E. P. Frutuoso e Melo, T. Gurova, S. Estefen, A. Leontiev
Flexible pipes have been used for decades for conveying produced fluids from oil wells to floating production, for storing and offloading units, and for flowing injection fluids inside wells under the seabed. Over the years, with an increase in oil demand globally, the exploration of new and deeper oil reservoirs has become a reality. With greater water depths, the top tension of the risers has increased significantly, as well as the pressure from the water column on the pipe structure, demanding the application of bigger pipes and the use of stronger materials. Pre-salt reservoirs on the Brazilian basins are rich in carbon dioxide (CO2) and hydrogen sulfide (H2S), which are great contributors to the premature fragilization of armour wires on the top section of the flexible risers and are capable of compromising the integrity of the structure. The wire fragilization and possible breakages cannot be avoided once the riser is connected to the floating unit, but they can be monitored, to avoid a complete riser structural failure. Several systems have been developed to monitor tensile armour wires integrity, such as visual monitoring, which visually detects torsion on the structure, acoustic waves, and magnetic collar systems, which have failed to provide reliable results. As the armour wires provide axial resistance to the structures, Fiber Bragg grating is being used in modern flexibles to monitor armour wire deformation and has been delivering reliable results. Another method, the inverse magnetostriction, is being tested using an anisotropic magneto sensor to detect wire deformation and generate a 2D stress map of the measured area. In this article, two tests are performed using the same equipment, but in different specimen. One test was performed on the wires without being applied on the flexible structure. The other test was performed on a window opened on a 6” nominal bore flexible pipe, with the objective of identifying if the method is reliable in detecting armour wire failures on flexible risers. This method could read stresses variations on the armour wires, but a larger sensor could penetrate deeper on the structure and provide a sharper stress map.
{"title":"INTEGRITY ANALYSIS OF FLEXIBLE PIPES TENSILE ARMOUR WIRES USING NON-DESTRUCTIVE METHOD OF INVERSE MAGNETOSTRICTION: A METHOD COMPARISON","authors":"E. P. Frutuoso e Melo, T. Gurova, S. Estefen, A. Leontiev","doi":"10.5419/bjpg2022-0003","DOIUrl":"https://doi.org/10.5419/bjpg2022-0003","url":null,"abstract":"Flexible pipes have been used for decades for conveying produced fluids from oil wells to floating production, for storing and offloading units, and for flowing injection fluids inside wells under the seabed. Over the years, with an increase in oil demand globally, the exploration of new and deeper oil reservoirs has become a reality. With greater water depths, the top tension of the risers has increased significantly, as well as the pressure from the water column on the pipe structure, demanding the application of bigger pipes and the use of stronger materials. Pre-salt reservoirs on the Brazilian basins are rich in carbon dioxide (CO2) and hydrogen sulfide (H2S), which are great contributors to the premature fragilization of armour wires on the top section of the flexible risers and are capable of compromising the integrity of the structure. The wire fragilization and possible breakages cannot be avoided once the riser is connected to the floating unit, but they can be monitored, to avoid a complete riser structural failure. Several systems have been developed to monitor tensile armour wires integrity, such as visual monitoring, which visually detects torsion on the structure, acoustic waves, and magnetic collar systems, which have failed to provide reliable results. As the armour wires provide axial resistance to the structures, Fiber Bragg grating is being used in modern flexibles to monitor armour wire deformation and has been delivering reliable results. Another method, the inverse magnetostriction, is being tested using an anisotropic magneto sensor to detect wire deformation and generate a 2D stress map of the measured area. In this article, two tests are performed using the same equipment, but in different specimen. One test was performed on the wires without being applied on the flexible structure. The other test was performed on a window opened on a 6” nominal bore flexible pipe, with the objective of identifying if the method is reliable in detecting armour wire failures on flexible risers. This method could read stresses variations on the armour wires, but a larger sensor could penetrate deeper on the structure and provide a sharper stress map.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"206 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80424199","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 shows a procedure to build fast and reliable numerical models with WAG-CO2-rich injection scheme. This novel and practical approach to numerical tuning high-complexity reservoir models can save days or even months of work. Improving step 2 of the 12-step reservoir characterization and modeling methodology proposed by Schiozer et al. (2015) leads to an optimization of the numerical control of the model based on the critical compositional numerical parameters and performance diagnostics. We show the results of a probabilistic risk analysis application. For the complex case scenario presented, results show that applying the proposed technique can save roughly 80% of the total time spent to perform a risk study. Furthermore, we found that time saving tends to increase as the number of simulations increases. This work improvement comes from making a methodology that includes both compositional and black-oil numerical solver parameters in every step of the numerical tuning optimization, rendering a broader and more robust method.
