Katia Souza d'Almeida, Marcos Frederico Farias de Souza, N. O. Castro, Pamela Cardoso Vilela, Raul Fagundes Leggieri, Regina Freitas Fernandes, R. A. Cardoso
This regional study proposes a regional evaluation of the petroleum potential of the Brazilian Equatorial Margin (EQM), based on the analysis of exploratory plays, in the geological context of the sedimentary basins that compose it. A methodological approach is adopted where plays are the key geological concept and the Geographic Information System (GIS) is the computational tool. The first step is the mapping of the plays' factors (charge, reservoir and trap systems). Subsequently, using geoprocessing techniques, the segments of the plays' factors (subplays) are qualitatively evaluated for geological favorability knowledge. The knowledge of charge, reservoir and trap elements of each exploratory play allows to observe the prospectivity of the area, despite the limitation of data availability at the exploratory frontier basins that make up the EQM. In this work, we have mapped exploratory superplays associated to the EQM's reservoirs with different characteristics and ages. The greatest chances of hydrocarbon discovery were observed in the central portion of the basins that make up the Brazilian EQM, near the 1,500 m isobath; medium and low chances occured in the rest of the effective basin.
{"title":"Exploratory Potential of the Brazilian Equatorial Margin","authors":"Katia Souza d'Almeida, Marcos Frederico Farias de Souza, N. O. Castro, Pamela Cardoso Vilela, Raul Fagundes Leggieri, Regina Freitas Fernandes, R. A. Cardoso","doi":"10.4043/29689-ms","DOIUrl":"https://doi.org/10.4043/29689-ms","url":null,"abstract":"\u0000 This regional study proposes a regional evaluation of the petroleum potential of the Brazilian Equatorial Margin (EQM), based on the analysis of exploratory plays, in the geological context of the sedimentary basins that compose it. A methodological approach is adopted where plays are the key geological concept and the Geographic Information System (GIS) is the computational tool. The first step is the mapping of the plays' factors (charge, reservoir and trap systems). Subsequently, using geoprocessing techniques, the segments of the plays' factors (subplays) are qualitatively evaluated for geological favorability knowledge. The knowledge of charge, reservoir and trap elements of each exploratory play allows to observe the prospectivity of the area, despite the limitation of data availability at the exploratory frontier basins that make up the EQM. In this work, we have mapped exploratory superplays associated to the EQM's reservoirs with different characteristics and ages. The greatest chances of hydrocarbon discovery were observed in the central portion of the basins that make up the Brazilian EQM, near the 1,500 m isobath; medium and low chances occured in the rest of the effective basin.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89842028","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}
L. P. Fulchignoni, M. A. Cardoso, A. Oshiro, T. D. F. D. Santos, L. A. Pinto, Djalene Maria Rocha
The conceptual stage of an oil and gas production projects comprises the identification and the subsequent evaluation of a suite of feasible alternatives for the production system. The evaluation process embraces several disciplines, both technical and economical. It is a common practice for each discipline to work individually, following its own internal process, where external information is treated as a definite input. When organized in this way, the process of evaluating the global production system tends to be complex, involving many professionals and information exchange, and time consuming, since it is performed sequentially. In addition, it is necessary to ensure that the results of each discipline converge to a common point, which is the global result for each production system scenario. In order to achieve this convergence, cycles of iteration between the disciplines may be required, which also contributes to the longer duration of the process. This paper proposes a framework that integrates individual simulation models of Reservoir and Flow Assurance with organizational economic premises. The framework was set to give as a result the NPV (Net Present Value) of each offshore production systems alternative, among other operational and economic metrics. The framework also integrates optimizers that propose the best reservoir drainage plan, FPU (Floating Production Unit) location and subsea layout for each alternative. A real case study is presented in order to exemplify its functionalities. The production system considered consists of three independent offshore reservoirs producing to the same production facility, through subsea manifolds and long tie-backs. The integrated simulation allowed for a quick and easy selection process of the production system alternative with higher economic return. There was a drastic reduction on the response time for the evaluation of the alternatives, which is essential to meet the growing dynamism of the oil and gas industry. The results confirmed the importance of the integrated simulation, both for the optimization of the alternatives evaluation process, and for the identification of gains of synergy among the several disciplines involved in project of high complexity. The use of integrated simulation is expected to continue increasing in the coming years in the oil and gas industry, as well as the robustness of the technique. The novelty of the integrated simulation framework is in the ability to efficiently run a wide number of simulations and optimizations for the production system and help to select the most suitable one.
