新疆石油天然气 ›› 2026, Vol. 22 ›› Issue (1): 88-96.DOI: 10.12388/j.issn.1673-2677.2026.01.010

• 油气开发 • 上一篇    下一篇

高温高压凝析气井压力预测精度影响因素分析及模型优选

韩国庆1，何天1，郭玲2，来思俣2，刘彤3   

  1. 1.中国石油大学（北京），北京昌平 102249；2.中国石油新疆油田分公司采油工艺研究院，新疆克拉玛依 834000；3.中国石油勘探开发研究院提高油气采收率全国重点实验室，北京海淀 100089
  • 收稿日期:2025-07-02 修回日期:2025-12-02 接受日期:2025-12-05 出版日期:2026-03-10 发布日期:2026-03-10
  • 通讯作者: 刘彤（1989-），2015年毕业于中国地质大学（北京）石油与天然气工程专业，硕士，副研究员，目前从事热介质提高采收率方面的研究。（E-mail）liutong1116@petrochina.com.cn
  • 作者简介:韩国庆（1969-），2004年毕业于中国石油大学（北京）油气田开发工程专业，博士，教授，目前从事油气井智能举升方面的研究。（E-mail）hanguoqing@163.com
  • 基金资助:
    中国石油天然气集团公司关键核心技术攻关项目“热辅助混相驱油技术研究”（2023ZG18）

Analysis of Factors Affecting Pressure Prediction Accuracy and Model Selection for HPHT Condensate Gas Wells

HAN Guoqing1，HE Tian1，GUO Ling2，LAI Siyu2，LIU Tong3   

  1. 1. China University of Petroleum （Beijing），Changping 102249，Beijing，China；2. Oil Production Technology Research Institute，PetroChina Xinjiang Oilfield Company，Karamay 834000，Xinjiang，China；3. State Key Laboratory of Enhanced Oil and Gas Recovery，PetroChina Research Institute of Petroleum Exploration and Development，Haidian 100089，Beijing，China
  • Received:2025-07-02 Revised:2025-12-02 Accepted:2025-12-05 Online:2026-03-10 Published:2026-03-10

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摘要： 我国投入开发的深层凝析气田大部分具有高温高压、相态复杂的特点。出于测试成本和安全方面的考虑，无法直接测试井下压力等资料，需要利用适合高温高压凝析气井的井筒多相管流模型，由井口参数反演井底流压。为了明确高温高压凝析气井井筒压力预测中多相管流模型的适用性差异，建立合理的模型优选依据，研究分析了跨露点后的相态演化及高压条件下的流型转换条件，比较了黑油模型与组分模型的适用性差异，并对4种机理模型和5种经验模型进行了实例井检验对比。结果表明，在7口实例井的预测对比中，机理模型在深井中的平均误差仅为1.76%，优于经验模型；机理模型和经验模型在常规井中的平均误差均增大至10%以上。考虑极性水影响的组分模型后，基于高压流动实验和现场测试数据拟合修正的多流体机理模型能更好反映凝析液析出及井筒持液率变化，更适用于高温高压凝析气井压力预测。研究成果为高温高压凝析气井井筒压力剖面及井底流压预测方法的改进与应用提供了重要参考。

关键词: 凝析气井, 高温高压, 井筒压力剖面, 多相流, 机理模型

Abstract: Most of the deep condensate gas fields under development in China are characterized by high temperature，high pressure，and complex phase behaviors. Due to the constraints of testing cost and safety，direct measurement of downhole pressure is not feasible，and therefore，multiphase pipe flow models suited to high pressure and high temperature （HPHT） condensate gas wells are required to predict bottomhole pressure according to wellhead data. To clarify the applicability differences of multiphase wellbore flow models for pressure prediction in HPHT condensate gas wells and establish a rational basis for model selection，this study analyzes the phase behavior evolution across the dew point and the flow pattern transitions under high pressure conditions，compares the applicability of black-oil and compositional models，and evaluates four mechanistic models and five empirical models through case studies. The results indicate that for the seven case wells，the average error of mechanistic models is only 1.76% in deep wells，lower than that of empirical models；in conventional wells，the average errors of both model types exceed 10%. The multi-fluid mechanistic model corrected by high pressure flow experiments and field test data，combined with compositional models accounting for the effect of polar water，can better capture condensate dropout，liquid holdup variation，and are thus more suitable for HPHT condensate gas well pressure prediction. This study provides important references for improving and applying prediction methods of wellbore pressure profiles and bottomhole pressure in HPHT condensate gas wells.

Key words: condensate gas well, HPHT, wellbore pressure profile, multiphase flow, mechanistic model

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