M. Pickarts, E. Brown, J. Delgado-Linares, G. Blanchard, V. Veedu, C. Koh
In pipelines, solid compounds including gas hydrates and asphaltenes may form/precipitate and accumulate on the pipe surface, leading to a gradual stenosis of the flowline. As a result, production may become increasingly difficult or possibly interrupted if mitigation efforts are not enacted. Typically, injected chemicals will either inhibit nucleation or dissolve already-formed deposits to restore original flow conditions back to the system; however, this can be a costly option. More recently, management strategies have been proposed where solids are handled in a controlled fashion rather than completely avoided. One such proposed management strategy as suggested for wall deposit formation is the use of coatings. Here, coatings can provide a low surface energy layer on the pipe wall, which restricts liquid and solid accumulation, allowing for a stable slurry flow through a system. This study utilized two material formulations within several experimental setups to probe their interactions with water, gas hydrate, asphaltene, and crude oil. The results serve as part of an ongoing investigation into a surface treatment formulation that can be tested on larger-scale, fully flowing systems, which could be ultimately implemented into real-world production scenarios. The first surface treatment is a water-based polymeric surface that displays repellency to both oil and water phases (omniphobic). Testing of this material consisted of water contact angle measurements and static asphaltene/crude oil deposition quantification at atmospheric conditions, as well as visual confirmation of hydrate deposition prevention at high pressures. Additionally, an experimental superomniphobic surface treatment, which displays elevated resiliency to both water and hydrocarbons, was also examined within the asphaltene/crude oil test as a comparison to the omniphobic surface treatment. Static contact angle results showed that the omniphobic surface treatment had reduced surface interaction with water droplets in air, increasing the low contact angles of corroded surfaces (0-31°) to slightly hydrophobic conditions of 91.5°. Additionally, rocking cells tests indicated that these omniphobic surface treatments may prevent gas hydrate deposition under high-pressure, semi-flowing conditions. Multiple tests found that formed hydrate agglomerants did not deposit for at least 48 and 72 hours. Finally, static deposition tests conducted in crude oil with forced asphaltene precipitation suggested that the omniphobic surface treatment displayed a resistance to both asphaltenes and crude oil when compared to untreated and superomniphobic surfaces.
{"title":"Deposition Mitigation in Flowing Systems Using Coatings","authors":"M. Pickarts, E. Brown, J. Delgado-Linares, G. Blanchard, V. Veedu, C. Koh","doi":"10.4043/29380-MS","DOIUrl":"https://doi.org/10.4043/29380-MS","url":null,"abstract":"\u0000 In pipelines, solid compounds including gas hydrates and asphaltenes may form/precipitate and accumulate on the pipe surface, leading to a gradual stenosis of the flowline. As a result, production may become increasingly difficult or possibly interrupted if mitigation efforts are not enacted. Typically, injected chemicals will either inhibit nucleation or dissolve already-formed deposits to restore original flow conditions back to the system; however, this can be a costly option. More recently, management strategies have been proposed where solids are handled in a controlled fashion rather than completely avoided. One such proposed management strategy as suggested for wall deposit formation is the use of coatings. Here, coatings can provide a low surface energy layer on the pipe wall, which restricts liquid and solid accumulation, allowing for a stable slurry flow through a system.\u0000 This study utilized two material formulations within several experimental setups to probe their interactions with water, gas hydrate, asphaltene, and crude oil. The results serve as part of an ongoing investigation into a surface treatment formulation that can be tested on larger-scale, fully flowing systems, which could be ultimately implemented into real-world production scenarios. The first surface treatment is a water-based polymeric surface that displays repellency to both oil and water phases (omniphobic). Testing of this material consisted of water contact angle measurements and static asphaltene/crude oil deposition quantification at atmospheric conditions, as well as visual confirmation of hydrate deposition prevention at high pressures. Additionally, an experimental superomniphobic surface treatment, which displays elevated resiliency to both water and hydrocarbons, was also examined within the asphaltene/crude oil test as a comparison to the omniphobic surface treatment.\u0000 Static contact angle results showed that the omniphobic surface treatment had reduced surface interaction with water droplets in air, increasing the low contact angles of corroded surfaces (0-31°) to slightly hydrophobic conditions of 91.5°. Additionally, rocking cells tests indicated that these omniphobic surface treatments may prevent gas hydrate deposition under high-pressure, semi-flowing conditions. Multiple tests found that formed hydrate agglomerants did not deposit for at least 48 and 72 hours. Finally, static deposition tests conducted in crude oil with forced asphaltene precipitation suggested that the omniphobic surface treatment displayed a resistance to both asphaltenes and crude oil when compared to untreated and superomniphobic surfaces.","PeriodicalId":11149,"journal":{"name":"Day 1 Mon, May 06, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82703641","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}
