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Article(id=1322941955126211398, tenantId=1146029695717560320, journalId=1322258508890079423, issueId=1322941718441623734, articleNumber=null, orderNo=null, doi=10.13809/j.cnki.cn32-1825/te.2025051, pmid=null, cstr=null, oa=null, hot=null, price=null, onlineType=0, articleFormat=0, articleType=null, articleTypeStr=null, receivedDate=1745510400000, receivedDateStr=2025-04-25, revisedDate=null, revisedDateStr=null, acceptedDate=null, acceptedDateStr=null, onlineDate=1793343541175, onlineDateStr=2026-10-30, pubDate=1779724800000, pubDateStr=2026-05-26, doiRegisterDate=null, doiRegisterDateStr=null, onlineIssueDate=1793343541175, onlineIssueDateStr=2026-10-30, onlineJustAcceptDate=null, onlineJustAcceptDateStr=null, onlineFirstDate=null, onlineFirstDateStr=null, sourceXml=null, magXml=null, createTime=1793343541175, creator=13701087609, updateTime=1793343541175, updator=13701087609, issue=Issue{id=1322941718441623734, tenantId=1146029695717560320, journalId=1322258508890079423, year='2026', volume='16', issue='3', pageStart='489', pageEnd='736', issueExtLink='null', onlineDate='null', pubDate='1779724800000', pubDateStr='2026-05-26', beforeIssueId=null, nextIssueId=null, price=null, status=1, issueComplete=1, articleOrder=1, issueType=-1, specialIssue=null, createTime=1793343484745, creator='13701087609', updateTime=1793344165564, updator='13701087609', preIssue=null, nextIssue=null, articleTotal=null, ext={EN=IssueExt(id=1322944574066402279, tenantId=1146029695717560320, journalId=1322258508890079423, issueId=1322941718441623734, language=EN, specialIssueTitle=, coverIllustrator=null, specialIssueEditor=, specialIssueAbout=), CN=IssueExt(id=1322944574070596584, tenantId=1146029695717560320, journalId=1322258508890079423, issueId=1322941718441623734, language=CN, specialIssueTitle=, coverIllustrator=null, specialIssueEditor=, specialIssueAbout=)}, issueFiles=null, downloadFileDto=null}, startPage=675, endPage=683, ext={EN=ArticleExt(id=1322941955344315207, articleId=1322941955126211398, tenantId=1146029695717560320, journalId=1322258508890079423, language=EN, title=Inversion method for fiber optic monitoring of two-phase flow production profiles in horizontal wells, columnId=1322941693024141328, journalTitle=Petroleum Reservoir Evaluation and Development, columnName=Oil and Gas Development, runingTitle=null, highlight=

Distributed temperature sensing (DTS) technology is widely applied in intelligent monitoring of production dynamics in oil and gas wells. To address the challenges in quantitatively analyzing oil-water two-phase flow profile in horizontal wells, a temperature profile prediction model applicable to oil-water two-phase flow in horizontal wells was constructed, comprehensively considering multiple micro-thermal effects, including the Joule-Thomson effect. Simulation and sensitivity analyses of the temperature profile of a reservoir horizontal well were conducted. Meanwhile, the particle swarm optimization (PSO) algorithm was used to establish a DTS data inversion model, innovatively enabling the inversion of multi-dimensional unknown downhole parameters based on a single DTS data source, thereby achieving a quantitative interpretation of the oil-water two-phase flow production profile in horizontal wells. The results showed that: (1) The main influencing factors of the temperature profile in oil-water two-phase horizontal wells, ranked by impact degree from high to low, were single-well production (Q)> permeability (k)> water cut (FW)> wellbore radius (Rw)> crude oil density (ρo)> damage zone radius (Rd)> reservoir thermal conductivity (Kt). (2) Single-well production, permeability, and water cut were the key dominant factors affecting the temperature profile. When inverting measured DTS data, formation permeability could be prioritized as the core target parameter for inversion, and secondary factors could be set as fixed values or assigned reasonable ranges to simplify the problem. (3) By using the PSO inversion model to invert the DTS temperature data of the field well, the production positions of the two-phase fluids could be accurately identified. The interpreted liquid production profile obtained from inversion showed high consistency with field production logging tool (PLT) test results, with a mean absolute error of the average liquid production per section of less than 10%, fully verifying the reliability of the PSO inversion model. Future research can focus on enhancing the model’s depiction of complex flows and expand toword multiphase flow application.

, articleAbstract=null, authors=HANLAN XIONG1, HONGWEN LUO1, HAITAO LI1, WENBIN AI2, YANI HUANG1, JIALIN MA1, BINGQI CHEN1, FEIFEI RAN1, XIAOYI PAN1, authorsList=HANLAN XIONG, HONGWEN LUO, HAITAO LI, WENBIN AI, YANI HUANG, JIALIN MA, BINGQI CHEN, FEIFEI RAN, XIAOYI PAN, authorCompany=null, correspAuthors=HONGWEN LUO, 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, fund=null), CN=ArticleExt(id=1322941958179664726, articleId=1322941955126211398, tenantId=1146029695717560320, journalId=1322258508890079423, language=CN, title=水平井两相流产出剖面光纤监测反演方法, columnId=1322941693259022355, journalTitle=油气藏评价与开发, columnName=油气开发, runingTitle=null, highlight=

