Leonardo Pacheco da Silva, Pedro Oliveira da Mata, Raphael Cristiano Oliveira, Carlos Alberto Almeida Junior, Alina Meylin Benitez Matamoros, Jorge de Carvalho Lopes Florido
This paper will describe the improvement made to the reamer cutter blocks to enhance its durability and optimize the Pre-salt Well Construction Currently, most of the Brazilian's Pre-Salt wells have the last phase built-in 12.25in. In some situations, it is necessary to drill oil wells in a giant offshore field wells with five phases, enlarging the third phase from 18.125in to 22in. The high abrasiveness encountered at this phase increased the number of runs needed to drill it and, consequently, time and costs that encouraged the development of solutions. This work relates what has been observed during the last years about reaming difficulties, specifically, in the enlargement from 18.125in to 22in when facing abrasive formations. Petrobras specialists analyzed these events and concluded the matrix of the reamer's cutter blocks was wearing faster and losing the capacity to hold the PDC cutters. The hole enlargement company, that Petrobras works for nowadays, developed a process that increased the resistance of the cutter blocks by increasing the hardness of the surface material prior to the brazing of the cutters. Then, Petrobras has had the opportunity to use both modified and common cutter blocks in a challenging operation to compare their durability and the results were completely satisfactory. The modified cutter blocks had much less wearing on the same formations. Based on this operation, we can conclude this process is validated since improved the reamer cutter blocks quality and its lifetime. This paper can serve as a guide to reduce operations costs and to optimize well construction when there are concrete possibilities to enlarge abrasive formations.
{"title":"Improved Reamer Cutter Blocks Optimizes the Brazilian's Pre Salt Well Construction","authors":"Leonardo Pacheco da Silva, Pedro Oliveira da Mata, Raphael Cristiano Oliveira, Carlos Alberto Almeida Junior, Alina Meylin Benitez Matamoros, Jorge de Carvalho Lopes Florido","doi":"10.4043/29959-ms","DOIUrl":"https://doi.org/10.4043/29959-ms","url":null,"abstract":"\u0000 This paper will describe the improvement made to the reamer cutter blocks to enhance its durability and optimize the Pre-salt Well Construction\u0000 Currently, most of the Brazilian's Pre-Salt wells have the last phase built-in 12.25in. In some situations, it is necessary to drill oil wells in a giant offshore field wells with five phases, enlarging the third phase from 18.125in to 22in. The high abrasiveness encountered at this phase increased the number of runs needed to drill it and, consequently, time and costs that encouraged the development of solutions.\u0000 This work relates what has been observed during the last years about reaming difficulties, specifically, in the enlargement from 18.125in to 22in when facing abrasive formations. Petrobras specialists analyzed these events and concluded the matrix of the reamer's cutter blocks was wearing faster and losing the capacity to hold the PDC cutters. The hole enlargement company, that Petrobras works for nowadays, developed a process that increased the resistance of the cutter blocks by increasing the hardness of the surface material prior to the brazing of the cutters. Then, Petrobras has had the opportunity to use both modified and common cutter blocks in a challenging operation to compare their durability and the results were completely satisfactory. The modified cutter blocks had much less wearing on the same formations. Based on this operation, we can conclude this process is validated since improved the reamer cutter blocks quality and its lifetime.\u0000 This paper can serve as a guide to reduce operations costs and to optimize well construction when there are concrete possibilities to enlarge abrasive formations.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"54 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82527709","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}
Kuo-Chaing Chen, Herman Artinian, Dennis Harris, Jinjiang Xiao
A new technology, Magnetic Drive System (MDS), to increase reliability and retrievability of electrical submersible pumps (ESPs) is described. With the improved reliability and retrievability, the production uptime of oil wells with artificial lift and the total cost of ownership of ESPs are improved significantly. An industry survey and literature review were conducted to identify the aspects of the ESP and the failure-prone ESP subsystems to improve upon. Based on the findings, the MDS technology is developed to improve ESP reliability by isolating the failure modes and to improve ESP retrievability by enabling fast deployments and retrievals from wells. Mean Time Between Failure (MTBF) models based on field observed failure mechanisms are applied to identify the impacts of isolating various failure modes on ESP reliability. The total cost of ownership (TCO) is calculated to illustrate the advantages of the MDS system to increase production gains and reduce costs. Analysis on ESP reliability shows that the electrical system is the primary ESP failure mode, covering more than 50% of the failures. Models based on field data from the literature review shows that MTBF can be more than tripled if these failures are eliminated. The MDS topology places all the electrical components, including motor stators, cables and penetrators, of an ESP in the isolated annulus space between the permanent completion and tubing, leaving only the mechanical components, including the permanent magnet motor rotors and pump stages, inside the production tubing. In this case, the electrical components are well protected from the hostile produced fluids, so that the failures modes of the electrical system are eliminated. Since the retrievable string has no electrical components, such as thousands of feet of power cable, the deployments and retrievals of the retrievable string can be easily done by slickline. The larger motor stator and higher power density enabled by enhanced heat dissipation of the MDS topology dramatically increase the motor horsepower and shorten the motor length, thus increasing the production gains of the ESP. Reliability and retrievability are further improved due to the elimination of motor protectors and replaced by the "built-in" magnetic coupling between the MDS motor stator and rotor. With the improved reliability, retrievability, and motor performance simultaneously, MDS reduces the total cost of ownership by more than 70% in some cases compared with the conventional tubing-hung ESP, enables live well deployment and retrieval, reduces production downtime and intervention complexity, and protects reservoir productivity.
