M. R. Ferreira, G. S. M. Reis, R. C. P. Nunes, E. F. Lucas
Stable water-in-oil (w/o) emulsions are undesirable from an operational standpoint, with the asphaltenes present in petroleum being considered the main stabilizers of these emulsions. Demulsifiers are agents added to destabilize these emulsions. The objective of this work is to evaluate the stability of w/o emulsions formed from an oil phase with different polarities (kerosene and toluene) containing asphaltene fractions C3I, C5I, and C7I, and how these systems affect the action of a demulsifier additive. Systems containing asphaltenes in toluene were more stable when using the C7I fraction due to its greater polarity and, consequently, considerable action at the interface. With the oil phase composed of a less polar solvent (kerosene), the C3I fraction increased the stability of the emulsion by reducing the action of the demulsifying additive, with an upper asphaltenes concentration limit of 1.0% observed where the action of the demulsifying agent was affected.
{"title":"SYNTHETIC WATER-IN-OIL EMULSIONS: EFFECT OF OIL COMPOSITION ON STABILITY AND DEMULSIFIER PERFORMANCE","authors":"M. R. Ferreira, G. S. M. Reis, R. C. P. Nunes, E. F. Lucas","doi":"10.5419/bjpg2024-0007","DOIUrl":"https://doi.org/10.5419/bjpg2024-0007","url":null,"abstract":"Stable water-in-oil (w/o) emulsions are undesirable from an operational standpoint, with the asphaltenes present in petroleum being considered the main stabilizers of these emulsions. Demulsifiers are agents added to destabilize these emulsions. The objective of this work is to evaluate the stability of w/o emulsions formed from an oil phase with different polarities (kerosene and toluene) containing asphaltene fractions C3I, C5I, and C7I, and how these systems affect the action of a demulsifier additive. Systems containing asphaltenes in toluene were more stable when using the C7I fraction due to its greater polarity and, consequently, considerable action at the interface. With the oil phase composed of a less polar solvent (kerosene), the C3I fraction increased the stability of the emulsion by reducing the action of the demulsifying additive, with an upper asphaltenes concentration limit of 1.0% observed where the action of the demulsifying agent was affected.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-07-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141685290","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. M. Santana, V. C. T. de Souza, H. O. da Rocha, J. A. O. Marinho
This research describes the direct and inverse problems of cross-well electromagnetic tomography. The model geometry has azimuthal symmetry, which simplifies the forward modeling and the inversion procedure. In the direct problem, the finite element method is used in the numerical solution of the Helmholtz equation. In the inverse problem, the study discusses the use of three stabilizer functionals: Global Smoothness (GS), Total Variation (TV), and Absolute Equality (AE). The first uses a smoothing function in the L2 norm, while the latter uses smoothing in the L1 norm, for it accepts abrupt changes between adjacent parameters. The results show that the TV method generated good estimates of both geometry and conductivity of the bodies, both for small and large conductivity contrast between the targets and the surrounding environment. Through the results, one can also observe that the regularization of the Total Variation presented a better estimate of the parameters than the Global Smoothness. In most of the synthetic models used in this work, the best estimates of the proposed model occurred when Absolute Equality constraints were used on the cells at the edges of the inversion grid, in addition to the stabilizer functional.