分布式光纤温度传感（Distributed Temperature Sensing，DTS）技术在油气井生产动态的智能化监测中应用广泛。针对水平井油水两相流产出剖面定量解析难题，本文构建了综合考虑焦耳-汤姆逊效应（Joule-Thomson effect）等多种微热效应、适用于水平井油水两相流的温度剖面预测模型，并对某油藏中的水平井温度剖面进行了模拟与敏感性分析。同时，本文采用粒子群优化（Particle Swarm Optimization，PSO）算法建立了DTS数据反演模型，创新性地实现了基于单一DTS数据源的井下多维未知参数反演，进而完成水平井两相流产出剖面的定量解释。研究表明：①油水两相流水平井温度剖面主要影响因素及其影响程度排序为，单井产量（Q）>渗透率（k）>含水率（Fw）>井筒半径（Rw）>原油密度（ρo） >伤害带半径（Rd）>储层导热系数（Kt）；②单井产量、渗透率和含水率是影响温度剖面的关键主导因素，在对实测DTS数据进行反演时，可优先将地层渗透率作为核心目标参数进行反演，次要因素可设定为固定值或合理范围以简化问题；③利用PSO反演模型对现场井DTS温度数据进行反演，能够精准识别两相流体的产出位置，反演得到的产液剖面解释结果与现场生产测井（PLT）测试结果高度吻合，各产出段平均产液量的平均绝对误差低于10%，充分验证了PSO反演模型的可靠性。未来可从提升模型对复杂流动的刻画精度、拓展至多相流等方向深入研究。

, articleAbstract=null, authors=熊瀚澜1, 罗红文1, 李海涛1, 艾文斌2, 黄雅妮1, 马佳林1, 陈柄杞1, 冉飞飞1, 潘晓艺1, authorsList=熊瀚澜, 罗红文, 李海涛, 艾文斌, 黄雅妮, 马佳林, 陈柄杞, 冉飞飞, 潘晓艺, authorCompany=null, correspAuthors=罗红文, authorNote=

熊瀚澜（2001—），男，在读硕士研究生，主要从事井下分布式光纤监测解释及物理模拟实验方向的研究。地址：四川省成都市新都区新都大道8号，邮政编码：610500。E-mail：

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罗红文（1990—），男，博士，讲师，硕士研究生导师，主要从事油气井分布式光纤监测（DTS/DAS/DSS）解释、注采动态评价及完井优化方面的研究工作。地址：四川省成都市新都区新都大道8号，邮政编码：610500。E-mail：
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熊瀚澜（2001—），男，在读硕士研究生，主要从事井下分布式光纤监测解释及物理模拟实验方向的研究。地址：四川省成都市新都区新都大道8号，邮政编码：610500。E-mail：

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熊瀚澜（2001—），男，在读硕士研究生，主要从事井下分布式光纤监测解释及物理模拟实验方向的研究。地址：四川省成都市新都区新都大道8号，邮政编码：610500。E-mail：

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Horizontal well production profile interpretation based on distributed temperature sensing[D]. Chengdu: Southwest Petroleum University, 2016., articleTitle=Horizontal well production profile interpretation based on distributed temperature sensing, refAbstract=null), Reference(id=1322941967235167150, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, doi=null, pmid=null, pmcid=null, year=2024, volume=null, issue=null, pageStart=null, pageEnd=null, url=null, language=null, rfNumber=2, rfOrder=2, authorNames=DENG R, ZHANG L, WANG L, journalName=null, refType=null, unstructuredReference=DENG R, ZHANG L, WANG L, et al. 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Geophysics, 2007, 72(2): F75-F83., articleTitle=Particle swarm optimization: A new tool to invert geophysical data, refAbstract=null)], funds=null, companyList=[AuthorCompany(id=1322941958443905879, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, xref=1, ext=[AuthorCompanyExt(id=1322941958456488792, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, companyId=1322941958443905879, language=EN, country=null, province=null, city=null, postcode=null, companyName=null, departmentName=null, remark=1 State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation , Southwest Petroleum University, Chengdu, Sichuan 610500, China), AuthorCompanyExt(id=1322941958464877401, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, companyId=1322941958443905879, language=CN, country=null, province=null, city=null, postcode=null, companyName=null, departmentName=null, remark=1　西南石油大学油气藏地质及开发工程全国重点实验室，四川　 　成都　 　610500)]), AuthorCompany(id=1322941958557152090, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, xref=2, ext=[AuthorCompanyExt(id=1322941958569735003, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, companyId=1322941958557152090, language=EN, country=null, province=null, city=null, postcode=null, companyName=null, departmentName=null, remark=2 PetroChina Changqing Oilfield Company, Shaanxi, Xi’an 710021, China), AuthorCompanyExt(id=1322941958578123612, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, companyId=1322941958557152090, language=CN, country=null, province=null, city=null, postcode=null, companyName=null, departmentName=null, remark=2　中国石油长庆油田分公司，陕西　 　西安　 　710021)])], figs=[ArticleFig(id=1322941963615482774, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=EN, label=Fig.1, caption=Schematic diagram of box-shaped oil reservoir horizontal well structure, figureFileSmall=Bra6vVb2M+BqvE19z0iIgg==, figureFileBig=9jifn2aHtoYgaWJfN3GlCQ==, tableContent=null), ArticleFig(id=1322941963699368855, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=CN, label=图1, caption=箱型油藏水平井结构示意图, figureFileSmall=Bra6vVb2M+BqvE19z0iIgg==, figureFileBig=9jifn2aHtoYgaWJfN3GlCQ==, tableContent=null), ArticleFig(id=1322941963934249880, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=EN, label=Fig.2, caption=Schematic diagram of fluid flow within horizontal wellbore, figureFileSmall=YbwPaSkqK5wgnAbfSFBkKg==, figureFileBig=aXL0jVm/fktxghYYaVtJjQ==, tableContent=null), ArticleFig(id=1322941964060079001, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=CN, label=图2, caption=水平井井筒内流体流动示意图

注：R为井筒半径，单位m；θ为井筒与垂直方向的夹角，单位（°）。

, figureFileSmall=YbwPaSkqK5wgnAbfSFBkKg==, figureFileBig=aXL0jVm/fktxghYYaVtJjQ==, tableContent=null), ArticleFig(id=1322941964135576474, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=EN, label=Fig.3, caption=Solution process of oil-water two-phase temperature profile prediction model for horizontal well, figureFileSmall=3mL3A+xy8CTuDQsLLeBWNQ==, figureFileBig=A8UM3sH5xeHGQuYzHJX+Sg==, tableContent=null), ArticleFig(id=1322941964206879643, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=CN, label=图3, caption=水平井油水两相流温度剖面预测模型求解流程