{"title":"Magnetic Drive System with Levitated Flow-Through Permanent Magnet Motors and Magnetic Bearings to Increase the Reliability and Retrievability of Electrical Submersible Pumps for Offshore Production","authors":"Kuo-Chaing Chen, Herman Artinian, Dennis Harris, Jinjiang Xiao","doi":"10.4043/29699-ms","DOIUrl":"https://doi.org/10.4043/29699-ms","url":null,"abstract":"\u0000 A new technology, Magnetic Drive System (MDS), to increase reliability and retrievability of electrical submersible pumps (ESPs) is described. With the improved reliability and retrievability, the production uptime of oil wells with artificial lift and the total cost of ownership of ESPs are improved significantly.\u0000 An industry survey and literature review were conducted to identify the aspects of the ESP and the failure-prone ESP subsystems to improve upon. Based on the findings, the MDS technology is developed to improve ESP reliability by isolating the failure modes and to improve ESP retrievability by enabling fast deployments and retrievals from wells. Mean Time Between Failure (MTBF) models based on field observed failure mechanisms are applied to identify the impacts of isolating various failure modes on ESP reliability. The total cost of ownership (TCO) is calculated to illustrate the advantages of the MDS system to increase production gains and reduce costs.\u0000 Analysis on ESP reliability shows that the electrical system is the primary ESP failure mode, covering more than 50% of the failures. Models based on field data from the literature review shows that MTBF can be more than tripled if these failures are eliminated. The MDS topology places all the electrical components, including motor stators, cables and penetrators, of an ESP in the isolated annulus space between the permanent completion and tubing, leaving only the mechanical components, including the permanent magnet motor rotors and pump stages, inside the production tubing. In this case, the electrical components are well protected from the hostile produced fluids, so that the failures modes of the electrical system are eliminated. Since the retrievable string has no electrical components, such as thousands of feet of power cable, the deployments and retrievals of the retrievable string can be easily done by slickline. The larger motor stator and higher power density enabled by enhanced heat dissipation of the MDS topology dramatically increase the motor horsepower and shorten the motor length, thus increasing the production gains of the ESP. Reliability and retrievability are further improved due to the elimination of motor protectors and replaced by the \"built-in\" magnetic coupling between the MDS motor stator and rotor. With the improved reliability, retrievability, and motor performance simultaneously, MDS reduces the total cost of ownership by more than 70% in some cases compared with the conventional tubing-hung ESP, enables live well deployment and retrieval, reduces production downtime and intervention complexity, and protects reservoir productivity.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"47 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88072677","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}
Offshore industry has about three decades of experience with the development and deployment of floating and subsea technologies in deep (> 500 m) and ultra-deep (> 1,500 m) waters. Most of the ultra-deep water experience has been gained from fields in the Gulf of Mexico, Brazil, and West of Africa. Significant exploration and development activities undergoing in deep and ultra-deep waters of more than eight South American countries require low cost solutions to enable their development. This Panel will present and discuss the innovative initiatives undertaken by the industry for further development of solutions and technologies for deepwater production facilities (floating and subsea units, risers, umbilicals, flowlines and pipelines) to reduce their capital and operating costs. The innovative initiatives range from variations in the design and execution plans to qualification of specific new technologies. The digitalization of these facilities is also providing means to further reduce capital and operating costs and enhance productivity, safety, and reduce environmental impact. In addition, the potential value from renewable energy to subsea and field operations is being evaluated. These initiatives are in various stages of development and some are being implemented in deepwater fields in Brazil and Guyana. Several of these innovative technology initiatives will go from Technology Readiness Level (TRL) 5 to 7 in South American fields after operating for more than 3 years.