{"title":"WELL-TO-WELL (W2W) ELECTROMAGNETIC TOMOGRAPHY MODELING ADVANCEMENT: IMPROVING PRECISION AND EFFECTIVENESS WITH REGULARIZATION","authors":"J. M. Santana, V. C. T. de Souza, H. O. da Rocha, J. A. O. Marinho","doi":"10.5419/bjpg2024-0005","DOIUrl":"https://doi.org/10.5419/bjpg2024-0005","url":null,"abstract":"This research describes the direct and inverse problems of cross-well electromagnetic tomography. The model geometry has azimuthal symmetry, which simplifies the forward modeling and the inversion procedure. In the direct problem, the finite element method is used in the numerical solution of the Helmholtz equation. In the inverse problem, the study discusses the use of three stabilizer functionals: Global Smoothness (GS), Total Variation (TV), and Absolute Equality (AE). The first uses a smoothing function in the L2 norm, while the latter uses smoothing in the L1 norm, for it accepts abrupt changes between adjacent parameters. The results show that the TV method generated good estimates of both geometry and conductivity of the bodies, both for small and large conductivity contrast between the targets and the surrounding environment. Through the results, one can also observe that the regularization of the Total Variation presented a better estimate of the parameters than the Global Smoothness. In most of the synthetic models used in this work, the best estimates of the proposed model occurred when Absolute Equality constraints were used on the cells at the edges of the inversion grid, in addition to the stabilizer functional.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-07-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141686025","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. M. O. Silveira, V. Botechia, D. J. Schiozer, A. Skauge
In immiscible displacements, lower viscosity injected fluids with higher mobility than crude oil can create viscous fingers, affecting displacement efficiency. The Buckley–Leverett approach for relative permeabilities (kr) may not represent accurately 2D features like increased water saturation in viscous fingering. Based on the physics issue, this work applies Sorbie's 4-Steps methodology to a 3D simulation of an offshore heavy oil reservoir focusing on waterflooding and tertiary polymer flooding, assessing their impact on oil production forecasts. It also explores the application of this methodology to coarse grid simulation models, employing pseudo kr functions by data assimilation. During tertiary polymer injection, two processes were identified in oil displacement: viscous crossflow mechanism and oil bank mobilization by a second finger. This combination resulted in earlier and increased oil production. For both strategies, refining the grid increased simulation runtime from minutes to days compared to coarse grids, making it impractical for intensive processes. From data assimilation, the best solution with matched field indicators reduced runtime from days to minutes. This study expanded the 4-Steps methodology for 3D reservoir simulation, proposing kr as uncertainties. Data assimilation enhances the methodology, generating pseudo kr for coarser grid simulations, reducing computational costs, and capturing small-scale phenomena.
{"title":"IMMISCIBLE VISCOUS FINGERING MODELING OF TERTIARY POLYMER FLOODING BASED ON REAL CASE OF HEAVY OIL RESERVOIR MODEL","authors":"B. M. O. Silveira, V. Botechia, D. J. Schiozer, A. Skauge","doi":"10.5419/bjpg2024-0006","DOIUrl":"https://doi.org/10.5419/bjpg2024-0006","url":null,"abstract":"In immiscible displacements, lower viscosity injected fluids with higher mobility than crude oil can create viscous fingers, affecting displacement efficiency. The Buckley–Leverett approach for relative permeabilities (kr) may not represent accurately 2D features like increased water saturation in viscous fingering. Based on the physics issue, this work applies Sorbie's 4-Steps methodology to a 3D simulation of an offshore heavy oil reservoir focusing on waterflooding and tertiary polymer flooding, assessing their impact on oil production forecasts. It also explores the application of this methodology to coarse grid simulation models, employing pseudo kr functions by data assimilation. During tertiary polymer injection, two processes were identified in oil displacement: viscous crossflow mechanism and oil bank mobilization by a second finger. This combination resulted in earlier and increased oil production. For both strategies, refining the grid increased simulation runtime from minutes to days compared to coarse grids, making it impractical for intensive processes. From data assimilation, the best solution with matched field indicators reduced runtime from days to minutes. This study expanded the 4-Steps methodology for 3D reservoir simulation, proposing kr as uncertainties. Data assimilation enhances the methodology, generating pseudo kr for coarser grid simulations, reducing computational costs, and capturing small-scale phenomena.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-07-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141684339","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}
R. T. Landim, M. M. F. Melo Neta, F. J. S. Barros, C. L. Cavalcante Jr., F. M. T. Luna
The scale inhibitor squeeze treatment is an important method used in the petroleum industry to control formation of inorganic deposition within the oil production wells. This treatment increases the life cycle of petroleum production by preventing or reducing the formation and growth of salt crystals. In recent years, studies on inhibitor squeeze treatments have been expanding and diversifying with the goal of improving the lifespan and reducing treatment costs. This study reports an advanced bibliometric analysis from 1970 to 2023, illustrating the extent of research on inhibitor squeeze treatments to prevent the formation of inorganic scale, with a systematic survey since the first registered publication. It highlights the evolution of research reports, assessing the relationships between institutions, journals, and authors, identifying of potential needs to be addressed by future investigations.