注：t为时间，单位min；t0为0次迭代的时间步长；tmax为允许的最大时间步长；Twb为井筒的温度，单位℃； n为第n次迭代；下标k为第k次计算更新的井筒温度剖面；ε为设定可接受的最大误差值；Y为判断成立；N为判断条件不成立。

, figureFileSmall=3mL3A+xy8CTuDQsLLeBWNQ==, figureFileBig=A8UM3sH5xeHGQuYzHJX+Sg==, tableContent=null), ArticleFig(id=1322941964278182812, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=EN, label=Fig.4, caption=Inversion interpretation process of production profile of oil-water two-phase flow in horizontal well, figureFileSmall=+CKGas0Qslso7Mc3mtrujw==, figureFileBig=BOQLVqVemO8PjIMh+hQ8uw==, tableContent=null), ArticleFig(id=1322941964341097373, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=CN, label=图4, caption=油水两相流水平井产出剖面反演解释流程

注：I为初始粒子群中的粒子总数量；c1为个体加速常数；c2为群体加速常数；T*为最大迭代次数；xi(t)为第t次迭代优化中第i个粒子的位置；vi(t)为第t次迭代优化中第i个粒子的速度；xi(t+1)为第t+1次迭代优化中第i个粒子的位置；vi(t+1)第t+1次迭代优化中第i个粒子的速度；Γxi(t)为经过t次迭代优化后第i个粒子的适应度值；Γxi(t+1)为经过t+1次迭代优化后第i个粒子的适应度值；pi(t)为第t次迭代优化中第i个粒子的个体极值；pi(t+1)为第t+1次迭代优化中第i个粒子的个体极值；g(t)为第t次迭代优化中粒子群的全局极值；g(t+1)为第t+1次迭代优化中粒子群的全局极值。

, figureFileSmall=+CKGas0Qslso7Mc3mtrujw==, figureFileBig=BOQLVqVemO8PjIMh+hQ8uw==, tableContent=null), ArticleFig(id=1322941964416594846, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=EN, label=Fig.5, caption=Measured DTS data of well X1, figureFileSmall=9Etm6JoDtZrwNnIgppVDgw==, figureFileBig=97K+0vabpHmjOmUCM0QZDg==, tableContent=null), ArticleFig(id=1322941966052373407, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=CN, label=图5, caption=X1井实测DTS数据, figureFileSmall=9Etm6JoDtZrwNnIgppVDgw==, figureFileBig=97K+0vabpHmjOmUCM0QZDg==, tableContent=null), ArticleFig(id=1322941966148842400, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=EN, label=Fig.6, caption=Inversion fitting results of DTS data, figureFileSmall=as0VfjxJInHKQ3OwOdgM3g==, figureFileBig=S/4qUJctPGdgoXxfJotG6Q==, tableContent=null), ArticleFig(id=1322941966220145569, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=CN, label=图6, caption=DTS数据反演拟合结果, figureFileSmall=as0VfjxJInHKQ3OwOdgM3g==, figureFileBig=S/4qUJctPGdgoXxfJotG6Q==, tableContent=null), ArticleFig(id=1322941966320808866, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=EN, label=Fig.7, caption=Inversion interpretation results of well X1, figureFileSmall=a2d2Iq/OrnzG67rtTXsjoA==, figureFileBig=hA1NGE38UsXD9UPAPZMdnA==, tableContent=null), ArticleFig(id=1322941966396306339, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=CN, label=图7, caption=X1井反演解释结果, figureFileSmall=a2d2Iq/OrnzG67rtTXsjoA==, figureFileBig=hA1NGE38UsXD9UPAPZMdnA==, tableContent=null), ArticleFig(id=1322941966475998116, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=EN, label=Table 1, caption=Basic parameters of horizontal well, figureFileSmall=null, figureFileBig=null, tableContent=
储层参数数值井筒参数数值流体物性数值
储层深度/m3 000水平井长度/m1 000原油密度/(kg/m3)950
水平渗透率/10-3 μm2200井筒直径/m0.24原油黏度/(mPa·s)22
垂向渗透率/10-3 μm220套管外径/m0.177 8原油热容/[J/(kg·K)]2 000
孔隙度/%18套管内径/m0.159 4原油膨胀系数/(10-4/K)4
饱和度0.2井壁粗糙度/m0.000 1原油体积系数/(m3/m3)1.37
供给半径/m500套管导热系数/[W/(m·K)]53原油热导率/[W/(m·K)]0.14
地面温度/℃20水泥环导热系数/[W/(m·K)]0.933地层水密度/(kg/m3)1 001
地温梯度/(℃/m)0.03储层岩石热力学参数/[W/(m·K)]2.5地层水黏度/(mPa·s)0.14
储层温度/℃50岩石密度/(kg/m3)2 377地层水热容/[J/(kg·K)]4 234
地层压力/MPa12岩石热容/[J/(kg·K)]845地层水热膨胀系数/(10-4/K)2.02
产层数量10总导热系数/W/(m·K)4.46地层水体积系数/(m3/m3)1.02
), ArticleFig(id=1322941966543106981, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=CN, label=表1, caption=

