J. Câmara, M. A. Sousa, E. Neto, M. C. A. Oliveira
Biosurfactants are employed in several industrial applications which require a high purity level. However, the downstream purification processes are responsible for a large portion of the expenses incurred by biosurfactant production plants. The high costs associated with these processes turn their application on a large scale a challenge for companies. This study aimed to evaluate the influence of the purification step on the capacity of the rhamnolipid produced by a Pseudomonas aeruginosa strain to recover oil. Both purified and non-purified biosurfactants were efficient in their ability to recover oil. The best result, for the API gravity oil of 27.67, presented a total Recovery Factor of 47.45±1.78%, in which 10.2±0.85% corresponds to the MEOR. However, the results show that non-purified biosurfactant was more efficient in terms of amount of oil recovered during the MEOR stage. This demonstrates that the purification step may not be necessary, reducing the production costs of the rhamnolipid.
{"title":"EVALUATION OF THE PURIFICATION PROCESS IN RHAMNOLIPID BIOSURFACTANT FOR APPLICATION IN MICROBIAL-ENHANCED OIL RECOVERY (MEOR)","authors":"J. Câmara, M. A. Sousa, E. Neto, M. C. A. Oliveira","doi":"10.5419/bjpg2019-0016","DOIUrl":"https://doi.org/10.5419/bjpg2019-0016","url":null,"abstract":"Biosurfactants are employed in several industrial applications which require a high purity level. However, the downstream purification processes are responsible for a large portion of the expenses incurred by biosurfactant production plants. The high costs associated with these processes turn their application on a large scale a challenge for companies. This study aimed to evaluate the influence of the purification step on the capacity of the rhamnolipid produced by a Pseudomonas aeruginosa strain to recover oil. Both purified and non-purified biosurfactants were efficient in their ability to recover oil. The best result, for the API gravity oil of 27.67, presented a total Recovery Factor of 47.45±1.78%, in which 10.2±0.85% corresponds to the MEOR. However, the results show that non-purified biosurfactant was more efficient in terms of amount of oil recovered during the MEOR stage. This demonstrates that the purification step may not be necessary, reducing the production costs of the rhamnolipid.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"29 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76805357","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
M. Mendes, J. B. Ramalho, O. K. Júnior, L. Palermo, C. Mansur
Foams generated during oil production are complex systems. The complexity of their continuous phase makes it difficult to understand what occurs in the foam layers. Some studies have shown that the main species that stabilize foams are asphaltenes, because they reduce the surface tension of the bubbles with their interfacial activity, causing this surface to become viscoelastic. To understand surface viscoelasticity, it is necessary to investigate the rheology of the crude oil/air interface. Since the great majority of works published have used a Du Nouy ring or BiCone accessory to evaluate the surface only of model asphaltene systems, the aim of this work is to study the crude oil/air interface of different crude oil samples and different antifoaming products using the BiCone accessory.
{"title":"STUDYING THE INFLUENCE OF ANTIFOAMING ADDITIVES ON CRUDE OIL/AIR INTERFACE: PROPOSAL OF A NEW METHODOLOGY","authors":"M. Mendes, J. B. Ramalho, O. K. Júnior, L. Palermo, C. Mansur","doi":"10.5419/bjpg2019-0014","DOIUrl":"https://doi.org/10.5419/bjpg2019-0014","url":null,"abstract":"Foams generated during oil production are complex systems. The complexity of their continuous phase makes it difficult to understand what occurs in the foam layers. Some studies have shown that the main species that stabilize foams are asphaltenes, because they reduce the surface tension of the bubbles with their interfacial activity, causing this surface to become viscoelastic. To understand surface viscoelasticity, it is necessary to investigate the rheology of the crude oil/air interface. Since the great majority of works published have used a Du Nouy ring or BiCone accessory to evaluate the surface only of model asphaltene systems, the aim of this work is to study the crude oil/air interface of different crude oil samples and different antifoaming products using the BiCone accessory.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"34 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84415845","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
G. D. Fernandes, E. Araújo, P. T. P. Aum, A. A. R. Diniz, J. L. Barillas
Many of Brazilian heavy oil reserves are located in the Northeast geographic region of Brazil. Presently, those reserves are being recovered using thermal recovery methods. To investigate the opportunity of improving the performance of configurations based on the SAGD process in fields with the characteristics of the Brazilian Northeast, a numerical simulation study was conducted in a semisynthetic reservoir, reproducing those characteristics. A W-SAGD configuration, with two parallel injector wells, in a different vertical alignment was proposed. Results revealed that keeping a steam injection of 200 ton/day anticipated the W-SAGD-25 oil production, improving recovery efficiency.
