The application of any empirical correlation is recommended only within its range of validity. Nonetheless, the indiscriminate usage of black oil correlations for fluid modeling happens frequently. This work evaluates Lasater’s (1958) correlation for the solution gas-oil ratio (Rs) fluid property specifically for oils with high CO2 content and high GOR. The correlation results are compared to experimental data, and high prediction errors are observed. Finally, the influence of the Rs prediction error on the flow simulation is assessed.
{"title":"EVALUATION OF THE SOLUTION GAS-OIL RATIO CORRELATION PROPOSED BY LASATER APPLIED TO OILS WITH HIGH CO2 AND HIGH GOR","authors":"L. P. Fulchignoni, A. R. Almeida, R. Fonseca Jr.","doi":"10.5419/bjpg2021-0007","DOIUrl":"https://doi.org/10.5419/bjpg2021-0007","url":null,"abstract":"The application of any empirical correlation is recommended only within its range of validity. Nonetheless, the indiscriminate usage of black oil correlations for fluid modeling happens frequently. This work evaluates Lasater’s (1958) correlation for the solution gas-oil ratio (Rs) fluid property specifically for oils with high CO2 content and high GOR. The correlation results are compared to experimental data, and high prediction errors are observed. Finally, the influence of the Rs prediction error on the flow simulation is assessed.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-10-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73163600","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 acquisition of geological data is of fundamental importance for the study of areas potentially relevant to the occurrence of petroleum systems. In this context, the development of research in outcropping rock formations has proven to be a potential method to investigate the geology of the geological unit studied in subsurface. One of several examples found in Brazil are the outcrops Barreiras do Boqueirão and Praia de Japaratinga, belonging to the Maceió Formation, located in the northern coast of Alagoas State. The Maceió Formation has the lowest cretaceous sedimentation record within the Alagoas Basin. This sedimentation, present almost in the entire basin, is located mainly in its subsurface. This geological unit is composed of several lithologies, including a turbiditic sequence predominantly formed by shales, sandstones and conglomerates. This environment makes it possible the occurrence of a petroleum system. Our research group chose to investigate this environment because turbiditic sandstones are excellent petroleum reservoirs, and they have a great economic relevance in the Brazilian petroleum scenario. To develop this research, a petrographic characterization of the Maceió Formation sandstones was conducted to help determine the compositional and diagenetic aspects of these rocks and infer the influence of diagenetic processes on the quality of these sandstones as reservoirs. The petrographic analysis showed that the studied sandstones can be classified as arkose and quartzenite, present moderate porosity and good permeability, observed through the predominant presence of floating contacts between the grains. The porosity is predominantly primary intergranular, averaging 15%, but secondary porosity by fracture and dissolution of primary grains also occurs. The sandstones of the Maceió Formation are poorly and moderately selected, with angular, sub-angular and sub-rounded grains, showing low to medium textural maturity, which may also influence the quality of the reservoir, impairing the primary porosity in the samples. The three diagenetic stages were identified as: eodiagenesis, mesodiagenesis, and telodiagenesis. The diagenetic processes found were: mechanical compaction, beginning of chemical compaction, clay infiltration, pyrite cementation, grain dissolution, chlorite cementation, quartz sintaxial growth, and mineral alteration and replacement. Mineral replacement was a phenomenon observed quite expressively in the samples analyzed. This event was evidenced, particularly, by the substitution of muscovite and feldspar for kaolinite, the alteration of biotite was also identified in the samples. Therefore, one can infer that the diagenetic processes had little influence on the reduction of the original porosity in the samples studied. In general, considering all the analyses performed in this research, one can see that the sandstones of the Maceió Formation (northern portion) present a good reservoir quality.