水平井基础参数

, figureFileSmall=null, figureFileBig=null, tableContent=
储层参数数值井筒参数数值流体物性数值
储层深度/m3 000水平井长度/m1 000原油密度/(kg/m3)950
水平渗透率/10-3 μm2200井筒直径/m0.24原油黏度/(mPa·s)22
垂向渗透率/10-3 μm220套管外径/m0.177 8原油热容/[J/(kg·K)]2 000
孔隙度/%18套管内径/m0.159 4原油膨胀系数/(10-4/K)4
饱和度0.2井壁粗糙度/m0.000 1原油体积系数/(m3/m3)1.37
供给半径/m500套管导热系数/[W/(m·K)]53原油热导率/[W/(m·K)]0.14
地面温度/℃20水泥环导热系数/[W/(m·K)]0.933地层水密度/(kg/m3)1 001
地温梯度/(℃/m)0.03储层岩石热力学参数/[W/(m·K)]2.5地层水黏度/(mPa·s)0.14
储层温度/℃50岩石密度/(kg/m3)2 377地层水热容/[J/(kg·K)]4 234
地层压力/MPa12岩石热容/[J/(kg·K)]845地层水热膨胀系数/(10-4/K)2.02
产层数量10总导热系数/W/(m·K)4.46地层水体积系数/(m3/m3)1.02
), ArticleFig(id=1322941966614410150, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=EN, label=Table 2, caption=Basic parameters of each section of horizontal well, figureFileSmall=null, figureFileBig=null, tableContent=
产层序号顶深/m底深/m渗透率/10-3 μm2孔隙度/%含水饱和度平均压力/MPa
13 0003 10050120.219.7
23 1003 200100130.419.7
33 2003 300500110.319.7
43 3003 400200130.319.7
53 4003 500400130.319.7
63 5003 6001 000130.319.7
73 6003 700400130.319.7
83 7003 800800130.319.7
93 8003 90050130.319.7
103 9004 000500130.319.7
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水平井各层段基础参数

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产层序号顶深/m底深/m渗透率/10-3 μm2孔隙度/%含水饱和度平均压力/MPa
13 0003 10050120.219.7
23 1003 200100130.419.7
33 2003 300500110.319.7
43 3003 400200130.319.7
53 4003 500400130.319.7
63 5003 6001 000130.319.7
73 6003 700400130.319.7
83 7003 800800130.319.7
93 8003 90050130.319.7
103 9004 000500130.319.7
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因素名Q/（m3/d）k/10-3 μm2Kt/[W/(m·K)]Fwρo/（kg/m3）Rw/mRd/m
水平110030030.17500.100
水平230040040.28500.141.5
水平350050050.39500.182.0
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正交试验分析因素及其取值水平设计

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因素名Q/（m3/d）k/10-3 μm2Kt/[W/(m·K)]Fwρo/（kg/m3）Rw/mRd/m
水平110030030.17500.100
水平230040040.28500.141.5
水平350050050.39500.182.0
), ArticleFig(id=1322941966878651306, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=EN, label=Table 4, caption=Schemes and results of orthogonal experiments, figureFileSmall=null, figureFileBig=null, tableContent=
试验编号QkRwFwKtρoRd平均温度差/℃
1水平1水平1水平1水平1水平1水平1水平12.578 8
2水平1水平2水平2水平2水平2水平2水平22.924 0
3水平1水平3水平3水平3水平3水平3水平33.159 4
4水平2水平1水平1水平2水平2水平3水平33.018 3
5水平2水平2水平2水平3水平3水平1水平13.238 0
6水平2水平3水平3水平1水平1水平2水平23.959 3
7水平3水平1水平2水平1水平3水平2水平33.882 6
8水平3水平2水平3水平2水平1水平3水平14.344 7
9水平3水平3水平1水平3水平2水平1水平23.395 9
10水平1水平1水平3水平3水平2水平2水平12.975 6
11水平1水平2水平1水平1水平3水平3水平22.776 2
12水平1水平3水平2水平2水平1水平1水平32.923 2
13水平2水平1水平2水平3水平1水平3水平23.255 0
14水平2水平2水平3水平1水平2水平1水平33.756 9
15水平2水平3水平1水平2水平3水平2水平13.181 0
16水平3水平1水平3水平2水平3水平1水平24.086 8
17水平3水平2水平1水平3水平1水平2水平33.353 8
18水平3水平3水平2水平1水平2水平3水平14.199 0
均值12.8913.0513.3003.5253.4043.3323.420
均值23.4013.4053.3993.4153.3783.3793.400
均值33.8773.7143.4713.2303.3873.4593.351
极差0.9860.6630.1990.2950.0250.1270.101
), ArticleFig(id=1322941966954148779, tenantId=1146029695717560320, journalId=1322258508890079423, articleId=1322941955126211398, language=CN, label=表4, caption=

正交试验方案及试验结果

, figureFileSmall=null, figureFileBig=null, tableContent=
试验编号QkRwFwKtρoRd平均温度差/℃
1水平1水平1水平1水平1水平1水平1水平12.578 8
2水平1水平2水平2水平2水平2水平2水平22.924 0
3水平1水平3水平3水平3水平3水平3水平33.159 4
4水平2水平1水平1水平2水平2水平3水平33.018 3
5水平2水平2水平2水平3水平3水平1水平13.238 0
6水平2水平3水平3水平1水平1水平2水平23.959 3
7水平3水平1水平2水平1水平3水平2水平33.882 6
8水平3水平2水平3水平2水平1水平3水平14.344 7
9水平3水平3水平1水平3水平2水平1水平23.395 9
10水平1水平1水平3水平3水平2水平2水平12.975 6
11水平1水平2水平1水平1水平3水平3水平22.776 2
12水平1水平3水平2水平2水平1水平1水平32.923 2
13水平2水平1水平2水平3水平1水平3水平23.255 0
14水平2水平2水平3水平1水平2水平1水平33.756 9
15水平2水平3水平1水平2水平3水平2水平13.181 0
16水平3水平1水平3水平2水平3水平1水平24.086 8
17水平3水平2水平1水平3水平1水平2水平33.353 8
18水平3水平3水平2水平1水平2水平3水平14.199 0
均值12.8913.0513.3003.5253.4043.3323.420
均值23.4013.4053.3993.4153.3783.3793.400
均值33.8773.7143.4713.2303.3873.4593.351
极差0.9860.6630.1990.2950.0250.1270.101
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水平井两相流产出剖面光纤监测反演方法
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熊瀚澜 1 , 罗红文 1 , 李海涛 1 , 艾文斌 2 , 黄雅妮 1 , 马佳林 1 , 陈柄杞 1 , 冉飞飞 1 , 潘晓艺 1
油气藏评价与开发 | 油气开发 2026,16(3): 675-683
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水平井两相流产出剖面光纤监测反演方法
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熊瀚澜（2001—），男，在读硕士研究生，主要从事井下分布式光纤监测解释及物理模拟实验方向的研究。地址：四川省成都市新都区新都大道8号，邮政编码：610500。E-mail：