{"title":"COMPUTATIONAL TIME REDUCTION OF COMPOSITIONAL RESERVOIR SIMULATION MODEL WITH WAG INJECTION AND GAS RECYCLE SCHEME THROUGH NUMERICAL TUNING OF SUBMODELS","authors":"S. F. Mello, G. Avansi, V. Rios, D. Schiozer","doi":"10.5419/bjpg2022-0004","DOIUrl":"https://doi.org/10.5419/bjpg2022-0004","url":null,"abstract":"This work shows a procedure to build fast and reliable numerical models with WAG-CO2-rich injection scheme. This novel and practical approach to numerical tuning high-complexity reservoir models can save days or even months of work. Improving step 2 of the 12-step reservoir characterization and modeling methodology proposed by Schiozer et al. (2015) leads to an optimization of the numerical control of the model based on the critical compositional numerical parameters and performance diagnostics. We show the results of a probabilistic risk analysis application. For the complex case scenario presented, results show that applying the proposed technique can save roughly 80% of the total time spent to perform a risk study. Furthermore, we found that time saving tends to increase as the number of simulations increases. This work improvement comes from making a methodology that includes both compositional and black-oil numerical solver parameters in every step of the numerical tuning optimization, rendering a broader and more robust method.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87934071","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 installation of slotted liners in horizontal wells controls formation sand production and prevents damage to installed downhole and surface facilities. Howbeit, while mitigating sand production, slotted liners also create skin problems when formation fines plug the slots, causing flow convergence and turbulence. These problems create additional pressure drop around the wellbore and, thus, reduction in production. A new analytical skin model is developed to account for the total skin slotted liners that incorporates distance between slots. Moreover, the effects of skin on flow rate, slot penetration ratio, slot width, distance between slots, wellbore radius, and slot length were also investigated. Results from this model show good agreement when validated with existing models. With an application illustrated in this paper, this model can be used in the optimization of slotted liner designs.
{"title":"MODEL FOR DETERMINING TOTAL SKIN IN HORIZONTAL WELLS COMPLETED WITH SLOTTED LINERS","authors":"A. Joseph, E. Ike","doi":"10.5419/bjpg2022-0002","DOIUrl":"https://doi.org/10.5419/bjpg2022-0002","url":null,"abstract":"The installation of slotted liners in horizontal wells controls formation sand production and prevents damage to installed downhole and surface facilities. Howbeit, while mitigating sand production, slotted liners also create skin problems when formation fines plug the slots, causing flow convergence and turbulence. These problems create additional pressure drop around the wellbore and, thus, reduction in production. A new analytical skin model is developed to account for the total skin slotted liners that incorporates distance between slots. Moreover, the effects of skin on flow rate, slot penetration ratio, slot width, distance between slots, wellbore radius, and slot length were also investigated. Results from this model show good agreement when validated with existing models. With an application illustrated in this paper, this model can be used in the optimization of slotted liner designs.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"25 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73053766","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}
Large companies in the oil sector have been expanding their activities to the renewable energy segment. The objective of this work is to identify patterns and relationships - in the 10 last years - between oil price and prices of the following renewable energies: wind, hydroelectric, solar, and bioenergy. The analysis of standards and the identification of relationships help decision-makers to define strategies and increase operation efficiency. Besides, it contributes to the development of models capable of predicting, interpreting, and testing hypotheses about the data. The main analytical and data treatment methodology used in this work comprises statistical tests involving Cross-Correlation and Granger Causality. The Cross-Correlation Test showed a strong negative correlation between oil and wind energy prices, and the Granger’s test did not show causality between them. New studies comparing oil and renewable energy prices by country and covering a longer period can bring interesting results.
