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Mohammadi S, Hemmat A, Afifi H, Mahmoudi Alemi F. Improvement of the Rheological Behavior of Viscoelastic Surfactant Fracturing Fluids by Metallic-Type Nanoparticles. ACS OMEGA 2024; 9:28676-28690. [PMID: 38973834 PMCID: PMC11223126 DOI: 10.1021/acsomega.4c03000] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Grants] [Track Full Text] [Download PDF] [Figures] [Subscribe] [Scholar Register] [Received: 03/28/2024] [Revised: 06/10/2024] [Accepted: 06/12/2024] [Indexed: 07/09/2024]
Abstract
The use of nanotechnology in the field of acidizing, particularly in fracturing fluids, has garnered significant attention over the past decade. Viscoelastic surfactants (VESs) are utilized as one of the most effective fracturing fluids, possessing both elasticity and viscosity properties. These fluids are crucial additives in acidizing packages, enhancing their performance. However, various factors, such as salinity, temperature, pressure, and concentration, can sometimes weaken the efficacy of these fluids. To address this, the integration of nanoparticles has been explored to improve fluid retention in reservoirs and enhance the efficiency. This study focuses on investigating the impact of the main metallic-type nanoparticles on the rheological behavior of VES fluids. Iron oxide, magnesium oxide, and zinc oxide nanoparticles were utilized, and the microscopic-scale rheological behavior of the fluids was thoroughly evaluated. The highest performance for enhancing fluid gelation, stability, and rheological characteristics of VES fluids was found for Fe2O3 nanoparticles at an optimum concentration of 500 ppm. At this concentration and shear rate of 100 s-1, the viscosity of the fluid reached 169.61 cP. For iron oxide nanoparticles at a concentration of 500 ppm, by increasing the temperature from 25 to 85 °C, the gelation state of the fluid increased from 7 h and 50 min to 17 h and 45 min. This improvement is attributed to their high surface area and the increased density of entanglement points within the micelles, leading to a more interconnected structure with enhanced viscoelastic properties. Furthermore, iron oxide nanoparticles significantly enhance gelation by physically connecting the micelles, thereby improving stability and structure. The absorption of surfactant molecules by the nanoparticles additionally contributes to micelle reconstruction and shape alteration. The presence of iron oxide nanoparticles helps maintain the gel structure even at elevated temperatures, preventing rapid viscosity decrease. Our findings may provide new insights for development of high-performance, economical, and environment-friendly fracturing fluids used in well stimulation operations.
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Affiliation(s)
- Saber Mohammadi
- Petroleum
Engineering Department, Research Institute
of Petroleum Industry (RIPI), Tehran 14665-1998, Iran
| | - Alimohammad Hemmat
- Department
of Chemical Engineering, Isfahan University
of Technology, Isfahan 84156-83111, Iran
| | - Hamidreza Afifi
- Petroleum
Engineering Department, Research Institute
of Petroleum Industry (RIPI), Tehran 14665-1998, Iran
| | - Fatemeh Mahmoudi Alemi
- Petroleum
Engineering Department, Research Institute
of Petroleum Industry (RIPI), Tehran 14665-1998, Iran
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Hao H, Wu H, Diao H, Zhang Y, Yang S, Deng S, Li Q, Yan X, Peng M, Qu M, Li X, Xu J, Yang E. A study on the bio-based surfactant sodium cocoyl alaninate as a foaming agent for enhanced oil recovery in high-salt oil reservoirs. RSC Adv 2024; 14:4369-4381. [PMID: 38304559 PMCID: PMC10828935 DOI: 10.1039/d3ra07840j] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Grants] [Track Full Text] [Download PDF] [Figures] [Journal Information] [Subscribe] [Scholar Register] [Received: 11/16/2023] [Accepted: 12/19/2023] [Indexed: 02/03/2024] Open
Abstract
