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Article(id=1217789898040463728, tenantId=1146029695717560320, journalId=1146123166801305609, issueId=1217789884081820362, articleNumber=null, orderNo=null, doi=10.12404/j.issn.1671-1815.2406349, pmid=null, cstr=null, oa=null, hot=null, price=null, onlineType=0, articleFormat=0, articleType=null, articleTypeStr=research-article, receivedDate=1724342400000, receivedDateStr=2024-08-23, revisedDate=1744646400000, revisedDateStr=2025-04-15, acceptedDate=null, acceptedDateStr=null, onlineDate=1768273337135, onlineDateStr=2026-01-13, pubDate=1753632000000, pubDateStr=2025-07-28, doiRegisterDate=null, doiRegisterDateStr=null, onlineIssueDate=1768273337135, onlineIssueDateStr=2026-01-13, onlineJustAcceptDate=null, onlineJustAcceptDateStr=null, onlineFirstDate=null, onlineFirstDateStr=null, sourceXml=null, magXml=null, createTime=1768273337135, creator=13701087609, updateTime=1768273337135, updator=13701087609, issue=Issue{id=1217789884081820362, tenantId=1146029695717560320, journalId=1146123166801305609, year='2025', volume='25', issue='21', pageStart='8761', pageEnd='9209', issueExtLink='null', onlineDate='null', pubDate='null', beforeIssueId=null, nextIssueId=null, price=null, status=1, issueComplete=1, articleOrder=1, issueType=-1, specialIssue=null, createTime=1768273333807, creator=13701087609, updateTime=1768273602927, updator=13701087609, preIssue=null, nextIssue=null, ext={EN=IssueExt(id=1217791012932604619, tenantId=1146029695717560320, journalId=1146123166801305609, issueId=1217789884081820362, language=EN, specialIssueTitle=, coverIllustrator=null, specialIssueEditor=, specialIssueAbout=), CN=IssueExt(id=1217791012932604620, tenantId=1146029695717560320, journalId=1146123166801305609, issueId=1217789884081820362, language=CN, specialIssueTitle=, coverIllustrator=null, specialIssueEditor=, specialIssueAbout=)}, issueFiles=null}, startPage=8871, endPage=8878, ext={EN=ArticleExt(id=1217789898820604359, articleId=1217789898040463728, tenantId=1146029695717560320, journalId=1146123166801305609, language=EN, title=Gas-Liquid Flow Patterns and Influencing Factors in Deep Shale Gas Wellbores, columnId=1156262729003422020, journalTitle=Science Technology and Engineering, columnName=Papers·Petroleum and Natural Gas Industry, runingTitle=null, highlight=null, articleAbstract=

As large-scale fracturing in the development of deep shale gas results in rapid production decline, the accurate understanding of gas-liquid flow patterns is considered essential for stabilizing gas well production. Gas well models with two different wellbore trajectory structures were established, and OLGA software was applied to conduct transient calculations on models with varying tubing depths. The results indicate that in deep shale gas well A1, slug flow only occurs in the build-up section and above, while in well B1, slug flow appears in the horizontal section and near the build-up section. Considering cumulative gas production and liquid loading, the optimal tubing depth for deep shale gas wells A1 and B1 is at the heel of the horizontal section, while for conventional shale gas wells A and B, the optimal tubing depths are at the heel of the horizontal section and one-third of the horizontal section. Deep shale gas wells are more favorable for drainage and production compared to conventional shale gas wells.The optimal tubing setting depths for conventional shale gas wells with two deep formation wellbore configurations are at the horizontal section heel and the one-third point of the lateral, respectively. It is determined that deep shale gas wells are more advantageous for drainage and production compared to conventional shale gas wells. As the tubing size decreases, both the gas production and the corresponding critical gas flow rate for liquid carryover are reduced. It is also found that the greater the light hydrocarbon content in the shale gas composition, the higher the gas production. This study is intended to provide a reference for determining the rational tubing placement in the drainage and gas production processes of deep shale gas wells.

, correspAuthors=Jie LIU, authorNote=null, correspAuthorsNote=null, copyrightStatement=null, copyrightOwner=null, extLink=null, articleAbsUrl=null, sourceXml=null, magXml=null, pdfUrl=null, pdf=null, pdfFileSize=null, pdfExtLink=null, richHtmlUrl=null, mobilePdfUrl=null, reviewReport=null, pdfFirstPage=null, abstractGraph=null, abstractGraphContent=null, abstractVideo=null, citation=null, cebUrl=null, magXmlContent=null, mapNumber=null, authorCompany=null, fund=null, authors=null, authorsList=Sheng JU, Jie LIU), CN=ArticleExt(id=1217789902188630840, articleId=1217789898040463728, tenantId=1146029695717560320, journalId=1146123166801305609, language=CN, title=深层页岩气井井筒气液流动规律及影响因素, columnId=1156262729603207500, journalTitle=科学技术与工程, columnName=论文·石油、天然气工业, runingTitle=null, highlight=null, articleAbstract=

