碳酸盐岩储层含硫气低盐度注水评价——数值模拟方法

Q1 Earth and Planetary Sciences Petroleum Research Pub Date : 2023-06-01 DOI:10.1016/j.ptlrs.2022.10.003
Lawrence Opoku Boampong, Roozbeh Rafati, Amin Sharifi Haddad
{"title":"碳酸盐岩储层含硫气低盐度注水评价——数值模拟方法","authors":"Lawrence Opoku Boampong,&nbsp;Roozbeh Rafati,&nbsp;Amin Sharifi Haddad","doi":"10.1016/j.ptlrs.2022.10.003","DOIUrl":null,"url":null,"abstract":"<div><p>Although significant amount of H<sub>2</sub>S (sour gas) rich natural gas is estimated globally, but not much attention has been given to the application of H<sub>2</sub>S in the oil recovery process. Recent studies on the use of H<sub>2</sub>S in oil recovery processes showed that H<sub>2</sub>S has the potential of improving the oil recovery, and it can be even more effective than using CO<sub>2</sub> in some processes. H<sub>2</sub>S can equally dissolve in the water, react with the reservoir rock to change its surface charge, porosity, and permeability. However, previous investigations on H<sub>2</sub>S oil recovery attributed the improved oil recoveries to the higher miscibility of H<sub>2</sub>S in the oil, and the reduction in the oil viscosity. Therefore, there is limited understanding on the H<sub>2</sub>S-oil-brine-rock geochemical interactions, and how they impact the oil recovery process. This study aims to investigate the interactions between H<sub>2</sub>S, oil, and carbonate formations, and to assess how the combination of H<sub>2</sub>S and low salinity water can impact the wettability and porosity of the reservoirs. A triple layer surface complexation model was used to understand the influence of key parameters (e.g., pressure, brine salinity, and composition) on the H<sub>2</sub>S-brine-oil-rock interactions. Moreover, the effects of mineral content of the carbonate rock on H<sub>2</sub>S interactions were studied. Thereafter, the results of the H<sub>2</sub>S-oil-brine-rock interactions were compared with a study where CO<sub>2</sub> was used as the injected gas. Results of the study showed that the seawater and its diluted forms yielded identical ζ-potential values of about 3.31 mV at a pH of 3.24. This indicates that at very low pH condition, pH controls the ζ-potential of the oil-brine interface regardless of the brine's ionic strength. The study further demonstrated that the presence of other minerals in the carbonate rock greatly reduced the calcite dissolution. For instance, the calcite dissolution was reduced by 4.5% when anhydrite mineral was present in the carbonate rock. Findings from the simulation also indicated that CO<sub>2</sub> produced negative ζ-potential values for the carbonate rocks, and these values were reduced by 18.4%–20% when H<sub>2</sub>S was used as the gas phase. This implies that the H<sub>2</sub>S shifted the carbonate rock ζ-potentials towards positive. The outcomes of this study can be applied when designing CO<sub>2</sub> flooding and CO<sub>2</sub> storage where the gas stream contains H<sub>2</sub>S gas since H<sub>2</sub>S greatly influences the dissolution of the carbonate mineral.</p></div>","PeriodicalId":19756,"journal":{"name":"Petroleum Research","volume":null,"pages":null},"PeriodicalIF":0.0000,"publicationDate":"2023-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":"2","resultStr":"{\"title\":\"Evaluation of sour gas-low salinity waterflooding in carbonate reservoirs - A numerical simulation approach\",\"authors\":\"Lawrence Opoku Boampong,&nbsp;Roozbeh Rafati,&nbsp;Amin Sharifi Haddad\",\"doi\":\"10.1016/j.ptlrs.2022.10.003\",\"DOIUrl\":null,\"url\":null,\"abstract\":\"<div><p>Although significant amount of H<sub>2</sub>S (sour gas) rich natural gas is estimated globally, but not much attention has been given to the application of H<sub>2</sub>S in the oil recovery process. Recent studies on the use of H<sub>2</sub>S in oil recovery processes showed that H<sub>2</sub>S has the potential of improving the oil recovery, and it can be even more effective than using CO<sub>2</sub> in some processes. H<sub>2</sub>S can equally dissolve in the water, react with the reservoir rock to change its surface charge, porosity, and permeability. However, previous investigations on H<sub>2</sub>S oil recovery attributed the improved oil recoveries to the higher miscibility of H<sub>2</sub>S in the oil, and the reduction in the oil viscosity. Therefore, there is limited understanding on the H<sub>2</sub>S-oil-brine-rock geochemical interactions, and how they impact the oil recovery process. This study aims to investigate the interactions between H<sub>2</sub>S, oil, and carbonate formations, and to assess how the combination of H<sub>2</sub>S and low salinity water can impact the wettability and porosity of the reservoirs. A triple layer surface complexation model was used to understand the influence of key parameters (e.g., pressure, brine salinity, and composition) on the H<sub>2</sub>S-brine-oil-rock interactions. Moreover, the effects of mineral content of the carbonate rock on H<sub>2</sub>S interactions were studied. Thereafter, the results of the H<sub>2</sub>S-oil-brine-rock interactions were compared with a study where CO<sub>2</sub> was used as the injected gas. Results of the study showed that the seawater and its diluted forms yielded identical ζ-potential values of about 3.31 mV at a pH of 3.24. This indicates that at very low pH condition, pH controls the ζ-potential of the oil-brine interface regardless of the brine's ionic strength. The study further demonstrated that the presence of other minerals in the carbonate rock greatly reduced the calcite dissolution. For instance, the calcite dissolution was reduced by 4.5% when anhydrite mineral was present in the carbonate rock. Findings from the simulation also indicated that CO<sub>2</sub> produced negative ζ-potential values for the carbonate rocks, and these values were reduced by 18.4%–20% when H<sub>2</sub>S was used as the gas phase. This implies that the H<sub>2</sub>S shifted the carbonate rock ζ-potentials towards positive. The outcomes of this study can be applied when designing CO<sub>2</sub> flooding and CO<sub>2</sub> storage where the gas stream contains H<sub>2</sub>S gas since H<sub>2</sub>S greatly influences the dissolution of the carbonate mineral.</p></div>\",\"PeriodicalId\":19756,\"journal\":{\"name\":\"Petroleum Research\",\"volume\":null,\"pages\":null},\"PeriodicalIF\":0.0000,\"publicationDate\":\"2023-06-01\",\"publicationTypes\":\"Journal Article\",\"fieldsOfStudy\":null,\"isOpenAccess\":false,\"openAccessPdf\":\"\",\"citationCount\":\"2\",\"resultStr\":null,\"platform\":\"Semanticscholar\",\"paperid\":null,\"PeriodicalName\":\"Petroleum Research\",\"FirstCategoryId\":\"1087\",\"ListUrlMain\":\"https://www.sciencedirect.com/science/article/pii/S2096249522000679\",\"RegionNum\":0,\"RegionCategory\":null,\"ArticlePicture\":[],\"TitleCN\":null,\"AbstractTextCN\":null,\"PMCID\":null,\"EPubDate\":\"\",\"PubModel\":\"\",\"JCR\":\"Q1\",\"JCRName\":\"Earth and Planetary Sciences\",\"Score\":null,\"Total\":0}","platform":"Semanticscholar","paperid":null,"PeriodicalName":"Petroleum Research","FirstCategoryId":"1087","ListUrlMain":"https://www.sciencedirect.com/science/article/pii/S2096249522000679","RegionNum":0,"RegionCategory":null,"ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":null,"EPubDate":"","PubModel":"","JCR":"Q1","JCRName":"Earth and Planetary Sciences","Score":null,"Total":0}
引用次数: 2

