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Article(id=1149769464427753835, tenantId=1146029695717560320, journalId=1146123166801305609, issueId=1149769458706723113, articleNumber=null, orderNo=null, doi=10.12404/j.issn.1671-1815.2405037, pmid=null, cstr=null, oa=null, hot=null, price=null, onlineType=0, articleFormat=0, articleType=null, articleTypeStr=null, receivedDate=1720108800000, receivedDateStr=2024-07-05, revisedDate=1740499200000, revisedDateStr=2025-02-26, acceptedDate=null, acceptedDateStr=null, onlineDate=1752056002002, onlineDateStr=2025-07-09, pubDate=1747497600000, pubDateStr=2025-05-18, doiRegisterDate=null, doiRegisterDateStr=null, onlineIssueDate=1752056002002, onlineIssueDateStr=2025-07-09, onlineJustAcceptDate=null, onlineJustAcceptDateStr=null, onlineFirstDate=null, onlineFirstDateStr=null, sourceXml=null, magXml=null, createTime=1752056002002, creator=13701087609, updateTime=1752056002002, updator=13701087609, issue=Issue{id=1149769458706723113, tenantId=1146029695717560320, journalId=1146123166801305609, year='2025', volume='25', issue='14', pageStart='5705', pageEnd='6154', issueExtLink='null', onlineDate='null', pubDate='null', beforeIssueId=null, nextIssueId=null, price=null, status=1, issueComplete=1, articleOrder=1, issueType=-1, specialIssue=0, createTime=1752056000638, creator=13701087609, updateTime=1768456798957, updator=13701087609, preIssue=null, nextIssue=null, ext={EN=IssueExt(id=1218559392753041779, tenantId=1146029695717560320, journalId=1146123166801305609, issueId=1149769458706723113, language=EN, specialIssueTitle=, coverIllustrator=, specialIssueEditor=, specialIssueAbout=), CN=IssueExt(id=1218559392753041780, tenantId=1146029695717560320, journalId=1146123166801305609, issueId=1149769458706723113, language=CN, specialIssueTitle=, coverIllustrator=, specialIssueEditor=, specialIssueAbout=)}, issueFiles=null}, startPage=5830, endPage=5839, ext={EN=ArticleExt(id=1149769464754909560, articleId=1149769464427753835, tenantId=1146029695717560320, journalId=1146123166801305609, language=EN, title=The Characteristics of Relative Permeability Curves in the Development of Heavy Oil Reservoirs Using Supercritical Multi-thermal Fluid, columnId=1156262729003422020, journalTitle=Science Technology and Engineering, columnName=Papers·Petroleum and Natural Gas Industry, runingTitle=null, highlight=null, articleAbstract=

The performance of supercritical multi-thermal fluid injection in heavy oil reservoirs is markedly superior to that of steam flooding. However, the underground seepage law of injecting supercritical multi-thermal fluid is not yet clear. Therefore, the “high-temperature and high-pressure steady-state method” was proposed to test the oil-water and oil-gas relative permeability curves at different temperatures. The viscosity of produced heavy oil and the contact angle between oil sand and water at different temperatures were tested, and finally, combined with the oil-water, oil-gas relative permeability and Stone-Ⅱ prediction model, the isoperms of oil phase relative permeability in different hot areas during three-phase seepage were obtained. The results show that after the action of supercritical water on heavy oil, the measured viscosity of produced heavy oil decreased by 31.03% at 50 ℃ compared to steam, and the contact angle between oil sand and water decreased from 139.5° to 100.9°, indicating that the wetting properties of the oil sand develop towards a water-wet direction. Compared with the relative permeability of oil phase, the relative permeability of water phase is very small, and the characteristic value of oil-water relative permeability curve changes gradually and then suddenly at supercritical temperature. The relative permeability of oil-gas increases gradually with the increase of temperature. In the isoperms of oil phase relative permeability, the area of the oil flow zone expanded as temperatures rose, and under supercritical conditions, the flow zone area grew to 54.59%, highlighting a significant enhancement in oil-phase flow capacity. The research results of this paper can provide theoretical basis for the seepage mechanism and numerical simulation of supercritical multi-thermal fluid injected in heavy oil reservoirs.