{"title":"SCALE INHIBITOR SQUEEZE TREATMENT: AN ADVANCED BIBLIOMETRIC ANALYSIS","authors":"R. T. Landim, M. M. F. Melo Neta, F. J. S. Barros, C. L. Cavalcante Jr., F. M. T. Luna","doi":"10.5419/bjpg2024-0008","DOIUrl":"https://doi.org/10.5419/bjpg2024-0008","url":null,"abstract":"The scale inhibitor squeeze treatment is an important method used in the petroleum industry to control formation of inorganic deposition within the oil production wells. This treatment increases the life cycle of petroleum production by preventing or reducing the formation and growth of salt crystals. In recent years, studies on inhibitor squeeze treatments have been expanding and diversifying with the goal of improving the lifespan and reducing treatment costs. This study reports an advanced bibliometric analysis from 1970 to 2023, illustrating the extent of research on inhibitor squeeze treatments to prevent the formation of inorganic scale, with a systematic survey since the first registered publication. It highlights the evolution of research reports, assessing the relationships between institutions, journals, and authors, identifying of potential needs to be addressed by future investigations.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2024-07-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"141688233","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}
Microbial control in oil fields can be considered a complex subject, since microbiome diversity and physical-chemical characteristics of produced water (PW) originate a unique profile in oil fields. Standard biocides are used as chemical treatment, but the toxicity and the high volumes can cause elevated environmental impacts. Treatment effectiveness and, consequently, reduction of environmental impact may be improved through an adequate planning. The present study examines the bacterial resistance mechanisms to biocides and suggests a 5-step approach for the treatment planning: 1) determination of objectives; 2) bioaudit; 3) selection of biocide(s) in laboratory; 4) selection of representative Key Performance Indicators (KPI); and 5) monitoring of the treatment. Finally, this article demonstrates an optimization of a biocide treatment using the 5-step approach. The results show a reduction of approximately 50% in the dosage of the biocide, as well as reduction in frequency of dosage.
{"title":"IMPROVING MICROBIAL CONTROL IN PRODUCED WATER FROM OIL FIELDS: A 5-STEP APPROACH","authors":"G. F. Pereira, T. R. Rosin, B. Braga, G. Corção","doi":"10.5419/bjpg2023-0015","DOIUrl":"https://doi.org/10.5419/bjpg2023-0015","url":null,"abstract":"Microbial control in oil fields can be considered a complex subject, since microbiome diversity and physical-chemical characteristics of produced water (PW) originate a unique profile in oil fields. Standard biocides are used as chemical treatment, but the toxicity and the high volumes can cause elevated environmental impacts. Treatment effectiveness and, consequently, reduction of environmental impact may be improved through an adequate planning. The present study examines the bacterial resistance mechanisms to biocides and suggests a 5-step approach for the treatment planning: 1) determination of objectives; 2) bioaudit; 3) selection of biocide(s) in laboratory; 4) selection of representative Key Performance Indicators (KPI); and 5) monitoring of the treatment. Finally, this article demonstrates an optimization of a biocide treatment using the 5-step approach. The results show a reduction of approximately 50% in the dosage of the biocide, as well as reduction in frequency of dosage.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-12-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"138952438","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}
I. S. Melo, V. L. A. Gomes, M. A. Costa Júnior, E. V. Bautista
The sand production happens when the reservoir begins its productive life, and the consolidation of the grains that compose the framework of the oil-producing formation is not enough to keep them cohesive. The front of the drag force is caused by the flow of fluids inside the pores of the rock-reservoir. Therefore, reservoir parameters must be analyzed to observe how they behave considering the production of solids. The operational parameters used in this study were compressional wave, shear wave and gamma ray profiles, depth, average overburden density, reservoir fluid pressure, and bottom pressure in flow during production. These data allowed us to predict the production of sand in a mature oil reservoir. The results show that in the zones that presented solids production, through the control of the dynamic pressure, it is possible to control the production of sand and determine the critical point of its production.