Environmental awareness is receiving increasing attention in the petroleum industry, especially when associated with chemical agents applied in enhanced oil recovery (EOR) technology. The bio-based surfactant sodium cocoyl alaninate (SCA) is environmentally friendly and can be easily biodegraded, which makes it a promising alternative to traditional surfactants. Herein, the SCA surfactant is proposed as a foaming agent for enhanced oil recovery. Laboratory investigations on the surfactant concentration, foaming performance, microbubble characterization, interfacial tension, and foam-flooding of the traditional surfactants SDS and OP-10 have been conducted. In particular, the anti-salt abilities of these three surfactants have been studied, taking into consideration the reservoir conditions at Bohai Bay Basin, China. The results show that concentrations of 0.20 wt%, 0.20 wt% and 0.50 wt% for SCA, SDS and OP-10, respectively, can achieve optimum foaming ability and foaming stability under formation salinity conditions, and 0.20 wt% SCA achieved the best foaming ability and stability compared to 0.20 wt% SDS and 0.50 wt% OP-10. Sodium fatty acid groups and amino acid groups present in the SCA molecular structure have high surface activities under different salinity conditions, making SCA an excellent anti-salt surfactant for enhanced oil recovery. The microstructure analysis results showed that most of the SCA bubbles were smaller in size, with an average diameter of about 150 μm, and the distribution of SCA bubbles was more uniform, which can reduce the risk of foam coalescence and breakdown. The IFT value of the SCA/oil system was measured to be 0.157 mN m-1 at 101.5 °C, which was the lowest. A lower IFT can make liquid molecules more evenly distributed on the surface, and enhance the elasticity of the foam film. Core-flooding experimental results showed that a 0.30 PV SCA foam and secondary waterflooding can enhance oil recovery by more than 15% after primary waterflooding, which can reduce the mobility ratio from 3.7711 to 1.0211. The more viscous SCA foam caused a greater flow resistance, and effectively reduced the successive water fingering, leading to a more stable driving process to fully displace the remaining oil within the porous media. The bio-based surfactant SCA proposed in this paper has the potential for application in enhanced oil recovery in similar high-salt oil reservoirs.
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Affiliation(s)
- Hongda Hao
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Hongze Wu
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Haoyu Diao
- CNPC Engineering Technology Research and Development Co. Ltd Beijing 100083 China
| | - Yixin Zhang
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Shuo Yang
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Song Deng
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Qiu Li
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Xiaopeng Yan
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Mingguo Peng
- School of Petroleum and Natural Gas Engineering, School of Energy, Changzhou University Changzhou 213164 China +86 15261180955
| | - Ming Qu
- Sanya Offshore Oil & Gas Research Institute, Northeast Petroleum University Sangya 572024 China
| | - Xinyu Li
- China Yangtze Power Co. Ltd Yichang 443000 China
| | - Jiaming Xu
- China Yangtze Power Co. Ltd Yichang 443000 China
| | - Erlong Yang
- School of Petroleum Engineering, Northeast Petroleum University Daqing 163318 China
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Saeedi Dehaghani AH, Gharibshahi R, Mohammadi M. Utilization of synthesized silane-based silica Janus nanoparticles to improve foam stability applicable in oil production: static study. Sci Rep 2023; 13:18652. [PMID: 37903908 PMCID: PMC10616180 DOI: 10.1038/s41598-023-46030-1] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Key Words] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Received: 08/14/2023] [Accepted: 10/26/2023] [Indexed: 11/01/2023] Open
Abstract