, correspAuthors=Wen-de YAN, 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=Ming-da DONG, Yu GAO, Wen-de YAN, Zhi-lin QI, Ying-zhong YUAN, Jie TIAN, Jin-gang FU, Jin-mei PENG, Xiao LING), CN=ArticleExt(id=1149769506286908039, articleId=1149769464427753835, tenantId=1146029695717560320, journalId=1146123166801305609, language=CN, title=稠油油藏注超临界多元热流体开发相渗曲线特征, 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=稠油油藏注超临界多元热流体开发效果明显优于蒸汽驱,但目前注超临界多元热流体地下渗流规律尚不明确。为此,通过“高温高压稳态法”得出不同温度下油-水、油-气相对渗透率曲线,并测试不同温度下油-水相对渗透率实验的采出稠油黏度及油砂与水的接触角,最后结合油-水、油-气两相相对渗透率和Stone-Ⅱ预测模型得出三相渗流时不同热区的油相等渗图。结果表明,稠油经超临界水作用后,测得的采出稠油黏度在50 ℃时相比于蒸汽减少了31.03%,油砂与水的接触角从139.5°降低至100.9°,油砂润湿性向亲水方向发展。相比于油相相对渗透率,水相相对渗透率极小,油-水相对渗透率曲线特征值随温度的升高先逐渐变化,后在超临界时发生突变;油气相对渗透率随温度的升高而逐渐增大。在油相等渗图中,随着温度的升高,油相流动区面积逐渐增大,超临界时流动区面积增加到54.59%,油相流动能力显著增强。研究结果可为稠油油藏注超临界多元热流体在储层中的渗流机理和数值模拟提供理论依据。, correspAuthors=严文德, authorNote=null, correspAuthorsNote=
*严文德(1979—),男,汉族,四川成都人,博士,教授。研究方向:油气藏工程、油气藏流体相态及渗流理论。E-mail:。
, copyrightStatement=null, copyrightOwner=null, extLink=null, articleAbsUrl=null, sourceXml=YewVzY9Ir5rE1EkyKg9Etw==, magXml=ebvasZAcaLkryZzDqkIvtw==, pdfUrl=null, pdf=HJc7pklpzdB2W6lD8yu/Sg==, pdfFileSize=null, pdfExtLink=null, richHtmlUrl=null, mobilePdfUrl=null, reviewReport=null, pdfFirstPage=null, abstractGraph=null, abstractGraphContent=null, abstractVideo=null, citation=null, cebUrl=null, magXmlContent=p6Hiw3U7HMvgp58O9RvN4w==, mapNumber=null, authorCompany=null, fund=null, authors=

董明达(1991—),男,汉族,黑龙江哈尔滨人,博士,副教授。研究方向:低渗油藏提高采收率。E-mail:。

, authorsList=董明达, 高宇, 严文德, 戚志林, 袁迎中, 田杰, 付金刚, 彭金梅, 凌霄)}, authors=[Author(id=1172984511714439752, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, orderNo=0, firstName=null, middleName=null, lastName=null, nameCn=null, orcid=null, stid=null, country=null, authorPic=null, dead=0, email=475582944@qq.com, emailSecond=null, emailThird=null, correspondingAuthor=0, authorType=1, ext={EN=AuthorExt(id=1172984511777354314, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, authorId=1172984511714439752, language=EN, stringName=Ming-da DONG, firstName=Ming-da, middleName=null, lastName=DONG, prefix=null, suffix=null, authorComment=null, nameInitials=null, affiliation=null, department=null, xref=null, address=College of Oil and Gas Engineering, Chongqing University of Science and Technology, Chongqing 401331, China, bio=null, bioImg=null, bioContent=null, aboutCorrespAuthor=null), CN=AuthorExt(id=1172984511987069515, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, authorId=1172984511714439752, language=CN, stringName=董明达, firstName=null, middleName=null, lastName=null, prefix=null, suffix=null, authorComment=null, nameInitials=null, affiliation=null, department=null, xref=null, address=重庆科技大学石油与天然气工程学院, 重庆 401331, bio={"content":"

董明达(1991—),男,汉族,黑龙江哈尔滨人,博士,副教授。研究方向:低渗油藏提高采收率。E-mail:。

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董明达(1991—),男,汉族,黑龙江哈尔滨人,博士,副教授。研究方向:低渗油藏提高采收率。E-mail:。

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Journal of Xi'an Shiyou University(Natural Science Edition), 2019, 34(2): 73-77., articleTitle=Influence of diffusion on the relative permeability characteristics of CO2 flooding in low-permeability oil reservoirs, refAbstract=null)], funds=[Fund(id=1172984517229949601, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, awardId=52104025, language=CN, fundingSource=国家自然科学基金(52104025), fundOrder=null, country=null), Fund(id=1172984517326418594, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, awardId=U22B2074, language=CN, fundingSource=国家自然科学基金(U22B2074), fundOrder=null, country=null), Fund(id=1172984517376750243, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, awardId=CSTB2022NSCQ-MSX0858, language=CN, fundingSource=重庆市自然科学基金(CSTB2022NSCQ-MSX0858), fundOrder=null, country=null), Fund(id=1172984517456442020, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, awardId=cstc2022ycjh-bgzxm0055, language=CN, fundingSource=重庆市自然科学基金(cstc2022ycjh-bgzxm0055), fundOrder=null, country=null), Fund(id=1172984517502579365, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, awardId=KJQN202001508, language=CN, fundingSource=重庆市教委科学技术研究项目(KJQN202001508), fundOrder=null, country=null), Fund(id=1172984517661962918, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, awardId=YKJCX2320106, language=CN, fundingSource=重庆科技大学研究生创新计划(YKJCX2320106), fundOrder=null, country=null)], companyList=[AuthorCompany(id=1172984511613776452, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, xref=null, ext=[AuthorCompanyExt(id=1172984511622165061, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, companyId=1172984511613776452, language=EN, country=null, province=null, city=null, postcode=null, companyName=null, departmentName=null, remark=College of Oil and Gas Engineering, Chongqing University of Science and Technology, Chongqing 401331, China), AuthorCompanyExt(id=1172984511630553670, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, companyId=1172984511613776452, language=CN, country=null, province=null, city=null, postcode=null, companyName=null, departmentName=null, remark=重庆科技大学石油与天然气工程学院, 重庆 401331)])], figs=[ArticleFig(id=1172984514977608321, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, language=EN, label=Fig.1, caption=High temperature and pressure relative permeability curve test experimental equipment, figureFileSmall=3Dom9CNG0s7DqK6qsD/XGQ==, figureFileBig=4L3olORYZo0z9VBE78fIDg==, tableContent=null), ArticleFig(id=1172984515023745666, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, language=CN, label=图1, caption=高温高压相对渗透率曲线测试实验装置