随着深层页岩气开发过程中大规压裂导致产量快速递减,准确掌握气液流动规律是气井稳产的必要手段,通过建立两种井身轨迹结构的气井模型,应用OLGA软件对不同油管下深模型进行瞬态计算。结果表明: 深层页岩气井A1仅在造斜段及以上出现段塞流,而B1井在水平段及造斜段附近出现段塞流的情况。考虑到累计产气量与积液,深层页岩气井A1、B1油管下入水平段跟端时最佳,与深层两种井身轨迹结构对应的常规页岩气井油管最优下深分别为水平段跟端和1/3水平段处;深层页岩气井较常规页岩气井更有利于排采和生产。随着油管尺寸的减小,产气量越小,对应气体的临界携液流量也越小;页岩气组分中轻烃的含量越大,气体产量随之增大。该研究可为深层页岩气井排水采气工艺中油管下入合理位置提供参考。

, correspAuthors=刘捷, authorNote=null, correspAuthorsNote=
* 刘捷(1979—),男,汉族,湖北广水人,博士,副教授。研究方向:油气田开发工程。E-mail:。
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巨生(1998—),男,汉族,甘肃会宁人,硕士研究生。研究方向:采气工艺及多相流。E-mail:。

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巨生(1998—),男,汉族,甘肃会宁人,硕士研究生。研究方向:采气工艺及多相流。E-mail:。

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巨生(1998—),男,汉族,甘肃会宁人,硕士研究生。研究方向:采气工艺及多相流。E-mail:。

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Study on gas-liquid two-phase flow in high liquid production horizontal gas wells with different gas lift methods[J]. Science Technology and Engineering, 2022, 22(28): 12362-12369., articleTitle=Study on gas-liquid two-phase flow in high liquid production horizontal gas wells with different gas lift methods, refAbstract=null), Reference(id=1217860131929379081, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, doi=null, pmid=null, pmcid=null, year=2024, volume=59, issue=6, pageStart=1290, pageEnd=1303, url=null, language=null, rfNumber=[29], rfOrder=54, authorNames=Mou C, Shan J, Cui S G H, journalName=Chemistry and Technology of Fuels and Oils, refType=null, unstructuredReference=Mou C, Shan J, Cui S G H. Study on seepage characteristics and capacity evaluation of shale gas reservoirs[J]. Chemistry and Technology of Fuels and Oils, 2024, 59(6): 1290-1303., articleTitle=Study on seepage characteristics and capacity evaluation of shale gas reservoirs, refAbstract=null)], funds=null, companyList=[AuthorCompany(id=1217860113281503406, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, xref=null, ext=[AuthorCompanyExt(id=1217860113285697712, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, companyId=1217860113281503406, language=EN, country=null, province=null, city=null, postcode=null, companyName=null, departmentName=null, remark=School of Petroleum Engineering, Yangtze University, Wuhan 430100, China), AuthorCompanyExt(id=1217860113294086320, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, companyId=1217860113281503406, language=CN, country=null, province=null, city=null, postcode=null, companyName=null, departmentName=null, remark=长江大学石油工程学院, 武汉 430100)])], figs=[ArticleFig(id=1217860117215760869, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=EN, label=Fig.1, caption=Schematic diagram of well structure of wells A1 and B1, figureFileSmall=K3CRoKZhiR0Np0QFQqKyAg==, figureFileBig=Wb7gK6H64k+dBMXl1Ntf5w==, tableContent=null), ArticleFig(id=1217860117316424173, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=CN, label=图1, caption=A1、B1井井身结构示意图, figureFileSmall=K3CRoKZhiR0Np0QFQqKyAg==, figureFileBig=Wb7gK6H64k+dBMXl1Ntf5w==, tableContent=null), ArticleFig(id=1217860117433864700, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=EN, label=Fig.2, caption=Comparative analysis of actual production and simulation results, figureFileSmall=6TIMOedWi8RERhMJmu+fjw==, figureFileBig=J5oxOmfq6fwslZcfWLLccg==, tableContent=null), ArticleFig(id=1217860117559693834, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=CN, label=图2, caption=实际生产数据与模拟结果对比分, figureFileSmall=6TIMOedWi8RERhMJmu+fjw==, figureFileBig=J5oxOmfq6fwslZcfWLLccg==, tableContent=null), ArticleFig(id=1217860117693911577, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=EN, label=Fig.3, caption=Flow regime diagrams, figureFileSmall=hdHqLNpB/NGqC7ZHEHMV6A==, figureFileBig=HRfl9HBVHosFaBeZxAxOug==, tableContent=null), ArticleFig(id=1217860117798769193, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=CN, label=图3, caption=流态直观图, figureFileSmall=hdHqLNpB/NGqC7ZHEHMV6A==, figureFileBig=HRfl9HBVHosFaBeZxAxOug==, tableContent=null), ArticleFig(id=1217860117912015412, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=EN, label=Fig.4, caption=Flow distribution in upward-inclined section of well A1, figureFileSmall=uSYWlv40uz+BzafBB+loyg==, figureFileBig=3MTh6EWGLjW6Qt+Uz1iQlw==, tableContent=null), ArticleFig(id=1217860118113342012, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=CN, label=图4, caption=水平段上翘深井A1流态分布