地质资料的获取对于研究可能与含油气系统产状有关的地区具有重要的基础意义。在这种背景下，对露头岩层的研究已被证明是研究地下地质单元的一种潜在方法。在巴西发现的几个例子之一是Barreiras do boqueir o和Praia de Japaratinga的露头，属于位于Alagoas州北部海岸的Maceió组。Maceió组是阿拉戈斯盆地内白垩纪沉积记录最低的组。这种沉积作用几乎遍及整个盆地，主要分布在盆地的地下。该地质单元由几种岩性组成，包括以页岩、砂岩和砾岩为主的浊积岩层序。这种环境使含油气系统的形成成为可能。我们的研究小组之所以选择研究这种环境，是因为浊积砂岩是一种优秀的油气储层，它们在巴西的石油前景中具有很大的经济意义。为了开展这项研究，对Maceió组砂岩进行了岩石学表征，以帮助确定这些岩石的组成和成岩方面，并推断成岩过程对这些砂岩作为储层质量的影响。岩石学分析表明，研究的砂岩可分为长石岩和石英岩，孔隙度中等，渗透率较好，颗粒间主要存在浮动接触。孔隙度以原生晶间孔隙度为主，平均为15%，但也有原生晶粒破裂和溶蚀作用产生的次生孔隙度。Maceió组砂岩选择偏差，颗粒呈棱角状、次棱角状、次圆角状，结构成熟度低至中等，也可能影响储层质量，影响样品的原生孔隙度。成岩作用分为三个阶段:早期成岩作用、中成岩作用和晚期成岩作用。成岩作用主要有:机械压实作用、化学压实作用开始、粘土渗透作用、黄铁矿胶结作用、颗粒溶蚀作用、绿泥石胶结作用、石英单轴生长作用和矿物蚀变和替代作用。在分析的样品中观察到的矿物质替代现象非常明显。特别是白云母和长石取代了高岭石，在样品中也发现了黑云母的蚀变，证明了这一事件。因此，可以推断成岩作用对所研究样品原始孔隙度的降低影响不大。总的来说，综合本研究的分析，可以看出Maceió组(北部)的砂岩具有良好的储层质量。
{"title":"PETROGRAPHIC CHARACTERIZATION AND DIAGENESIS IN SANDSTONES OUTCROPS OF THE NORTHERN MACEIÓ FORMATION: IMPLICATIONS IN RESERVOIR QUALITY","authors":"M. Tenorio, Z. V. Batista, G. D. Fernandes","doi":"10.5419/bjpg2021-0004","DOIUrl":"https://doi.org/10.5419/bjpg2021-0004","url":null,"abstract":"The acquisition of geological data is of fundamental importance for the study of areas potentially relevant to the occurrence of petroleum systems. In this context, the development of research in outcropping rock formations has proven to be a potential method to investigate the geology of the geological unit studied in subsurface. One of several examples found in Brazil are the outcrops Barreiras do Boqueirão and Praia de Japaratinga, belonging to the Maceió Formation, located in the northern coast of Alagoas State. The Maceió Formation has the lowest cretaceous sedimentation record within the Alagoas Basin. This sedimentation, present almost in the entire basin, is located mainly in its subsurface. This geological unit is composed of several lithologies, including a turbiditic sequence predominantly formed by shales, sandstones and conglomerates. This environment makes it possible the occurrence of a petroleum system. Our research group chose to investigate this environment because turbiditic sandstones are excellent petroleum reservoirs, and they have a great economic relevance in the Brazilian petroleum scenario. To develop this research, a petrographic characterization of the Maceió Formation sandstones was conducted to help determine the compositional and diagenetic aspects of these rocks and infer the influence of diagenetic processes on the quality of these sandstones as reservoirs. The petrographic analysis showed that the studied sandstones can be classified as arkose and quartzenite, present moderate porosity and good permeability, observed through the predominant presence of floating contacts between the grains. The porosity is predominantly primary intergranular, averaging 15%, but secondary porosity by fracture and dissolution of primary grains also occurs. The sandstones of the Maceió Formation are poorly and moderately selected, with angular, sub-angular and sub-rounded grains, showing low to medium textural maturity, which may also influence the quality of the reservoir, impairing the primary porosity in the samples. The three diagenetic stages were identified as: eodiagenesis, mesodiagenesis, and telodiagenesis. The diagenetic processes found were: mechanical compaction, beginning of chemical compaction, clay infiltration, pyrite cementation, grain dissolution, chlorite cementation, quartz sintaxial growth, and mineral alteration and replacement. Mineral replacement was a phenomenon observed quite expressively in the samples analyzed. This event was evidenced, particularly, by the substitution of muscovite and feldspar for kaolinite, the alteration of biotite was also identified in the samples. Therefore, one can infer that the diagenetic processes had little influence on the reduction of the original porosity in the samples studied. In general, considering all the analyses performed in this research, one can see that the sandstones of the Maceió Formation (northern portion) present a good reservoir quality.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-06-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78633710","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}