1为注入泵;2为NaCl溶液储存器;3为超临界蒸汽发生器;4为非凝析气瓶;5为压力表;6为中间容器;7为稠油储存器;8为低温加热装置;9为温度控制器;10为高温加热装置;11为温度控制器(高温);12为沿程加热管线;13为温度探头;14为填砂管;15为回压阀;16为二通阀; 17为量筒;18为手摇泵

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lglgμ为黏度的双对数;lgT为绝对温度的对数

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Physical properties of oil sample

, figureFileSmall=null, figureFileBig=null, tableContent=
50 ℃下的参数 组分质量分数/%
黏度/
(mPa·s)		 密度/
(g·cm-3)		 饱和烃 芳香烃 胶质 沥青质
2 902.8 975.3 26.4 38.6 25.2 9.8
), ArticleFig(id=1172984516709855898, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, language=CN, label=表1, caption=

油样物性参数

, figureFileSmall=null, figureFileBig=null, tableContent=
50 ℃下的参数 组分质量分数/%
黏度/
(mPa·s)		 密度/
(g·cm-3)		 饱和烃 芳香烃 胶质 沥青质
2 902.8 975.3 26.4 38.6 25.2 9.8
), ArticleFig(id=1172984516781159067, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, language=EN, label=Table 2, caption=

Experimental scheme of relative permeability test

, figureFileSmall=null, figureFileBig=null, tableContent=
序号 类型 压力/
MPa		 温度/
℃		 序号 类型 压力/
MPa		 温度/
℃
1 油-水相对
渗透率		 16.5 150 8 油-气相对
渗透率		 16.5 150
2 16.5 200 9 16.5 200
3 16.5 250 10 16.5 250
4 16.5 300 11 16.5 300
5 16.5 350 12 16.5 350
6 22.5 400 13 22.5 400
7 22.5 420 14 22.5 420
), ArticleFig(id=1172984516848267932, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, language=CN, label=表2, caption=

相对渗透率测试实验方案

, figureFileSmall=null, figureFileBig=null, tableContent=
序号 类型 压力/
MPa		 温度/
℃		 序号 类型 压力/
MPa		 温度/
℃
1 油-水相对
渗透率		 16.5 150 8 油-气相对
渗透率		 16.5 150
2 16.5 200 9 16.5 200
3 16.5 250 10 16.5 250
4 16.5 300 11 16.5 300
5 16.5 350 12 16.5 350
6 22.5 400 13 22.5 400
7 22.5 420 14 22.5 420
), ArticleFig(id=1172984516911182493, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, language=EN, label=Table 3, caption=

Characteristic parameters of oil-water relative permeability curve at different temperatures

, figureFileSmall=null, figureFileBig=null, tableContent=
温度/
℃		 束缚水饱
和度/%		 残余油饱
和度/%		 残余油下水
相相渗		 等渗点含水
饱和度/%
150 25.5 24.8 0.010 5 72.8
200 25.3 23.5 0.011 5 73.4
250 25.1 22.9 0.012 5 74.6
300 24.9 21.1 0.014 6 76.8
350 24.6 19.5 0.017 9 78.2
400 24.1 7.5 0.022 7 89.3
420 23.8 6.9 0.023 5 90.3
), ArticleFig(id=1172984516982485662, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, language=CN, label=表3, caption=

不同温度下油-水相渗曲线特征参数

, figureFileSmall=null, figureFileBig=null, tableContent=
温度/
℃		 束缚水饱
和度/%		 残余油饱
和度/%		 残余油下水
相相渗		 等渗点含水
饱和度/%
150 25.5 24.8 0.010 5 72.8
200 25.3 23.5 0.011 5 73.4
250 25.1 22.9 0.012 5 74.6
300 24.9 21.1 0.014 6 76.8
350 24.6 19.5 0.017 9 78.2
400 24.1 7.5 0.022 7 89.3
420 23.8 6.9 0.023 5 90.3
), ArticleFig(id=1172984517045400223, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, language=EN, label=Table 4, caption=

Characteristic parameters of oil-gas relative permeability curves at different temperatures

, figureFileSmall=null, figureFileBig=null, tableContent=
温度/
℃		 残余油饱和度/
%		 残余油下气
相相渗		 等渗点相渗
150 59.2 0.174 0.089
200 58.8 0.183 0.098
250 57.9 0.195 0.117
300 56.8 0.207 0.129
350 55.6 0.220 0.142
400 53.1 0.246 0.153
420 52.4 0.255 0.161
), ArticleFig(id=1172984517104120480, tenantId=1146029695717560320, journalId=1146123166801305609, articleId=1149769464427753835, language=CN, label=表4, caption=