{"title":"Integrated Simulation of Offshore Oil and Gas Production Systems During Project Design","authors":"L. P. Fulchignoni, M. A. Cardoso, A. Oshiro, T. D. F. D. Santos, L. A. Pinto, Djalene Maria Rocha","doi":"10.4043/29733-ms","DOIUrl":"https://doi.org/10.4043/29733-ms","url":null,"abstract":"\u0000 The conceptual stage of an oil and gas production projects comprises the identification and the subsequent evaluation of a suite of feasible alternatives for the production system. The evaluation process embraces several disciplines, both technical and economical. It is a common practice for each discipline to work individually, following its own internal process, where external information is treated as a definite input. When organized in this way, the process of evaluating the global production system tends to be complex, involving many professionals and information exchange, and time consuming, since it is performed sequentially. In addition, it is necessary to ensure that the results of each discipline converge to a common point, which is the global result for each production system scenario. In order to achieve this convergence, cycles of iteration between the disciplines may be required, which also contributes to the longer duration of the process.\u0000 This paper proposes a framework that integrates individual simulation models of Reservoir and Flow Assurance with organizational economic premises. The framework was set to give as a result the NPV (Net Present Value) of each offshore production systems alternative, among other operational and economic metrics. The framework also integrates optimizers that propose the best reservoir drainage plan, FPU (Floating Production Unit) location and subsea layout for each alternative. A real case study is presented in order to exemplify its functionalities. The production system considered consists of three independent offshore reservoirs producing to the same production facility, through subsea manifolds and long tie-backs.\u0000 The integrated simulation allowed for a quick and easy selection process of the production system alternative with higher economic return. There was a drastic reduction on the response time for the evaluation of the alternatives, which is essential to meet the growing dynamism of the oil and gas industry. The results confirmed the importance of the integrated simulation, both for the optimization of the alternatives evaluation process, and for the identification of gains of synergy among the several disciplines involved in project of high complexity. The use of integrated simulation is expected to continue increasing in the coming years in the oil and gas industry, as well as the robustness of the technique.\u0000 The novelty of the integrated simulation framework is in the ability to efficiently run a wide number of simulations and optimizations for the production system and help to select the most suitable one.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"55 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88800162","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}
V. E. Beal, R. Claro, Márcio Araújo, Danilo Colombo, Sara Marques O. A Souza
Blowout preventer (BOP) is critical equipment during the exploration of O&G fields. It keeps the sealing between the well and the external environment and supports the blowouts from the well keeping the drilling safe. Current technology has been challenged to improve reliability, availability and safety specially when exploring new wells on deep and ultra-deep water. In the end, the development of new technologies applied for the BOP targets the overall cost reduction of the well lifecycle. The current weight and size of the BOPs are rulers for the size of the drilling platforms. The deeper the well, the higher the pressure and the bigger and heavier the equipment. This lead to the need of new platforms to operate in such range and increase of the exploration cost. Not to mention the problems with long hydraulic lines. New technologies should target reliability, weight and size reduction of BOPs. Current BOPs are a jigsaw of redundant equipment that might not make sense for future technology to be developed. However, only tested, proofed and reliable technology can be used in the final equipment. Nevertheless, radical changes in the current design of BOP will also trigger modifications on standards/regulations and procedures.