Hydraulic fracturing consists of a technique capable of stimulating oil wells that have suffered a decline in production over time. It also allows the production in reservoirs that have low permeability through the creation of a network of channels in the rock. In this context, this article aims to numerically simulate the hydraulic fracturing applied in a sandstone reservoir according to data extracted from an oil well located in the Aracaju City field of the Sergipe-Alagoas Basin. To complete this study, a geological model of the reservoir was generated. Subsequently, a fracture was created in the rock-reservoir in a controlled manner using the Perkins and Kern fracture model. Results show that the fracture takes a satisfactory proportion in the reservoir rock, reaching a depth of penetration equivalent to 695.7 meters.
{"title":"HYDRAULIC FRACTURING OF AN ARENITIC RESERVOIR BASED IN THE PERKINS-KERN MODEL USING A STIMPLAN SIMULATOR","authors":"G. B. Silva, L. Rojas, J. A. Soares","doi":"10.5419/bjpg2021-0001","DOIUrl":"https://doi.org/10.5419/bjpg2021-0001","url":null,"abstract":"Hydraulic fracturing consists of a technique capable of stimulating oil wells that have suffered a decline in production over time. It also allows the production in reservoirs that have low permeability through the creation of a network of channels in the rock. In this context, this article aims to numerically simulate the hydraulic fracturing applied in a sandstone reservoir according to data extracted from an oil well located in the Aracaju City field of the Sergipe-Alagoas Basin. To complete this study, a geological model of the reservoir was generated. Subsequently, a fracture was created in the rock-reservoir in a controlled manner using the Perkins and Kern fracture model. Results show that the fracture takes a satisfactory proportion in the reservoir rock, reaching a depth of penetration equivalent to 695.7 meters.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-06-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90447140","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}
This work addresses the transportation of viscous crude oil as concentrated oil-in-water (O/W) emulsions flowing in a partially submerged onshore pipeline. The main goal of this study is to analyze the effects of inversion point of the water-in-oil emulsion in the pressure drop with the aid of Pipesim® software. Pressure drop is determined by applying the Dukler correlation (Taitel and Dukler, 1976) to represent dead oil viscosity as a function of temperature, and API density using the Hossain correlation (Hossain et al., 2005). The Brinkman model (Brinkman, 1952) is applied to calculate the viscosity of the emulsion, with the Brauner and Ullmann (2002) equation for the water cut off method (inversion point). The pipeline, of 3,600 m and 4 inches in diameter, transports the oil and consists of three sections. The first and third sections are above ground and are in contact with the external environment. The intermediate section is sitting on the river bed and is the critical part of the pipeline, once high heat losses are observed. The results of this 1D and non-isothermal problem show that water cuts of 5 and 6%, for low heat exchange and high heat exchange, respectively, make it possible to transport the oil, as an oil-in-water emulsion, through the entire extension of the pipeline. However, a water cut of 10% creates a high-pressure drop in the system, assuring the movement of the fluid in long sections without compromising the system operation. The use of isolation influences the temperature gradient but doesn’t have a high influence on pressure gradient compared to emulsions.