This study investigated the effect of silane-based silica (SiO2) Janus nanoparticles (JNPs) on stabilizing the foam generated by different types of gases. Two types of SiO2 JNPs were synthesized through surface modification using HMDS and APTS silane compounds. Static analyses were conducted to examine the impact of different concentrations of the synthesized nanoparticles in various atmospheres (air, CO2, and CH4) on surface tension, foamability, and foam stability. The results indicated that the synthesized SiO2 JNPs and bare SiO2 nanoparticles exhibited nearly the same ability to reduce surface tension at ambient temperature and pressure. Both of these nanoparticles reduced the surface tension from 71 to 58-59 mN m-1 at 15,000 ppm and 25 °C. While bare SiO2 nanoparticles exhibited no foamability, the synthesis of SiO2 JNPs significantly enhanced their ability to generate and stabilize gas foam. The foamability of HMDS-SiO2 JNPs started at a higher concentration than APTS-SiO2 JNPs (6000 ppm compared to 4000 ppm, respectively). The type of gas atmosphere played a crucial role in the efficiency of the synthesized JNPs. In a CH4 medium, the foamability of synthesized JNPs was superior to that in air and CO2. At a concentration of 1500 ppm in a CH4 medium, HMDS-SiO2 and APTS-SiO2 JNPs could stabilize the generated foam for 36 and 12 min, respectively. Due to the very low dissolution of CO2 gas in water at ambient pressure, the potential of synthesized JNPs decreased in this medium. Finally, it was found that HMDS-SiO2 JNPs exhibited better foamability and foam stability in all gas mediums compared to APTS-SiO2 JNPs for use in oil reservoirs. Also, the optimal performance of these JNPs was observed at a concentration of 15,000 ppm in a methane gas medium.
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Affiliation(s)
| | - Reza Gharibshahi
- Faculty of Chemical Engineering, Tarbiat Modares University, Tehran, Iran
| | - Mohammad Mohammadi
- Faculty of Chemical Engineering, Tarbiat Modares University, Tehran, Iran
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Zhou W, Wang C, Meng R, Chen Z, Lu H, Chi J. Study on thermal insulation cement and its thermal insulation characteristics for geothermal wells. Sci Rep 2023; 13:4157. [PMID: 36914700 PMCID: PMC10011513 DOI: 10.1038/s41598-023-30614-y] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Key Words] [Journal Information] [Subscribe] [Scholar Register] [Received: 11/26/2022] [Accepted: 02/27/2023] [Indexed: 03/16/2023] Open
Abstract
Reducing the heat loss in wellbore is the key for efficient development of geothermal resource. It is a reliable solution to establish a long-term stable wellbore with good thermal insulation through cementing. In this paper, the cement-based composite thermal insulation material was prepared by using cement as the cementing material, hollow glass beads, foaming agent and stabilizer as main raw materials, and other conventional admixtures. Foams and hollow glass beads can introduce gas with low thermal conductivity into cement, so as to improve the thermal insulation of composite material. Foams are produced by chemical forming process, using foaming agent, which is prepared according electrochemistry and thermodynamics, and the foam stabilizer helps foam distribute in cement slurry stably and uniformly. 10-13% hollow glass beads can significantly reduce the thermal conductivity of hardened cement, without significant adverse effects on the rheology and strength of the material. The thermal conductivity of the composite thermal insulation material can be as low as 0.2998 W·(m·K)-1, which is 62% lower than that of conventional cement, while the compressive strength is 6.10 MPa, meeting the engineering requirement. A thermal-conductivity prediction method is proposed correspondingly based on Maxwell model, and the prediction error of the newly established model is within 2%. This research can provide technical support for efficient development of geothermal resources.
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Affiliation(s)
- Wei Zhou
- Key Laboratory of Unconventional Oil and Gas Development, China University of Petroleum (East China), Qingdao, 266580, China
| | - Chengwen Wang
- Key Laboratory of Unconventional Oil and Gas Development, China University of Petroleum (East China), Qingdao, 266580, China. .,College of Petroleum Engineering, China University of Petroleum (East China), Qingdao, 266580, China.