纵坐标数字1表示分层流,2表示环状流,3表示段塞流,4表示泡状流

, figureFileSmall=uSYWlv40uz+BzafBB+loyg==, figureFileBig=3MTh6EWGLjW6Qt+Uz1iQlw==, tableContent=null), ArticleFig(id=1217860118394360401, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=EN, label=Fig.5, caption=Flow distribution in the downward-inclined section of well B1, figureFileSmall=yp4ZcGoGj4KJhGMzmo0tZA==, figureFileBig=O9OtVkU8KB5l5HGvgkiLOA==, tableContent=null), ArticleFig(id=1217860118532772443, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=CN, label=图5, caption=水平段下倾深井B1流态分布

纵坐标数字1表示分层流,2表示环状流,3表示段塞流,4表示泡状流

, figureFileSmall=yp4ZcGoGj4KJhGMzmo0tZA==, figureFileBig=O9OtVkU8KB5l5HGvgkiLOA==, tableContent=null), ArticleFig(id=1217860118654407269, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=EN, label=Fig.6, caption=Production curves at different tubing positions, figureFileSmall=1XuaMGnBSpCw4rKAByOOrg==, figureFileBig=16KSRwrkDvSOwHQtPQaUSw==, tableContent=null), ArticleFig(id=1217860118763459187, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=CN, label=图6, caption=不同油管位置下生产曲线, figureFileSmall=1XuaMGnBSpCw4rKAByOOrg==, figureFileBig=16KSRwrkDvSOwHQtPQaUSw==, tableContent=null), ArticleFig(id=1217860118876705414, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=EN, label=Fig.7, caption=Production curves for different tubing sizes, figureFileSmall=IiIO/y1vEhPsEc/RPhdfSg==, figureFileBig=fCXvY0l6LIP4x31y9aEXnw==, tableContent=null), ArticleFig(id=1217860118981563029, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=CN, label=图7, caption=不同油管尺寸下的生产曲线, figureFileSmall=IiIO/y1vEhPsEc/RPhdfSg==, figureFileBig=fCXvY0l6LIP4x31y9aEXnw==, tableContent=null), ArticleFig(id=1217860119115780766, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=EN, label=Fig.8, caption=Impact of shale gas composition on gas production, figureFileSmall=lT4p9CtmYdhUL0Ix4B4u6g==, figureFileBig=EM3+CD1AjQevw5zu7hKwcg==, tableContent=null), ArticleFig(id=1217860120076276396, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=CN, label=图8, caption=页岩气组分对产气量的影响, figureFileSmall=lT4p9CtmYdhUL0Ix4B4u6g==, figureFileBig=EM3+CD1AjQevw5zu7hKwcg==, tableContent=null), ArticleFig(id=1217860120227271348, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=EN, label=Fig.9, caption=Relationship curve between tubing position and gas productionwellbore liquid accumulation time, figureFileSmall=xqS+5ohaFrdi5K/gm3y6Pw==, figureFileBig=/k6OCbMbox/2Pz+dD06vhw==, tableContent=null), ArticleFig(id=1217860120344711867, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=CN, label=图9, caption=油管位置与产气量的关系曲线, figureFileSmall=xqS+5ohaFrdi5K/gm3y6Pw==, figureFileBig=/k6OCbMbox/2Pz+dD06vhw==, tableContent=null), ArticleFig(id=1217860120474735306, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=EN, label=Fig.10, caption=The relationship curve between tubing position and liquid accumulation time in the wellbore, figureFileSmall=0jhGbxNzPyU2dcUQB8bJeA==, figureFileBig=MPXiX2eMY5B1FpIN+bVcvw==, tableContent=null), ArticleFig(id=1217860120604758738, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=CN, label=图10, caption=油管位置与井筒积液时间的关系曲线, figureFileSmall=0jhGbxNzPyU2dcUQB8bJeA==, figureFileBig=MPXiX2eMY5B1FpIN+bVcvw==, tableContent=null), ArticleFig(id=1217860120806085341, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=EN, label=Table 1, caption=