{"title":"ANALYSIS OF SAND PRODUCTION CONTROL IN A MATURE OIL RESERVOIR THROUGH ELECTRICAL WELL PROFILES","authors":"I. S. Melo, V. L. A. Gomes, M. A. Costa Júnior, E. V. Bautista","doi":"10.5419/bjpg2023-0009","DOIUrl":"https://doi.org/10.5419/bjpg2023-0009","url":null,"abstract":"The sand production happens when the reservoir begins its productive life, and the consolidation of the grains that compose the framework of the oil-producing formation is not enough to keep them cohesive. The front of the drag force is caused by the flow of fluids inside the pores of the rock-reservoir. Therefore, reservoir parameters must be analyzed to observe how they behave considering the production of solids. The operational parameters used in this study were compressional wave, shear wave and gamma ray profiles, depth, average overburden density, reservoir fluid pressure, and bottom pressure in flow during production. These data allowed us to predict the production of sand in a mature oil reservoir. The results show that in the zones that presented solids production, through the control of the dynamic pressure, it is possible to control the production of sand and determine the critical point of its production.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-12-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"138950237","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. von Hohendorff Filho, I. R. S. Victorino, A. Bigdeli, D. J. Schiozer
The objective of this work is to evaluate the impact of integration between reservoir and production systems on the decision making for field production development. The authors demonstrated, in a benchmark case, the applicability of water injection (WI) and water alternating gas injection (WAG) techniques for various production systems by proposing a novel methodology. This work explores three optimization approaches: (1) based on the complete model considering integrated systems, (2) for production system based solely on reservoir model and followed by the integration and optimization of production system, and (3) derived from (2) considering subsequent integration and optimization for complete model. In the implementation step, production strategies are applied in a reference model. This work compares production strategies, reservoir performance forecast, and the net present value (NPV) objective function. The integrated models yeild similar objective-function values by utilizing a production system that does not alter the bottom-hole conditions significantly, thereby replicating the behavior observed in the non-integrated model. The results of non-integrated reservoir optimizations should be used with caution for decision-making purposes, as the subsequent integration may cause the changes to the the production forecasts. The differences in reservoir behaviors can be attributed to the changes in the dynamics (movement) of fluids from the reservoir to the wells and the type of recovery mechanism affected by well positioning. The implementation of production strategies in the reference model resulted in lower values of NPV (20% for WI and 60% for WAG) than those obtained in the optimization step. The findings demand caution in the application of closed-loop procedures to prevent biased or inaccurate assessments of decisions made solely based on reservoir models. The application of this work can be considered an import study for Carbon Capture Utilization and Storage (CCUS), as well as for energy transition based on WAG optimization.
{"title":"APPLICATION OF WATER FLOODING AND WATER ALTERNATIVE GAS (WAG) FLOODING TECHNIQUES IN A CARBONATE RESERVOIR: INTEGRATION OF RESERVOIR AND PRODUCTION SYSTEMS FOR DECISION MAKING","authors":"J. C. von Hohendorff Filho, I. R. S. Victorino, A. Bigdeli, D. J. Schiozer","doi":"10.5419/bjpg2023-0012","DOIUrl":"https://doi.org/10.5419/bjpg2023-0012","url":null,"abstract":"The objective of this work is to evaluate the impact of integration between reservoir and production systems on the decision making for field production development. The authors demonstrated, in a benchmark case, the applicability of water injection (WI) and water alternating gas injection (WAG) techniques for various production systems by proposing a novel methodology. This work explores three optimization approaches: (1) based on the complete model considering integrated systems, (2) for production system based solely on reservoir model and followed by the integration and optimization of production system, and (3) derived from (2) considering subsequent integration and optimization for complete model. In the implementation step, production strategies are applied in a reference model. This work compares production strategies, reservoir performance forecast, and the net present value (NPV) objective function. The integrated models yeild similar objective-function values by utilizing a production system that does not alter the bottom-hole conditions significantly, thereby replicating the behavior observed in the non-integrated model. The results of non-integrated reservoir optimizations should be used with caution for decision-making purposes, as the subsequent integration may cause the changes to the the production forecasts. The differences in reservoir behaviors can be attributed to the changes in the dynamics (movement) of fluids from the reservoir to the wells and the type of recovery mechanism affected by well positioning. The implementation of production strategies in the reference model resulted in lower values of NPV (20% for WI and 60% for WAG) than those obtained in the optimization step. The findings demand caution in the application of closed-loop procedures to prevent biased or inaccurate assessments of decisions made solely based on reservoir models. The application of this work can be considered an import study for Carbon Capture Utilization and Storage (CCUS), as well as for energy transition based on WAG optimization.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-12-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"138951765","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}