"}, bioImg=null, bioContent=

熊瀚澜（2001—），男，在读硕士研究生，主要从事井下分布式光纤监测解释及物理模拟实验方向的研究。地址：四川省成都市新都区新都大道8号，邮政编码：610500。E-mail：

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熊瀚澜1 , 罗红文1, 李海涛1, 艾文斌2, 黄雅妮1, 马佳林1, 陈柄杞1, 冉飞飞1, 潘晓艺1
作者信息
  • 1　西南石油大学油气藏地质及开发工程全国重点实验室，四川　 　成都　 　610500
  • 2　中国石油长庆油田分公司，陕西　 　西安　 　710021
通讯作者:
罗红文（1990—），男，博士，讲师，硕士研究生导师，主要从事油气井分布式光纤监测（DTS/DAS/DSS）解释、注采动态评价及完井优化方面的研究工作。地址：四川省成都市新都区新都大道8号，邮政编码：610500。E-mail：
作者简介:

熊瀚澜（2001—），男，在读硕士研究生，主要从事井下分布式光纤监测解释及物理模拟实验方向的研究。地址：四川省成都市新都区新都大道8号，邮政编码：610500。E-mail：

Inversion method for fiber optic monitoring of two-phase flow production profiles in horizontal wells
HANLAN XIONG1 , HONGWEN LUO1, HAITAO LI1, WENBIN AI2, YANI HUANG1, JIALIN MA1, BINGQI CHEN1, FEIFEI RAN1, XIAOYI PAN1
Affiliations
  • 1 State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation , Southwest Petroleum University, Chengdu, Sichuan 610500, China
  • 2 PetroChina Changqing Oilfield Company, Shaanxi, Xi’an 710021, China
出版时间: 2026-05-26 doi: 10.13809/j.cnki.cn32-1825/te.2025051
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产出剖面  /  反演方法  /  分布式光纤传感  /  粒子群优化算法  /  两相流水平井  /  敏感性分析
production profile  /  inversion method  /  distributed temperature sensing  /  particle swarm optimization algorithm  /  two-phase flow in horizontal well  /  sensitivity analysis
熊瀚澜, 罗红文, 李海涛, 艾文斌, 黄雅妮, 马佳林, 陈柄杞, 冉飞飞, 潘晓艺. 水平井两相流产出剖面光纤监测反演方法. 油气藏评价与开发, 2026 , 16 (3) : 675 -683 . DOI: 10.13809/j.cnki.cn32-1825/te.2025051
HANLAN XIONG, HONGWEN LUO, HAITAO LI, WENBIN AI, YANI HUANG, JIALIN MA, BINGQI CHEN, FEIFEI RAN, XIAOYI PAN. Inversion method for fiber optic monitoring of two-phase flow production profiles in horizontal wells[J]. Petroleum Reservoir Evaluation and Development, 2026 , 16 (3) : 675 -683 . DOI: 10.13809/j.cnki.cn32-1825/te.2025051
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光纤测量技术与智能完井技术作为石油工程领域的两大创新力量，正深刻改变着油气勘探与开发的传统模式，并推动井下温度监测领域催生出多项创新技术与设备。例如，分布式光纤温度传感（DTS）可实现对油气井井筒温度分布的实时监测，进而用于评估裂缝发育状况、获取作业参数等关键信息。其显著优势在于强大的长距离监测能力：通过对水平井温度和压力分布的直接测量，结合反演算法，能有效重建水平井的产出剖面，获取生产动态信息，并准确预测生产指标[1-2]。基于对水平井井筒温度预测模型的深入研究，结合对DTS实时测量的温度数据进行解释，可实现对井筒内流体流动特征的定量分析[3-6]。
在水平井温度剖面预测方面，众多学者以传统直井温度模型[7-9]为基础进行深入拓展，取得了显著进展。YOSHIOKA等[10]提出了一种油藏水平井的稳态温度模型，该模型融合了焦耳-汤姆逊效应、热对流与热传导等多重机制。该模型经过不断发展与完善，被用于求解水平井内的温度与压力分布，并定位油井中气、水的流入位置[11-12]。冯晓炜等[13]基于Levenberg-Marquardt（L-M）算法，构建了压裂水平井温度数据反演的模型。ZHAO等[14]建立了一个完全耦合的井筒-储层模型，并提出了热-嵌入式离散压裂模型和离散井筒模型，用于研究复杂压裂裂缝网络中的流体流动和热传导特性。ZHANG等[15]结合快速行进法（FMM）正演模型和包含初始评估等步骤的反演过程，解决了水平井多级压裂处理中井下温度测量数据的定量解释问题，但该方法对初始猜测的依赖性较强且存在非唯一解。综上所述，当前分布式光纤监测技术在产出剖面解释领域的应用研究多聚焦于气井；相比之下，针对油藏水平井，特别是涉及两相流（如油水两相流）的水平井产出剖面解释研究则相对有限。在油水两相流的水平井中，温度剖面受多种因素综合影响，解释复杂度显著增加。此外，实际两相流水平井中待反演的未知参数通常构成1个m×n维矩阵，这种多维特性使得传统方法（如L-M算法）难以有效实现基于DTS的自适应反演。目前，尚缺乏能够同时定量反演油水两相流水平井多维未知参数的有效方法。针对多维参数自适应反演问题，WU等[16]创新性地引入粒子群优化（PSO）算法，通过改进其寻优机制实现了多个参数同步反演，成功获取了纵波速率、横波波速和介质密度这3个表征储层含油气性的核心物性指标；MA等[17]则将PSO算法拓展至测井曲线解析领域，其构建的智能反演模型结果与实测数据高度吻合。结合罗红文等[18]的研究，可见PSO算法在处理多变量优化方面具有较强的适用性。