| | - Renzhou Meng
- CNPC Engineering Technology R&D Company Limited, Beijing, 102206, China
| | - Zehua Chen
- Key Laboratory of Unconventional Oil and Gas Development, China University of Petroleum (East China), Qingdao, 266580, China
| | - Haoxin Lu
- Key Laboratory of Unconventional Oil and Gas Development, China University of Petroleum (East China), Qingdao, 266580, China
| | - Jialun Chi
- Key Laboratory of Unconventional Oil and Gas Development, China University of Petroleum (East China), Qingdao, 266580, China
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Abdous B, Sajjadi SM, Bagheri A. Predicting the aggregation number of cationic surfactants based on ANN-QSAR modeling approaches: understanding the impact of molecular descriptors on aggregation numbers. RSC Adv 2022; 12:33666-33678. [PMID: 36505704 PMCID: PMC9685374 DOI: 10.1039/d2ra06064g] [Citation(s) in RCA: 1] [Impact Index Per Article: 0.5] [Reference Citation Analysis] [Abstract] [Track Full Text] [Figures] [Journal Information] [Subscribe] [Scholar Register] [Received: 09/26/2022] [Accepted: 11/03/2022] [Indexed: 11/25/2022] Open
Abstract
In this work, a quantitative structure-activity relationship (QSAR) study is performed on some cationic surfactants to evaluate the relationship between the molecular structures of the compounds with their aggregation numbers (AGGNs) in aqueous solution at 25 °C. An artificial neural network (ANN) model is combined with the QSAR study to predict the aggregation number of the surfactants. In the ANN analysis, four out of more than 3000 molecular descriptors were used as input variables, and the complete set of 41 cationic surfactants was randomly divided into a training set of 29, a test set of 6, and a validation set of 6 molecules. After that, a multiple linear regression (MLR) analysis was utilized to build a linear model using the same descriptors and the results were compared statistically with those of the ANN analysis. The square of the correlation coefficient (R 2) and root mean square error (RMSE) of the ANN and MLR models (for the whole data set) were 0.9392, 7.84, and 0.5010, 22.52, respectively. The results of the comparison revealed the efficiency of ANN in detecting a correlation between the molecular structure of surfactants and their AGGN values with a high predictive power due to the non-linearity in the studied data. Based on the ANN algorithm, the relative importance of the selected descriptors was computed and arranged in the following descending order: H-047 > ESpm12x > JGI6> Mor20p. Then, the QSAR data was interpreted and the impact of each descriptor on the AGGNs of the molecules were thoroughly discussed. The results showed there is a correlation between each selected descriptor and the AGGN values of the surfactants.
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Affiliation(s)
- Behnaz Abdous
- Faculty of Chemistry, Semnan University Semnan Iran +98-23-33384110 +98-23-31533192
| | - S Maryam Sajjadi
- Faculty of Chemistry, Semnan University Semnan Iran +98-23-33384110 +98-23-31533192
| | - Ahmad Bagheri
- Faculty of Chemistry, Semnan University Semnan Iran +98-23-33384110 +98-23-31533192
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Lai N, Zhao J, Wang J, Gao L, He Q. Influence of external conditions on the stability of inorganic gel foam and exploration of the mechanism of action. J Mol Liq 2022. [DOI: 10.1016/j.molliq.2022.120873] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/27/2022]
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Kong D, Wang D, Chen J, Zhang J, He X, Li B, He X, Liu H. Assessing the mixed foam stability of different foam extinguishing agents under room temperature and thermal radiation: An experimental study. J Mol Liq 2022. [DOI: 10.1016/j.molliq.2022.120805] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/18/2022]
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Fundamental Investigation on a Foam-Generating Microorganism and Its Potential for Mobility Reduction in High-Permeability Flow Channels. ENERGIES 2022. [DOI: 10.3390/en15072344] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Track Full Text] [Subscribe] [Scholar Register] [Indexed: 02/04/2023]
Abstract
This study proposed a novel foam EOR technique using Pseudomonas aeruginosa to generate the foam and investigated the potential of the microbial foam EOR to modify the permeability of a high-permeability porous system. We investigated oxygen nanobubble, carbon dioxide nanobubble and ferrous sulfate concentrations to discover the optimal levels for activating the foam generation of the microorganism through cultivation experiments. We also clarified the behavior of the microbial foam generation and the bioproducts that contribute to the foam generation. The potential of the foam to decrease the permeability of high-permeability porous systems was evaluated through flooding experiments using sand pack cores. The foam generation became more active with the increase in the number of nanobubbles, while there was an optimal concentration of ferrous sulfate for foam generation. The foam was identified as being induced by the proteins produced by the microorganism, which can be expected to bring about several advantages over surfactant-induced foam. The foam successfully decreased the permeability of high-permeability sand pack cores to half of their initial levels. These results demonstrate that the microbial foam EOR has the potential to decrease the permeability of high-permeability porous systems and improve the permeability heterogeneity in oil reservoirs.