Life cycle management of oil fields involves complex decisions, with many variables to be considered. In some fields of the Brazilian pre-salt, this task is even more challenging given the ultra-deep water location, with an expressive amount of gas (including CO2) production. This feature becomes a restricting factor for oil production in these types of fields, and a proper management is essential to overcome this issue, improving both production and economic returns. Therefore, Water-Alternate-Gas (WAG) is often used as an Enhanced Oil Recovery- EOR mechanism, providing a better mobility control, improving reservoir sweep and oil recovery. Moreover, WAG can be an alternative for recycling the produced gas, providing an adequate destination (mainly for CO2) and avoiding environmental problems. In this case, we name the method as WAG-CO2. Moreover, Interval Control Valves (ICVs) are also a good alternative to deal with these fields, since they work as flow control devices and allow for a better balance of the fluid flow in the reservoir. In this work, we evaluate the impact of the use of ICVs in producers, injectors, along with WAG cycles size to improve the performance of a developed field. The work consists of two parts. In Part I, using a single simulation model, we performed (1) six hierarchical optimization approaches to verify if the order in which the optimization occurs influences the final results, and (2) a joint optimization of all parameters for comparison purposes. The final strategies are simulated in a reference case (representing the “true response” of the field) to evaluate how the achieved control rules would behave in a real field. In Part II, we considered a probabilistic procedure, applying one of the hierarchical approaches in several representative models (RMs) expressing uncertain scenarios. In this case, we compared nominal optimization of individual RMs against a robust optimization (in which all RMs are optimized simultaneously). The study is applied to the benchmark case SEC1_2022, a synthetic model analogous to a pre-salt field. The results show an expressive increase in the economic return of the field with a proper operation of the ICVs and size of the WAG-CO2 cycles, despite the platform being restricted by gas production capacity. This result occurred because of a better balance in fluid flow through the reservoir and among wells. Moreover, in the first part of the work, all hierarchical approaches presented very similar results in terms of NPV, so the order of the optimization steps did not significantly affect the results. The non-hierarchical approach presented a slightly better result, but still close to those obtained in the hierarchical approaches. Furthermore, the most impacting variable was the ICV for producers, followed by ICV for injectors and, then, WAG-CO2 cycles. Similar tendencies were observed in the second part of the work, with higher expected economic return for the robust optimization.
{"title":"MODEL-BASED OPTIMIZATION OF ICVs’ CONTROL FOR PRODUCERS, INJECTORS, AND WAG-CO2 CYCLES SIZE IN A CARBONATE RESERVOIR UNDER UNCERTAINTY","authors":"V. Botechia, D. J. Schiozer","doi":"10.5419/bjpg2023-0010","DOIUrl":"https://doi.org/10.5419/bjpg2023-0010","url":null,"abstract":"Life cycle management of oil fields involves complex decisions, with many variables to be considered. In some fields of the Brazilian pre-salt, this task is even more challenging given the ultra-deep water location, with an expressive amount of gas (including CO2) production. This feature becomes a restricting factor for oil production in these types of fields, and a proper management is essential to overcome this issue, improving both production and economic returns. Therefore, Water-Alternate-Gas (WAG) is often used as an Enhanced Oil Recovery- EOR mechanism, providing a better mobility control, improving reservoir sweep and oil recovery. Moreover, WAG can be an alternative for recycling the produced gas, providing an adequate destination (mainly for CO2) and avoiding environmental problems. In this case, we name the method as WAG-CO2. Moreover, Interval Control Valves (ICVs) are also a good alternative to deal with these fields, since they work as flow control devices and allow for a better balance of the fluid flow in the reservoir. In this work, we evaluate the impact of the use of ICVs in producers, injectors, along with WAG cycles size to improve the performance of a developed field. The work consists of two parts. In Part I, using a single simulation model, we performed (1) six hierarchical optimization approaches to verify if the order in which the optimization occurs influences the final results, and (2) a joint optimization of all parameters for comparison purposes. The final strategies are simulated in a reference case (representing the “true response” of the field) to evaluate how the achieved control rules would behave in a real field. In Part II, we considered a probabilistic procedure, applying one of the hierarchical approaches in several representative models (RMs) expressing uncertain scenarios. In this case, we compared nominal optimization of individual RMs against a robust optimization (in which all RMs are optimized simultaneously). The study is applied to the benchmark case SEC1_2022, a synthetic model analogous to a pre-salt field. The results show an expressive increase in the economic return of the field with a proper operation of the ICVs and size of the WAG-CO2 cycles, despite the platform being restricted by gas production capacity. This result occurred because of a better balance in fluid flow through the reservoir and among wells. Moreover, in the first part of the work, all hierarchical approaches presented very similar results in terms of NPV, so the order of the optimization steps did not significantly affect the results. The non-hierarchical approach presented a slightly better result, but still close to those obtained in the hierarchical approaches. Furthermore, the most impacting variable was the ICV for producers, followed by ICV for injectors and, then, WAG-CO2 cycles. Similar tendencies were observed in the second part of the work, with higher expected economic return for the robust optimization.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-12-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"138952046","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}
E. R. Silva, E. L. Barros Neto, P. F. P. Nascimento, H. M. N. Oliveira, G. G. Medeiros, L. J. N. Duarte
The present study analyzes the hydrothermal liquefaction of residual coffee biomass using glycerin from the production of biodiesel through the homogeneous route. The reactions occurred by varying the glycerol/water ratio (1:0, 1:1, and 1:2) and the solvent/biomass ratio (70 and 90%) with heating at 180°C for 30 minutes (mixing phase) and at 250°C for 15 minutes. The products obtained were identified as light bio-oil (BOL), heavy bio-oil (BOP), gaseous fraction (FG), and solids (SOL). These products were submitted to characterization through density, thermogravimetry, and viscosity analyses. The condition that generated the highest oil yields was the one where 70% solvent and a glycerin/water ratio of 1:2 were used, producing approximately 83% of bio-oils. In this perspective, coffee biomass and residual glycerin were suitable for use in the hydrothermal liquefaction process.