摘要

尽管全球范围内估计了大量富含H2S(酸性气)的天然气,但对H2S在采油过程中的应用却没有给予太多关注。最近关于H2S在采油过程中使用的研究表明,H2S具有提高采油率的潜力,在某些过程中甚至比使用CO2更有效。H2S可以同样溶解在水中,与储层岩石反应,改变其表面电荷、孔隙度和渗透率。然而,先前对H2S采油的研究将采油率的提高归因于H2S在油中的更高混溶性和油粘度的降低。因此,对H2S-油-盐水-岩石地球化学相互作用及其如何影响采油过程的了解有限。本研究旨在研究H2S、石油和碳酸盐岩地层之间的相互作用,并评估H2S和低盐度水的组合如何影响储层的润湿性和孔隙度。使用三层表面络合模型来了解关键参数(如压力、盐水盐度和成分)对H2S-盐水-油岩相互作用的影响。此外,还研究了碳酸盐岩矿物含量对H2S相互作用的影响。之后,将H2S-油-盐水-岩石相互作用的结果与使用CO2作为注入气体的研究进行比较。研究结果表明,海水及其稀释形式在3.24的pH下产生了相同的ζ-电位值,约为3.31 mV。这表明,在非常低的pH条件下,无论盐水的离子强度如何,pH都会控制油-盐水界面的ζ-电势。研究进一步表明,碳酸盐岩中其他矿物的存在大大降低了方解石的溶解。例如,当碳酸盐岩中存在硬石膏矿物时,方解石的溶解减少了4.5%。模拟结果还表明,CO2对碳酸盐岩产生了负ζ电位值,当使用H2S作为气相时,这些值降低了18.4%-20%。这意味着H2S使碳酸盐岩ζ电位向正方向移动。本研究的结果可应用于设计CO2驱替和CO2储存时,其中气流含有H2S气体,因为H2S极大地影响碳酸盐矿物的溶解。
本文章由计算机程序翻译,如有差异,请以英文原文为准。
查看原文
分享 分享
微信好友 朋友圈 QQ好友 复制链接
本刊更多论文
Evaluation of sour gas-low salinity waterflooding in carbonate reservoirs - A numerical simulation approach