不同温度下油-气相渗曲线特征参数

, figureFileSmall=null, figureFileBig=null, tableContent=
温度/
℃		 残余油饱和度/
%		 残余油下气
相相渗		 等渗点相渗
150 59.2 0.174 0.089
200 58.8 0.183 0.098
250 57.9 0.195 0.117
300 56.8 0.207 0.129
350 55.6 0.220 0.142
400 53.1 0.246 0.153
420 52.4 0.255 0.161
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稠油油藏注超临界多元热流体开发相渗曲线特征
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董明达 , 高宇 , 严文德 * , 戚志林 , 袁迎中 , 田杰 , 付金刚 , 彭金梅 , 凌霄
科学技术与工程 | 论文·石油、天然气工业 2025,25(14): 5830-5839
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科学技术与工程 | 论文·石油、天然气工业 2025, 25(14): 5830-5839
稠油油藏注超临界多元热流体开发相渗曲线特征
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董明达 , 高宇, 严文德* , 戚志林, 袁迎中, 田杰, 付金刚, 彭金梅, 凌霄
作者信息
  • 重庆科技大学石油与天然气工程学院, 重庆 401331

    • 董明达(1991—),男,汉族,黑龙江哈尔滨人,博士,副教授。研究方向:低渗油藏提高采收率。E-mail:。

通讯作者:

*严文德(1979—),男,汉族,四川成都人,博士,教授。研究方向:油气藏工程、油气藏流体相态及渗流理论。E-mail:。
The Characteristics of Relative Permeability Curves in the Development of Heavy Oil Reservoirs Using Supercritical Multi-thermal Fluid
Ming-da DONG , Yu GAO, Wen-de YAN* , Zhi-lin QI, Ying-zhong YUAN, Jie TIAN, Jin-gang FU, Jin-mei PENG, Xiao LING
Affiliations
  • College of Oil and Gas Engineering, Chongqing University of Science and Technology, Chongqing 401331, China
出版时间: 2025-05-18 doi: 10.12404/j.issn.1671-1815.2405037
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摘要
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稠油油藏注超临界多元热流体开发效果明显优于蒸汽驱,但目前注超临界多元热流体地下渗流规律尚不明确。为此,通过“高温高压稳态法”得出不同温度下油-水、油-气相对渗透率曲线,并测试不同温度下油-水相对渗透率实验的采出稠油黏度及油砂与水的接触角,最后结合油-水、油-气两相相对渗透率和Stone-Ⅱ预测模型得出三相渗流时不同热区的油相等渗图。结果表明,稠油经超临界水作用后,测得的采出稠油黏度在50 ℃时相比于蒸汽减少了31.03%,油砂与水的接触角从139.5°降低至100.9°,油砂润湿性向亲水方向发展。相比于油相相对渗透率,水相相对渗透率极小,油-水相对渗透率曲线特征值随温度的升高先逐渐变化,后在超临界时发生突变;油气相对渗透率随温度的升高而逐渐增大。在油相等渗图中,随着温度的升高,油相流动区面积逐渐增大,超临界时流动区面积增加到54.59%,油相流动能力显著增强。研究结果可为稠油油藏注超临界多元热流体在储层中的渗流机理和数值模拟提供理论依据。
稠油油藏  /  超临界多元热流体  /  润湿性  /  水热裂解  /  相渗曲线  /  三相相对渗透率

The performance of supercritical multi-thermal fluid injection in heavy oil reservoirs is markedly superior to that of steam flooding. However, the underground seepage law of injecting supercritical multi-thermal fluid is not yet clear. Therefore, the “high-temperature and high-pressure steady-state method” was proposed to test the oil-water and oil-gas relative permeability curves at different temperatures. The viscosity of produced heavy oil and the contact angle between oil sand and water at different temperatures were tested, and finally, combined with the oil-water, oil-gas relative permeability and Stone-Ⅱ prediction model, the isoperms of oil phase relative permeability in different hot areas during three-phase seepage were obtained. The results show that after the action of supercritical water on heavy oil, the measured viscosity of produced heavy oil decreased by 31.03% at 50 ℃ compared to steam, and the contact angle between oil sand and water decreased from 139.5° to 100.9°, indicating that the wetting properties of the oil sand develop towards a water-wet direction. Compared with the relative permeability of oil phase, the relative permeability of water phase is very small, and the characteristic value of oil-water relative permeability curve changes gradually and then suddenly at supercritical temperature. The relative permeability of oil-gas increases gradually with the increase of temperature. In the isoperms of oil phase relative permeability, the area of the oil flow zone expanded as temperatures rose, and under supercritical conditions, the flow zone area grew to 54.59%, highlighting a significant enhancement in oil-phase flow capacity. The research results of this paper can provide theoretical basis for the seepage mechanism and numerical simulation of supercritical multi-thermal fluid injected in heavy oil reservoirs.