Mass gravity flow phenomena resulting from mobilization of unstable sediments on submarine slopes are well recognized as a major geologic hazard for offshore infrastructure development. Previously published research pertaining to mass gravity flow impact on offshore infrastructure has focused on evaluating the direct impact loads generated by the flowing sediment mass in contact with the analyzed infrastructure component, such as a pipeline or a mudmat. In this study, the mass gravity flow impact on offshore infrastructure is addressed from a different perspective by investigating the potential for mass gravity flow induced seafloor scouring. Finite-element analysis is used to investigate the mobilization of near-seafloor sediments in a deepwater setting under the loads generated by a mass gravity flow event. Analysis results representative for a mass gravity flow in the far-field, near-field, and at the location of a mudmat supported subsea structure are presented and discussed in terms of failure mechanism, near-seafloor sediment deformation pattern and associated impact on stability of the subsea structure, in relation to flow thickness and position of the front of the flow relative to the subsea structure. For the case of a mass gravity flow in contact with the subsea structure, an example of failure envelope providing the ultimate lateral impact load from mass gravity flow required to cause instability of the structure, accounting for the flow induced mobilization of sediments underneath the mudmat, is also presented.
{"title":"Assessment of Mass Gravity Flow Induced Seafloor Scour Impact on Stability of Mudmat Supported Subsea Structures","authors":"A. Trandafir","doi":"10.4043/29464-MS","DOIUrl":"https://doi.org/10.4043/29464-MS","url":null,"abstract":"\u0000 Mass gravity flow phenomena resulting from mobilization of unstable sediments on submarine slopes are well recognized as a major geologic hazard for offshore infrastructure development. Previously published research pertaining to mass gravity flow impact on offshore infrastructure has focused on evaluating the direct impact loads generated by the flowing sediment mass in contact with the analyzed infrastructure component, such as a pipeline or a mudmat. In this study, the mass gravity flow impact on offshore infrastructure is addressed from a different perspective by investigating the potential for mass gravity flow induced seafloor scouring. Finite-element analysis is used to investigate the mobilization of near-seafloor sediments in a deepwater setting under the loads generated by a mass gravity flow event. Analysis results representative for a mass gravity flow in the far-field, near-field, and at the location of a mudmat supported subsea structure are presented and discussed in terms of failure mechanism, near-seafloor sediment deformation pattern and associated impact on stability of the subsea structure, in relation to flow thickness and position of the front of the flow relative to the subsea structure. For the case of a mass gravity flow in contact with the subsea structure, an example of failure envelope providing the ultimate lateral impact load from mass gravity flow required to cause instability of the structure, accounting for the flow induced mobilization of sediments underneath the mudmat, is also presented.","PeriodicalId":11149,"journal":{"name":"Day 1 Mon, May 06, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83524071","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}
Mooring system life extension for offshore floating production installation has become a hot topic for offshore industry as more and more floating units approach the end of their design lives. Some mooring system life extension projects have already been completed successfully, there are still some issues upon which the mooring industry has not reached consensus, such as field inspection capability/accuracy, uninspected items assessment, component degradation assessment, and acceptance criteria for numerical evaluation. This paper demonstrates two mooring system life extension processes located at Liuhua (LH) 11-1 oil field, following ABS rules as well as industry best practices. It also presents the challenging issues met during this long period of operation, initiated in 2016 and to be completed by end of 2019. Nanhai Shengli (NHSL) FPSO and Nanhai Tiaozhan (NHTZ) FPS are located in Liuhua 11-1 oil field. Both of the mooring systems were installed in 1995 with an originally designed life of 10 years, and already upgraded/replaced partially to extend their lives for continual safety operation. Thus, this is the second life extension for them, and some special challenges are presented. The upgrade of the mooring system is proposed based on inspection, testing, and analysis results for the existing mooring components. This paper focuses on some of the work that has been performed. These experiences may be helpful for the life extension of other similar mooring systems.