Basic data for wells A1 and B1

, figureFileSmall=null, figureFileBig=null, tableContent=
A1井 B1井
参数 数值 参数 数值
井深/m 6 180 井深/m 6 240
地层温度/℃ 157.9 地层温度/℃ 158.5
地层压力/MPa 39.5 地层压力/MPa 39.6
油管外径/mm 73.025 油管外径/mm 73.025
井口油压/MPa 2 井口油压/MPa 2
井口温度/℃ 15 井口温度/℃ 15
), ArticleFig(id=1217860120969663212, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=CN, label=表1, caption=

A1、B1井基础数据

, figureFileSmall=null, figureFileBig=null, tableContent=
A1井 B1井
参数 数值 参数 数值
井深/m 6 180 井深/m 6 240
地层温度/℃ 157.9 地层温度/℃ 158.5
地层压力/MPa 39.5 地层压力/MPa 39.6
油管外径/mm 73.025 油管外径/mm 73.025
井口油压/MPa 2 井口油压/MPa 2
井口温度/℃ 15 井口温度/℃ 15
), ArticleFig(id=1217860121129046772, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=EN, label=Table 2, caption=

Error analysis table between actual production and simulation results

, figureFileSmall=null, figureFileBig=null, tableContent=
气井 实际生产
时间/h		 模拟时间/
h		 实际生产累计
产气量/m3		 模拟生产累计
产气量/m3
A1井 9.38×103 9.43×103 5.37×107 5.38×107
B1井 8.72×103 9.32×103 5.06×107 5.21×107
), ArticleFig(id=1217860121246487292, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=CN, label=表2, caption=

实际生产与模拟结果误差分析表

, figureFileSmall=null, figureFileBig=null, tableContent=
气井 实际生产
时间/h		 模拟时间/
h		 实际生产累计
产气量/m3		 模拟生产累计
产气量/m3
A1井 9.38×103 9.43×103 5.37×107 5.38×107
B1井 8.72×103 9.32×103 5.06×107 5.21×107
), ArticleFig(id=1217860121380705036, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=EN, label=Table 3, caption=

Shale gas composition

, figureFileSmall=null, figureFileBig=null, tableContent=
组分 组分1
摩尔分数/%		 组分2
摩尔分数/%		 组分3
摩尔分数/%
甲烷 96.34 95.00 88.29
乙烷 2.04 2.62 7.35
丙烷 0.27 0.56 2.51
丁烷及以上烷烃 0.50 1.55 1.01
氮气 0.43 0.12 0.70
二氧化碳 0.30 0.15 0.14
), ArticleFig(id=1217860121573643037, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1217789898040463728, language=CN, label=表3, caption=

页岩气主要组分表

, figureFileSmall=null, figureFileBig=null, tableContent=
组分 组分1
摩尔分数/%		 组分2
摩尔分数/%		 组分3
摩尔分数/%
甲烷 96.34 95.00 88.29
乙烷 2.04 2.62 7.35
丙烷 0.27 0.56 2.51
丁烷及以上烷烃 0.50 1.55 1.01
氮气 0.43 0.12 0.70
二氧化碳 0.30 0.15 0.14
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深层页岩气井井筒气液流动规律及影响因素
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巨生 , 刘捷 *
科学技术与工程 | 论文·石油、天然气工业 2025,25(21): 8871-8878
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科学技术与工程 | 论文·石油、天然气工业 2025, 25(21): 8871-8878
深层页岩气井井筒气液流动规律及影响因素
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巨生 , 刘捷*
作者信息
  • 长江大学石油工程学院, 武汉 430100

    • 巨生(1998—),男,汉族,甘肃会宁人,硕士研究生。研究方向:采气工艺及多相流。E-mail:。

通讯作者:

* 刘捷(1979—),男,汉族,湖北广水人,博士,副教授。研究方向:油气田开发工程。E-mail:。
Gas-Liquid Flow Patterns and Influencing Factors in Deep Shale Gas Wellbores
Sheng JU , Jie LIU*
Affiliations
  • School of Petroleum Engineering, Yangtze University, Wuhan 430100, China
出版时间: 2025-07-28 doi: 10.12404/j.issn.1671-1815.2406349
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摘要
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随着深层页岩气开发过程中大规压裂导致产量快速递减,准确掌握气液流动规律是气井稳产的必要手段,通过建立两种井身轨迹结构的气井模型,应用OLGA软件对不同油管下深模型进行瞬态计算。结果表明: 深层页岩气井A1仅在造斜段及以上出现段塞流,而B1井在水平段及造斜段附近出现段塞流的情况。考虑到累计产气量与积液,深层页岩气井A1、B1油管下入水平段跟端时最佳,与深层两种井身轨迹结构对应的常规页岩气井油管最优下深分别为水平段跟端和1/3水平段处;深层页岩气井较常规页岩气井更有利于排采和生产。随着油管尺寸的减小,产气量越小,对应气体的临界携液流量也越小;页岩气组分中轻烃的含量越大,气体产量随之增大。该研究可为深层页岩气井排水采气工艺中油管下入合理位置提供参考。