{"title":"Challenges for the Development of New Bop Generation","authors":"V. E. Beal, R. Claro, Márcio Araújo, Danilo Colombo, Sara Marques O. A Souza","doi":"10.4043/29680-ms","DOIUrl":"https://doi.org/10.4043/29680-ms","url":null,"abstract":"\u0000 Blowout preventer (BOP) is critical equipment during the exploration of O&G fields. It keeps the sealing between the well and the external environment and supports the blowouts from the well keeping the drilling safe. Current technology has been challenged to improve reliability, availability and safety specially when exploring new wells on deep and ultra-deep water. In the end, the development of new technologies applied for the BOP targets the overall cost reduction of the well lifecycle. The current weight and size of the BOPs are rulers for the size of the drilling platforms. The deeper the well, the higher the pressure and the bigger and heavier the equipment. This lead to the need of new platforms to operate in such range and increase of the exploration cost. Not to mention the problems with long hydraulic lines. New technologies should target reliability, weight and size reduction of BOPs. Current BOPs are a jigsaw of redundant equipment that might not make sense for future technology to be developed. However, only tested, proofed and reliable technology can be used in the final equipment. Nevertheless, radical changes in the current design of BOP will also trigger modifications on standards/regulations and procedures.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"12 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87689493","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}
Following the discovery of the giant Pre-salt play in Brazil in 2006, the Government implemented a new fiscal regime in 2010, namely the Production Sharing Contract (PSC), for the exploration and production of oil and gas in this area. The introduction of the PSC regime brought about challenges and uncertainties on the day-to-day activities for all stakeholders involved. In this context, the objective of this article is to highlight the main challenges faced by the industry participants in Brazil, based on international experiences and literature review. Concurrently, the paper adds more clarity on areas where, in practice, we expect the majority of these risks to materialize, such as the design, implementation and operation of PSCs, with a view to investigate the main challenges related to the implementation of PSCs. Most notably, the article addresses the resource and competency requirements that regulators and oil companies alike require to enable an accurate and compliant recovery of eligible costs. We focus our international experience analysis on Indonesia, a jurisdiction with a mature oil industry, which pioneered the cost recovery PSC model, and draw learnings from the premises and results of recent changes in the Indonesian fiscal regime, as documented in industry publications. Moreover, the article attempts to quantify the financial impact on oil companies for not recognizing all recoverable costs and the magnitude of government revenue losses arising from poor cost discipline or gold plating behaviors by offshore contractors. Conclusions are drawn on key improvements since the first pre-salt licensing round, when the terms of the PSC were considered relatively onerous and risky for investors. We also draw attention to the key factors which have enabled a more transparent and competitive bidding environment in the Pre-Salt in recent years, while allowing the Brazilian Government to maintain a significant share of revenues and control over the assets.
{"title":"Challenges with Production Sharing Contracts in Brazil: What the International Experience and Literature Review Can Tell Us?","authors":"Breno Barreto Medeiros, Renata Britto, F. Barsan","doi":"10.4043/29743-ms","DOIUrl":"https://doi.org/10.4043/29743-ms","url":null,"abstract":"\u0000 Following the discovery of the giant Pre-salt play in Brazil in 2006, the Government implemented a new fiscal regime in 2010, namely the Production Sharing Contract (PSC), for the exploration and production of oil and gas in this area. The introduction of the PSC regime brought about challenges and uncertainties on the day-to-day activities for all stakeholders involved. In this context, the objective of this article is to highlight the main challenges faced by the industry participants in Brazil, based on international experiences and literature review. Concurrently, the paper adds more clarity on areas where, in practice, we expect the majority of these risks to materialize, such as the design, implementation and operation of PSCs, with a view to investigate the main challenges related to the implementation of PSCs. Most notably, the article addresses the resource and competency requirements that regulators and oil companies alike require to enable an accurate and compliant recovery of eligible costs. We focus our international experience analysis on Indonesia, a jurisdiction with a mature oil industry, which pioneered the cost recovery PSC model, and draw learnings from the premises and results of recent changes in the Indonesian fiscal regime, as documented in industry publications. Moreover, the article attempts to quantify the financial impact on oil companies for not recognizing all recoverable costs and the magnitude of government revenue losses arising from poor cost discipline or gold plating behaviors by offshore contractors. Conclusions are drawn on key improvements since the first pre-salt licensing round, when the terms of the PSC were considered relatively onerous and risky for investors. We also draw attention to the key factors which have enabled a more transparent and competitive bidding environment in the Pre-Salt in recent years, while allowing the Brazilian Government to maintain a significant share of revenues and control over the assets.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"45 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86114065","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 objective of this paper is to present the historical development of installed riser systems from the earliest offshore installations to the current state of the art and into the future. The paper describes the main driving forces during the riser design process and presents the evolution of riser technology in a range of different regions and describes the influencing factors behind each development and the propagation of technology around the world. Using graphical visualizations of an extensive dataset of installed riser systems, the paper breaks down the global trends in riser by type, size, water depth and market dominance.