{"title":"Liuhua 11-1 FPSO & FPS Mooring System Life Extension Evaluation and Challenging Issues","authors":"Huoping Wang, Qinghe Zhang, Yiyong Liu, Mao Jiayou, Weiquan Zhu, Hui Shen","doi":"10.4043/29338-MS","DOIUrl":"https://doi.org/10.4043/29338-MS","url":null,"abstract":"\u0000 Mooring system life extension for offshore floating production installation has become a hot topic for offshore industry as more and more floating units approach the end of their design lives. Some mooring system life extension projects have already been completed successfully, there are still some issues upon which the mooring industry has not reached consensus, such as field inspection capability/accuracy, uninspected items assessment, component degradation assessment, and acceptance criteria for numerical evaluation. This paper demonstrates two mooring system life extension processes located at Liuhua (LH) 11-1 oil field, following ABS rules as well as industry best practices. It also presents the challenging issues met during this long period of operation, initiated in 2016 and to be completed by end of 2019.\u0000 Nanhai Shengli (NHSL) FPSO and Nanhai Tiaozhan (NHTZ) FPS are located in Liuhua 11-1 oil field. Both of the mooring systems were installed in 1995 with an originally designed life of 10 years, and already upgraded/replaced partially to extend their lives for continual safety operation. Thus, this is the second life extension for them, and some special challenges are presented. The upgrade of the mooring system is proposed based on inspection, testing, and analysis results for the existing mooring components. This paper focuses on some of the work that has been performed. These experiences may be helpful for the life extension of other similar mooring systems.","PeriodicalId":11149,"journal":{"name":"Day 1 Mon, May 06, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89558488","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}
With increasing volatility in the oil prices, continued focus on low cost solutions is key to maintain a sustainable subsea industry. The industry has and will continue to have a tremendous amount of focus across many standardization initiatives and Joint Industry Programs. The total number of trees awarded since 1961 is in the range of 7 000 - 8 000 representing an annual average of approximately 140 which in the last 10 years has been closer to 300. Assuming 2/3 are installed by a manifold with an average of 4.5 trees per manifold, gives roughly 45 manifolds worldwide per year in the entire subsea industry. Take into consideration that the manifold is the largest piece of equipment in the subsea production system acting as system integrator and interface, bridging the trees with the flow line, often having to absorb the field specific requirements and you have the ultimate standardization challenge in a low volume environment. An important aspect discussed above is that the manifold is indeed part of a bigger system. There are many ways to approach standardization and, in the article, we argue that the optimal approach is to standardize from materials and upwards in the system hierarchy. The approach taken to standardize the manifold was therefore to start with a broad set of system attributes across the subsea production system rather than focusing on the manifold alone. This allows the standardization to be a wholistic approach aiming to optimize the supplier’s operational production strategies, maximize use of lowest cost production processes as well as developing the right standard products. The modular compact manifold has therefore been developed through extensive use of data analytics due both to the large number of variables and the size of the dataset to find the optimum breakdown of the manifold into modules. The manifold shares components and production process with the subsea tree for valves and branch blocks using standard pressure classes. Standard pipe schedules have been identified to further reduce number of parts required in the portfolio. This has enabled configure to order manifolds with a limited number of pre-defined components that can be held in stock to minimize lead time. The use of compact branch blocks has also the allowed the manifold to significantly reduce footprint and weight further ensuring efficient installation.