{"title":"RELATIONSHIP BETWEEN OIL AND RENEWABLE ENERGIES PRICES","authors":"R. Branski, S. Oku","doi":"10.5419/bjpg2022-0001","DOIUrl":"https://doi.org/10.5419/bjpg2022-0001","url":null,"abstract":"Large companies in the oil sector have been expanding their activities to the renewable energy segment. The objective of this work is to identify patterns and relationships - in the 10 last years - between oil price and prices of the following renewable energies: wind, hydroelectric, solar, and bioenergy. The analysis of standards and the identification of relationships help decision-makers to define strategies and increase operation efficiency. Besides, it contributes to the development of models capable of predicting, interpreting, and testing hypotheses about the data. The main analytical and data treatment methodology used in this work comprises statistical tests involving Cross-Correlation and Granger Causality. The Cross-Correlation Test showed a strong negative correlation between oil and wind energy prices, and the Granger’s test did not show causality between them. New studies comparing oil and renewable energy prices by country and covering a longer period can bring interesting results.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"51 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73398750","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}
In the Brazilian popular imagination, the discovery of oil was announced on August 9, 1938, by the Viscount of Corncob. The Donabentense Oil Company drilled Caraminguá’s first well, near the creek that passed through the Yellow Woodpecker Ranch (“Sítio do Picapau Amarelo,” in colloquial Portuguese). The latter was the name of a famous Brazilian children’s book. In fact, the first oil well flowed in Salvador, Bahia, on January 21, 1939, discovered by Manoel Ignácio Bastos (1891 - 1940), a Brazilian geographer engineer, whose business partner, Oscar Salvador Cordeiro (1890 - 1970), was the president of the Bahia Commodities Exchange. A brief analysis of documents, such as reports, Brazilian decrees and executive orders, as well as newspapers, detail the actions of these Brazilian oil pioneers. Statistical data analysis was also performed about onshore and offshore oil production between 1941 and 2019, as a part of Bastos and Cordeiros’ heritage.
在巴西民众的想象中，石油的发现是在1938年8月9日由玉米芯子爵宣布的。Donabentense石油公司在流经黄啄木鸟牧场(“Sítio do Picapau Amarelo”，葡萄牙语口语)的小溪附近，钻了caramingu的第一口井。后者是一本著名的巴西儿童读物的名字。事实上，巴伊亚州萨尔瓦多的第一口油井是1939年1月21日由巴西地理学家工程师Manoel Ignácio Bastos(1891 - 1940)发现的，他的商业伙伴Oscar Salvador Cordeiro(1890 - 1970)是巴伊亚商品交易所的总裁。对报告、巴西法令和行政命令以及报纸等文件的简要分析，详细介绍了这些巴西石油先驱的行动。作为Bastos和Cordeiros遗产的一部分，还对1941年至2019年期间的陆上和海上石油生产进行了统计数据分析。
{"title":"BRAZILIAN OIL PIONEERS","authors":"Marcio Luis Ferreira Nascimento","doi":"10.5419/bjpg2021-0009","DOIUrl":"https://doi.org/10.5419/bjpg2021-0009","url":null,"abstract":"In the Brazilian popular imagination, the discovery of oil was announced on August 9, 1938, by the Viscount of Corncob. The Donabentense Oil Company drilled Caraminguá’s first well, near the creek that passed through the Yellow Woodpecker Ranch (“Sítio do Picapau Amarelo,” in colloquial Portuguese). The latter was the name of a famous Brazilian children’s book. In fact, the first oil well flowed in Salvador, Bahia, on January 21, 1939, discovered by Manoel Ignácio Bastos (1891 - 1940), a Brazilian geographer engineer, whose business partner, Oscar Salvador Cordeiro (1890 - 1970), was the president of the Bahia Commodities Exchange. A brief analysis of documents, such as reports, Brazilian decrees and executive orders, as well as newspapers, detail the actions of these Brazilian oil pioneers. Statistical data analysis was also performed about onshore and offshore oil production between 1941 and 2019, as a part of Bastos and Cordeiros’ heritage.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"103 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-01-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75669684","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}
Pre-salt reservoirs are among the most important discoveries in recent decades due to the large quantities of oil in them. However, high levels of uncertainties related to its large gas/CO2 production prompt a more complex gas/CO2 management, including the use of alternating water and gas/CO2 injection (WAG) as a recovery mechanism to increase oil recovery from the field. The purpose of this work is to develop a methodology to manage cycle sizes of the WAG/CO2, and analyze the impact of other variables related to the management of producing wells during the process. The methodology was applied to a benchmark synthetic reservoir model with pre-salt characteristics. We used five approaches to evaluate the optimum cycle size under study, also assessing the impact of the management of producing wells: (A) without closing producers due to gas-oil ratio (GOR) limit; (B) GOR limit fixed at a fixed value (1600 m³/m³) for all wells; (C) GOR limit optimized per well; (D) joint optimization between GOR limit values of producers and WAG cycles; and (E) optimization of the cycle size per injector well with an optimized GOR limit. The results showed that the optimum cycle size depends on the management of the producers. Leaving all production wells open until the end of the field's life (without closing based on the GOR limit) or controlling the wells in a more restricted manner (with closing based on the GOR limit), led to significant variation of the results (optimal size of the WAG/CO2 cycles). Our study, therefore, demonstrates that the optimum cycle size depends on other control variables and can change significantly due to these variables. This work presents a study that aimed to manage the WAG-CO2 injection cycle size by optimizing the life cycle control variables to obtain better economic performance within the premises already established, such as the total reinjection of gas/CO2 produced, also analyzing the impact of other variables (management of producing wells) along with the WAG-CO2 cycles.