本研究解决了稠油在部分淹没的陆上管道中作为浓缩水包油(O/W)乳剂的输送问题。本研究的主要目的是借助Pipesim®软件分析油包水乳液的反转点对压降的影响。压降是通过应用Dukler相关(Taitel和Dukler, 1976)来表示死油粘度作为温度的函数，而API密度则使用Hossain相关(Hossain et al.， 2005)。采用Brinkman模型(Brinkman, 1952)计算乳状液的黏度，采用Brauner and Ullmann(2002)方程计算水截断法(反演点)。该管道长3600米，直径4英寸，由三段组成，用于输送石油。第一部分和第三部分在地面上，与外部环境接触。中间段位于河床上，是管道的关键部分，一旦观察到高热损失。该一维和非等温问题的结果表明，对于低换热和高换热，含水率分别为5%和6%，使得油作为水包油乳化液通过整个管道延伸输送成为可能。然而，10%的含水率会在系统中产生高压降，确保流体在长段内的运动，而不会影响系统的运行。与乳剂相比，隔离的使用会影响温度梯度，但对压力梯度的影响不大。
{"title":"INVERSION POINT OF EMULSIONS AS A MECHANISM OF HEAD LOSS REDUCTION IN ONSHORE PIPELINE HEAVY OIL FLOW","authors":"M. Justiniano, O. J. Romero","doi":"10.5419/bjpg2021-0002","DOIUrl":"https://doi.org/10.5419/bjpg2021-0002","url":null,"abstract":"This work addresses the transportation of viscous crude oil as concentrated oil-in-water (O/W) emulsions flowing in a partially submerged onshore pipeline. The main goal of this study is to analyze the effects of inversion point of the water-in-oil emulsion in the pressure drop with the aid of Pipesim® software. Pressure drop is determined by applying the Dukler correlation (Taitel and Dukler, 1976) to represent dead oil viscosity as a function of temperature, and API density using the Hossain correlation (Hossain et al., 2005). The Brinkman model (Brinkman, 1952) is applied to calculate the viscosity of the emulsion, with the Brauner and Ullmann (2002) equation for the water cut off method (inversion point). The pipeline, of 3,600 m and 4 inches in diameter, transports the oil and consists of three sections. The first and third sections are above ground and are in contact with the external environment. The intermediate section is sitting on the river bed and is the critical part of the pipeline, once high heat losses are observed. The results of this 1D and non-isothermal problem show that water cuts of 5 and 6%, for low heat exchange and high heat exchange, respectively, make it possible to transport the oil, as an oil-in-water emulsion, through the entire extension of the pipeline. However, a water cut of 10% creates a high-pressure drop in the system, assuring the movement of the fluid in long sections without compromising the system operation. The use of isolation influences the temperature gradient but doesn’t have a high influence on pressure gradient compared to emulsions.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-06-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88948946","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. R. Santana, J. S. Nunes, I. Pergher, L. Silva, R. V. S. Aquino
This paper presents a flowchart monitoring study to be used on investigating conditions that can promote environmental impact. The study relies on a computational simulation of the natural gas separation process, using COCO modeling software and communication of the WAR algorithm. The WAR algorithm is a methodology used to analyze the potential environmental impact (PEI) of a chemical process, and to study the environmental compatibility of this process. The WAR algorithm proved efficient and effective when accessing the CCO currents to obtain pressure and temperature parameters of each equipment used in the modeling and simulation of the plant. The results indicate the need for optimization requiring further research on ways to reduce the impact generated by the terrestrial toxicity potential, the toxicity potential for man, and the photochemical oxidation potential, which presented higher PEI generated in the process.