{"title":"Compact Modular Manifold – Standardization and Modularization for Low Cost in a Low Volume Market","authors":"Hans Kristian Sundt, Hasan Ali","doi":"10.4043/29665-MS","DOIUrl":"https://doi.org/10.4043/29665-MS","url":null,"abstract":"\u0000 With increasing volatility in the oil prices, continued focus on low cost solutions is key to maintain a sustainable subsea industry. The industry has and will continue to have a tremendous amount of focus across many standardization initiatives and Joint Industry Programs.\u0000 The total number of trees awarded since 1961 is in the range of 7 000 - 8 000 representing an annual average of approximately 140 which in the last 10 years has been closer to 300.\u0000 Assuming 2/3 are installed by a manifold with an average of 4.5 trees per manifold, gives roughly 45 manifolds worldwide per year in the entire subsea industry. Take into consideration that the manifold is the largest piece of equipment in the subsea production system acting as system integrator and interface, bridging the trees with the flow line, often having to absorb the field specific requirements and you have the ultimate standardization challenge in a low volume environment.\u0000 An important aspect discussed above is that the manifold is indeed part of a bigger system. There are many ways to approach standardization and, in the article, we argue that the optimal approach is to standardize from materials and upwards in the system hierarchy. The approach taken to standardize the manifold was therefore to start with a broad set of system attributes across the subsea production system rather than focusing on the manifold alone. This allows the standardization to be a wholistic approach aiming to optimize the supplier’s operational production strategies, maximize use of lowest cost production processes as well as developing the right standard products.\u0000 The modular compact manifold has therefore been developed through extensive use of data analytics due both to the large number of variables and the size of the dataset to find the optimum breakdown of the manifold into modules. The manifold shares components and production process with the subsea tree for valves and branch blocks using standard pressure classes. Standard pipe schedules have been identified to further reduce number of parts required in the portfolio. This has enabled configure to order manifolds with a limited number of pre-defined components that can be held in stock to minimize lead time. The use of compact branch blocks has also the allowed the manifold to significantly reduce footprint and weight further ensuring efficient installation.","PeriodicalId":11149,"journal":{"name":"Day 1 Mon, May 06, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78148962","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}
Marcus T. Ogle, Rosemary B. Smith, Benjamin Williams, R. V. Schiller, Ruth Perry, P. Leung, S. DiMarco, S. Howden
Fugro was contracted in 2014 by Shell to provide a Fugro Wavescan Buoy system to support the life of field of the Stones development in the Gulf of Mexico. The companies have worked together to expand the monitoring system of the Shell Alcyone buoy system from a tool designed to satisfying regulatory compliance into a scientific platform for deep ocean research. In 2018, Fugro was contracted by the National Academies Gulf Research Program to expand the real-time monitoring of currents below the required 1000 meters to the full water depth of 2950 meters. Shell and Fugro invited universities and non-governmental partners to utilize the Alcyone buoy as a platform to make additional measurements varying from marine life monitoring to deep water column temperature readings to characterize thermocline variability. Fugro's metocean support to the development of the Shell Stones field started with the installation of a moored buoy system prior to the arrival of the FPSO Turritella and has grown to provide an abundance of unique metocean data. The objective of this paper is to discuss the evolution of a metocean buoy originally designed for NTL compliance, into a collaborative platform for research, development and innovation between the Industry, Academia and Research. Among hurricane data, interesting metocean features captured in the data such as the Loop Current activity and Topographical Rossby Waves are presented. Since its deployment in January 2015, the Shell Alcyone buoy is evolving into a pioneer platform for asset integrity, metocean monitoring and scientific collaboration. Fugro and Shell's partnership is looking to well beyond 2025 and both parties will continue to strive to learn as much as possible utilizing this unique opportunity and platform.
{"title":"Four Years of Metocean Support to the Shell Stones Field: From Asset Integrity to Collaborative Research","authors":"Marcus T. Ogle, Rosemary B. Smith, Benjamin Williams, R. V. Schiller, Ruth Perry, P. Leung, S. DiMarco, S. Howden","doi":"10.4043/29392-MS","DOIUrl":"https://doi.org/10.4043/29392-MS","url":null,"abstract":"\u0000 Fugro was contracted in 2014 by Shell to provide a Fugro Wavescan Buoy system to support the life of field of the Stones development in the Gulf of Mexico. The companies have worked together to expand the monitoring system of the Shell Alcyone buoy system from a tool designed to satisfying regulatory compliance into a scientific platform for deep ocean research. In 2018, Fugro was contracted by the National Academies Gulf Research Program to expand the real-time monitoring of currents below the required 1000 meters to the full water depth of 2950 meters. Shell and Fugro invited universities and non-governmental partners to utilize the Alcyone buoy as a platform to make additional measurements varying from marine life monitoring to deep water column temperature readings to characterize thermocline variability.\u0000 Fugro's metocean support to the development of the Shell Stones field started with the installation of a moored buoy system prior to the arrival of the FPSO Turritella and has grown to provide an abundance of unique metocean data. The objective of this paper is to discuss the evolution of a metocean buoy originally designed for NTL compliance, into a collaborative platform for research, development and innovation between the Industry, Academia and Research. Among hurricane data, interesting metocean features captured in the data such as the Loop Current activity and Topographical Rossby Waves are presented.\u0000 Since its deployment in January 2015, the Shell Alcyone buoy is evolving into a pioneer platform for asset integrity, metocean monitoring and scientific collaboration. Fugro and Shell's partnership is looking to well beyond 2025 and both parties will continue to strive to learn as much as possible utilizing this unique opportunity and platform.","PeriodicalId":11149,"journal":{"name":"Day 1 Mon, May 06, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78670207","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}