{"title":"MODEL-BASED OPTIMIZATION OF CYCLES OF CO2 WATER-ALTERNATING-GAS (CO2-WAG) INJECTION IN CARBONATE RESERVOIR","authors":"F. Pereira, V. Botechia, D. Schiozer","doi":"10.5419/bjpg2021-0012","DOIUrl":"https://doi.org/10.5419/bjpg2021-0012","url":null,"abstract":"Pre-salt reservoirs are among the most important discoveries in recent decades due to the large quantities of oil in them. However, high levels of uncertainties related to its large gas/CO2 production prompt a more complex gas/CO2 management, including the use of alternating water and gas/CO2 injection (WAG) as a recovery mechanism to increase oil recovery from the field. The purpose of this work is to develop a methodology to manage cycle sizes of the WAG/CO2, and analyze the impact of other variables related to the management of producing wells during the process. The methodology was applied to a benchmark synthetic reservoir model with pre-salt characteristics. We used five approaches to evaluate the optimum cycle size under study, also assessing the impact of the management of producing wells: (A) without closing producers due to gas-oil ratio (GOR) limit; (B) GOR limit fixed at a fixed value (1600 m³/m³) for all wells; (C) GOR limit optimized per well; (D) joint optimization between GOR limit values of producers and WAG cycles; and (E) optimization of the cycle size per injector well with an optimized GOR limit. The results showed that the optimum cycle size depends on the management of the producers. Leaving all production wells open until the end of the field's life (without closing based on the GOR limit) or controlling the wells in a more restricted manner (with closing based on the GOR limit), led to significant variation of the results (optimal size of the WAG/CO2 cycles). Our study, therefore, demonstrates that the optimum cycle size depends on other control variables and can change significantly due to these variables. This work presents a study that aimed to manage the WAG-CO2 injection cycle size by optimizing the life cycle control variables to obtain better economic performance within the premises already established, such as the total reinjection of gas/CO2 produced, also analyzing the impact of other variables (management of producing wells) along with the WAG-CO2 cycles.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"32 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-01-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87434618","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 paper aims to analyze the use of Brazilian shale gas in power generation, including carbon dioxide capture by cogeneration from the flue gases (CCU – Carbon Capture Utilization). Besides producing electricity, the idea is to generate additional revenue by making the carbon dioxide stream available to companies interested in its commercial exploitation, requiring its recovery, purification, and liquefaction.