{"title":"FLOWCHART MONITORING FOR THE DEVELOPMENT OF SUSTAINABLE PROCESSES USING THE WASTE REDUCTION ALGORITHM IN A NATURAL GAS PRODUCTION PLANT","authors":"R. R. Santana, J. S. Nunes, I. Pergher, L. Silva, R. V. S. Aquino","doi":"10.5419/bjpg2021-0003","DOIUrl":"https://doi.org/10.5419/bjpg2021-0003","url":null,"abstract":"This paper presents a flowchart monitoring study to be used on investigating conditions that can promote environmental impact. The study relies on a computational simulation of the natural gas separation process, using COCO modeling software and communication of the WAR algorithm. The WAR algorithm is a methodology used to analyze the potential environmental impact (PEI) of a chemical process, and to study the environmental compatibility of this process. The WAR algorithm proved efficient and effective when accessing the CCO currents to obtain pressure and temperature parameters of each equipment used in the modeling and simulation of the plant. The results indicate the need for optimization requiring further research on ways to reduce the impact generated by the terrestrial toxicity potential, the toxicity potential for man, and the photochemical oxidation potential, which presented higher PEI generated in the process.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-06-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80964739","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}
A. Carvalho, D. Galindo, M. S. C. Tenório, J. G. O. Marinho
Fluids produced from oil reservoirs typically contain oil, natural gas, water, sediments, in varying amounts, and contaminating gases. Considering that economic interest usually targets mostly oil and gas, primary processing is used to separate water/oil/gas, in addition to treating these phases. Therefore, the well stream should be processed as soon as possible after reaching the surface. Separator vessels are among the main equipment used at surface production facilities, being responsible for the separation of the produced phases. This work focuses on studying the fluid dynamic behavior in a horizontal three-phase separator. To accomplish this goal, we used the computer fluid dynamics software ANSYS CFX. First, we performed a detailed analysis of a “Standard Case” to understand in detail the entire separation process within the vessel. The results show the three phases through the simulation time, analyses of the separation efficiency, different fluids flow lines, pressure gradient inside the vessel, and effect of the diverter baffle. It also considers a variation of fluid flow at the inlet of the separator. These analyses include pictures of all cases studied. Afterwards, some parameters of the standard case were altered to evaluate its influence on fluid dynamics behavior and the functioning of the separator vessel. At last, we analyzed the influences of oil density and viscosity on the separation. The oil quality affects the primary separation directly, as the oil density and viscosity increase, for example, increases the drag between the fluids and decreases the rate of sedimentation, which stickles the separation process difficult. Two out of the three cases generated satisfactory results. The simulation with the heaviest oil presented the worse results.
{"title":"MODELING AND SIMULATION OF A HORIZONTAL THREE-PHASE SEPARATOR: INFLUENCE OF PHYSICOCHEMICAL PROPERTIES OF OIL","authors":"A. Carvalho, D. Galindo, M. S. C. Tenório, J. G. O. Marinho","doi":"10.5419/BJPG2020-0016","DOIUrl":"https://doi.org/10.5419/BJPG2020-0016","url":null,"abstract":"Fluids produced from oil reservoirs typically contain oil, natural gas, water, sediments, in varying amounts, and contaminating gases. Considering that economic interest usually targets mostly oil and gas, primary processing is used to separate water/oil/gas, in addition to treating these phases. Therefore, the well stream should be processed as soon as possible after reaching the surface. Separator vessels are among the main equipment used at surface production facilities, being responsible for the separation of the produced phases. This work focuses on studying the fluid dynamic behavior in a horizontal three-phase separator. To accomplish this goal, we used the computer fluid dynamics software ANSYS CFX. First, we performed a detailed analysis of a “Standard Case” to understand in detail the entire separation process within the vessel. The results show the three phases through the simulation time, analyses of the separation efficiency, different fluids flow lines, pressure gradient inside the vessel, and effect of the diverter baffle. It also considers a variation of fluid flow at the inlet of the separator. These analyses include pictures of all cases studied. Afterwards, some parameters of the standard case were altered to evaluate its influence on fluid dynamics behavior and the functioning of the separator vessel. At last, we analyzed the influences of oil density and viscosity on the separation. The oil quality affects the primary separation directly, as the oil density and viscosity increase, for example, increases the drag between the fluids and decreases the rate of sedimentation, which stickles the separation process difficult. Two out of the three cases generated satisfactory results. The simulation with the heaviest oil presented the worse results.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-01-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84408299","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}
Polymer flooding has been widely used for enhancing oil recovery, due to the growing number of successful applications around the world. The process aims to increase water viscosity and, thus, decrease the water/oil mobility ratio, thereby improving sweep efficiency. The understanding of the physical mechanisms involved in this enhanced oil recovery process allows us to forecast the application potential of polymer flooding. This work aims to assess physical phenomena associated with heavy oil recovery through polymer flooding using 1D small-scale simulation models. We evaluate the influence of different levels of adsorption, accessible pore volume, residual resistance factor, and polymer concentration on the results and compare their magnitude effect on the results. The models used in this study were built using data from previous lab work and literature. For each one of the mentioned parameters, this work compares the histories of water cut, cumulative water-oil ratio, average pressure, and oil recovery factor. Additionally, water saturation, water viscosity, and water mobility profile were determined for specific periods of the flooding process. The sensitivity analyses showed that high levels of adsorption influence the polymer loss of the advance front, delaying oil recovery. Low values of accessible pore volume lead to a slightly faster polymer breakthrough and oil recovery anticipation. A high residual resistance factor increases the average pressure and improves oil recovery. Higher polymer concentration enhances the displacement efficiency and enhances the recovery factor.
