d of curing. In contrast， the early performance of the H70-NA system without additives was poor. The compressive strength was only 33 MPa after 2 d of curing， the permeability was high， and the median pore size reached 100 nm. However， as the curing time was extended to 90 d， its compressive strength increased to 40 MPa， the permeability decreased （similar phenomenon was observed in the M70 system）， the median pore size was refined to 30 nm， and the total porosity remained stable. The content of C-S-H in the hydration products increased， the amount of xonotlite significantly decreased， and the proportion of small pores increased. The performance of the H70-NR system without retarder was between the two （H70 system and H70-NA system）. The thickening time test showed that the system containing additives could initially set at 240 ℃ normally， while the system without additives set prematurely during the heating stage.
Conclusion The absence of additives has a significant impact on the high-temperature mechanical properties of silica-enriched oil well cement. Cement containing an appropriate amount of additives shows significant strength degradation under 240 ℃ curing conditions， while systems lacking retarder， dispersant， and fluid loss agent do not show significant strength degradation. With increasing curing time， the pore structure of cement samples containing appropriate additives coarsens sharply. On the contrary， the pore structure of cement samples without retarder or any additives is relatively stable， and some samples even exhibit pore refinement. In the H70 system containing an appropriate amount of additives， the main reason for the strength degradation is the reduction of amorphous hydration products that have a positive effect on mechanical properties and the decrease in the content of tobermorite. On the contrary， the amorphous hydration products in the H70-NR system lacking retarder and the H70-NA system without any additives increase， while the xonotlite， which has an adverse effect on mechanical properties， significantly decreases during the curing process. This is the main reason for the significant difference in cement hydration products and mechanical properties due to the different setting temperatures of the cement slurry. The setting temperature has a significant impact on the high-temperature mechanical properties of cement， and targeted research should be conducted on the influence of setting temperature on the high-temperature mechanical properties of cement in future efforts.
Keywords：high-temperature mechanical properties; strength retrogression; sand-containing oil well cement; additives
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