{"title":"Development of Deepwater Fields in South America – Available Technologies and Innovative Initiatives","authors":"R. Aggarwal, D. Carneiro","doi":"10.4043/29747-ms","DOIUrl":"https://doi.org/10.4043/29747-ms","url":null,"abstract":"\u0000 Offshore industry has about three decades of experience with the development and deployment of floating and subsea technologies in deep (> 500 m) and ultra-deep (> 1,500 m) waters. Most of the ultra-deep water experience has been gained from fields in the Gulf of Mexico, Brazil, and West of Africa. Significant exploration and development activities undergoing in deep and ultra-deep waters of more than eight South American countries require low cost solutions to enable their development.\u0000 This Panel will present and discuss the innovative initiatives undertaken by the industry for further development of solutions and technologies for deepwater production facilities (floating and subsea units, risers, umbilicals, flowlines and pipelines) to reduce their capital and operating costs. The innovative initiatives range from variations in the design and execution plans to qualification of specific new technologies. The digitalization of these facilities is also providing means to further reduce capital and operating costs and enhance productivity, safety, and reduce environmental impact. In addition, the potential value from renewable energy to subsea and field operations is being evaluated.\u0000 These initiatives are in various stages of development and some are being implemented in deepwater fields in Brazil and Guyana. Several of these innovative technology initiatives will go from Technology Readiness Level (TRL) 5 to 7 in South American fields after operating for more than 3 years.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"66 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83141589","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}
Juliana Casaccia Vaz, Sílvia Lima Touma, Lucas Costa Frota, Éder Henriqson, Paola Cardoso De Almeida, L. Garotti, O. Wambersie
Safety culture enhancement is currently the most studied approach for HSE performance improvements in the oil and gas industry. However, the conception and implementation of a correspondent program or action plan is still a challenge. This study presents the structure, analysis and results of a human factors and resilience engineering study conducted by Libra Joint Venture and PUCRS. The objective is to build a human factors program focusing on safety culture enhancement in offshore drilling and FPSO operations. Oil and gas offshore operations can be considered complex social-technical systems with multiple tight-coupling interactions. For this reason, the study’s approach was multidisciplinary, involving professionals from areas of Resilience Engineering, Knowledge Engineering, Knowledge Management, Sociology, Social Service and Environment. The research project consisted of data collection, data analysis and recommendations proposition, validation and prioritization. Tools and methodologies used include interviews, biographic narratives, focus group, workshops, observation, questionnaires and Functional Resonance Analysis Method (FRAM), a systemic analysis methodology widely used in Aviation Industry, to model work as done. A great part of these tools were applied onboard a drillship and a FPSO, both currently operating in the Pre-Salt Area, in Santos Basin. As the main results, this work provides important field observations and oil and gas industry prioritized recommendations for conceiving a Human Factors Program for offshore operations, with the aim of increasing safety and resilience of the system, which ultimately will reduce risk exposure and avoid accidents.