Although significant amount of H2S (sour gas) rich natural gas is estimated globally, but not much attention has been given to the application of H2S in the oil recovery process. Recent studies on the use of H2S in oil recovery processes showed that H2S has the potential of improving the oil recovery, and it can be even more effective than using CO2 in some processes. H2S can equally dissolve in the water, react with the reservoir rock to change its surface charge, porosity, and permeability. However, previous investigations on H2S oil recovery attributed the improved oil recoveries to the higher miscibility of H2S in the oil, and the reduction in the oil viscosity. Therefore, there is limited understanding on the H2S-oil-brine-rock geochemical interactions, and how they impact the oil recovery process. This study aims to investigate the interactions between H2S, oil, and carbonate formations, and to assess how the combination of H2S and low salinity water can impact the wettability and porosity of the reservoirs. A triple layer surface complexation model was used to understand the influence of key parameters (e.g., pressure, brine salinity, and composition) on the H2S-brine-oil-rock interactions. Moreover, the effects of mineral content of the carbonate rock on H2S interactions were studied. Thereafter, the results of the H2S-oil-brine-rock interactions were compared with a study where CO2 was used as the injected gas. Results of the study showed that the seawater and its diluted forms yielded identical ζ-potential values of about 3.31 mV at a pH of 3.24. This indicates that at very low pH condition, pH controls the ζ-potential of the oil-brine interface regardless of the brine's ionic strength. The study further demonstrated that the presence of other minerals in the carbonate rock greatly reduced the calcite dissolution. For instance, the calcite dissolution was reduced by 4.5% when anhydrite mineral was present in the carbonate rock. Findings from the simulation also indicated that CO2 produced negative ζ-potential values for the carbonate rocks, and these values were reduced by 18.4%–20% when H2S was used as the gas phase. This implies that the H2S shifted the carbonate rock ζ-potentials towards positive. The outcomes of this study can be applied when designing CO2 flooding and CO2 storage where the gas stream contains H2S gas since H2S greatly influences the dissolution of the carbonate mineral.

求助全文
通过发布文献求助,成功后即可免费获取论文全文。 去求助
来源期刊
Petroleum Research
Petroleum Research Earth and Planetary Sciences-Geology
CiteScore
7.10
自引率
0.00%
发文量
90
审稿时长
35 weeks
期刊最新文献
Applicability of deep neural networks for lithofacies classification from conventional well logs: An integrated approach Investigation of a solid particle deposition velocity in drag reducing fluids with salinity Use of graphs to assess well safety in drilling projects and during operations by identification of available barrier elements and consolidation of barrier envelopes Sedimentary microfacies of Member 5 of Xujiahe Formation in the Dongfengchang area, Sichuan Basin Research on physical explosion crater model of high-pressure natural gas pipeline
×
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
现在去查看 取消
×
提示
确定
0
微信
客服QQ
Book学术公众号 扫码关注我们
反馈
×
意见反馈
请填写您的意见或建议
请填写您的手机或邮箱
已复制链接
已复制链接
快去分享给好友吧!
我知道了
×
扫码分享
扫码分享
Book学术官方微信
Book学术文献互助
Book学术文献互助群
群 号:481959085
Book学术
文献互助 智能选刊 最新文献 互助须知 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 Book学术 All rights reserved.
ghs 京公网安备 11010802042870号 京ICP备2023020795号-1