超临界CO<sub>2</sub>压裂井筒传热规律

郭兴; 孙晓; 穆景福; 乔红军; 罗攀; 李珮

doi:10.12358/j.issn.1001-5620.2021.06.020

超临界CO₂压裂井筒传热规律

doi: 10.12358/j.issn.1001-5620.2021.06.020

郭兴^{1, 2,},
孙晓^{1, 2},
穆景福^{1, 2},
乔红军^{1, 2},
罗攀^{1, 2},
李珮^{1, 2}

1.
陕西延长石油（集团）有限责任公司研究院, 西安710065
2.
陕西省陆相页岩气成藏与开发重点实验室, 西安710065

基金项目: 陕西省创新能力支撑计划项目“CO₂压裂井筒温压及地层波及规律研究”（2019KJXX-023）；国家科技重大专项“延安地区陆相页岩气勘探开发关键技术”课题四“非均质陆相页岩气储层压裂改造配套工艺技术”（2017ZX05039-004）

详细信息

作者简介:
郭兴，工程师，1991年生，毕业于中国石油大学（华东）油气井工程专业，现在主要从事CO₂压裂工艺技术和超临界CO₂钻完井基础理论研究。电话 18049604069；E-mail：1174508734@qq.com

中图分类号: TE357
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出版历程
- 收稿日期: 2021-08-30
- 录用日期: 2021-04-22
- 刊出日期: 2021-11-30

Heat Transfer in Wellbores Fractured with Supercritical CO₂ Fracturing Fluid

GUO Xing^{1, 2
,},
SUN Xiao^{1, 2},
MU Jingfu^{1, 2},
QIAO Hongjun^{1, 2},
LUO Pan^{1, 2},
LI Pei^{1, 2}

1.
Research Institute of Shaanxi Yanchang Petroleum (Group) Company Limited, Xi’an, Shaanxi 710065
2.
Shaanxi Key Laboratory of Lacustrine Shale Gas Accumulation and Exploitation, Xi’an, Shaanxi 710065

摘要

摘要: 为了优化超临界CO₂压裂工艺技术和施工参数，考虑到井筒温压变化与CO₂物性之间的相互影响与作用，基于CO₂物性模型，建立CO₂压裂井筒压降、传热耦合数学模型，通过现场压裂施工数据验证模型准确性，进行耦合计算和井筒传热规律分析。研究表明：不同排量下，油管内温度分布均明显低于地层原始温度，且随着排量增加，井筒温度出现了先减小后增加的变化趋势；井底温度随着注入温度的增大而增大，且较高排量下，井底温度随注入温度的变化更加显著；井口压力增加对井底温度的影响很小，在工程上可以忽略其影响；不同排量下，井底温度均随着注入时间的增大而降低，且降幅随着注入时间增大逐渐减小；加入降阻剂会显著降低油管内温度，且不同排量下，降阻后井筒温度差异较小。该研究对于CO₂压裂设计优化及现场施工具有重要指导意义。
- 超临界CO₂ /
- 压裂 /
- 井筒流动 /
- 传热 /
- 耦合
Abstract: To optimize the techniques and operational parameters of well fracturing with supercritical CO2 fracturing fluid, a mathematical model coupling the pressure drawdown and heat transfer of a well fractured with CO₂ fracturing fluid is established based on the physical properties of CO₂, taking into account the mutual influence and interaction between the changes in temperature and pressure of the well and the properties of CO₂. The accuracy of the model is verified with data collected from field fracturing operations. Using this model, the effect of coupled temperature and pressure is calculated, and heat transfer pattern in the wellbore analyzed. Laboratory studies have shown that the temperature distribution inside the tubing is significantly lower than the in-situ formation temperature at different flow rates of the fracturing fluid. With the increase in flow rate, the wellbore temperature is first decreasing and then increasing. The bottomhole temperature is increasing with the increase in the temperature of the injected fluid, and the change in the bottomhole temperature becomes more significant with the temperature of the injected fluid at higher flow rates. Increase in the wellhead pressure has little, if any, influence on the bottomhole temperature, and its effect can be ignored in engineering calculations. The bottom hole temperature is always decreasing with time at different flow rates, and the amplitude of this temperature decrease is gradually decreasing with time. The tubing temperature can be significantly reduced if drag reducer is added into the fracturing fluid. At any flow rate, the changes in the wellbore temperatures are becoming smaller in a wellbore fractured with a fracturing fluid containing drag reducers. This research has important guiding significance to CO₂ fracturing design optimization and field operations.
- Supercritical CO₂ /
- Fracturing /
- Flow in wellbore /
- Heat transfer /
- Couple

HTML全文

图 1 计算框架示意图

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图 2 液态CO₂压裂井井底温度曲线

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图 3 不同CO₂注入排量下的井筒温度剖面

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图 4 不同CO₂注入温度下的井筒温度剖面

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图 5 不同排量下CO₂注入温度对井底温度的影响

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图 6 不同排量下井口压力对井底温度影响变化

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图 7 不同排量下CO₂注入时间对井底温度的影响

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图 8 添加减阻剂前后不同CO₂排量下的井筒温度剖面

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