F. Queiroz, Fernando B. C de Araujo, Mylene Marques Fernandes, Juliana Casaccia Vaz
This paper presents the strategy behind the conceptual design for Libra FPSOs and the technologies being studied to be applied in the future. Considering new reservoir conditions when compared to other Pre-Salt areas in Brazil, such as high GOR, high CO2 content and high productivity wells, surface facilities team have faced new challenges to define the optimum process plant configuration. Concerns related to topside weight and footprint had to be addressed since the early project phase to make sure that the FPSO would be able to operate safely with high production efficiency in a very restricted area. Right after Libra block contract signature, Libra Project Team elaborated the documentation to lease the first FPSO (EWT FPSO Pioneiro de Libra) and started conceptual studies for the design of the FPSOs that will develop the production of the field. Besides the economic benefits related to the increase of the oil capacity, the conceptual studies at an early stage of the field development provided the project team more confidence regarding lead time and technical aspects of the FPSO. It is expected that new technologies development will add more value to the projects in the near future.
本文介绍了Libra fpso概念设计背后的策略以及未来正在研究的应用技术。与巴西其他盐下地区相比，考虑到新的储层条件，如高GOR、高CO2含量和高产能井，地面设施团队面临着确定最佳工艺装置配置的新挑战。从项目早期开始，就必须解决与上层重量和占地面积有关的问题，以确保FPSO能够在非常有限的区域内以高生产效率安全运行。在Libra区块合同签署后，Libra项目团队制定了租赁第一艘FPSO (EWT FPSO pioneer de Libra)的文件，并开始了FPSO设计的概念研究，这些FPSO将用于开发该油田的生产。除了与产油量增加相关的经济效益外，油田开发早期阶段的概念研究使项目团队对FPSO的交货时间和技术方面更有信心。预计在不久的将来，新技术的发展将为项目增加更多的价值。
{"title":"Libra's FPSO - Conceptual Design Challenges","authors":"F. Queiroz, Fernando B. C de Araujo, Mylene Marques Fernandes, Juliana Casaccia Vaz","doi":"10.4043/29536-MS","DOIUrl":"https://doi.org/10.4043/29536-MS","url":null,"abstract":"\u0000 This paper presents the strategy behind the conceptual design for Libra FPSOs and the technologies being studied to be applied in the future. Considering new reservoir conditions when compared to other Pre-Salt areas in Brazil, such as high GOR, high CO2 content and high productivity wells, surface facilities team have faced new challenges to define the optimum process plant configuration. Concerns related to topside weight and footprint had to be addressed since the early project phase to make sure that the FPSO would be able to operate safely with high production efficiency in a very restricted area.\u0000 Right after Libra block contract signature, Libra Project Team elaborated the documentation to lease the first FPSO (EWT FPSO Pioneiro de Libra) and started conceptual studies for the design of the FPSOs that will develop the production of the field.\u0000 Besides the economic benefits related to the increase of the oil capacity, the conceptual studies at an early stage of the field development provided the project team more confidence regarding lead time and technical aspects of the FPSO. It is expected that new technologies development will add more value to the projects in the near future.","PeriodicalId":11149,"journal":{"name":"Day 1 Mon, May 06, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78826538","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}
Wellbore schematics are essential to well planning and operations because they detail well design, completions, and sometimes the production mechanism. There are multiple formats and types of wellbore schematics; however, they generally consist of a well diagram accompanied by tables of annotations listing components and equipment details such as depths and diameters. Paper-based wellbore schematic reports are often distributed as the primary account of technical information concerning old wells after being acquired by oil and gas operators. Any intervention or further operation on those wells would require a thorough and manual interpretation of those reports, which can be lengthy and prone to errors. Therefore, to automatically convert the diagram and annotations into a readable database, a practical technique or tool has to be developed. Artificial intelligence (AI)-powered image analysis addresses similar problems for other engineering disciplines and industries, and with the latest advances for software and computer hardware capabilities, it is possible to design specialized solutions for the oil and gas industry. Therefore, a methodology was defined and implemented to import the available machine learning technology for automating the interpretation and analysis of wellbore schematics. With this novel tool, scanning the paper-based wellbore schematic results in digital and easily shareable structured data that can be used to regenerate a digital wellbore schematic. This method analyzes the diagram and the annotations on the wellbore schematic file and then combines the analysis results by matching the diagram with the surrounding annotations and engineering constraints. The methodology was tested on a set of wellbore schematic files, and digital schematics were regenerated. Fundamental components and equipment were detected that matched the original schematics in terms of depths and diameters. The designed tool saves considerable time and effort while providing accuracy and repeatability. These results highlight some of the benefits of applying multidisciplinary ideas for data management to the industry. The object detection technique in image analytics is new to the oil and gas industry for identifying components in well schematics. Further, this project is comprehensive because it identifies the diagram and related annotations. Challenges and breakthroughs experienced in this research will be addressed.