{"title":"ANALYSIS OF DIFFERENT OIL-WELL CONFIGURATIONS IN THE SAGD PROCESS CONSIDERING PRESSURE DROP AND HEAT LOSS IN THE INJECTION WELL","authors":"G. D. Fernandes, E. Araújo, P. T. P. Aum, A. A. R. Diniz, J. L. Barillas","doi":"10.5419/BJPG2019-0010","DOIUrl":"https://doi.org/10.5419/BJPG2019-0010","url":null,"abstract":"Many of Brazilian heavy oil reserves are located in the Northeast geographic region of Brazil. Presently, those reserves are being recovered using thermal recovery methods. To investigate the opportunity of improving the performance of configurations based on the SAGD process in fields with the characteristics of the Brazilian Northeast, a numerical simulation study was conducted in a semisynthetic reservoir, reproducing those characteristics. A W-SAGD configuration, with two parallel injector wells, in a different vertical alignment was proposed. Results revealed that keeping a steam injection of 200 ton/day anticipated the W-SAGD-25 oil production, improving recovery efficiency.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"156 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-06-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82416014","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
B. C. L. D. Silva, B. C. L. D. Silva, B. Fialho, Isabella Leite Ferraz, L. Vitorazi, J. A. Castro
The study of gas hydrate formation has attracted researchers' attention due to the importance of this topic to oil and gas industries. Gas hydrates can interrupt flow during the petroleum extraction resulting in production losses as well as in safety concerns. Understanding the kinetics of the process is useful to delay hydrate formation by using kinetic inhibitors that are applied often at lower concentrations. Acquisition of experimental data on the process is important to predict ranges of conditions for hydrate formation. This work applies the Johnson-Mehl-Avrami-Kolmogorov (JMAK) phenomenological model for a set of data acquired for pectin, a natural polymer used as kinetic inhibitor, to predict the fraction of hydrate formed. Results suggest the use pectin as potential natural hydrate inhibitor, considering that the data are in agreement with the model’s prediction.
{"title":"PECTIN AS NATURAL GAS HYDRATE INHIBITOR: APPLICATION OF THE AVRAMI MODEL","authors":"B. C. L. D. Silva, B. C. L. D. Silva, B. Fialho, Isabella Leite Ferraz, L. Vitorazi, J. A. Castro","doi":"10.5419/BJPG2019-0008","DOIUrl":"https://doi.org/10.5419/BJPG2019-0008","url":null,"abstract":"The study of gas hydrate formation has attracted researchers' attention due to the importance of this topic to oil and gas industries. Gas hydrates can interrupt flow during the petroleum extraction resulting in production losses as well as in safety concerns. Understanding the kinetics of the process is useful to delay hydrate formation by using kinetic inhibitors that are applied often at lower concentrations. Acquisition of experimental data on the process is important to predict ranges of conditions for hydrate formation. This work applies the Johnson-Mehl-Avrami-Kolmogorov (JMAK) phenomenological model for a set of data acquired for pectin, a natural polymer used as kinetic inhibitor, to predict the fraction of hydrate formed. Results suggest the use pectin as potential natural hydrate inhibitor, considering that the data are in agreement with the model’s prediction.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"46 3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-06-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78517170","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Crude distillation equipment is usually subject to the corrosive activity of acids. This problem could be mitigated by the addition of amines to reduce corrosion effects. The present work applies two different optimization methods, Nelder-Mead (NM) and Particle Swarm Optimization (PSO), to reduce operational costs by adding neutralizing amines. This improvement was accomplished using an in-house software taking into account the following parameters: salt formation temperature, water dew point temperature, and pH in condensate vessel conditions. These operating parameters and the addition of amines were used to minimize the cost in four different case studies. Results show that a considerable cost reduction is possible in several cases when using the global optimization method. Nevertheless, the local search method was less successful in improving the given start point, getting stuck in local minima.