{"title":"Deepwater Riser Systems – Historical Review and Future Projections","authors":"P. J. Simpson, Alexandre Lima","doi":"10.4043/29787-ms","DOIUrl":"https://doi.org/10.4043/29787-ms","url":null,"abstract":"\u0000 The objective of this paper is to present the historical development of installed riser systems from the earliest offshore installations to the current state of the art and into the future.\u0000 The paper describes the main driving forces during the riser design process and presents the evolution of riser technology in a range of different regions and describes the influencing factors behind each development and the propagation of technology around the world. Using graphical visualizations of an extensive dataset of installed riser systems, the paper breaks down the global trends in riser by type, size, water depth and market dominance.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"31 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88208457","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}
Reda Bouamra, G. Carneiro, P. Machado, Manoel Feliciano Silva, Gabriela Franquiz, H. Guan, T. Lindvig
The complexity of carbonate reservoir in pre-salt plays dictates the use of advanced inflow devices to enable optimized reservoir recovery. Intelligent Completions are considered one of the most effective systems for flow control for a production interval. Depending on the actual design and geometry of the intelligent completion tool, inorganic scale deposition can be very difficult to prevent and/or to mitigate. The failure of such equipment tools can cause severe production impairment and affect the entire field economics. In order to provide a high accuracy assessment of the scale deposition risk, a novel methodology involving scale deposition experiments and model generation has been developed. The proposed workflow combines 1D mechanistic methods to define scaling conditions, thermodynamic models to define the scaling tendencies at these conditions and 3D models to predict particles accumulation in complex geometries using numerical techniques describing the multiphysics interactions between solid particles and live fluids. The basis of the models will be presented in this article along with numerical results of the precipitation and deposition phenomena at downhole conditions. This work represents the first holistic approach to characterize scale build-up in the vicinity of inflow equipment walls. Numerical results are presented in this paper.