瞬态计算  /  最优下深  /  气井积液  /  深层页岩气  /  气液流动

As large-scale fracturing in the development of deep shale gas results in rapid production decline, the accurate understanding of gas-liquid flow patterns is considered essential for stabilizing gas well production. Gas well models with two different wellbore trajectory structures were established, and OLGA software was applied to conduct transient calculations on models with varying tubing depths. The results indicate that in deep shale gas well A1, slug flow only occurs in the build-up section and above, while in well B1, slug flow appears in the horizontal section and near the build-up section. Considering cumulative gas production and liquid loading, the optimal tubing depth for deep shale gas wells A1 and B1 is at the heel of the horizontal section, while for conventional shale gas wells A and B, the optimal tubing depths are at the heel of the horizontal section and one-third of the horizontal section. Deep shale gas wells are more favorable for drainage and production compared to conventional shale gas wells.The optimal tubing setting depths for conventional shale gas wells with two deep formation wellbore configurations are at the horizontal section heel and the one-third point of the lateral, respectively. It is determined that deep shale gas wells are more advantageous for drainage and production compared to conventional shale gas wells. As the tubing size decreases, both the gas production and the corresponding critical gas flow rate for liquid carryover are reduced. It is also found that the greater the light hydrocarbon content in the shale gas composition, the higher the gas production. This study is intended to provide a reference for determining the rational tubing placement in the drainage and gas production processes of deep shale gas wells.