{"title":"COST OPTIMIZATION OF NEUTRALIZING AMINES USED IN DISTILLATION COLUMN OVERHEAD SYSTEMS","authors":"J. Froehlich, R. Soares","doi":"10.5419/BJPG2019-0007","DOIUrl":"https://doi.org/10.5419/BJPG2019-0007","url":null,"abstract":"Crude distillation equipment is usually subject to the corrosive activity of acids. This problem could be mitigated by the addition of amines to reduce corrosion effects. The present work applies two different optimization methods, Nelder-Mead (NM) and Particle Swarm Optimization (PSO), to reduce operational costs by adding neutralizing amines. This improvement was accomplished using an in-house software taking into account the following parameters: salt formation temperature, water dew point temperature, and pH in condensate vessel conditions. These operating parameters and the addition of amines were used to minimize the cost in four different case studies. Results show that a considerable cost reduction is possible in several cases when using the global optimization method. Nevertheless, the local search method was less successful in improving the given start point, getting stuck in local minima.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"39 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-06-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79269155","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Finding an efficient injection strategy using polymers to reduce water-oil mobility ratio and improve sweep efficiency relies on many parameters. To overcome the disadvantages (injectivity loss and high costs) of injecting a continuous polymer bank, an alternative is to alternate water-polymer injection cycles, combining the benefits of water flooding (better injectivity) and polymer flooding (better sweep). A common approach is the injection of a continuous polymer bank after a period of water injection. In this case, parameters of the polymer bank (i.e. duration and starting date of the bank) are control variables and must optimized for the strategy. This work (1) evaluates the impact of alternate water-polymer injection parameters and (2) analyzes the viability of using alternate water-polymer cycles to improve the performance of the polymer flooding strategy, previously optimized for continuous injection bank. We analyze the cycle period, starting date of the cycle, and initial injected fluid using net present value (NPV) and other indicators (cumulative oil and water productions and cost of polymer injection). We apply the study to two reservoir models based on offshore heavy oil fields. The results show that cycle parameters can impact strategy performance significantly and that proper evaluation can benefit production. We observed that reducing the cycle period helped maintain injection flow at higher levels, avoiding the reduction of oil production by pressure depletion. We also noted that the cycle must start in the first years after the beginning of injection. It is important to identify the most influential parameters to set injection levels to support beneficial effects of both methods, and adjust the optimum amount of polymer to be injected.
{"title":"EVALUATION OF ALTERNATE WATER-POLYMER INJECTION PARAMETERS USING NUMERICAL SIMULATION","authors":"V. Botechia, C. Barreto, L. F. Lamas, D. Schiozer","doi":"10.5419/BJPG2019-0009","DOIUrl":"https://doi.org/10.5419/BJPG2019-0009","url":null,"abstract":"Finding an efficient injection strategy using polymers to reduce water-oil mobility ratio and improve sweep efficiency relies on many parameters. To overcome the disadvantages (injectivity loss and high costs) of injecting a continuous polymer bank, an alternative is to alternate water-polymer injection cycles, combining the benefits of water flooding (better injectivity) and polymer flooding (better sweep). A common approach is the injection of a continuous polymer bank after a period of water injection. In this case, parameters of the polymer bank (i.e. duration and starting date of the bank) are control variables and must optimized for the strategy. This work (1) evaluates the impact of alternate water-polymer injection parameters and (2) analyzes the viability of using alternate water-polymer cycles to improve the performance of the polymer flooding strategy, previously optimized for continuous injection bank. We analyze the cycle period, starting date of the cycle, and initial injected fluid using net present value (NPV) and other indicators (cumulative oil and water productions and cost of polymer injection). We apply the study to two reservoir models based on offshore heavy oil fields. The results show that cycle parameters can impact strategy performance significantly and that proper evaluation can benefit production. We observed that reducing the cycle period helped maintain injection flow at higher levels, avoiding the reduction of oil production by pressure depletion. We also noted that the cycle must start in the first years after the beginning of injection. It is important to identify the most influential parameters to set injection levels to support beneficial effects of both methods, and adjust the optimum amount of polymer to be injected.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"27 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-06-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80888275","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
M. Sousa, Wenna Raissa dos Santos Cruz, B. S. Andrade, R. Medronho, R. F. Vianna
Cyclic steam injection is an enhanced oil recovery (EOR) process which is characterized by oil viscosity reduction after the injection of steam into the well. However, like any thermal method, there is great concern regarding the excess of heat coming into the oil well casing, which is susceptible to thermal stress and may damage the reservoir. In order to solve this problem, the company ENGEPET developed the Cyclical Steam Injection and Pneumatic Artificial Lift with water seal (CSI/PAL/WS) system for temperature control in oil well casings. This work proposes a model for predicting the thermal exchange between the water and steam inside the CSI/PAL/WS system using Computational Fluid Dynamics (CFD). A simplified model was proposed and results show that it has great potential to contribute to the study of the CSI/PAL/WS system, as well as to predict operating conditions that may prevent the temperature of well casings to exceed safety limits.