{"title":"SENSITIVITY ANALYSIS FOR POLYMER INJECTION TO IMPROVE HEAVY OIL RECOVERY – SMALL-SCALE SIMULATION STUDY","authors":"M. Zampieri, C. Quispe, R. Moreno","doi":"10.5419/BJPG2020-0018","DOIUrl":"https://doi.org/10.5419/BJPG2020-0018","url":null,"abstract":"Polymer flooding has been widely used for enhancing oil recovery, due to the growing number of successful applications around the world. The process aims to increase water viscosity and, thus, decrease the water/oil mobility ratio, thereby improving sweep efficiency. The understanding of the physical mechanisms involved in this enhanced oil recovery process allows us to forecast the application potential of polymer flooding. This work aims to assess physical phenomena associated with heavy oil recovery through polymer flooding using 1D small-scale simulation models. We evaluate the influence of different levels of adsorption, accessible pore volume, residual resistance factor, and polymer concentration on the results and compare their magnitude effect on the results. The models used in this study were built using data from previous lab work and literature. For each one of the mentioned parameters, this work compares the histories of water cut, cumulative water-oil ratio, average pressure, and oil recovery factor. Additionally, water saturation, water viscosity, and water mobility profile were determined for specific periods of the flooding process. The sensitivity analyses showed that high levels of adsorption influence the polymer loss of the advance front, delaying oil recovery. Low values of accessible pore volume lead to a slightly faster polymer breakthrough and oil recovery anticipation. A high residual resistance factor increases the average pressure and improves oil recovery. Higher polymer concentration enhances the displacement efficiency and enhances the recovery factor.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-01-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82797194","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}
Relative permeability curves obtained in laboratory are used in reservoir simulators to predict production and establish the best strategies for an oil field. Therefore, researchers study several procedures to obtain relative permeability curves. Among these procedures are the multiple flow rates injection methods. Thus, this work proposes to develop an experimental procedure with multiple increasing flows. To make this feasible, simulations were initially carried out at CYDAR, aiming to establish flow rates and time necessary to achieve system stabilization, within the limits of the equipment. After that, tests were carried out establishing the minimum time of 5 hours to stabilize the oil production, and the differential pressure at each flow rate. The accounting and minimization of the capillary end effect in these tests were also evaluated. Capillary pressure constraints contributed to minimize the number of possible solutions to the optimization problem improving the fit of solutions for a specific case.