{"title":"LIQUEFACTION OF COFFEE BIOMASS WITH RESIDUAL GLYCERIN: A STUDY OF RENEWABLE FUEL PRODUCTION","authors":"E. R. Silva, E. L. Barros Neto, P. F. P. Nascimento, H. M. N. Oliveira, G. G. Medeiros, L. J. N. Duarte","doi":"10.5419/bjpg2023-0011","DOIUrl":"https://doi.org/10.5419/bjpg2023-0011","url":null,"abstract":"The present study analyzes the hydrothermal liquefaction of residual coffee biomass using glycerin from the production of biodiesel through the homogeneous route. The reactions occurred by varying the glycerol/water ratio (1:0, 1:1, and 1:2) and the solvent/biomass ratio (70 and 90%) with heating at 180°C for 30 minutes (mixing phase) and at 250°C for 15 minutes. The products obtained were identified as light bio-oil (BOL), heavy bio-oil (BOP), gaseous fraction (FG), and solids (SOL). These products were submitted to characterization through density, thermogravimetry, and viscosity analyses. The condition that generated the highest oil yields was the one where 70% solvent and a glycerin/water ratio of 1:2 were used, producing approximately 83% of bio-oils. In this perspective, coffee biomass and residual glycerin were suitable for use in the hydrothermal liquefaction process.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-12-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"138952218","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}
The high production of CO2 from Brazilian pre-salt reservoirs requires research on CO2 interactions with carbonate reservoirs for enhanced oil recovery (EOR) or CO2 trapping. This interaction causes reactive phenomena that are not fully understood. Experimental tests on carbonate facies are crucial for understanding reactions and their impact on reservoir characteristics. This study investigates experimentally reactions generated by reactive fluid flow in carbonate rocks from two geological scenarios by analyzing chemical and morphological parameters before and after the tests. Salinity was the most significant parameter for reactive flow, impacting porosity for modern continental carbonate samples from Patagonia. However, the sample from the Brazilian pre-salt showed higher mineral stability and less mineral dissolution. Results provide data for simulating reactive transport in these rocks for CCS and understanding diagenetic processes' impact on reservoir quality.
{"title":"REACTIVE FLOW IN CARBONATE ROCKS FROM LACUSTRINE ENVIRONMENTS: THE EFFECTS OF PRESSURE AND FLUID SALINITY","authors":"K. C. Silva, L. F. Cury, L. F. L. Luz Junior","doi":"10.5419/bjpg2023-0013","DOIUrl":"https://doi.org/10.5419/bjpg2023-0013","url":null,"abstract":"The high production of CO2 from Brazilian pre-salt reservoirs requires research on CO2 interactions with carbonate reservoirs for enhanced oil recovery (EOR) or CO2 trapping. This interaction causes reactive phenomena that are not fully understood. Experimental tests on carbonate facies are crucial for understanding reactions and their impact on reservoir characteristics. This study investigates experimentally reactions generated by reactive fluid flow in carbonate rocks from two geological scenarios by analyzing chemical and morphological parameters before and after the tests. Salinity was the most significant parameter for reactive flow, impacting porosity for modern continental carbonate samples from Patagonia. However, the sample from the Brazilian pre-salt showed higher mineral stability and less mineral dissolution. Results provide data for simulating reactive transport in these rocks for CCS and understanding diagenetic processes' impact on reservoir quality.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-12-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"138949915","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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