{"title":"ScaleProTect – Scale Deposition Modeling in Pre-Salt Reservoir","authors":"Reda Bouamra, G. Carneiro, P. Machado, Manoel Feliciano Silva, Gabriela Franquiz, H. Guan, T. Lindvig","doi":"10.4043/29886-ms","DOIUrl":"https://doi.org/10.4043/29886-ms","url":null,"abstract":"\u0000 The complexity of carbonate reservoir in pre-salt plays dictates the use of advanced inflow devices to enable optimized reservoir recovery. Intelligent Completions are considered one of the most effective systems for flow control for a production interval. Depending on the actual design and geometry of the intelligent completion tool, inorganic scale deposition can be very difficult to prevent and/or to mitigate. The failure of such equipment tools can cause severe production impairment and affect the entire field economics.\u0000 In order to provide a high accuracy assessment of the scale deposition risk, a novel methodology involving scale deposition experiments and model generation has been developed. The proposed workflow combines 1D mechanistic methods to define scaling conditions, thermodynamic models to define the scaling tendencies at these conditions and 3D models to predict particles accumulation in complex geometries using numerical techniques describing the multiphysics interactions between solid particles and live fluids. The basis of the models will be presented in this article along with numerical results of the precipitation and deposition phenomena at downhole conditions.\u0000 This work represents the first holistic approach to characterize scale build-up in the vicinity of inflow equipment walls. Numerical results are presented in this paper.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"22 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89783818","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}
Resource scheduling, particularly when applied to hydrocarbon filled atmospheric tanks, challenges planning professionals. When presented with new projects, it is important to maintain the new costs coherent and in line with the company's past portfolio. An ill formed financial schedule leads to problems within contracts as well as in the company's regular activities. Although sometimes it is not as easily perceived as operational losses, one can easily see that such wrong predictions invariably lead to incorrect resource allocation leading to financial misuse of the company's funds. Such concern is notably true for the Brazilian petroleum industry, especially within the transport sector. The sheer size of the projects and the assets involved – mainly due to the country’s continental territory - make any deviation of critical importance. Therefore, to establish a solid methodology in order to obtain parameters and foreseen the resource expenditure as well as operational impacts would be of great value for companies trying to assess opportunities, targets, resource allocation and return rates. Throughout the current research, the authors assessed over thirty physical-financial project plans from a well-known Brazilian pipeline company. From this bulk of projects schedules, twenty were further selected for a more detailed analysis based on similarities - among them - in complexity and investment sizes. The projects were then normalized according to their total capital and time expenditure. The resulting normalized project schedules provided the basis for the methodology presented through the text. The resulting methodology, presented in this paper, aims at assisting planning professionals to infer future financial needs to new projects, as long as similarities constraints are respected. The technique is able to provide data to engineers, planning professionals and managers make a more informed decision. Furthermore, the methodology demands that the resulting database must be updated as new projects are included in the company's portfolio. The database should acquire a Bayesian character in order to provide actual information.
{"title":"Financial Planning of Maintenance Services for Atmospheric Hydrocarbon Filled Tanks","authors":"JoseÌ Eduardo., Heitor Federico Honda","doi":"10.4043/29869-ms","DOIUrl":"https://doi.org/10.4043/29869-ms","url":null,"abstract":"\u0000 Resource scheduling, particularly when applied to hydrocarbon filled atmospheric tanks, challenges planning professionals. When presented with new projects, it is important to maintain the new costs coherent and in line with the company's past portfolio. An ill formed financial schedule leads to problems within contracts as well as in the company's regular activities. Although sometimes it is not as easily perceived as operational losses, one can easily see that such wrong predictions invariably lead to incorrect resource allocation leading to financial misuse of the company's funds. Such concern is notably true for the Brazilian petroleum industry, especially within the transport sector. The sheer size of the projects and the assets involved – mainly due to the country’s continental territory - make any deviation of critical importance. Therefore, to establish a solid methodology in order to obtain parameters and foreseen the resource expenditure as well as operational impacts would be of great value for companies trying to assess opportunities, targets, resource allocation and return rates.