{"title":"EVALUATION OF CAPILLARY END EFFECT IN WATER-OIL PERMEABILITY TESTS USING MULTIPLE FLOW RATES TECHNIQUE","authors":"I. D. Santos, F. Eler, D. Nunes, P. Couto","doi":"10.5419/BJPG2020-0019","DOIUrl":"https://doi.org/10.5419/BJPG2020-0019","url":null,"abstract":"Relative permeability curves obtained in laboratory are used in reservoir simulators to predict production and establish the best strategies for an oil field. Therefore, researchers study several procedures to obtain relative permeability curves. Among these procedures are the multiple flow rates injection methods. Thus, this work proposes to develop an experimental procedure with multiple increasing flows. To make this feasible, simulations were initially carried out at CYDAR, aiming to establish flow rates and time necessary to achieve system stabilization, within the limits of the equipment. After that, tests were carried out establishing the minimum time of 5 hours to stabilize the oil production, and the differential pressure at each flow rate. The accounting and minimization of the capillary end effect in these tests were also evaluated. Capillary pressure constraints contributed to minimize the number of possible solutions to the optimization problem improving the fit of solutions for a specific case.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-01-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81498201","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. Nobrega, A. S. Zimmermann, S. Mattedi, O. Chiavone-Filho
Distillation columns are important separation equipment that comprise most of the investment needed in a petroleum refining plant. Utilities and energy demands, though, are a concerning factor in the current economic and environmental scenario. The present work proposes a methodology to optimize the energy consumption of a crude oil distillation column using the Distop Calibration technique that allows faster convergence than the Tray-to-Tray method. The methodology presented involves process simulation, sensitivity analysis, factorial design, and the use of response surface methodology. Results show that it is possible to achieve significant gains by changing feed temperature and rectifying vapor flow, causing a relevant reduction in energy consumption. Hence, the methodology can be used as an optimization tool to increase energetic efficiency.
{"title":"OPTIMIZATION OF A PETROLEUM FRACTIONAL DISTILLATION COLUMN USING DISTOP CALIBRATION AND STATISTICAL METHODS","authors":"M. Nobrega, A. S. Zimmermann, S. Mattedi, O. Chiavone-Filho","doi":"10.5419/BJPG2020-0017","DOIUrl":"https://doi.org/10.5419/BJPG2020-0017","url":null,"abstract":"Distillation columns are important separation equipment that comprise most of the investment needed in a petroleum refining plant. Utilities and energy demands, though, are a concerning factor in the current economic and environmental scenario. The present work proposes a methodology to optimize the energy consumption of a crude oil distillation column using the Distop Calibration technique that allows faster convergence than the Tray-to-Tray method. The methodology presented involves process simulation, sensitivity analysis, factorial design, and the use of response surface methodology. Results show that it is possible to achieve significant gains by changing feed temperature and rectifying vapor flow, causing a relevant reduction in energy consumption. Hence, the methodology can be used as an optimization tool to increase energetic efficiency.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-01-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79236246","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}
One of the main problems of the oil industry is hydrate formation. Hydrates of natural gas are crystalline solids, formed by the association of water molecules and molecules of certain gas in an organized structure. Its occurrence is a natural concern for the Oil & Gas Industry, given the potential risk of flow assurance. Nevertheless, ever-challenging scenarios encourage the search for risk assessment methodologies seeking to identify conditions where hydrates will form, but with little possibility of plugging. The present study aims to develop a water-in-oil emulsion capable of giving hydrate at ambient pressure. This work analyzes the effects of water and surfactant concentration in viscosity, storage, and dissipation modulus in a model water-in-oil emulsion. Rheological data are obtained for several combinations of emulsion components, and their mechanical behavior is related to hydrate formation.
{"title":"RHEOLOGY CHARACTERIZATION OF WATER-IN-OIL EMULSIONS","authors":"P. Silva, M. Naccache, Paulo Mendes","doi":"10.5419/bjpg2020-0011","DOIUrl":"https://doi.org/10.5419/bjpg2020-0011","url":null,"abstract":"One of the main problems of the oil industry is hydrate formation. Hydrates of natural gas are crystalline solids, formed by the association of water molecules and molecules of certain gas in an organized structure. Its occurrence is a natural concern for the Oil & Gas Industry, given the potential risk of flow assurance. Nevertheless, ever-challenging scenarios encourage the search for risk assessment methodologies seeking to identify conditions where hydrates will form, but with little possibility of plugging. The present study aims to develop a water-in-oil emulsion capable of giving hydrate at ambient pressure. This work analyzes the effects of water and surfactant concentration in viscosity, storage, and dissipation modulus in a model water-in-oil emulsion. Rheological data are obtained for several combinations of emulsion components, and their mechanical behavior is related to hydrate formation.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2020-10-06","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76633204","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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