{"title":"Human Factors and Resilience Engineering Program for Safety Culture Enhancement","authors":"Juliana Casaccia Vaz, Sílvia Lima Touma, Lucas Costa Frota, Éder Henriqson, Paola Cardoso De Almeida, L. Garotti, O. Wambersie","doi":"10.4043/29711-ms","DOIUrl":"https://doi.org/10.4043/29711-ms","url":null,"abstract":"\u0000 Safety culture enhancement is currently the most studied approach for HSE performance improvements in the oil and gas industry. However, the conception and implementation of a correspondent program or action plan is still a challenge. This study presents the structure, analysis and results of a human factors and resilience engineering study conducted by Libra Joint Venture and PUCRS. The objective is to build a human factors program focusing on safety culture enhancement in offshore drilling and FPSO operations.\u0000 Oil and gas offshore operations can be considered complex social-technical systems with multiple tight-coupling interactions. For this reason, the study’s approach was multidisciplinary, involving professionals from areas of Resilience Engineering, Knowledge Engineering, Knowledge Management, Sociology, Social Service and Environment. The research project consisted of data collection, data analysis and recommendations proposition, validation and prioritization. Tools and methodologies used include interviews, biographic narratives, focus group, workshops, observation, questionnaires and Functional Resonance Analysis Method (FRAM), a systemic analysis methodology widely used in Aviation Industry, to model work as done. A great part of these tools were applied onboard a drillship and a FPSO, both currently operating in the Pre-Salt Area, in Santos Basin.\u0000 As the main results, this work provides important field observations and oil and gas industry prioritized recommendations for conceiving a Human Factors Program for offshore operations, with the aim of increasing safety and resilience of the system, which ultimately will reduce risk exposure and avoid accidents.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82193476","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. B. Vadinal, Leomir Samuel Tormen Reis, Daniel Ribeiro Del Claro, S. Ceolin, Maria Carolina do Couto Pessanha Bernardes
The main wastes associated with well drilling activity are drilling fluids and cuttings. With regard to drilling fluids, the oil industry has invested in more environmentally friendly formulations to reduce environmental impact. For offshore operations, cuttings are generally disposal at sea after meeting environmental criteria of government agencies. This paper presents the lessons learned in the operation of the cuttings collector system and the collection of cuttings associated with water based mud in cutting boxes in Campos Basin wells. The main advances to reduce the non-productive time of the cuttings collector system were the use of hybrid boats and the increase of the screw conveyor reliability. To collect cuttings associated with water-based mud, the drilling fluid + cuttings mixture needs to be treated to prevent H2S generation.
{"title":"Lessons Learned from Cuttings Treatment at Offshore Wells in the Campos Basin","authors":"R. B. Vadinal, Leomir Samuel Tormen Reis, Daniel Ribeiro Del Claro, S. Ceolin, Maria Carolina do Couto Pessanha Bernardes","doi":"10.4043/29919-ms","DOIUrl":"https://doi.org/10.4043/29919-ms","url":null,"abstract":"\u0000 The main wastes associated with well drilling activity are drilling fluids and cuttings. With regard to drilling fluids, the oil industry has invested in more environmentally friendly formulations to reduce environmental impact. For offshore operations, cuttings are generally disposal at sea after meeting environmental criteria of government agencies. This paper presents the lessons learned in the operation of the cuttings collector system and the collection of cuttings associated with water based mud in cutting boxes in Campos Basin wells. The main advances to reduce the non-productive time of the cuttings collector system were the use of hybrid boats and the increase of the screw conveyor reliability. To collect cuttings associated with water-based mud, the drilling fluid + cuttings mixture needs to be treated to prevent H2S generation.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"4 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73352939","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}
S. Anjos, F. M. Passarelli, O. Wambersie, K. Lewis, P. S. Rovina, O. Coelho, Mariela Martins, O. Ribeiro, R. A. R. Fernandes, F. A. Borges
Libra reservoirs are among the most productive in Brazil pre-salt province, with oil columns up to 400 m thick. These heterogeneous carbonate reservoirs contain oil with a relatively high Gas Oil Ratio (GOR) and CO2 levels ranging from 40 to 45% in the associated gas. It is also characterized by sparse occurrences of intrusive and extrusive igneous rock within the pre-salt and post salt horizons, which causes additional challenges for seismic imaging and reservoir architecture modelling. Driven by the challenges and fueled by an innovation spirit, the Libra Consortium have been developing a portfolio of technologies to address those challenges and close the technical and operational gaps, in order to add value by reducing and managing uncertainties, optimizing production and overall improving hydrocarbon recovery. Since Libra development strategy is based on full reinjection of produced gas for CO2 disposal purposes and enhanced oil recovery, gas management and its operational robustness over the full life cycle of the field are key. In this context, a focused and robust technological approach based on applied technology portfolio has been adopted to address the many unique challenges and add value to the project through the implementation of new and innovative solutions as well as technologies over the life cycle of the projects.