{"title":"Wellbore Schematics to Structured Data Using Artificial Intelligence Tools","authors":"Kemajou Vanessa Ndonhong, A. Bao, O. Germain","doi":"10.4043/29490-MS","DOIUrl":"https://doi.org/10.4043/29490-MS","url":null,"abstract":"\u0000 Wellbore schematics are essential to well planning and operations because they detail well design, completions, and sometimes the production mechanism. There are multiple formats and types of wellbore schematics; however, they generally consist of a well diagram accompanied by tables of annotations listing components and equipment details such as depths and diameters. Paper-based wellbore schematic reports are often distributed as the primary account of technical information concerning old wells after being acquired by oil and gas operators. Any intervention or further operation on those wells would require a thorough and manual interpretation of those reports, which can be lengthy and prone to errors. Therefore, to automatically convert the diagram and annotations into a readable database, a practical technique or tool has to be developed.\u0000 Artificial intelligence (AI)-powered image analysis addresses similar problems for other engineering disciplines and industries, and with the latest advances for software and computer hardware capabilities, it is possible to design specialized solutions for the oil and gas industry. Therefore, a methodology was defined and implemented to import the available machine learning technology for automating the interpretation and analysis of wellbore schematics. With this novel tool, scanning the paper-based wellbore schematic results in digital and easily shareable structured data that can be used to regenerate a digital wellbore schematic. This method analyzes the diagram and the annotations on the wellbore schematic file and then combines the analysis results by matching the diagram with the surrounding annotations and engineering constraints.\u0000 The methodology was tested on a set of wellbore schematic files, and digital schematics were regenerated. Fundamental components and equipment were detected that matched the original schematics in terms of depths and diameters. The designed tool saves considerable time and effort while providing accuracy and repeatability. These results highlight some of the benefits of applying multidisciplinary ideas for data management to the industry.\u0000 The object detection technique in image analytics is new to the oil and gas industry for identifying components in well schematics. Further, this project is comprehensive because it identifies the diagram and related annotations. Challenges and breakthroughs experienced in this research will be addressed.","PeriodicalId":11149,"journal":{"name":"Day 1 Mon, May 06, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78501936","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}
Hao Qin, V. Srivastava, Hua Wang, L. Zerpa, C. Koh
Recently the concept of "no external gas hydrate control measures" has been proposed, whereby gas hydrate formation can occur in oil and gas subsea pipelines during steady state and transient operations, with the operational window defined by predictive analytic tools. Flow assurance engineers routinely use computer programs, including transient multiphase flow simulators coupled to a gas hydrate kinetics model to simulate gas hydrate formation and transportability. Given the complexity in multiphase flow modeling, modern machine learning technologies, especially artificial intelligence, could be applied to solve high-level, non-linear problems, such as evaluating gas hydrate risk based on measurable process parameters. In this work, several machine learning techniques, such as regression, classification, feature learning with an algorithm/framework like support vector machine (SVM) and neural networks (NN), are applied to analyze the data sets on: 1) hydrate tests conducted at pilot-scale flowloop facilities (4,500 data points), as well as 2) transient operation field data. The classification/regression model based on flowloop test data uses several independent input variables (features), such as water cut, gas-oil ratio, hydrate particle cohesive force, fluid velocity, oil viscosity, specific gravity, interfacial tension, and time in the hydrate stable zone, to output the hydrate fraction and probability of hydrate plugging in the pipeline. The semi-supervised learning model was applied based on the field data use as input, including water cut, shut-down time (where applicable), and gas-oil ratio to determine the level of hydrate resistance to flow during restart or dead oil displacement after production shut-down. The flowloop based machine learning model exhibited good prediction accuracies in test and validation processes, and was used to assess the hydrate risks in an actual field. The field data based machine learning model demonstrated the ability to construct field risk maps. The machine learning technique could be potentially applied in hydrate management to evaluate hydrate risks in subsea oil/gas pipelines. As a complement to more complex transient multiphase flow simulations, this machine learning approach can aid in the development of advanced hydrate management strategies.