\u0000 Throughout the current research, the authors assessed over thirty physical-financial project plans from a well-known Brazilian pipeline company. From this bulk of projects schedules, twenty were further selected for a more detailed analysis based on similarities - among them - in complexity and investment sizes. The projects were then normalized according to their total capital and time expenditure. The resulting normalized project schedules provided the basis for the methodology presented through the text.\u0000 The resulting methodology, presented in this paper, aims at assisting planning professionals to infer future financial needs to new projects, as long as similarities constraints are respected. The technique is able to provide data to engineers, planning professionals and managers make a more informed decision. Furthermore, the methodology demands that the resulting database must be updated as new projects are included in the company's portfolio. The database should acquire a Bayesian character in order to provide actual information.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"27 17","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91442536","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}
Félix Gallo Cruz, A. Sola, Joshua Andre Rosero, J. Gonzalez
Thermal numerical simulation of two undersea flowlines of natural gas production at Amistad field was developed in order to avoid non-productive time caused by plugging of solid precipitation; due to the operation conditions and recorded problems during gas production in this field, a complete study of thermodynamics, heat losses and multiphase behavior of the production fluid becomes imperative to prevent and control solid formation and flow blockage. The thermodynamic behavior of gas was analytically determined based on the thermal and transport properties of fluid phases, beginning with the study of the pressure-temperature diagram of the production fluid to define the type of solids that could precipitate within the flow lines (hydrates). The heat transfer analysis was determined applying two methods, one numerical and one analytical, the numerical by the computational fluid dynamics (CFD) method with the support of the ANSYS-CFX software; and the analytical model obtained from the literature that was used to validate it. The hydrodynamic behavior of multiphase flow and pressure losses were determined by the Beggs & Brill (1973) correlation and were contrasted with the open source DWSIM software tool performance. The overall heat transfer coefficient was determined before continuing with the numerical modeling due to its importance and influence in the CFD simulation, which covers three stages: selection of the most optimum pipeline model, mesh refining, and validation of the developed model for a heat transfer phenomenon in two-phase flow. Once the heat loss model was defined by a steady state simulation, a transient simulation was carried out to calculate the gas cooling time in a case of sudden flow shutdown, considering the standard pipe currently used and three polymers of low thermal conductivity as proposed alternate materials instead of carbon-steel or as or as thermal insulation coatings, as appropriate; these are polypropylene, polyurethane and high density polyethylene. Finally, five analytical correlations of hydrate precipitation obtained from the literature and two software precipitation equilibrium curves were selected to define the precipitation scenarios of the system using the simulation results. According to the P-T diagram, the only solids that could be precipitated in the steel pipelines are methane hydrates due to the composition of the production fluid and the operating conditions of the wells. The thermal gradient of the flowlines is the most relevant result of the numerical heat transfer analysis, this one shows the critical points of the pipes where the fluid reaches its lowest temperature, that is, the temperature of the underwater current. The critical point from the wellhead for both steel lines is 5560 [ft] according to the resulting thermal gradient, although for the second line, it is actually a bit shorter due to its length limit, 5300 [ft]. From the analysis of pressure and temperature conditions at these
{"title":"Thermal-Numerical Simulation of the Gas Offshore Production Undersea Facilities at the Amistad Field","authors":"Félix Gallo Cruz, A. Sola, Joshua Andre Rosero, J. Gonzalez","doi":"10.4043/29751-ms","DOIUrl":"https://doi.org/10.4043/29751-ms","url":null,"abstract":"\u0000 Thermal numerical simulation of two undersea flowlines of natural gas production at Amistad field was developed in order to avoid non-productive time caused by plugging of solid precipitation; due to the operation conditions and recorded problems during gas production in this field, a complete study of thermodynamics, heat losses and multiphase behavior of the production fluid becomes imperative to prevent and control solid formation and flow blockage.