{"title":"Libra: Applied Technologies Adding Value to a Giant Ultra Deep Water Pre-salt Field - Santos Basin, Brazil","authors":"S. Anjos, F. M. Passarelli, O. Wambersie, K. Lewis, P. S. Rovina, O. Coelho, Mariela Martins, O. Ribeiro, R. A. R. Fernandes, F. A. Borges","doi":"10.4043/29685-ms","DOIUrl":"https://doi.org/10.4043/29685-ms","url":null,"abstract":"\u0000 Libra reservoirs are among the most productive in Brazil pre-salt province, with oil columns up to 400 m thick. These heterogeneous carbonate reservoirs contain oil with a relatively high Gas Oil Ratio (GOR) and CO2 levels ranging from 40 to 45% in the associated gas. It is also characterized by sparse occurrences of intrusive and extrusive igneous rock within the pre-salt and post salt horizons, which causes additional challenges for seismic imaging and reservoir architecture modelling. Driven by the challenges and fueled by an innovation spirit, the Libra Consortium have been developing a portfolio of technologies to address those challenges and close the technical and operational gaps, in order to add value by reducing and managing uncertainties, optimizing production and overall improving hydrocarbon recovery. Since Libra development strategy is based on full reinjection of produced gas for CO2 disposal purposes and enhanced oil recovery, gas management and its operational robustness over the full life cycle of the field are key. In this context, a focused and robust technological approach based on applied technology portfolio has been adopted to address the many unique challenges and add value to the project through the implementation of new and innovative solutions as well as technologies over the life cycle of the projects.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"21 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75326663","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}
Raphael Veloso Beppler, R. Camargo, C. A. Cardoso, E. R. Nascimento, D. Pimentel, R. Rodrigues, Renato de Freitas Soares
Oil and gas flowlines plugging due to hydrate formation is one of the main reasons for production losses in deep water production systems. Therefore, several hydrate prevention and mitigation techniques have been constantly developed and applied by industry. Regarding hydrate dissociation techniques, efforts focus on avoiding the use of naval resources, such as workover rigs or special vessels, because of the high cost involved and, very often, the poor readiness. This work presents an ROV connection device, installed in the Production Adapter Base / Tubing Head Spool (PAB / THS) of a Wet Christmas Tree (WCT), which allows coupling a local system of fluids depressurizing and handling, eliminating the need of a classified vessel to handle hydrocarbons. Besides allowing faster hydrate removal in subsea flowlines, the proposed method do not require any technological development since it consists of the integrated use of subsea devices and tools commonly used in the offshore industry.
{"title":"Wet Christmas Tree Interface for Depressurizing Underwater Flowlines","authors":"Raphael Veloso Beppler, R. Camargo, C. A. Cardoso, E. R. Nascimento, D. Pimentel, R. Rodrigues, Renato de Freitas Soares","doi":"10.4043/29858-ms","DOIUrl":"https://doi.org/10.4043/29858-ms","url":null,"abstract":"\u0000 Oil and gas flowlines plugging due to hydrate formation is one of the main reasons for production losses in deep water production systems. Therefore, several hydrate prevention and mitigation techniques have been constantly developed and applied by industry.\u0000 Regarding hydrate dissociation techniques, efforts focus on avoiding the use of naval resources, such as workover rigs or special vessels, because of the high cost involved and, very often, the poor readiness.\u0000 This work presents an ROV connection device, installed in the Production Adapter Base / Tubing Head Spool (PAB / THS) of a Wet Christmas Tree (WCT), which allows coupling a local system of fluids depressurizing and handling, eliminating the need of a classified vessel to handle hydrocarbons.\u0000 Besides allowing faster hydrate removal in subsea flowlines, the proposed method do not require any technological development since it consists of the integrated use of subsea devices and tools commonly used in the offshore industry.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 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":"76264512","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}
P. Silva, C. Branco, Dirceu Bampi, Gustavo Echenique Silveira, F. Nunes, Marcos Faerstein, Fernanda Garcia Cordeiro Tessarolli