heavy oil reservoirs  /  supercritical multi-thermal fluid  /  wettability  /  pyrolysis  /  relative permeability curve  /  three-phase relative permeability
董明达, 高宇, 严文德, 戚志林, 袁迎中, 田杰, 付金刚, 彭金梅, 凌霄. 稠油油藏注超临界多元热流体开发相渗曲线特征. 科学技术与工程, 2025 , 25 (14) : 5830 -5839 . DOI: 10.12404/j.issn.1671-1815.2405037
Ming-da DONG, Yu GAO, Wen-de YAN, Zhi-lin QI, Ying-zhong YUAN, Jie TIAN, Jin-gang FU, Jin-mei PENG, Xiao LING. The Characteristics of Relative Permeability Curves in the Development of Heavy Oil Reservoirs Using Supercritical Multi-thermal Fluid[J]. Science Technology and Engineering, 2025 , 25 (14) : 5830 -5839 . DOI: 10.12404/j.issn.1671-1815.2405037
正文
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中国稠油资源丰富,主要分布在新疆、渤海和辽河等区域,目前稠油探明储量大约为82×108 t,稠油因黏度大、流动能力差等问题导致其动用程度较低[1-2]。近年来,将超临界水与稠油热采技术相结合,即注超临界多元热流体成为一种新的开采方式。超临界多元热流体的产生机理为以油田排出的有机废液为原料,在超临界水和特定的空气环境下气化并燃烧而形成[3]。因此,超临界多元热流体的使用不但降低了生产成本,还减少了油田加热蒸汽排放的CO2,保护环境。超临界多元热流体是由超临界水(温度在374 ℃以上,压力在22.1 MPa以上的水)、超临界N2和超临界CO2等组成的混合物,温度越高,超临界水占据的比例也越大[4-6]。其中,超临界水是超临界多元热流体的主要组成部分,也是主要的热源;超临界水通过大幅降低稠油的黏度来增强其流动能力,超临界水开采稠油具有很大的潜力[7-8]。超临界多元热流体中的超临界CO2和超临界水都能与稠油形成混相驱替,有效地减小了油水之间的界面张力[9];超临界N2的导热能力弱、溶解性差,能有效地减少注入介质的热损失,维持地层压力[10]。黄祖杰等[11]通过超临界多元热流体驱替实验发现,超临界多元热流体能显著增大温度的传播速度,热效率值比超临界水驱高16%;超临界多元热流体在驱替过程中具有混相驱替、气驱和热驱的特点,驱油效率高达95%。压力增大后,超临界多元热流体的溶解性增强,驱替过程中能形成较大的压差,稠油的流动性增强[12]。在此基础上,李晓宇等[13]通过超临界多元热流体驱油物理模拟研究发现,超临界多元热流体能显著抑制超覆现象、增加稠油流动能力以及与稠油发生混相反应等特点,因此超临界多元热流体驱的采收率比蒸汽驱高13.06%。文献[14-16]开展的岩心尺度驱替和吞吐实验表明,超临界多元热流体单井4轮次吞吐效率大于75%,相比于蒸汽超覆,超临界多元热流体超覆现象发生晚、时间短。总之,从前人对超临界多元热流体驱油的研究来看,超临界多元热流体是显著提高了热介质的驱油效率。
目前中外超临界多元热流体开采稠油的研究还处于初始阶段,其注入地层后的三相渗流规律尚不明确。为此,现利用“高温高压稳态法”获得不同温度下的油-水、油-气两相相对渗透率曲线,并通过测试不同温度下油-水两相相对渗透率实验的采出稠油黏度和油砂与水的接触角明确超临界水对油相相对渗透率产生的影响。最后,结合两相相对渗透率结果和Stone-Ⅱ预测模型得出三相渗流时油相相对渗透率曲线。以期为稠油油藏注超临界多元热流体在储层中的渗流机理和数值模拟研究提供理论依据。
1 超临界多元热流体相渗实验
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1.1 实验材料及装置
实验中所使用的原油和储层砂样均来自渤海某实际矿场区块,原油物性参数如表1所示。使用质量分数为0.5%的NaCl溶液作为地层水;实验用气是经过配比后的非凝析气,其中CO2的摩尔分数为15%,N2的摩尔分数为85%,纯度为99.99%,用于测量高温高压油气相渗曲线。
超临界多元热流体高温高压相对渗透率曲线测试实验装置如图1所示,主要由注入设备、填砂管模型、温度控制设备、压力检测设备和采出液计量装置等部分组成。其中,加热控制器由温度探头、低温和高温加热装置组成。此外,为了解决中间容器内的非凝析气和稠油不能加热到超临界温度的问题,使用高温加热箱加热沿程管线来确保整个实验过程满足超临界温度,并用保温棉进行包裹,提高实验精度。
1.2 实验方案
根据超临界多元热流体开采稠油过程中储层温度场的分布,将储层热区依次划分为超临界区、近临界区、亚临界区和过渡区,如图2所示。本次实验针对不同热区进行了温度的设置,通过不同温度下的相渗实验来获得注超临界多元热流体时储层中不同热区的相对渗透率曲线特征。测试不同温度下的油-水、油-气相对渗透率如表2所示。其中目标油藏地层压力为15.3 MPa,为了保证注入流体为气相形态,实验压力均维持在饱和蒸汽压以上。