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Yu W, Zhou X, Kanj MY. Microfluidic Investigation of Foam Coarsening Dynamics in Porous Media at High-Pressure and High-Temperature Conditions. LANGMUIR : THE ACS JOURNAL OF SURFACES AND COLLOIDS 2022; 38:2895-2905. [PMID: 35192368 DOI: 10.1021/acs.langmuir.1c03301] [Citation(s) in RCA: 0] [Impact Index Per Article: 0] [Reference Citation Analysis] [Abstract] [Track Full Text] [Subscribe] [Scholar Register] [Indexed: 06/14/2023]
Abstract
Coarsening or Oswald ripening, induced by interbubble gas diffusion, is considered to dominate foam structure evolution in porous media. We present the first study of trapped foam coarsening dynamics under realistic deep reservoir conditions (up to 3200 psi/22 MPa of pore pressure and 100 °C of temperature) in a high-pressure and high-temperature microfluidic system. The findings are expected to help predict foam structure evolution in applications such as enhanced oil recovery and CO2 geological sequestration. It is shown that, in porous media, larger bubbles grow at the expense of smaller bubbles. The growth rate of the average bubble area (⟨a⟩) over time shows a long-term linear increase when ⟨a⟩ is between 1/5 and 1/2 of the average pore size. The foam coarsening kinetics are determined by the liquid film permeability, gas-liquid interfacial tension, and the molar volume of the dispersed phase. In summary, foams prepared with less water-soluble gases (e.g., N2 and air) and lower foam quality show slower coarsening kinetics due to a lower film permeability. Foam coarsening is more sensitive to surfactant concentration (than surfactant type), as it determines the interfacial tension that controls the mass transfer driving force (capillary pressure difference). The transport properties of the dispersed phase depend strongly on its density, which increases with increasing pore pressure and decreasing temperature. At the same experimental conditions, gas CO2 foam shows a 10-fold faster coarsening rate than N2 foam. However, dense (i.e., liquid and supercritical) CO2 foams show a remarkable 20-500-fold reduction in coarsening kinetics compared with gas N2 and CO2 foams due to the significantly reduced mass transfer driving forces. In a sense, trapped CO2 foam can be stronger than N2 foam at high-pressure and high-temperature conditions.
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Affiliation(s)
- Wei Yu
- Center for Integrative Petroleum Research, College of Petroleum Engineering & Geosciences, King Fahd University of Petroleum & Minerals, Dhahran 31261, Saudi Arabia
| | - Xianmin Zhou
- Center for Integrative Petroleum Research, College of Petroleum Engineering & Geosciences, King Fahd University of Petroleum & Minerals, Dhahran 31261, Saudi Arabia
| | - Mazen Yousef Kanj
- Center for Integrative Petroleum Research, College of Petroleum Engineering & Geosciences, King Fahd University of Petroleum & Minerals, Dhahran 31261, Saudi Arabia
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Improved foam stability through the combination of silica nanoparticle and thixotropic polymer: An experimental study. J Mol Liq 2022. [DOI: 10.1016/j.molliq.2021.117153] [Citation(s) in RCA: 5] [Impact Index Per Article: 2.5] [Reference Citation Analysis] [Track Full Text] [Journal Information] [Subscribe] [Scholar Register] [Indexed: 11/23/2022]
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