This paper describes recent efforts into continually increasing the recovery factors in the Campos Basin reservoirs, which translate in significant investments foreseen for the next years to increase the production and recovery of the Basin. Some strategic efforts comprise measurement and critical analysis of current recovery factor, evaluation of recovery potential per reservoir and the creation of initiatives focused on the main technical requisites that would allow higher recoveries. Campos Basin complexity, along with the maturity of the existing infrastructure, brings new challenges to the continuity of production. Among those challenges are the capacity to process large amounts of produced water and the demand for revitalization of production facilities, including topside, subsea and new wells. Despite excellent results achieved in pre-salt reservoirs in Santos Basin in the recent years, Campos Basin remains an important province for Brazil's oil production. Still responding for 40% of the current production of oil in Brazil, the basin presents a promising future in the next decades. Revitalization projects, development of recent pre-salt discoveries and concession contract extensions are among the ongoing efforts towards Campos Basin renewal. Along with operations and complementary projects, a strategic program called RF Ambition was set up in 2019, aiming to: deepen the diagnosis of the recovery factor per reservoir;establish recovery targets and ambitions for each reservoir;identify initiatives to boost recovery;provide the technical support to deploy the projects with potential to allow achieving the targets and ambitions in Brazilian fields. An accurate diagnosis of the basin's recovery factor relies on a careful and thorough detailing of its reservoirs. Campos Basin has hundreds of production zones with different lithologies, in place volumes, types of fluids, geological complexities and water depth. Data analysis, evaluation and comparison to analytical estimates and international benchmarks can minimize the risk of reaching superficial or even incorrect conclusions. The remaining potential of the reservoirs, approached by the identification of opportunities, translates into mid- and long-term supplementary projects to exploit undeveloped zones and optimize the recovery of the reservoirs, thus increasing overall recovery of the fields in Campos Basin. The aggregated contribution of these new opportunities integrates an ambitious target of recovery factor for the basin. There are significant opportunities to increase Campos Basin's recovery factor and, to achieve the forecasted targets, technical and economic challenges must be overcome with the contributions of all agents involved in the upstream chain.
{"title":"Improving Recovery Factor in Campos Basin","authors":"P. Silva, C. Branco, Dirceu Bampi, Gustavo Echenique Silveira, F. Nunes, Marcos Faerstein, Fernanda Garcia Cordeiro Tessarolli","doi":"10.4043/29798-ms","DOIUrl":"https://doi.org/10.4043/29798-ms","url":null,"abstract":"\u0000 This paper describes recent efforts into continually increasing the recovery factors in the Campos Basin reservoirs, which translate in significant investments foreseen for the next years to increase the production and recovery of the Basin. Some strategic efforts comprise measurement and critical analysis of current recovery factor, evaluation of recovery potential per reservoir and the creation of initiatives focused on the main technical requisites that would allow higher recoveries.\u0000 Campos Basin complexity, along with the maturity of the existing infrastructure, brings new challenges to the continuity of production. Among those challenges are the capacity to process large amounts of produced water and the demand for revitalization of production facilities, including topside, subsea and new wells.\u0000 Despite excellent results achieved in pre-salt reservoirs in Santos Basin in the recent years, Campos Basin remains an important province for Brazil's oil production. Still responding for 40% of the current production of oil in Brazil, the basin presents a promising future in the next decades. Revitalization projects, development of recent pre-salt discoveries and concession contract extensions are among the ongoing efforts towards Campos Basin renewal.\u0000 Along with operations and complementary projects, a strategic program called RF Ambition was set up in 2019, aiming to: deepen the diagnosis of the recovery factor per reservoir;establish recovery targets and ambitions for each reservoir;identify initiatives to boost recovery;provide the technical support to deploy the projects with potential to allow achieving the targets and ambitions in Brazilian fields.\u0000 An accurate diagnosis of the basin's recovery factor relies on a careful and thorough detailing of its reservoirs. Campos Basin has hundreds of production zones with different lithologies, in place volumes, types of fluids, geological complexities and water depth. Data analysis, evaluation and comparison to analytical estimates and international benchmarks can minimize the risk of reaching superficial or even incorrect conclusions.\u0000 The remaining potential of the reservoirs, approached by the identification of opportunities, translates into mid- and long-term supplementary projects to exploit undeveloped zones and optimize the recovery of the reservoirs, thus increasing overall recovery of the fields in Campos Basin. The aggregated contribution of these new opportunities integrates an ambitious target of recovery factor for the basin.\u0000 There are significant opportunities to increase Campos Basin's recovery factor and, to achieve the forecasted targets, technical and economic challenges must be overcome with the contributions of all agents involved in the upstream chain.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77595208","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
B. Machado, O. Vale, Bruno Coccaro Pivatto, Leticia Santos Motta, C. Cavaliere, Marcus Vinicius Souza