{"title":"COMPUTATIONAL SIMULATION OF CYCLICAL STEAM INJECTION AND PNEUMATIC ARTIFICIAL LIFT SYSTEM WITH WATER SEAL FOR OIL RECOVERY","authors":"M. Sousa, Wenna Raissa dos Santos Cruz, B. S. Andrade, R. Medronho, R. F. Vianna","doi":"10.5419/BJPG2019-0001","DOIUrl":"https://doi.org/10.5419/BJPG2019-0001","url":null,"abstract":"Cyclic steam injection is an enhanced oil recovery (EOR) process which is characterized by oil viscosity reduction after the injection of steam into the well. However, like any thermal method, there is great concern regarding the excess of heat coming into the oil well casing, which is susceptible to thermal stress and may damage the reservoir. In order to solve this problem, the company ENGEPET developed the Cyclical Steam Injection and Pneumatic Artificial Lift with water seal (CSI/PAL/WS) system for temperature control in oil well casings. This work proposes a model for predicting the thermal exchange between the water and steam inside the CSI/PAL/WS system using Computational Fluid Dynamics (CFD). A simplified model was proposed and results show that it has great potential to contribute to the study of the CSI/PAL/WS system, as well as to predict operating conditions that may prevent the temperature of well casings to exceed safety limits.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"66 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86819126","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Crude oil produced as water-in-oil (W/O) emulsion can show high viscosity, causing difficulties during pipeline transportation. The production of O/W emulsion by adding an aqueous phase containing solid particles and surfactant is an alternative to decrease oil viscosity. Thus, the objective of this work is to study the synergistic effect of a surfactant (Triton X-100) and a solid particle (sodium bentonite) addition on emulsion inversion. Emulsions were characterized in conductivity, rheology, kinetic stability, and droplet size analyses. W/O to O/W emulsions inversion occurred when aqueous solutions were between 30 and 40% (m/m), according to conductivity and rheology analyses. The increment of water content from 30 to 50 % (w/w) increased mean droplet size from 2.6 to 10.6 µm, increased phase separation from 9.5 to 68.0 (v/v), and decreased emulsion viscosity from 183 to 1.07 mPa.s. Aqueous solution containing solid particle and surfactant affected emulsions’ properties, producing systems with lower viscosity than crude oil, making it easier for oil pumping and pipeline transportation.
{"title":"EMULSION INVERSION OF CRUDE OIL BY SOLID PARTICLE AND SURFACTANT ADDITION","authors":"A. Mendes, V. S. Santos, R. Santana","doi":"10.5419/BJPG2019-0004","DOIUrl":"https://doi.org/10.5419/BJPG2019-0004","url":null,"abstract":"Crude oil produced as water-in-oil (W/O) emulsion can show high viscosity, causing difficulties during pipeline transportation. The production of O/W emulsion by adding an aqueous phase containing solid particles and surfactant is an alternative to decrease oil viscosity. Thus, the objective of this work is to study the synergistic effect of a surfactant (Triton X-100) and a solid particle (sodium bentonite) addition on emulsion inversion. Emulsions were characterized in conductivity, rheology, kinetic stability, and droplet size analyses. W/O to O/W emulsions inversion occurred when aqueous solutions were between 30 and 40% (m/m), according to conductivity and rheology analyses. The increment of water content from 30 to 50 % (w/w) increased mean droplet size from 2.6 to 10.6 µm, increased phase separation from 9.5 to 68.0 (v/v), and decreased emulsion viscosity from 183 to 1.07 mPa.s. Aqueous solution containing solid particle and surfactant affected emulsions’ properties, producing systems with lower viscosity than crude oil, making it easier for oil pumping and pipeline transportation.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"346 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79664461","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
J. C. Moura, T. Santos, J. S. Silva, K. R. Santos, J. P. Gonçalves, G. Simonelli
Several materials have been added to oil well cement slurries to improve their fresh and hardened properties. Many of these materials are industrial and agroindustrial wastes, and their use promotes sustainable development, avoiding their disposal in the environment. In this context, this study evaluates the rheological behaviour of oil well cement slurries containing granite cutting waste. The slurries were formulated with additions of 10%, 15%, and 20% of granite waste (by weight of cement – BWOC), as well as reference slurry containing only water and Portland cement. The results revealed that slurries containing up to 20% of granite waste presented satisfactory rheological properties, proving their potential for application in oil well cementing operations. Moreover, the addition of 20% of granite waste was not considered detrimental to the compressive strength of the cement slurries.