transient calculation  /  optimal tubing depth  /  liquid accumulation in gas wells  /  deep shale gas  /  gas-liquid flow
巨生, 刘捷. 深层页岩气井井筒气液流动规律及影响因素. 科学技术与工程, 2025 , 25 (21) : 8871 -8878 . DOI: 10.12404/j.issn.1671-1815.2406349
Sheng JU, Jie LIU. Gas-Liquid Flow Patterns and Influencing Factors in Deep Shale Gas Wellbores[J]. Science Technology and Engineering, 2025 , 25 (21) : 8871 -8878 . DOI: 10.12404/j.issn.1671-1815.2406349
正文
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随着页岩气的开发,水平井压裂投产[1-2] 的模式被广泛应用,大大提高了页岩气井的工业气流,但单井产量递减快是开发过程中必须面对的现实问题[3-4]。因此排水采气工艺成为气井稳产的重要手段,而井筒气液流动规律和油管下深是排采效果的重要影响因素,使得如何准确分析、评估井筒内流体的流动规律成为国内外工程界和学术界的关注焦点和研究重点[5-8]。
目前中外对这两方面的研究通常从物理模拟、数值计算和数值模拟3个方面开展,其中物理模拟是以室内气液两相流动实验为指导的研究方法,数值计算是基于最小压降理论,用多相管流压降公式进行评价的研究方法[9-10],数值模拟是运用商业软件对井筒内流体的流动进行模拟的研究方法。李朋等[11]基于质量、动量和能量守恒定律考虑井斜角影响以及硫的气液固3种相态特征,建立高含硫气藏气井井筒压力、温度和硫析出预测模型,对于井筒压力和硫析出规律影响因素研究。王贵生等[12]通过搭建可视化垂直管流实验,揭示泡沫排水井井筒压降规律及携液规律及起泡剂对于气液两相流型特征及流型转化条件的影响。何志国等[13]通过计算流体动力学(computational fluid dynamics,CFD)仿真技术,通过井筒建模,研究了起伏结构水平段全井筒持液率曲线出现不同程度的波动现象。王松等[14]通过OLGA软件建立油气井模型,模拟了井筒内流体温度、压力、产量等关键参数,通过规避天然气水合物和蜡沉积风险,设计井下安全阀下入深度。黄全华等[15]认为气井携液能力的因素依次为油管内径、井底流压、井斜角、井底温度,通过开展水平井模拟正交实验,修正了液滴模型并建立了新的临界携液流量图版。李丽等[16]通过实验研究在不同完井方式下水平井井筒气水的流动规律,分析了套管固井完井和套管不固井完井方式中井筒各部分流动的差异性和特点,该过程没有考虑井身结构问题。
鉴于深层页岩气井的全生命周期内气液流动问题目前研究相对较少,为了研究深层页岩气井不同影响因素下的的生产情况,现采用数值模拟的方法对井筒内气液流动规律进行研究,探究深层页岩气井的流动规律及后期积液情况。国外计算流体力学和工艺计算软件的发展,产生了很多瞬态模拟软件,OLGA软件是国际上普遍认可且计算结果较好的瞬态模拟软件,故采用OLGA建立深层页岩气井气液两相流动的物理模型。提出合理的油管下入位置,并将其与常规页岩气井的生产进行对比分析。
1 气井生产动态模型
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为了明确深层页岩气井井筒流体的流动规律,模拟选择OLGA软件中的Well Liquid Loading模块开展研究。首先采用PVTsim软件制作天然气的tab组分文件,其中真实气体的状态方程为SRK(Soave-Redlich-Kwong);然后选用扩展的双流体模型作为模拟计算的数学模型,基于同一平台的两种不同井身轨迹数据构建页岩气水平井的物理模型;最后依据W气田实际生产数据设定模拟所需的边界和初始条件。
1.1 数学模型
多相流模型一般包括流形模型、均相流模型、分相流模型、漂移流模型、双流体模型等。其中双流体模型以各守恒方程为基础且适用于各种流型。包括气相、液膜相以及气相中所夹带的液滴三相,现采用扩展的双流体模型进行模拟计算。
1.2 物理模型
1.2.1 井身轨迹
由于目前中国水平页岩气井居多,且水平段包括上翘和下倾两类,在页岩气生产中,下入速度管柱生产是比较经济有效的措施。选择页岩气田同一平台上不同井身轨迹的水平井A1、B1,根据其测井数据构建水平段上翘和水平段下倾两种不同的井身结构,并设置不同油管位置参数,如图1所示。
1.2.2 完井方式
为了研究油管不同下入深度时井筒气液的流动规律[17],在构建的井筒中,分别建立油管下入到垂直段、造斜段、水平段跟端、水平段1/3处、水平段2/3处和水平段趾端6种不同油管下深时的物理模型,分别模拟深井和常规井在水气比0.000 775时的气液流动情况。
1.2.3 产能方程
无论是水平段上翘或是水平段下倾,为了便于对积液规律进行对比分析,选取相同的气井产能方程[式(1)]进行数值模拟。
$P_{\mathrm{R}}^{2}-P_{\mathrm{wf}}^{2}=0.62 Q_{\mathrm{g}}+1.42 \times 10^{-7} Q_{\mathrm{g}}^{2}$
式(1)中:PR为平均地层压力,MPa;Pwf为平均井底流动压力,MPa;Qg为日产气量,m3/d。
1.2.4 边界和初始条件
W页岩气田A1、B1井的储层和生产参数如表1所示。
OLGA软件模拟设置DTPLOT为100 s。网格划分最小管段长度为50 m,最大管段长度为500 m。时间迭代步长取0.01 s,最大时间迭代步长和最小时间迭代步长分别取100 s和0.001 s。