Water injection is a traditional method of secondary recovery used in the petroleum industry. Typically, even with the injection of water supplementing the initial energy of the reservoirs (primary recovery), less than 50% of the original volume of oil is produced. By altering the chemical composition of the injected water, tests performed in laboratory and in pilot units have shown significant oil recovery (5 to 40%), when compared with a field with traditional water injection. The oil industry has shown great interest in smart water (SMW). Basically, the SMW comprises a seawater stream with altered ionic composition and low total dissolved solids (TDS). Membrane separation is the most suitable method for producing SMW offshore, though, it has some limitations for water ion tuning. Reverse Osmosis (RO) membrane technology plays an important role in SMW generation process due to its hability to promote a high rejection for all ionics species. This paper describes the results of a topside conceptual design of a 39,500 m3/d Water Treatment System to produce SMW (WTSMW), that generates water with a TDS of 1,884 mg/l, from seawater with 40,000 mg/l of salt. The treatment scheme comprises RO membrane permeate plus seawater, with a device to recover energy from the RO reject stream. The product water is also used for oil desalting and may be used for membrane cleaning. Electrical consumption, weight and footprint were compared with a sulphate removal unit (SRU) of 35,400 m3/d, of an existing 150 Kbpd floating production storage and offloading unit (FPSO) used as reference design (RDF). It was also evaluated the suitability of the RDF to incorporate the WTSMW, concerning electrical consumption, weight and footprint. The WTSMW is heavier (571 t), requires one more module level, which resulted in a module 9 m higher, and consumes more energy (3.3 MW), despite the use of the energy recovery device (ERD). To receive the WTSMW, the generation nominal capacity (4 × 23 MW) of the RDF should be changed to 4 × 28 MW. The increase in height and weight do not represent any restriction for design or construction of a new production unit to include the WTSMW.
{"title":"Conceptual Design of a Large Water Treatment System for Offshore Smart Water Injection","authors":"B. Machado, O. Vale, Bruno Coccaro Pivatto, Leticia Santos Motta, C. Cavaliere, Marcus Vinicius Souza","doi":"10.4043/29822-ms","DOIUrl":"https://doi.org/10.4043/29822-ms","url":null,"abstract":"\u0000 Water injection is a traditional method of secondary recovery used in the petroleum industry. Typically, even with the injection of water supplementing the initial energy of the reservoirs (primary recovery), less than 50% of the original volume of oil is produced. By altering the chemical composition of the injected water, tests performed in laboratory and in pilot units have shown significant oil recovery (5 to 40%), when compared with a field with traditional water injection. The oil industry has shown great interest in smart water (SMW). Basically, the SMW comprises a seawater stream with altered ionic composition and low total dissolved solids (TDS). Membrane separation is the most suitable method for producing SMW offshore, though, it has some limitations for water ion tuning. Reverse Osmosis (RO) membrane technology plays an important role in SMW generation process due to its hability to promote a high rejection for all ionics species.\u0000 This paper describes the results of a topside conceptual design of a 39,500 m3/d Water Treatment System to produce SMW (WTSMW), that generates water with a TDS of 1,884 mg/l, from seawater with 40,000 mg/l of salt. The treatment scheme comprises RO membrane permeate plus seawater, with a device to recover energy from the RO reject stream. The product water is also used for oil desalting and may be used for membrane cleaning. Electrical consumption, weight and footprint were compared with a sulphate removal unit (SRU) of 35,400 m3/d, of an existing 150 Kbpd floating production storage and offloading unit (FPSO) used as reference design (RDF). It was also evaluated the suitability of the RDF to incorporate the WTSMW, concerning electrical consumption, weight and footprint. The WTSMW is heavier (571 t), requires one more module level, which resulted in a module 9 m higher, and consumes more energy (3.3 MW), despite the use of the energy recovery device (ERD). To receive the WTSMW, the generation nominal capacity (4 × 23 MW) of the RDF should be changed to 4 × 28 MW. The increase in height and weight do not represent any restriction for design or construction of a new production unit to include the WTSMW.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"6 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87992401","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}