1.3 实验方法
参照稠油油藏高温相对渗透率测定方法SY/T 6315—2017,本次实验采用恒温驱替的方式进行,驱替过程中要求填砂管温度与注入介质温度一致。考虑到超临界多元热流体是混合物,超临界水与原油、岩石颗粒发生反应,实验温度高造成油水乳化严重,影响计量的准确性。因此,设计了以“高温高压稳态法”为基础的稠油油藏注超临界多元热流体相对渗透率测试方法。实验中填砂管的渗透率为:2 400~2 500 mD,油-水/油-气相对渗透率测试步骤如下。
(1)连接实验设备并检查装置密封性,进行压力测试。
(2)将矿场砂装入填砂管,抽真空24 h后用自吸水方式饱和水。
(3)恒流法水测100%水相绝对渗透率,使填砂管的孔隙度和渗透率符合油藏要求。
(4)填砂管饱和油。打开低温加热装置,将稠油以低速注入填砂管,建立束缚水饱和度。
(5)用高温加热装置将填砂管加热到超临界温度,注入稠油以测量束缚水饱和度下油相有效渗透率。
(6)保持超临界温度,将8组不同比例的超临界水和稠油或非凝析气和稠油注入填砂管,流动稳定后记录不同比例下填砂管进出口压力、流量。
(7)基于达西定律计算不同注入比例下水相和油相或非凝析气和油相的有效渗透率、相对渗透率,根据物质平衡法计算含水饱和度或含气饱和度。
(8)改变实验条件,重复步骤(1)~步骤(7),测试不同温度下油-水或油-气相渗曲线。
(9)得出超临界多元热流体热采稠油油-水或油-气相渗曲线。
2 超临界多元热流体相渗实验结果
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2.1 油砂接触角测试
岩石润湿性的变化是影响相对渗透率的重要因素。通过DSA100型接触角测量仪测试不同温度下油-水两相相对渗透率实验后的油砂与水接触角,分析在超临界水作用下油砂润湿性的变化规律及其对油水相对渗透率产生的影响。测试的油砂与水的接触角变化如图3所示。
油砂与水的接触角随温度的变化如图4所示。随着温度的升高,接触角在减小,表明油砂润湿性在逐渐变化。原始状态下油砂与水的接触角为139.5°,属于亲油;当温度从150 ℃增加到350 ℃时,接触角从132.3°逐渐降低到119.7°;温度升高到超临界后,油砂与水的接触角减小至100.9°,此时油砂已呈现弱亲水的趋势。产生这一现象的原因是岩石颗粒表面的原油被剥离,亲油性逐渐减弱。但值得注意的是,温度升高到超临界后,油砂与水的接触角显著降低。这是因为超临界水的高反应性和高扩散性能将更多残存于小孔隙或附着于颗粒表面的油膜驱替出,这些小孔隙和喉道将逐渐被水所占据;同时储层岩石在超临界水作用下性质也会发生变化,逐渐从亲油向亲水方向转变,储层润湿性得到相应的改善,因此超临界下油相相对渗透率急剧增加。
2.2 原油黏度分析
温度较低时,原油黏度随着温度的升高大幅下降,50 ℃时原油黏度为2 902.84 mPa·s;温度升高后,原油黏度受温度的影响较小,如图5(a)所示。由于本次实验温度为150~420 ℃,现有实验条件无法直接测量高温下原油黏度,因此采用经验公式来拟合。温度对稠油密度的影响较小,可近似认为稠油的动力黏度与温度的关系在ASTM坐标图上呈直线关系,采用下式拟合原油黏温关系。
l g l g μ o = C - D l g T
式(1)中:μo为原油黏度,mPa·s;C、D为拟合常数;T为温度,℃。
两者的拟合结果存在良好的线性关系,如图5(b)所示。根据式(1)可计算出该区块稠油在不同温度下的黏度,如150 ℃时黏度为26.33 mPa·s,200 ℃时黏度为9.58 mPa·s。
超临界水与稠油会发生水热裂解反应,促使稠油中的重质组分如沥青质、胶质等转化为轻质油,稠油黏度大幅降低[16]。因此,通过测试不同实验温度下油-水相对渗透率曲线的采出原油黏度,分析水热裂解反应对原油黏度的影响。如图6所示,当温度从150 ℃升高到350 ℃,采出原油黏温曲线近似重合,50 ℃时原油黏度在2 900 mPa·s左右;当温度升高到400 ℃或420 ℃时,采出原油黏温曲线明显向下移动,50 ℃时原油黏度为2 000 mPa·s左右,原油黏度相比于蒸汽驱替时降低了31.03%。这是由于水的相态发生改变,超临界水与原油发生了水热裂解反应,C-C、C-S等键的断裂促使稠油中的重质组分转化为轻质油馏分,大幅降低了原油的黏度。在驱替过程中,由于原油在填砂管中流动时与超临界水的反应时间较短,只有部分原油发生了水热裂解反应,导致采出原油黏度大于完全裂解后的原油黏度。这一现象也充分地证明了原油发生水热裂解反应需要满足相应的温度、压力和时间等条件。
2.3 油-水相渗测试结果
分别测试了不同温度下的油-水两相相对渗透率,得出不同温度下油-水两相相对渗透率曲线特征点如表3所示。
不同温度下油-水两相相对渗透率曲线如图7所示。水相相对渗透率值较小,油水两相相对渗透率值相差很大。随着温度的升高,油相相对渗透率曲线逐渐趋于平缓,水相相对渗透率曲线抬升幅度逐渐变大,油水相对渗透率都在增加,共渗区变大。
值得注意的是,超临界前,随着温度的升高,油相相渗曲线形状和变化幅度基本相似。在超临界后,油相流动能力显著增强,相对渗透率快速增大,油相相对渗透率曲线发生突变,曲线形态和变化幅度完全不同于超临界前。