\u0000 The thermodynamic behavior of gas was analytically determined based on the thermal and transport properties of fluid phases, beginning with the study of the pressure-temperature diagram of the production fluid to define the type of solids that could precipitate within the flow lines (hydrates). The heat transfer analysis was determined applying two methods, one numerical and one analytical, the numerical by the computational fluid dynamics (CFD) method with the support of the ANSYS-CFX software; and the analytical model obtained from the literature that was used to validate it. The hydrodynamic behavior of multiphase flow and pressure losses were determined by the Beggs & Brill (1973) correlation and were contrasted with the open source DWSIM software tool performance. The overall heat transfer coefficient was determined before continuing with the numerical modeling due to its importance and influence in the CFD simulation, which covers three stages: selection of the most optimum pipeline model, mesh refining, and validation of the developed model for a heat transfer phenomenon in two-phase flow. Once the heat loss model was defined by a steady state simulation, a transient simulation was carried out to calculate the gas cooling time in a case of sudden flow shutdown, considering the standard pipe currently used and three polymers of low thermal conductivity as proposed alternate materials instead of carbon-steel or as or as thermal insulation coatings, as appropriate; these are polypropylene, polyurethane and high density polyethylene. Finally, five analytical correlations of hydrate precipitation obtained from the literature and two software precipitation equilibrium curves were selected to define the precipitation scenarios of the system using the simulation results.\u0000 According to the P-T diagram, the only solids that could be precipitated in the steel pipelines are methane hydrates due to the composition of the production fluid and the operating conditions of the wells. The thermal gradient of the flowlines is the most relevant result of the numerical heat transfer analysis, this one shows the critical points of the pipes where the fluid reaches its lowest temperature, that is, the temperature of the underwater current. The critical point from the wellhead for both steel lines is 5560 [ft] according to the resulting thermal gradient, although for the second line, it is actually a bit shorter due to its length limit, 5300 [ft]. From the analysis of pressure and temperature conditions at these","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"262 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79679870","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}
Carlos A. Silva, D. Filho, Gislaine Maria Nunes, G. S. Bassani, N. Almeida, Z. Panossian
The necessity to reduce cost in handling fluids requires a high flow rates with an inherent risk for turbulence influencing the corrosion process of the involved equipment. These conditions occur especially in offshore environments, as oil and gas production, and in chemical processes and energy production industries. There are several ways to discuss corrosion control associated to multiphase-flow- induced corrosion. One possibility is the mechanistic approach and the other makes use of professionals' practical experiences. A pre-requisite for any effective control practices in multiphase flow induced corrosion is a basic understanding of the involved flow mechanisms. This work presents the study of the influence of slug multiphase flow on API 5L X80 carbon steel pipe corrosion in an environment that simulates oil wells. As a simulated environment, an 80 %water-cut mixture, comprised of 20 % light oil (10 cP) or heavy oil (150 cP) plus 15 % of sodium chloride and 80 % of deionized water, was used. The tests were performed at 40 oC under a different CO2 and H2S partial pressure balanced by N2 to reach a total pressure of 2.5 bar. The tests were conducted in a multiphase simulating loop. All test parameters were monitored to guarantee a slug flow pattern. The conceptual design of the loop allowed the simultaneous evaluation of the influence of the horizontal (0°) and inclined (45°) position of the flow to verify the influence of hydrodynamic effects on the weight loss. The conducted laboratory test results allow the establishment of empirical correlations between the corrosion rate and specific exposure conditions. These correlations may be used in corrosion prediction softwares, which can help an engineer to design and to monitor life expectancies of industrial pipes. Studies conducted in autoclaves and in glass cells produce results which, despite here being useful on the understanding of corrosion mechanisms, are not able to produce multiphase-flow regime results like those related to the conditions of pipelines in oil and gas exploitations. A smaller scale corrosion loop provides a suitable environment for better reproducing hydrodynamic effects on the corrosion of pipe walls. In tests performed in the presence of only CO2, concavities on the carbon steel surface were observed. This was attributed to the flow regime, which allowed the formation of a higher disperse-bubble volume and of an emulsion, either by the formation of an oil-in-water emulsion or a water-in-oil emulsion. However, the increase in CO2 partial pressure promoted, in all tested conditions, an increase of the weight loss rate. Thus, the work allowed scoring basic mechanisms of multiphase-flow-induced corrosion which intensifies the damages of carbon steel pipes in environments containing CO2 and H2S, in different concentrations and in controlled conditions of pressure and temperature.
