Analysis of Rock Permeability Variation and Sulfonated Surfactant Concentration in The Oil Recovery By Imbibition and Coreflooding Test in High-Temperature and Waxy Reservoirs

Y. D. Rendragraha
{"title":"Analysis of Rock Permeability Variation and Sulfonated Surfactant Concentration in The Oil Recovery By Imbibition and Coreflooding Test in High-Temperature and Waxy Reservoirs","authors":"Y. D. Rendragraha","doi":"10.29118/ipa22-e-330","DOIUrl":null,"url":null,"abstract":"Oil production of the mature field in Indonesia is decreasing sharply with one of the efforts to increase oil recovery by implementing Enhanced Oil Recovery (EOR) methods. EOR techniques have been used to minimize the amount of crude oil and petroleum that is left behind in underground reservoirs from conventional extraction methods. One of the proven EOR methods is surfactant flooding. The effectivity of surfactant flooding is influenced by various parameters. Rock permeability and the concentration of surfactant are some of the parameters affecting the oil recovery factor. Rock permeability could affect the effectiveness of surfactant injection performance in the reservoir. The surfactant concentration determination for the slug injection in the reservoir will give an optimum oil recovery by creating a low interfacial tension and microemulsion phase in the high-temperature and waxy reservoir. In this study, an imbibition and core flooding experiment were conducted in the laboratory to determine the optimum surfactant concentration to increase oil recovery with variations in rock permeability for a high temperature and waxy reservoir. In this experiment, sandstone with a permeability range of 5,000-10,000 mD was used with a synthetic brine solution (salinity of 18,000 ppm) that removes scale levels to control the precipitation problem. From the results, the imbibition using only synthetic brine gave only 40% oil recovery, while imbibition using surfactant X#3 solution produced 80% oil recovery. The core flooding experiment at a surfactant concentration of 0.8% with rock permeability of 6,000 mD and 10,000 mD gave the optimum recovery compared with using 0.6% and 1% surfactant concentration. The results gained from coreflooding experiments were 80% RF in 6,000 mD rock samples and 70% RF in 10,000 mD rock samples. In conclusion, surfactant injection using 0.8% concentration into 6,000 mD reservoir layer gave the optimum injection scenario into this reservoir.","PeriodicalId":442360,"journal":{"name":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","volume":"1 1","pages":"0"},"PeriodicalIF":0.0000,"publicationDate":"2022-09-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":"0","resultStr":null,"platform":"Semanticscholar","paperid":null,"PeriodicalName":"Proceedings of Indonesian Petroleum Association, 46th Annual Convention & Exhibition, 2022","FirstCategoryId":"1085","ListUrlMain":"https://doi.org/10.29118/ipa22-e-330","RegionNum":0,"RegionCategory":null,"ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":null,"EPubDate":"","PubModel":"","JCR":"","JCRName":"","Score":null,"Total":0}
引用次数: 0

Abstract

Oil production of the mature field in Indonesia is decreasing sharply with one of the efforts to increase oil recovery by implementing Enhanced Oil Recovery (EOR) methods. EOR techniques have been used to minimize the amount of crude oil and petroleum that is left behind in underground reservoirs from conventional extraction methods. One of the proven EOR methods is surfactant flooding. The effectivity of surfactant flooding is influenced by various parameters. Rock permeability and the concentration of surfactant are some of the parameters affecting the oil recovery factor. Rock permeability could affect the effectiveness of surfactant injection performance in the reservoir. The surfactant concentration determination for the slug injection in the reservoir will give an optimum oil recovery by creating a low interfacial tension and microemulsion phase in the high-temperature and waxy reservoir. In this study, an imbibition and core flooding experiment were conducted in the laboratory to determine the optimum surfactant concentration to increase oil recovery with variations in rock permeability for a high temperature and waxy reservoir. In this experiment, sandstone with a permeability range of 5,000-10,000 mD was used with a synthetic brine solution (salinity of 18,000 ppm) that removes scale levels to control the precipitation problem. From the results, the imbibition using only synthetic brine gave only 40% oil recovery, while imbibition using surfactant X#3 solution produced 80% oil recovery. The core flooding experiment at a surfactant concentration of 0.8% with rock permeability of 6,000 mD and 10,000 mD gave the optimum recovery compared with using 0.6% and 1% surfactant concentration. The results gained from coreflooding experiments were 80% RF in 6,000 mD rock samples and 70% RF in 10,000 mD rock samples. In conclusion, surfactant injection using 0.8% concentration into 6,000 mD reservoir layer gave the optimum injection scenario into this reservoir.
高温含蜡油藏吸吸驱心试验采油时岩石渗透率变化及磺化表面活性剂浓度分析
印度尼西亚成熟油田的石油产量急剧下降,其中一项努力是通过实施提高石油采收率(EOR)方法来提高石油采收率。EOR技术已被用于最大限度地减少传统开采方法遗留在地下储层中的原油和石油的数量。其中一种行之有效的提高采收率方法是表面活性剂驱。表面活性剂驱油效果受各种参数的影响。岩石渗透率和表面活性剂浓度是影响采收率的主要参数。岩石渗透率会影响表面活性剂在油藏中的注入效果。通过在高温含蜡油藏中创造低界面张力和微乳液相,确定段塞注入油藏的表面活性剂浓度,从而获得最佳采收率。在本研究中,在实验室进行了渗吸和岩心驱油实验,以确定高温含蜡油藏随着岩石渗透率变化而提高采收率的最佳表面活性剂浓度。在该实验中,渗透率范围为5000 - 10000 mD的砂岩与合成盐水溶液(盐度为18000 ppm)一起使用,该溶液可以去除水垢,从而控制沉淀问题。结果表明,仅使用合成盐水的渗吸采收率仅为40%,而使用表面活性剂x# 3溶液的渗吸采收率为80%。与表面活性剂浓度为0.6%和1%的岩心驱油相比,表面活性剂浓度为0.8%、岩石渗透率为6000 mD和10000 mD的岩心驱油效果最佳。岩心驱替实验结果显示,在6000 mD岩石样品中RF含量为80%,在10000 mD岩石样品中RF含量为70%。综上所述,在6000 mD储层中以0.8%的浓度注入表面活性剂是该储层的最佳注入方案。
本文章由计算机程序翻译,如有差异,请以英文原文为准。
求助全文
约1分钟内获得全文 求助全文
来源期刊
自引率
0.00%
发文量
0
×
引用
GB/T 7714-2015
复制
MLA
复制
APA
复制
导出至
BibTeX EndNote RefMan NoteFirst NoteExpress
×
提示
您的信息不完整,为了账户安全,请先补充。
现在去补充
×
提示
您因"违规操作"
具体请查看互助需知
我知道了
×
提示
确定
请完成安全验证×
copy
已复制链接
快去分享给好友吧!
我知道了
右上角分享
点击右上角分享
0
联系我们:info@booksci.cn Book学术提供免费学术资源搜索服务,方便国内外学者检索中英文文献。致力于提供最便捷和优质的服务体验。 Copyright © 2023 布克学术 All rights reserved.
京ICP备2023020795号-1
ghs 京公网安备 11010802042870号
Book学术文献互助
Book学术文献互助群
群 号:604180095
Book学术官方微信