深海水合物生产井筒水合物二次形成规律研究

doi:10.11885/j.issn.1674-5086.2024.04.06.31

西南石油大学学报(自然科学版) ›› 2026, Vol. 48 ›› Issue (2): 75-89.DOI: 10.11885/j.issn.1674-5086.2024.04.06.31

深海水合物生产井筒水合物二次形成规律研究

姜淑贤¹, 宋宣锜¹, 何玉发², 刘畅³, 宋金泽¹

1. 西南石油大学石油与天然气工程学院, 四川成都 610500;
2. 中海油研究总院有限责任公司, 北京朝阳 100028;
3. 中国石油大庆油田勘探开发研究院, 黑龙江大庆 163712

收稿日期:2024-04-06 发布日期:2026-04-30
通讯作者: 宋金泽，E-mail:pete.songjinze@gmail.com
作者简介:姜淑贤，1988年生，女，汉族，山西运城人，讲师，主要从事钻井安全与岩石力学方面的研究工作。E-mail:sxjiang@swpu.edu.cn
宋宣锜，2000年生，男，汉族，四川巴中人，硕士研究生，主要从事钻井安全与岩石力学方面的研究。E-mail:2665332575@qq.com
何玉发，1980年生，男，汉族，湖南衡阳人，高级工程师，主要从事深海油气及天然气水合物钻完井、海洋碳封存监测方面研究工作。E-mail:heyf@cnooc.com.cn
刘畅，1997年生，女，汉族，黑龙江哈尔滨人，助理工程师，硕士，主要从事提高采收率方面研究工作。E-mail:1452195099@qq.com
宋金泽，1988年生，男，汉族，黑龙江大庆人，讲师，主要从事天然气水合物生产防砂、海洋钻完井、机器学习方面研究工作。E-mail:pete.songjinze@gmail.com
基金资助:
国家重点研发计划（2019YFC0312301）；国家自然科学基金地质联合基金（U2244223）

Investigation of NGH Secondary Formation in Wellbore During Deep Sea Hydrate Production

JIANG Shuxian¹, SONG Xuanqi¹, HE Yufa², LIU Chang³, SONG Jinze¹

1. Petroleum Engineering School, Southwest Petroleum University, Chengdu, Sichuan 610500, China;
2. CNOOC Research Institute Co. Ltd., Chaoyang, Beijing 100028, China;
3. Daqing Oilfield Exploration and Development Research Institute, CNPC, Daqing, Heilongjiang 163712, China

Received:2024-04-06 Published:2026-04-30

摘要/Abstract

摘要： 为防止水合物的二次形成并提升井筒内流动效率，建立了深海水合物储层生产过程中的温度模型，综合考虑产砂粒径、产砂量和焦耳汤姆逊效应对水合物生产井筒中热传导的影响，模拟了深海水合物储层生产过程中适度出砂工况下的井筒温度曲线和压力曲线。考虑深水天然气水合物储层开发环境，明确地层产砂粒径、井筒尺寸、天然气产量、套管厚度、套管导热系数、流体导热系数、岩石导热系数及水合物储层埋深等因素对于井筒内水合物二次形成的影响。敏感性分析发现，水合物生产过程中，如果挡砂精度设计过小，地层产砂较小，井筒内温度降低较明显，水合物二次形成风险加剧；同时通过模拟也证明了局部加热水合物生产井筒，可以从降低水合物二次形成的角度，适度降低水合物防砂精度，减轻高精度挡砂带来的井筒流动性风险。模型计算结果现场生产案例中推荐地层产砂粒径控制在30 μm以下，井筒临界厚度为0.389 m，并适当降低天然气产量从而提高井筒流通效率和降低水合物二次形成风险；浅层水合物地层开发过程中，井筒内更易发生水合物二次形成；通过计算验证安装局部加热电极可以有效降低泥线附近水合物二次形成风险。研究结果为深海水合物储层生产精细防砂与井身结构设计提供理论支撑。

关键词: 深水水合物储层开发, 适度防砂, 焦耳-汤姆逊效应, 温度剖面, 压力剖面, 水合物二次形成

Abstract: To prevent secondary hydrate formation and enhance wellbore flow, the mathematical model to investigate the temperature and pressure in the development of the argillaceous natural gas hydrate. With the moderate sand control technique, this model predicted the temperature and pressure profiles along the well considering the sand particle size effect and the JouleThompson effect on heat transfer within the hydrate production wellbore. According to the moderate sand control principle, the paper also analyzed how the size of produced formation sand and the wellbore size could affect the secondary formation of natural gas hydrates in the wellbore. The effect is quantitatively described in the sensitivity analysis. Considering the development environment of NGH, several key factors were selected in the sensitivity analysis including produced formation sand size, wellbore diameter and thickness, production rate, thermal conductivity, and NGH formation depth. The analysis recommended the produced formation sand as less than 30 μm and the wellbore thickness as 0.389 m to reduce the risk of NGH secondary formation. The risk secondary NGH formation for shallow reservoir depth was higher than that for deep reservoir. The calculation verified that the installation of local heating electrode could effectively reduce the secondary formation risk of hydrate near the mud line. The research results of this paper provide theoretical support for fine sand control and well structure design of deep sea hydrate reservoir production.

Key words: natural gas hydrate in deep water, moderate sand control, Joule-Thompson effect, temperature profile, pressure profile, secondary formation of natural gas hydrate

中图分类号:

TE31

姜淑贤, 宋宣锜, 何玉发, 刘畅, 宋金泽. 深海水合物生产井筒水合物二次形成规律研究[J]. 西南石油大学学报(自然科学版), 2026, 48(2): 75-89.

JIANG Shuxian, SONG Xuanqi, HE Yufa, LIU Chang, SONG Jinze. Investigation of NGH Secondary Formation in Wellbore During Deep Sea Hydrate Production[J]. Journal of Southwest Petroleum University(Science & Technology Edition), 2026, 48(2): 75-89.

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深海水合物生产井筒水合物二次形成规律研究

Investigation of NGH Secondary Formation in Wellbore During Deep Sea Hydrate Production

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