本文综合考虑焦耳-汤姆逊效应、热对流、热传导及井筒摩擦生热等关键物理机制，建立了水平井油水两相流温度剖面预测模型。在正演模型基础上，利用PSO算法构建了基于DTS数据的反演模型，进而提出了一套水平井两相流产出剖面的光纤监测反演方法。该方法经现场应用，成功实现了对产出剖面、产水量、含水率和渗透率等关键参数的定量反演。
1　油水两相流水平井温度剖面预测模型
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温度预测模型由油藏模型和井筒模型构成（图1）。油藏模型基于质量守恒定律描述油藏内部流体流动以及油藏与井筒间的流体交换；井筒模型则基于能量守恒定律，分析井筒内的热传递过程。通过耦合求解建立的油藏模型和井筒模型，可获得水平井油水两相流的温度剖面[19]。
1.1　油藏模型
1.1.1　油藏渗流模型
通过多相流体渗流达西定律[20]，可以得到油、水两相渗流的基本微分方程为：
∇⋅ρokkroμo∇po-ρog∇D=∂∂tφρoSo
∇⋅ρwkkrwμw∇pw-ρwg∇D=∂∂tφρwSw
式中：∇为散度算子，单位m-1；ρo、ρw分别为油相密度、水相密度，单位kg/m3；φ为孔隙度，%；t为时间，单位s；k为地层渗透率，单位10-3 μm2；kro、krw分别为油相对渗透率、水相相对渗透率；μo、μw分别为油相动力黏度、水相动力黏度，单位mPa·s；po、pw分别为油相压强、水相压强，单位MPa；g为重力加速度，单位m/s2；D为深度，单位m；So、Sw分别为油相饱和度、水相饱和度，%。
消去饱和度随时间的变化项得到油、水两相的渗流模型[1]为：
1ρo∇⋅ρokkroμo∇po-ρog∇D+1ρw∇⋅ρwkkrwμw∇pw-ρwg∇D=∂φ∂t-φSoCo∂po∂t+SwCw∂pw∂t
式中：Co、Cw分别为油压缩系数、水压缩系数，单位MPa-1。
边界条件：
pG=fp(x,y,z,t)
∂p∂nG=fq(x,y,z,t)
∂p∂nG=0
r∂p∂rr=rw=qμ2πkh
pr=rw=pwfx,y,z,t
式中： p为油藏流体压力，单位MPa；下标G为油藏边界；fp为边界定压函数；n为边界G的外法线方向；pwf为给出的井底压力，单位MPa；r为径向坐标（到井轴距离），单位m；rw为井眼半径，单位m；h为油层厚度，单位m； q为地下流量，单位m3/s；μ为流体黏度，单位MPa·s；x、y、z为空间坐标。
1.1.2　储层热学模型
忽略动能的变化，在油藏控制体积内能量变化量可表示为：
ΔQ=φ∑iρiSiUi+gD+1-φρr(Ur+gD)tt+dt⋅V
式中：Q为系统吸收的热量，单位J；ρi为第i种流体的密度，单位kg/m3；Si为第i种流体的饱和度，%；Ui为第i种流体的单位质量内能，单位J/kg；V为控制总体积，单位m3；ρr为岩石密度，单位kg/m³；Ur为岩石的单位质量内能，单位J/kg。
下角标i为流体各相根据焓和内能的定义，整理即可得到油藏温度方程为：
-∑iφρiSiCpi+(1-φ)ρrCpr∂T∂t+∑iφρiSiCpiβiT∂pi∂t=∑iρiui⋅Cpi∇T+∑iui⋅∇pi-∑iρiCpiβiTui⋅∇pi+∑iρigui-∇⋅λ∇T
式中：Cpi为第i种流体的比热容，单位J/（kg·K）；Cpr为岩石的比热容，单位J/（kg·K）；βi为第i种流体的体积压缩系数，单位MPa-1；λ为导热系数，单位W/（m·K）；T为温度，单位℃；ui为第i种流体的渗流速度，单位m/s；∇pi为第i种流体的压力梯度，单位MPa/m。
式（10）中等式左端第一项是能量变化项，第二项是由压力随时间变化所引起的热膨胀项；等式右端第一项是热对流项，第二项是黏性耗散项，第三项是由压力随空间位置变化所引起的热膨胀项，第四项是势能变化项，第五项是热传导项。
1.2　井筒模型
1.2.1　流动模型
井筒内任意微元段的流体流动如图2所示：
井筒中的流动模型为：
dρivihidx=2γρi,Ivi,Ihi,IR
式中：R为井筒半径，单位m；vi为流体沿井筒轴线方向的渗流速度，单位m/s；ρi，I为流体从油藏流入井筒时的密度，单位kg/m3；vi，I为流体从油藏流入井筒时的径向速度，单位m/s；γ为径向流入的效率因子；hi，I为流体从油藏流入井筒时的相持率。
1.2.2　热学模型
井筒热学模型为：
dTdx=ρvCpKJTTρvCpTdpdx+2αT,IRρvCpTTI-T-ρvTρvCpTgsinθ
式中：KJT为焦耳-汤姆逊系数，单位℃/MPa；αT，I为井筒内流体与地层之间的总传热系数，单位W/（m·K）；θ为流动方向与水平面的夹角，单位（°）；TI为流体从油藏流到井壁时得流入温度，单位℃；下标T为井筒内多相流体的加权平均值。
1.3　油藏与井筒热学模型耦合及求解
1.3.1　耦合模型
在耦合油藏温度模型与井筒温度模型时，由于井筒直径远小于模型网格尺寸，数值模型难以表征网格与井筒之间的流动关系。这种尺度差异导致井筒内的流动特征无法被网格充分捕捉，进而影响数值模拟的精度，因此，引入等效特征位置作为二者之间的连接纽带。为了求解流入温度，需要作出以下假设：
1） 网格内的油藏温度和压力作用于等效特征位置。
2） 同一网格中的渗透率计算公式为：
k'=ky⋅kz
