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{"title":"Mechanistic analysis of acid gas storage and oil recovery in naturally fractured reservoirs using single matrix block approach","authors":"Goran Shirzad, Zahra Sadeghzadeh, Mehdi Assareh","doi":"10.1002/ghg.2276","DOIUrl":null,"url":null,"abstract":"<p>The objective of this study is to assess the storage of acid gas, containing CO<sub>2</sub> and H<sub>2</sub>S, in a depleted naturally fractured reservoir (NFR) using single matrix block (SMB) approach. The acid gas dissolution in oil is considered by Peng-Robinson equation of state and compositional simulation. The PHREEQC package is used to determine acid gas solubility in formation brine. Three types of acid gases with different compositions are used for this study and their swelling behavior and miscibility in relation to the reservoir oil are analyzed. An SMB model, with a matrix block surrounded by fractures, is constructed, and validated for simulation of a real experiment. The simulation is conducted for synthetic and real reservoir fluids when the oil is in its residual saturation. A sensitivity analysis is performed to study the effects of key parameters, such as acid gas composition, reservoir pressure, permeability, porosity and matrix height on the storage capacity and oil recovery factor. The matrix has a volume of 27 m<sup>3</sup> and about half of acid gas storage is achieved in the first 5 years while the simulations are run for 30 years. The results show that up to 90% of remained oil is recoverable, and more than 0.67 kmol of acid gas per cubic meter of matrix is stored whether matrix contains a real oil or a synthetic one. Higher storage is achieved for higher matrix porosities and heights and large H<sub>2</sub>S proportion in acid gas. In all cases about 10% of acid gas is trapped in water and the remaining 90% is dissolved in oil. The mineral trapping was more active in CO<sub>2</sub>-rich acid gases. While about 10 kg of the matrix rock was dissolved in the acidic brine when the acid gas contained H<sub>2</sub>S, the amount of the dissolved minerals in acidic brine resulted from the injection of CO<sub>2</sub>-rich acid gas was more than 16 kg. Finally, this study gives a comparative analysis of the storage performance of acid gas mixture and pure CO<sub>2</sub>. © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd.</p>","PeriodicalId":12796,"journal":{"name":"Greenhouse Gases: Science and Technology","volume":"14 3","pages":"371-399"},"PeriodicalIF":2.7000,"publicationDate":"2024-05-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":"0","resultStr":null,"platform":"Semanticscholar","paperid":null,"PeriodicalName":"Greenhouse Gases: Science and Technology","FirstCategoryId":"93","ListUrlMain":"https://onlinelibrary.wiley.com/doi/10.1002/ghg.2276","RegionNum":4,"RegionCategory":"环境科学与生态学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":null,"EPubDate":"","PubModel":"","JCR":"Q3","JCRName":"ENERGY & FUELS","Score":null,"Total":0}
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Abstract
The objective of this study is to assess the storage of acid gas, containing CO2 and H2 S, in a depleted naturally fractured reservoir (NFR) using single matrix block (SMB) approach. The acid gas dissolution in oil is considered by Peng-Robinson equation of state and compositional simulation. The PHREEQC package is used to determine acid gas solubility in formation brine. Three types of acid gases with different compositions are used for this study and their swelling behavior and miscibility in relation to the reservoir oil are analyzed. An SMB model, with a matrix block surrounded by fractures, is constructed, and validated for simulation of a real experiment. The simulation is conducted for synthetic and real reservoir fluids when the oil is in its residual saturation. A sensitivity analysis is performed to study the effects of key parameters, such as acid gas composition, reservoir pressure, permeability, porosity and matrix height on the storage capacity and oil recovery factor. The matrix has a volume of 27 m3 and about half of acid gas storage is achieved in the first 5 years while the simulations are run for 30 years. The results show that up to 90% of remained oil is recoverable, and more than 0.67 kmol of acid gas per cubic meter of matrix is stored whether matrix contains a real oil or a synthetic one. Higher storage is achieved for higher matrix porosities and heights and large H2 S proportion in acid gas. In all cases about 10% of acid gas is trapped in water and the remaining 90% is dissolved in oil. The mineral trapping was more active in CO2 -rich acid gases. While about 10 kg of the matrix rock was dissolved in the acidic brine when the acid gas contained H2 S, the amount of the dissolved minerals in acidic brine resulted from the injection of CO2 -rich acid gas was more than 16 kg. Finally, this study gives a comparative analysis of the storage performance of acid gas mixture and pure CO2 . © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd.
利用单基质区块法对天然裂缝储层中的酸性气体储存和石油采收进行机理分析
本研究的目的是采用单基质块（SMB）方法，评估含 CO2 和 H2S 的酸性气体在枯竭的天然裂缝储层（NFR）中的储存情况。通过彭-罗宾逊（Peng-Robinson）状态方程和成分模拟考虑了酸性气体在石油中的溶解。PHREEQC 软件包用于确定酸性气体在地层盐水中的溶解度。本研究使用了三种不同成分的酸性气体，分析了它们的溶胀行为以及与储层油的混溶性。构建了一个由裂缝包围的基质块的 SMB 模型，并对实际实验进行了模拟验证。在石油处于剩余饱和状态时，对合成和真实储层流体进行模拟。进行了敏感性分析，以研究酸性气体成分、储层压力、渗透率、孔隙度和基质高度等关键参数对储量和采油系数的影响。基质体积为 27 立方米，酸性气体储存量的一半左右是在前 5 年实现的，而模拟运行时间为 30 年。结果表明，残留石油的可采收率高达 90%，无论基质含有真正的石油还是合成石油，每立方米基质都能储存超过 0.67 千摩尔的酸性气体。基质孔隙度和高度越高，酸性气体中 H2S 的比例越大，存储量就越高。在所有情况下，约 10% 的酸性气体被截留在水中，其余 90% 溶解在油中。矿物捕集在富含二氧化碳的酸性气体中更为活跃。当酸性气体中含有 H2S 时，约有 10 千克的基质岩石溶解在酸性盐水中，而注入富含 CO2 的酸性气体后，酸性盐水中的矿物溶解量超过 16 千克。最后，本研究对酸性气体混合物和纯 CO2 的储存性能进行了比较分析。© 2024 化学工业协会和约翰-威利父子有限公司版权所有。
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