{"title":"THE USE OF SHALE GAS FOR POWER GENERATION WITH CARBON CAPTURE","authors":"F. Cörner da Costa","doi":"10.5419/bjpg2021-0011","DOIUrl":"https://doi.org/10.5419/bjpg2021-0011","url":null,"abstract":"This paper aims to analyze the use of Brazilian shale gas in power generation, including carbon dioxide capture by cogeneration from the flue gases (CCU – Carbon Capture Utilization). Besides producing electricity, the idea is to generate additional revenue by making the carbon dioxide stream available to companies interested in its commercial exploitation, requiring its recovery, purification, and liquefaction.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"13 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-01-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84805984","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}
To analyze the economic viability of Pelican Lake field, located in Canada, some scenarios using enhanced oil recovery methods were simulated by request of the field operator, Canadian Natural Resources Limited. Surfactant concentrations influence essential characteristics responsible for promoting good recovery, lowering interfacial tension of fluids and aiding oil bank mobility. Considering different polymer and surfactant concentrations in the injection water and using the PumaFlow software, 5 (five) scenarios of fluid injection were simulated. Results show that the oil recovery factor is directly proportional to the concentration of chemical agents. Among the injection tests carried out, the one with the best performance was the case presenting a concentration of 1400 ppm of polymer and 3000 ppm of surfactant in the injected water, allowing a larger oil production from the field. The case presenting the best outcomes had a 50% higher net present value if compared to the water injection case, as well as an increase of 4.85 percent points in the recovery factor. In addition, for each barrel of additional oil produced, only USD 8.18 is spent on chemical agents, which makes it a cost-effective solution to oil production.
{"title":"ANALYSIS OF ENHANCED OIL RECOVERY IN THE PELICAN LAKE FIELD USING SURFACTANT AND POLYMER INJECTION","authors":"R. Delazeri, L. F. Lamas","doi":"10.5419/bjpg2021-0006","DOIUrl":"https://doi.org/10.5419/bjpg2021-0006","url":null,"abstract":"To analyze the economic viability of Pelican Lake field, located in Canada, some scenarios using enhanced oil recovery methods were simulated by request of the field operator, Canadian Natural Resources Limited. Surfactant concentrations influence essential characteristics responsible for promoting good recovery, lowering interfacial tension of fluids and aiding oil bank mobility. Considering different polymer and surfactant concentrations in the injection water and using the PumaFlow software, 5 (five) scenarios of fluid injection were simulated. Results show that the oil recovery factor is directly proportional to the concentration of chemical agents. Among the injection tests carried out, the one with the best performance was the case presenting a concentration of 1400 ppm of polymer and 3000 ppm of surfactant in the injected water, allowing a larger oil production from the field. The case presenting the best outcomes had a 50% higher net present value if compared to the water injection case, as well as an increase of 4.85 percent points in the recovery factor. In addition, for each barrel of additional oil produced, only USD 8.18 is spent on chemical agents, which makes it a cost-effective solution to oil production.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"135 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86355306","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}
Floating Production, Storage, and Offloading (FPSOs) are vessels utilized to produce, process, and storage oil in deep water. Determining its chartering price is a complex task, but it is critical to ensure economic viability and the profit of shareholders. The objective of this study is to propose a pricing model for FPSOs chartering. The pricing model was constructed through the elaboration of a cash flow that considers the input values - contract rate and real operating time (uptime) – and the outputs – investment, operational costs, financial costs, and taxes. The definition of cash flow structure was based on several proposals to FPSOs chartering in Brazil and papers published in scientific journals and Congress proceedings. The model allows analyzing different scenarios by varying parameters such as investment and operational costs, and financing conditions. So, it can support the analysis of the FPSO contract price and contribute to the evaluation of charter proposals.
{"title":"PRICING MODEL FOR FPSO CHARTERING","authors":"R. Branski, M. Jesús","doi":"10.5419/bjpg2021-0005","DOIUrl":"https://doi.org/10.5419/bjpg2021-0005","url":null,"abstract":"Floating Production, Storage, and Offloading (FPSOs) are vessels utilized to produce, process, and storage oil in deep water. Determining its chartering price is a complex task, but it is critical to ensure economic viability and the profit of shareholders. The objective of this study is to propose a pricing model for FPSOs chartering. The pricing model was constructed through the elaboration of a cash flow that considers the input values - contract rate and real operating time (uptime) – and the outputs – investment, operational costs, financial costs, and taxes. The definition of cash flow structure was based on several proposals to FPSOs chartering in Brazil and papers published in scientific journals and Congress proceedings. The model allows analyzing different scenarios by varying parameters such as investment and operational costs, and financing conditions. So, it can support the analysis of the FPSO contract price and contribute to the evaluation of charter proposals.","PeriodicalId":9312,"journal":{"name":"Brazilian Journal of Petroleum and Gas","volume":"49 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-10-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80115701","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 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":"230 1","pages":""},"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}
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