2 深层页岩气井生产动态模拟研究
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2.1 模型合理性验证
模拟过程中将页岩气的开发过程视为衰竭式的开采过程,生产过程中储层压力的变化通过地层压力随着生产时间的降低来反映,其中忽略水平段流体流入位置、储层渗透率变化以及解吸附等影响因素造成的影响[18]。地层压力随时间下降梯度为0.06 MPa/d时得到拟合结果表明,软件模拟结果与实际生产数据的变化趋势基本一致,如图2所示。
由于实际生产时间较长,如果按照实际情况进行模拟,模拟一种工况时间需要较长的时间。为了加快模拟时间,把所有模拟过程中的地层压力随时间的下降梯度增加24倍至0.06 MPa/h。由表2可知,数值模拟的结果与实际误差在10%范围内。因此,后面通过缩短时间进行模拟具有一定的合理性和可行性。
2.2 流动状态分析
OLGA认为两种基本的流型:分离流和分散流,前者细分为分层流和环空流,后者细分为分散气泡流和段塞流,如图3所示。
气井井筒内气液流动动态特征的研究是评价气井生产效果的重要环节[19],因此对于产水气井携液以及后期积液情况的模拟尽可能考虑与实际情况相一致。对于前期气井生产,在非水平段流体一般在环状流状态下流动,在水平段位置气液流动呈现分层流动,如图4、图5所示。由于水平段倾斜角度的差异,不同井身轨迹的页岩气中流体在水平段产生不同的流动形态和变化,油管尺寸的大小也会造成气液流动的差异,因此采用管径分别为60、67、73 mm的油管进行动态模拟。
如图4所示,对于水平段上翘井A1,当采用不同油管尺寸时,在生产前、中、后阶段时会表现出不同的流动状态。随着油管尺寸逐渐变小,使得气体流速增大,在生产的各个阶段变化不大,其中由于流动方向及重力的因素,在水平段呈现分层流动,而在造斜段及以上位置呈现环状流。当油管尺寸逐渐增大时,气体流速变小,在生产的各个阶段在造斜段不同位置处出现段塞流,到后期由于水平段积液的原因,液多气少时出现气泡流。
如图5所示,对于水平段下倾的B1井,由于在水平部分气液流动方向与重力方向相反,使得流体刚流入井筒时就已经有能量损耗。因此,当3种不同管径的油管在中后期生产时在水平段会出现段塞流的流态,并且随着管径的减小,液相所占的份额比气相更大,更容易出现泡状流。
对于水平段上翘井A1和水平段下倾井B1,当生产进入中后期时在造斜段位置附近处出现段塞流,最易在造斜段发生积液[20]。这是由于随着井口生产压力逐渐降低,井筒各段的流态发生变化,当井筒中的气液混合流体在上升过程中出现段塞流的时候,井筒中出现一段液一段气的情况,当液柱在上升过程中能量不足时会产生滑脱损失,逐渐积累在井底位置,并随着井底回压逐渐增加,又一轮的段塞流产生,积液被带出井口,伴随着井底压力下降,液柱又一次回落在井底位置[21-22]。产生段塞流的根本原因是地层压力的下降。当液相充满整个油管时,气相会进入液相发生泡状流,两种井身结构的深井均会在造斜点附近产生泡状流,气泡的产生是由于液柱高度增加使得井底背压增大,液相中的气体为挣脱束缚而形成的。两种不同井身轨迹井的不同点在于,水平段上翘井只在造斜段出现段塞流;但是对于水平段下倾井来说,此时在水平段也会产生段塞流的情况。
2.3 临界携液流量分析
临界携液流量是气体将井底液体完全带出地面所需的气流量,通常以直径最大的液滴能够被连续带出的气流量为标准,当气相流速超过这一临界值时,气井能够连续带液生产,如果气相流速低于这一临界值,气体将缺乏足够的能量将液体携带至地面,增加了井底积液的风险[23-24]。
如图6、图7所示,通过对油管下入不同位置时和不同油管管径下的临界携液[25]分析,发现油管下入深度对于临界携液流量的影响因素较小,而油管尺寸对于临界携液流量有较大影响,且随着油管尺寸的减小所需临界携液流量越小,更易携带液体。这是由于随着流体流通截面减小,气体流速增加,能够携带更多的液体。
2.4 页岩气组分因素分析
由于不同区块的页岩气成分的差异性,使得在气井生产过程产生多方面的影响。页岩气的组分会影响其热值,较高的甲烷含量通常意味着较高的热值,而较高的重烃(如乙烷、丙烷)含量则可能带来额外的经济价值。如果气体中含有较多的轻烃,可能会提高总产量和经济效益。如果页岩气中含有较高的二氧化碳(CO2)或硫化氢(H2S),则可能导致管道和设备的腐蚀问题[26]。不同组分的气体在井筒和管道中的流动特性可能不同,影响到压降和流动阻力。较高的重烃含量可能增加流动阻力。
如表3所示,采用3种页岩气组分,分别模拟气井生产过程。图8为不同页岩气组分下在不同油管下入位置处的产量变化。
如图8所示,轻烃含量越高,对应的产量也就越高,这是由于轻烃的分子量和密度更低,在储层中更容易迁移并聚集成气相,增加了气体流动的驱动力,从而流体在井筒中更容易流动。低黏度减少了流动阻力,并且轻烃能够降低液相的表面张力,从而提高流体流动效率。
2.5 产气量分析
随着油管下入井筒深度的增加,流体流经通道的尺寸变小,提高了气井携液能力的同时也会造成沿程摩阻的增加[27-28],使得油管深度的差别导致油管和套管内的流体流速、压力和温度的变化。对于常规井和深井中构建的6种不同油管下深物理模型的模拟结果如图9和图10所示。
随着油管下入深度的增加,累计产量均呈下降趋势,但是油管在水平段位置对产量的影响较大。对于水平段上翘的深井A1来说,随着油管下入深度的增加,积液越迟,这是由于油管下入深度增加,使得流体通过的过流面积减小,导致气体流速增加,使得气体的临界携液流量变小,从而使积液时间变缓。对于水平段下倾深井B1,随着油管下入深度的增加,积液时间先增加后减小,曲线在水平段1/3处存在极大值,油管下至垂直段最易发生积液。因此,对于深层页岩气井,从累计产气量角度考虑,两种井身轨迹中油管应下入垂直段;从积液时间考虑,水平段上翘井油管应下入趾端,水平段下倾井油管应下入水平段1/3处;从累计产量与积液综合考虑,两种井身轨迹气井油管下入跟端最有利于生产。