式中：k'为网格等效渗透率，单位10-3 μm2；ky为y方向主渗透率，单位10-3 μm2；kz为z方向主渗透率，单位10-3 μm2。
3） 流体从等效特征位置到井筒中的流动为径向流。
4） 相同数值模拟时间步长内，压力和温度视为处于稳态条件。
5） 相同数值模拟时间步长内，流体性质和饱和度视为恒定。
6） 不计毛管力和重力的干扰。
则井筒的耦合热学模型：
λr2d2Tdr2+C1rdTdr-C2T+C3=0
式中：C1为径向热对流强度系数；C2为热交换能力系数；C3为常数热源项。
1.3.2　模型求解
采用有限差分法编程迭代求解温度预测模型，即可获得油藏水平井油水两相流温度剖面，井筒温度方程、油藏温度方程和流入温度方程是相互耦合的且方程是非线性的，所以这些方程需要迭代求解，模型求解流程如图3所示，由于非等温渗流，流体物性不能视为常数，在迭代计算过程中，还需要对流体物性参数进行修正。
2　油水两相流水平井温度剖面影响规律分析
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通过上述温度剖面预测模型，对两相流水平井进行分析，并结合正交试验方法，完成油水两相流水平井温度剖面的敏感性分析，得出影响温度剖面的关键因素，为后续反演工作奠定基础。模拟计算所用基础参数如下表1所示，假设该井套管固井完井，各层段基础物性如表2所示。
选取单井产量（Q）、渗透率（k）、储层总导热系数（Kt）、储层平均含水率（Fw）、原油密度（ρo）、井筒半径（Rw）和伤害带半径（Rd）这7个对温度剖面产生直接影响的因素开展如表3所示的正交分析试验，L18（37）的正交表如表4所示，以地温剖面与井筒温度剖面的温差作为正交试验的分析指标。
基于极差分析法，确定各因素对两相流水平井温度剖面影响权重的次序为： 单井产量>渗透率>含水率>井筒半径>原油密度>伤害率半径>储层热导系数，其中单井产量、渗透率和含水率是影响两相流水平井温度剖面的关键参数，而单井产量可通过井口直接测量。因此，在后续两相流产出剖面反演过程中，选取渗透率和含水率作为目标参数xinverm×n。
3　水平井两相流产出剖面反演解释模型
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DTS温度数据反演解释模型主要包括误差函数和反演模型。误差函数用于衡量模拟计算值与实际观测值之间的偏差，而反演模型则是对迭代过程中目标参数值进行不断修正，逐步缩小模拟值与实测值之间的误差，直至误差达到收敛条件。
3.1　误差函数
定义误差函数式为：
Γxinverm×n=trTinver¯-TDTS¯Tinver¯-TDTS¯T
式中：Γ为误差函数，单位℃2；xinverm×n为待反演的目标参数（m×n维矩阵），单位℃；tr为算子符号；TDTS¯为实测的DTS温度均值向量，单位℃；Tinver¯为将xinverm×n代入温度预测模型后进行反演模拟所得到的温度均值向量，单位℃；上标T为残差向量的转置。
在井筒压力的约束下，确保误差函数达到迭代终止条件：
Γxinverm×n<ε'
式中：ε'为迭代终止阈值表示反演结果与观测数据的偏差可接受的最大值。
3.2　DTS数据反演模型
采用PSO算法[18]实现DTS数据的自适应反演，以定量解释井下未知参数（包括水平井的产量、储层渗透率及含水率）。
PSO算法原理：存在一个m×n维的解空间，解空间中存在一个粒子群P，包含I个随机分布的粒子，每个粒子初始速度和初始位置均随机生成于解空间内，在第t次迭代（t=1，2，…I）T*为总迭代次数时，定义第i个粒子的位置的状态矩阵为[21]：
xi(t)=xi,1,1(t), xi,1,2(t), ⋯, xi,1,m(t)xi,2,1(t), xi,2,2(t), ⋯, xi,2,m(t)  ⋮     ⋮   ⋱    ⋮   xi,n,1(t), xi,n,2(t), ⋯, xi,n,m(t)
式中：xi(t)为第t次迭代优化中第i个粒子的位置；t为迭代次数；i为粒子索引；m、n为问题维度。
定义在t次迭代优化中第i个粒子的速度的状态矩阵为：
vi(t)=vi,1,1(t), vi,1,2(t), ⋯, vi,1,m(t)vi,2,1(t), vi,2,2(t), ⋯, vi,2,m(t)  ⋮     ⋮   ⋱    ⋮   vi,n,1(t), vi,n,2(t), ⋯, vi,n,m(t)
式中：vi(t)为第t次迭代优化中第i个粒子的速度矩阵。
定义在t次迭代优化中第i个粒子找到的最优解的状态矩阵，即该粒子的个体极值为：
pi(t)=pi,1,1(t), pi,1,2(t), ⋯, pi,1,m(t)pi,2,1(t), pi,2,2(t), ⋯, pi,2,m(t)  ⋮     ⋮    ⋱    ⋮   pi,n,1(t), pi,n,2(t), ⋯, pi,n,m(t)
式中： pi(t)为第t次迭代优化中第i个粒子的个体极值。
定义在t次迭代优化中粒子群P找到的最优解的状态矩阵，即该粒子群的全局极值为：
g(t)=g1,1(t), g1,2(t), ⋯, g1,m(t)g2,1(t), g2,2(t), ⋯, g2,m(t) ⋮    ⋮   ⋱   ⋮   gn,1(t), gn,2(t), ⋯, gn,m(t)
式中：g(t)为第t次迭代优化中粒子群的全局极值。
粒子依据自身的运动轨迹以及群体中其他成员的位置和速度信息，动态调整其在解空间中的搜索方向和步长，其速度的更新方式为：
vi(t+1)=wvi(t)+c1r1pi(t)-xi(t)+c2r2g(t)-xi(t)
w=wmax-tT*wmax-wmin
式中：vi(t+1)为第i个粒子在第t+1次迭代中的速度矩阵；c1、c2为加速常数，反映了粒子对个体经验和群体经验的学习速率；r1、r2分别为个体极值和全局极值的影响度扰动因子；w为惯性权重参数；wmax为惯性权重的初始最大值，通常取0.9；wmin为惯性权重的最终最小值，通常取0.4。
在每次迭代过程中，粒子根据其当前速度和位置信息进行动态调整，以优化其在解空间中的位置分布，具体更新公式为：