{"title":"Corrosion in Multiphase Slug Flow Loop in Deep-Water Oil and Gas Exploitation","authors":"Carlos A. Silva, D. Filho, Gislaine Maria Nunes, G. S. Bassani, N. Almeida, Z. Panossian","doi":"10.4043/29720-ms","DOIUrl":"https://doi.org/10.4043/29720-ms","url":null,"abstract":"\u0000 The necessity to reduce cost in handling fluids requires a high flow rates with an inherent risk for turbulence influencing the corrosion process of the involved equipment. These conditions occur especially in offshore environments, as oil and gas production, and in chemical processes and energy production industries. There are several ways to discuss corrosion control associated to multiphase-flow- induced corrosion. One possibility is the mechanistic approach and the other makes use of professionals' practical experiences. A pre-requisite for any effective control practices in multiphase flow induced corrosion is a basic understanding of the involved flow mechanisms. This work presents the study of the influence of slug multiphase flow on API 5L X80 carbon steel pipe corrosion in an environment that simulates oil wells. As a simulated environment, an 80 %water-cut mixture, comprised of 20 % light oil (10 cP) or heavy oil (150 cP) plus 15 % of sodium chloride and 80 % of deionized water, was used. The tests were performed at 40 oC under a different CO2 and H2S partial pressure balanced by N2 to reach a total pressure of 2.5 bar. The tests were conducted in a multiphase simulating loop. All test parameters were monitored to guarantee a slug flow pattern. The conceptual design of the loop allowed the simultaneous evaluation of the influence of the horizontal (0°) and inclined (45°) position of the flow to verify the influence of hydrodynamic effects on the weight loss. The conducted laboratory test results allow the establishment of empirical correlations between the corrosion rate and specific exposure conditions. These correlations may be used in corrosion prediction softwares, which can help an engineer to design and to monitor life expectancies of industrial pipes. Studies conducted in autoclaves and in glass cells produce results which, despite here being useful on the understanding of corrosion mechanisms, are not able to produce multiphase-flow regime results like those related to the conditions of pipelines in oil and gas exploitations. A smaller scale corrosion loop provides a suitable environment for better reproducing hydrodynamic effects on the corrosion of pipe walls. In tests performed in the presence of only CO2, concavities on the carbon steel surface were observed. This was attributed to the flow regime, which allowed the formation of a higher disperse-bubble volume and of an emulsion, either by the formation of an oil-in-water emulsion or a water-in-oil emulsion. However, the increase in CO2 partial pressure promoted, in all tested conditions, an increase of the weight loss rate. Thus, the work allowed scoring basic mechanisms of multiphase-flow-induced corrosion which intensifies the damages of carbon steel pipes in environments containing CO2 and H2S, in different concentrations and in controlled conditions of pressure and temperature.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76818312","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 provides case histories for new methods facilitated by Hull Inspection Techniques & Strategy (HITS) Joint Industry Projects (JIP) including: i) Diverless inspections of hull and mooring systems; and ii) Robotic inspection of cargo oil tanks and pressure vessels. Also, will describe how non-contact thickness measurements by synchronous lasers and big data statistical analysis for inspection scopes are being trialled in the year of 2019 on operating assets. Further innovations around non-intrusive and robotic methods for inspection of electrical systems and pressure vessels, described with case histories supported by business cases, showing how these latest innovations meet the $50-barrel oil industry price target.
{"title":"Floating Deepwater Production Integrity Challenges and Solutions","authors":"M. Paris, D. Constantinis","doi":"10.4043/29767-ms","DOIUrl":"https://doi.org/10.4043/29767-ms","url":null,"abstract":"\u0000 This paper provides case histories for new methods facilitated by Hull Inspection Techniques & Strategy (HITS) Joint Industry Projects (JIP) including: i) Diverless inspections of hull and mooring systems; and ii) Robotic inspection of cargo oil tanks and pressure vessels. Also, will describe how non-contact thickness measurements by synchronous lasers and big data statistical analysis for inspection scopes are being trialled in the year of 2019 on operating assets. Further innovations around non-intrusive and robotic methods for inspection of electrical systems and pressure vessels, described with case histories supported by business cases, showing how these latest innovations meet the $50-barrel oil industry price target.","PeriodicalId":10927,"journal":{"name":"Day 3 Thu, October 31, 2019","volume":"638 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76815509","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}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：