As the Industry of Oil and Gas advanced in deeper waters exploring, the drilling units positioning technique alternated from anchors to dynamic positioning (DP). Nowadays, even in deep or shallow waters, a large number of DP drilling units has been used. In addition, it was noticed that technology has been improved and was incresead redundancy and hardware in diferentes subsytems of the vessels. No matter how many redundancys a DP drillship contractor can provide to his own vessel, the faults, in the system and subsystem, have been experienced over the years, either for equipment failure or for human errors, and also could lead a of positioning and disconnect from the well. Taking a deeper look into all DP Petrobras incidents experienced, it was observed that the most of them are related to power system in many differents types of failure. As of knowlodge, there are two main types of switchboards mode: single busbar and split busbar, each of them has yours own vantages and disvantages, but based in its past experienced, few years ago, Petrobras strongly recommended to all its drilling contractors to operate in split busbar instead of a single busbar mode, in order to prevent major failures. Once that most part of the DP drilling units operating in split switchboards, the worst case failure experienced in the power system, is a partial blackout, but others could be linked a DP incidents. The events assessed, from the Petrobras database DP only, showed that human failures and faults arising from maintenance processes in critical equipment are, currently, the major factors causing DP incidents. Considering the faults occurred, they, usually, do not result in major events, such drift-off and emergency disconnect from the well. In fact, a partial blackout itself does not even lead to a yellow alarm, by Petrobras definitions; even though, knowing the main type and root cause of the failures will help to prevent similar events. Keeping in mind how importante is to find the root cause of all incidentes, associanting it to a systematic collection and analysis of numerical data helps to investigate the relationships among incidents and to explain and control their occurrence. In other words, a statistical analysis gives a full picture of all incidents and recurrences, also provides substantial informations to estabilished proper barriers to avoid similar ocrurrences; and, especially, when is talking about switchboards modes, adds another decision parameter in the choice which is better. This is paper will present a statistical analysis of the failures occurred and non productive time during operation in split busbar due to dynamic positioning incidents related to power system failures. Evaluate and compares performance over time of semi-submersible and drillship rigs.
{"title":"Statistical Analysis of Split Switchboard Operation in Dynamic Positioning Drilling Units","authors":"Marina Passos Ramalhete","doi":"10.4043/29849-ms","DOIUrl":"https://doi.org/10.4043/29849-ms","url":null,"abstract":"\u0000 As the Industry of Oil and Gas advanced in deeper waters exploring, the drilling units positioning technique alternated from anchors to dynamic positioning (DP). Nowadays, even in deep or shallow waters, a large number of DP drilling units has been used. In addition, it was noticed that technology has been improved and was incresead redundancy and hardware in diferentes subsytems of the vessels. No matter how many redundancys a DP drillship contractor can provide to his own vessel, the faults, in the system and subsystem, have been experienced over the years, either for equipment failure or for human errors, and also could lead a of positioning and disconnect from the well.\u0000 Taking a deeper look into all DP Petrobras incidents experienced, it was observed that the most of them are related to power system in many differents types of failure. As of knowlodge, there are two main types of switchboards mode: single busbar and split busbar, each of them has yours own vantages and disvantages, but based in its past experienced, few years ago, Petrobras strongly recommended to all its drilling contractors to operate in split busbar instead of a single busbar mode, in order to prevent major failures.\u0000 Once that most part of the DP drilling units operating in split switchboards, the worst case failure experienced in the power system, is a partial blackout, but others could be linked a DP incidents. The events assessed, from the Petrobras database DP only, showed that human failures and faults arising from maintenance processes in critical equipment are, currently, the major factors causing DP incidents. Considering the faults occurred, they, usually, do not result in major events, such drift-off and emergency disconnect from the well. In fact, a partial blackout itself does not even lead to a yellow alarm, by Petrobras definitions; even though, knowing the main type and root cause of the failures will help to prevent similar events.\u0000 Keeping in mind how importante is to find the root cause of all incidentes, associanting it to a systematic collection and analysis of numerical data helps to investigate the relationships among incidents and to explain and control their occurrence. In other words, a statistical analysis gives a full picture of all incidents and recurrences, also provides substantial informations to estabilished proper barriers to avoid similar ocrurrences; and, especially, when is talking about switchboards modes, adds another decision parameter in the choice which is better.\u0000 This is paper will present a statistical analysis of the failures occurred and non productive time during operation in split busbar due to dynamic positioning incidents related to power system failures. Evaluate and compares performance over time of semi-submersible and drillship rigs.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"33 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90928427","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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