{"title":"INFLUENCE OF GRANITE WASTE ON THE RHEOLOGICAL BEHAVIOR OF OIL WELL CEMENT SLURRIES","authors":"J. C. Moura, T. Santos, J. S. Silva, K. R. Santos, J. P. Gonçalves, G. Simonelli","doi":"10.5419/BJPG2019-0005","DOIUrl":"https://doi.org/10.5419/BJPG2019-0005","url":null,"abstract":"Several materials have been added to oil well cement slurries to improve their fresh and hardened properties. Many of these materials are industrial and agroindustrial wastes, and their use promotes sustainable development, avoiding their disposal in the environment. In this context, this study evaluates the rheological behaviour of oil well cement slurries containing granite cutting waste. The slurries were formulated with additions of 10%, 15%, and 20% of granite waste (by weight of cement – BWOC), as well as reference slurry containing only water and Portland cement. The results revealed that slurries containing up to 20% of granite waste presented satisfactory rheological properties, proving their potential for application in oil well cementing operations. Moreover, the addition of 20% of granite waste was not considered detrimental to the compressive strength of the cement slurries.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"6 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90351618","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Alessandro Alisson de Lemos Araújo, Wanessa Paulino Neves Silva, E. Foletto, E. Neto
This work examines the thermodynamics of phenol extraction by cloud point varying the ethoxylation degrees of nonylphenolpoliethoxylate surfactants (NPEOn) (9.5, 10, 11 and 12). The Flory-Huggins model was applied to estimate enthalpy (ΔHmix) and entropy (ΔSmix) parameters of the mixture, as well as the aggregate number (N). Results show that ΔHmix and ΔSmix values have a direct relationship with the ethoxylation degree of the surfactant used. Differently, aggregate number (N) values have an inverse relationship with the ethoxylation degree. The fitting to the Flory-Huggins model presented a standard deviation (SD) that ranged from 0.161 to 4.037 for each surfactant studied. It was observed that the increase of the phenol concentration in the surfactant + water system resulted in a decrease in the cloud point of the studied surfactants. These results contribute significantly to the application of this type of surfactant in phenol extraction processes.
{"title":"PHENOL ESTIMATION USING FLORY-HUGGINS PARAMETERS AND CLOUD POINT OF POLIETHOXYLATE SURFACTANTS","authors":"Alessandro Alisson de Lemos Araújo, Wanessa Paulino Neves Silva, E. Foletto, E. Neto","doi":"10.5419/BJPG2019-0002","DOIUrl":"https://doi.org/10.5419/BJPG2019-0002","url":null,"abstract":"This work examines the thermodynamics of phenol extraction by cloud point varying the ethoxylation degrees of nonylphenolpoliethoxylate surfactants (NPEOn) (9.5, 10, 11 and 12). The Flory-Huggins model was applied to estimate enthalpy (ΔHmix) and entropy (ΔSmix) parameters of the mixture, as well as the aggregate number (N). Results show that ΔHmix and ΔSmix values have a direct relationship with the ethoxylation degree of the surfactant used. Differently, aggregate number (N) values have an inverse relationship with the ethoxylation degree. The fitting to the Flory-Huggins model presented a standard deviation (SD) that ranged from 0.161 to 4.037 for each surfactant studied. It was observed that the increase of the phenol concentration in the surfactant + water system resulted in a decrease in the cloud point of the studied surfactants. These results contribute significantly to the application of this type of surfactant in phenol extraction processes.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"35 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78679530","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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