不同温度下油-水两相相对渗透率曲线特征点如图8所示。当温度增加到400 ℃时,曲线特征点发生了明显的突变,这主要与超临界水的特有性质相关。此后随着温度的继续增加,曲线特征点缓慢变化。图中束缚水饱和度和残余油饱和度随温度的升高而减小。束缚水饱和度在150 ℃和420 ℃时相差1.7%,产生这种现象的原因主要是水相受到的黏滞力和毛管力随温度的升高而减小,同时温度升高也改善了原油的流动性,促使原油在运移中将部分水相从小孔隙中携带出来,导致束缚水饱和度降低。150 ℃和350 ℃下的残余油饱和度差值为5.3%,而150 ℃与400、420 ℃下的残余油饱和度分别相差17.3%和17.9%,产生这种结果的原因是,温度升高减弱了驱替过程中的黏性指进现象,更多残留在小孔隙中的油滴被驱出,残余油饱和度逐渐减小;此外,温度和压力升高后,水的相态会发生变化,由蒸汽转变为超临界水,超临界水与稠油会发生更加明显的水热裂解反应,稠油黏度大幅下降,如图6所示;同时,在超临界条件下,油砂润湿性有从亲油向亲水方向发展的趋势(图4),从而提高了油相相对渗透率。这些因素共同导致油相相对渗透率曲线在超临界时发生突变,残余油饱和度值从24.8%显著降低到6.9%,洗油效率高达90.9%。
残余油饱和度下水相相对渗透率和等渗点含水饱和度随温度的升高而逐渐变大。150 ℃和200 ℃时残余油饱和度下水相相对渗透率值仅相差0.001,而350 ℃与400、420 ℃时的残余油饱和度下水相渗透率值相差0.004 8和0.005 6。出现这种结果的原因是,温度升高使油水黏度比减小,残留在孔隙或喉道里的油滴被驱替出,减弱了水相在渗流中因油滴的阻碍产生的贾敏效应和指进现象;同时温度升高会增大孔隙流体膨胀所产生的压力,促进流体的流动,水相相对渗透率变大。等渗点含水饱和度均大于70%,表明矿场砂样为水湿。随着温度升高,等渗点含水饱和度增幅逐渐变大,350 ℃到400 ℃时增幅为11.2%。这是因为超临界水与稠油中的部分组分发生了混相反应,减小了油水界面张力,油水相对渗透率增大,相对渗透率曲线向右上方移动,等渗点含水饱和度增大。
2.4 油-气相渗测试结果
分别测试了不同温度下的油-气两相相对渗透率,得出不同温度下油-气两相相对渗透率曲线特征点如表4所示。
不同温度下油-气两相相对渗透率曲线如图9所示。随着温度的升高,油气两相相对渗透率增加,油相相对渗透率曲线逐渐平缓,气相相对渗透率曲线逐渐抬升,油气两相共渗区变大。
不同温度下油-气两相相对渗透率曲线特征点如图10所示。随着温度的增加,残余油饱和度逐渐减小,洗油效率逐渐增大。150 ℃和200 ℃时残余油饱和度相差0.4%,而350 ℃与420 ℃时相差3.2%,说明随着温度的升高,残余油饱和度降幅逐渐变大。产生这种现象的原因是,注入气体的温度越高,携带的热量也就越多,加热降黏作用越突出;增大注入压力有利于增强气体的溶解度,促进原油的溶解,使油相在多孔介质中的流动能力增强,部分残余油能从较小的孔隙、喉道中被驱替出,残余油饱和度下降。
此外,随着温度的升高,残余油饱和度下气相相渗和等渗点相渗逐渐增大。残余油饱和度下气相相渗在350 ℃和420 ℃时相差0.035,是150 ℃和200 ℃时差值的3.8倍,温度升高促使残余油饱和度下气相相渗值增幅逐渐增大。由于温度升高增加了气相黏度,改善了气油流度比,减弱了气体指进现象,气相流动空间和能力变大,相对渗透率变大。同时地层中的岩石颗粒和气体分子等因温度升高产生的膨胀压力能促进油气两相的渗流,油气相对渗透率增大,等渗点向上移动,420 ℃时油气等渗点相渗值为150 ℃时的1.8倍。
3 超临界多元热流体三相相渗特征
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3.1 三相相渗曲线建立
基于Stone-Ⅱ预测模型建立三相相对渗透率曲线,该预测模型利用油-水、油-气两相相对渗透率数据并根据渠道流动理论得出三相相对渗透率曲线。在三相渗流中,油、气、水三相相对渗透率之和必须小于或等于1,该模型把油水两相相渗之和表示为σw,σw会随着含水饱和度的增加而减小。因为当含水饱和度大于束缚水后,水在流动的过程中会阻止油在小孔隙中的流动,但水相相对渗透率的增量比油相相对渗透率的减量小,因此σw会减小;把油气两相相渗之和表示为σg,σg变化也是如此,将σw与σg的乘积表示为三相渗流中对油气水的相对渗透率[17],即
K r o + K r w + K r g = σ w σ g
将σw与σg代入式(2)中得出Stone-Ⅱ模型为
K r o = ( K r o w + K r w ) ( K r o g + K r w ) -   ( K r w + K r g )
之后Aziz and Settari对该预测模型进行了修改,改进后的模型[18]为
K r o = K r o c w [ K r o w K r o c w + K r w K r o g K r o c w + K r g - K r w - K r g ]
式(4)中:Krocw为束缚水饱和度下油相相对渗透率;Krow为油水两相中油相相对渗透率;Krw为油水两相中水相相对渗透率;Krog为油气两相中油相相对渗透率;Krg为油气两相中气相相对渗透率;Kro为三相渗流中油相相对渗透率。
3.2 三相相渗曲线规律
不同温度下的油相相对渗透率等渗线如图11所示。油相等渗线都是凹向100%含油饱和度顶点的曲线;随着含油饱和度的增加,油相等渗线越密集;油相等渗线在图中偏右下方的位置。此外,在含油饱和度一定的情况下,随着含气饱和度增加和含水饱和度减小,油相相对渗透率逐渐减小,当含气饱和度增加到48%时,基本没有可动油,油相相对渗透率降为零。产生这种现象的原因是含水饱和度降低导致油相逐渐进入先前被水相占据的小孔隙或喉道,油相渗流阻力变大,相对渗透率减小[19];同时高温加剧了气体分子的热运动,随着含气饱和度的增加,气体在流动的过程中会捕获油流,油相逐渐因气体的流动而失去连续性,导致油相流动能力变差。说明超临界多元热流体开采稠油时,需要控制非凝析气在超临界多元热流体组分中的比重。