xi(t+1)=xi(t)+vi(t)
3.3　产出剖面解释流程
在采用粒子群优化算法对分布式光纤温度传感器（DTS）数据进行反演的过程中，可将粒子群P中的I个粒子的初始位置和速度分别设定为待反演目标参数的起始值，以及每次迭代中目标参数的修正量，并将误差函数式（15）作为适应度函数。具体步骤如下：
1） 初始化参数：设定一个包含I个粒子的粒子群P，定义c1和c2为个体加速常数和群体加速常数，定义T*为最大迭代次数，适应度函数选用式（15）。
2） 粒子群初始化：定义粒子群P由I个具有初始位置和初始速度的粒子组成，粒子群P中粒子的位置xi(t)设定为适应度函数中的参数xinverm×n（m×n维矩阵）；粒子的速度vi(t)设定为xinverm×n的修正量Δxm(t)（m×n维矩阵）。将xi(t)代入温度正演预测模型，通过适应度函数确定每个粒子的个体极值pi(t)和粒子群P的全局极值g(t)。
3） 更新粒子状态和极值：利用式（21）和式（23）修正每个粒子的速度vi(t+1)和位置xi(t+1)，将修正后每个粒子的位置xi(t+1)代入温度正演预测模型，并通过适应度函数重新确定每个粒子的适应度值，如果粒子i在新位置xi(t+1)上的pi(t+1)优于pi(t)，则更新pi(t)；同理，若g(t+1)优于g(t)，则更新g(t)。
4） 终止条件判断：重复执行步骤（2）至步骤（3）。如果迭代次数 t 达到设定的最大值，则终止迭代；或者，如果找到全局最优适应度值（即该值使得误差函数满足公式（16）），则终止迭代。
算法具体流程图如下所示：
4　现场应用
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4.1　X1井基本情况及光纤监测情况
X1井为中国某油田的一口水平井，完钻井深为3 908 m。原始地层压力为23.1 MPa、地层温度为103.3 ℃。储层孔隙度为0.21，非均质性较强，水平井段渗透率介于（10~357）×10-3 μm2，根据测井曲线解释，水平段被划分为6个产层段。根据完井设计，各产层射孔位置位于3 288、3 405、3 483、3 571、3 682、3 812 m附近。该井投产后，含水率呈逐步上升趋势。分布式光纤测温期间，全井段温度剖面监测对应的产液量约为320 m3/d，含水率约40%，为现场测得的DTS数据（图5）。
4.2　X1井产出剖面解释
X1井在DTS测试期间，为了获取较为准确的地温剖面，进行了约48 h的关井，测得了较为稳定的DTS数据。
采用上述反演模型对X1井稳定生产时段的DTS数据进行反演。如图6所示，温度反演模拟结果与现场实测DTS数据总体拟合良好，各产出层段的温度误差均满足收敛精度要求。该井产出剖面的反演解释结果如图7所示。结果显示：反演解释的产液剖面与现场生产测井（PLT）测试结果一致性较好，各产出段产液量的绝对误差均小于6.13 m³/d，相对误差均小于10%（图7a）。图7b展示了各层段的产水量解释结果。可以看出，该井产水主要来源于靠近跟端的井段，靠近趾端的产水量相对较低，这与该井实际的底水脊进特征相符。基于反演解释的各段产液量和产水量，计算得出水平井段各分段的含水率（图7c）。结果显示，反演解释的含水率与PLT测试结果的相对误差均小于15%。通过DTS数据反演获得的储层渗透率解释结果如图7d所示。对比表明，反演解释的渗透率与测井解释的渗透率总体较为接近，进一步验证了PSO模型的可靠性。
5　结论
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1） 建立了油水两相流水平井温度剖面预测模型，综合考虑了焦耳-汤姆逊效应、摩擦生热等热力学效应。通过油藏-井筒耦合求解，该模型既可预测不同开发条件下的温度剖面，也可作为分布式温度传感数据反演的正演基础模型。
2） 油水两相流水平井温度剖面的主控因素（按影响程度降序排列）：单井产量>渗透率>含水率>井筒半径>原油密度>伤害带半径>储层导热系数。
3） 单井产量、渗透率和含水率是影响温度剖面的主要因素。在基于实测DTS数据反演时，可在已知产量与含水率的条件下，将地层渗透率作为目标反演参数。
4） 基于粒子群优化算法的DTS温度反演结果表明：温度拟合结果符合收敛精度要求；产液剖面反演结果与PLT测试一致性高，各段产液量平均绝对误差<10%；渗透率反演结果与测井解释值吻合良好，验证了PSO反演模型的可靠性。
5） 反演模型创新实现了基于单一DTS数据源的井下多维未知参数的定量解释，但尚未涵盖页岩气、稠油开发等复杂地质环境及含气多相流场景，未来可以从提升模型对复杂流动的刻画精度、拓展至多相流等方向深入研究。

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2026年第16卷第3期
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doi: 10.13809/j.cnki.cn32-1825/te.2025051
  • 接收时间：2025-04-25
  • 首发时间：2026-10-30
  • 出版时间：2026-05-26
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  • 收稿日期：2025-04-25
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    1　西南石油大学油气藏地质及开发工程全国重点实验室，四川　 　成都　 　610500
    2　中国石油长庆油田分公司，陕西　 　西安　 　710021

通讯作者:

罗红文（1990—），男，博士，讲师，硕士研究生导师，主要从事油气井分布式光纤监测（DTS/DAS/DSS）解释、注采动态评价及完井优化方面的研究工作。地址：四川省成都市新都区新都大道8号，邮政编码：610500。E-mail：
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