对于深井A1、B1积液规律的不同之处在于:对于水平段上翘的深井A1,积液时间随着油管下入深度的增加而推迟;而对于水平段下倾的深井B1,并不是油管下入越深越有利于延缓积液,而是从垂直段到水平段1/3位置处,井筒开始积液时间先逐渐变大,而后从水平段1/3位置处到趾端位置,井筒积液时间随着油管深度的增加又逐渐提前。其中在1/3处为最不容易发生积液位置。积液规律的相同之处在于:油管下入垂直段时均易发生积液。从产量分析,水平段上翘深井明显优于水平段下倾深井,这是由于无论油管位于哪个位置,水平段上翘深井均有相对较高产量且正常生产时间较长积液较迟。因此,采用水平段上翘的气井开采生产较为经济。
为了便于将深层和常规页岩气井的积液规律进行对比分析,在深层页岩气井身轨迹的基础上,通过将垂直段减少1 000 m构建常规页岩气水平井的井身结构。通过模拟常规井和深井在同一类型井身轨迹下的气液流动情况,得出了井深影响下的产量和井筒积液变化规律,其中深井产量均比常规井高且正常生产时间更长,分析原因是由于深井地层温度和压力增加,而气体在产出过程中也有膨胀能,随着深度的增加,气体的膨胀能增加也越多,另外气体的流速也越大,能更好地携带液体[29],使得井筒不容易积液,因此增加了气井生产时间。
如图9和图10所示,通过比较水平段上翘时的常规井和深井,可以发现当油管下入垂直段至水平段跟端位置处时常规井和深井在产量变化不一致,其中常规井随着油管下入深度的增加产量也随之增加,深井随着油管深度的增加产量随之减小,二者变化趋势正好相反。当油管下入水平段跟端至趾端位置处时常规井和深井在产量变化一致,并随着油管下入深度的增加,产量随之减小。在积液方面,常规井和深井变化趋势一致。随着油管下入深度的增加,越不容易发生积液。但是不同之处在于从造斜段至趾端位置二者变化幅度不一样,深井油管下入深度对于积液时间的影响比常规井积液时间随油管下深的影响大。
通过比较水平段上翘时的常规井和深井, 可以发现随着油管下入深度的增加,两种井产量随井深变化趋势一致,均是先减后增再减。区别在于常规井在水平段1/3处产量最大,深井在垂直段产量最大。在积液方面,常规井和深井变化趋势一致,变化趋势为先增后减。不同之处在于常规井油管下入水平段2/3处不容易发生积液,当油管下入越深,受油管下深的影响越小;在深井油管位于水平段1/3处最不易发生积液,油管下入水平段1/3以下位置,积液变化较大。
3 结论
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在前人研究的基础上,通过瞬态模拟的方法,对水平段上翘和水平段下倾两种深层页岩气井油管下入不同位置条件下的气液流动规律进行研究,进而对油管下深问题进行优化研究,并得出以下结论。
(1)水平段正常生产时流态为分层流,垂直段部分流态为环状流。当水平段上翘时,流体易在造斜段附近出现段塞流;水平段下倾时,在水平段及造斜段附近出现段塞流,在生产后期积液严重时出现泡状流。水平段下倾的深层页岩气井更容易发生积液。从产量和积液综合考虑建议两种井身轨迹油管均下入水平段跟端位置。
(2)随着油管尺寸的减小,产量越小,对应气体的临界携液流量也越小。页岩气组分中轻烃的含量越大,气体产量随之增大。
(3)对于常规页岩气井,油管最优下入位置为水平段跟端和水平段1/3处,从生产和积液情况考虑,水平段上翘井优于水平段下倾井,深层页岩气井相比于常规页岩气井产量更高且不易积液。
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2025年第25卷第21期
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doi: 10.12404/j.issn.1671-1815.2406349
  • 接收时间：2024-08-23
  • 首发时间：2026-01-13
  • 出版时间：2025-07-28
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  • 收稿日期：2024-08-23
  • 修回日期：2025-04-15
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    长江大学石油工程学院, 武汉 430100

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* 刘捷(1979—),男,汉族,湖北广水人,博士,副教授。研究方向:油气田开发工程。E-mail:。
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2种不同金属材料的力学参数
科
Family		 属数
Number of
genus		 种数
Number of
species		 占总种数比例
Percentage of
total species (%)		 属
Genus		 种数
Number of
species		 占总种数比例
Percentage of total
species (%)
鹅膏菌科Amanitaceae 2 11 5.26 鹅膏菌属 Amanita 10 4.78
小菇科 Mycenaceae 2 12 5.74 丝盖伞属 Inocybe 5 2.39
多孔菌科 Polyporaceae 8 14 6.70 蜡蘑属 Laccaria 5 2.39
红菇科 Russulaceae 3 23 11.00 小皮伞属 Marasmius 6 2.87
小菇属 Mycena 11 5.26
光柄菇属 Pluteus 5 2.39
红菇属 Russula 17 8.13
栓菌属 Trametes 5 2.39
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