当实验温度在150~350 ℃时,随着温度升高,不同温度下相同油相等渗线逐渐向含水饱和度顶点和含气饱和度顶点移动,造成相同油相等渗线曲率逐渐变小,油相流动区大小逐渐增加。值得注意的是,当达到超临界状态时[图11(f)~图11(g)],各条油相等渗线更加接近含水饱和度顶点,等渗线曲率快速变小,油相流动区面积急剧增加。
不同温度下油相流动区大小如图12所示。可以发现150 ℃时油相流动区大小仅为38.86%,400 ℃和420 ℃时的油相流动区大小分别为52.66%和54.59%。150 ℃和350 ℃时的油相流动区大小差值仅为5.61%,而150 ℃与400 ℃、420 ℃时的油相流动区大小差值分别为13.80%和15.73%,上述差距最高约为3倍。产生这种结果的主要原因是超临界多元热流体与稠油发生了剧烈的水热裂解反应,促使稠油中重质组分转化为轻质油,稠油黏度大幅降低,在多孔介质中的流动能力增强;在驱替过程中,稠油与超临界多元热流体反复接触后,可能在驱替前缘形成近似的混相反应,降低了油水之间的界面张力和毛细管力;在超临界条件下,油砂润湿性有从亲油向亲水方向发展的趋势;此外,超临界多元热流体的压力更大、溶解性更强,随着超临界多元热流体的注入,稠油流动性增强,有利于在驱替中形成较高的压差;同时压力增大也有利于提高CO2在稠油中的扩散效果[20],从而增强了油相的流动能力和连续性。在这些因素的共同作用下,油相相对渗透率不断增大,流动区面积显著增加。最后,从图中可以发现,在超临界以后,继续增大温度虽然提高了油相流动区的大小,但其增加的幅度在变小。
4 结论
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(1)稠油在超临界水作用下发生了水热裂解反应,测得的采出稠油黏度在50 ℃时相比于蒸汽减少了31.03%。油砂与水的接触角随温度的升高而减小,接触角降幅在超临界时最为显著,油砂有向亲水方向发展的趋势。
(2)油-水两相相对渗透率结果表明,油相相对渗透率大,水相相对渗透率极小,油-水两相相对渗透率曲线特征值在超临界时发生突变。根据油气两相相对渗透率结果,油气相对渗透率随温度的升高而增大,且曲线特征值逐渐变化。
(3)在油相相渗等渗图中,油相等渗线为凹向100%含油饱和度顶点的曲线,油相相对渗透率随着含水饱和度的减小和含气饱和度的增加而减小。随着温度的升高,油相等渗线曲率逐渐变小,油相流动区面积逐渐增加,在超临界时迅速增大到54.59%,油相流动能力显著增强。
基金
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  • 国家自然科学基金(52104025)
  • 国家自然科学基金(U22B2074)
  • 重庆市自然科学基金(CSTB2022NSCQ-MSX0858)
  • 重庆市自然科学基金(cstc2022ycjh-bgzxm0055)
  • 重庆市教委科学技术研究项目(KJQN202001508)
  • 重庆科技大学研究生创新计划(YKJCX2320106)
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2025年第25卷第14期
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文章信息
doi: 10.12404/j.issn.1671-1815.2405037
  • 接收时间：2024-07-05
  • 首发时间：2025-07-09
  • 出版时间：2025-05-18
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  • 收稿日期：2024-07-05
  • 修回日期：2025-02-26
基金
国家自然科学基金(52104025)
国家自然科学基金(U22B2074)
重庆市自然科学基金(CSTB2022NSCQ-MSX0858)
重庆市自然科学基金(cstc2022ycjh-bgzxm0055)
重庆市教委科学技术研究项目(KJQN202001508)
重庆科技大学研究生创新计划(YKJCX2320106)
作者信息
    重庆科技大学石油与天然气工程学院, 重庆 401331

通讯作者:

*严文德(1979—),男,汉族,四川成都人,博士,教授。研究方向:油气藏工程、油气藏流体相态及渗流理论。E-mail:。
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https://castjournals.cast.org.cn/joweb/kxjsygc/CN/10.12404/j.issn.1671-1815.2405037
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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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