{"title":"Machine Learning Models to Predict Gas Hydrate Plugging Risks Using Flowloop and Field Data","authors":"Hao Qin, V. Srivastava, Hua Wang, L. Zerpa, C. Koh","doi":"10.4043/29411-MS","DOIUrl":"https://doi.org/10.4043/29411-MS","url":null,"abstract":"\u0000 Recently the concept of \"no external gas hydrate control measures\" has been proposed, whereby gas hydrate formation can occur in oil and gas subsea pipelines during steady state and transient operations, with the operational window defined by predictive analytic tools. Flow assurance engineers routinely use computer programs, including transient multiphase flow simulators coupled to a gas hydrate kinetics model to simulate gas hydrate formation and transportability. Given the complexity in multiphase flow modeling, modern machine learning technologies, especially artificial intelligence, could be applied to solve high-level, non-linear problems, such as evaluating gas hydrate risk based on measurable process parameters.\u0000 In this work, several machine learning techniques, such as regression, classification, feature learning with an algorithm/framework like support vector machine (SVM) and neural networks (NN), are applied to analyze the data sets on: 1) hydrate tests conducted at pilot-scale flowloop facilities (4,500 data points), as well as 2) transient operation field data. The classification/regression model based on flowloop test data uses several independent input variables (features), such as water cut, gas-oil ratio, hydrate particle cohesive force, fluid velocity, oil viscosity, specific gravity, interfacial tension, and time in the hydrate stable zone, to output the hydrate fraction and probability of hydrate plugging in the pipeline. The semi-supervised learning model was applied based on the field data use as input, including water cut, shut-down time (where applicable), and gas-oil ratio to determine the level of hydrate resistance to flow during restart or dead oil displacement after production shut-down.\u0000 The flowloop based machine learning model exhibited good prediction accuracies in test and validation processes, and was used to assess the hydrate risks in an actual field. The field data based machine learning model demonstrated the ability to construct field risk maps.\u0000 The machine learning technique could be potentially applied in hydrate management to evaluate hydrate risks in subsea oil/gas pipelines. As a complement to more complex transient multiphase flow simulations, this machine learning approach can aid in the development of advanced hydrate management strategies.","PeriodicalId":11149,"journal":{"name":"Day 1 Mon, May 06, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77784763","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
J. Lou, A. Hoor, Wilson Zeng, M. Hull, John Wei, Chris Walton, Dave Truch, S. Silva, Bill Broman
Integrity management (IM) is an ongoing lifecycle process for ensuring safe operation and fitness for service of offshore oil and gas production systems, including riser and flowlines. Riser and flowlines offer a means of transporting fluids between subsea wells and the host platform. A key component of the riser system is above water riser hull pipes. With their proximity to topside equipment and the people on the platform, these pipes are considered safety critical, and are therefore, subject to rigorous and frequent inspections followed by an engineering assessment of the findings. A thorough knowledge of the past and current conditions of these pipes is required to manage the risk to their integrity. Traditionally, these inspections are carried out by rope access technicians. Such activities are often limited by accessibility, weather, and/or Personnel on Board (POB) availability and involve risks to inspector's safety. This paper discusses the motivation and business driver for developing and implementing new robotic inspection technologies for above water riser inspection. The technology management process of robotic inspection tools is outlined. Comparison is made between traditional and new inspection technologies based on BP Gulf of Mexico (GoM) robotic inspection campaigns. Examples are presented to demonstrate the reduction of safety risks and improvement of inspection execution and effectiveness. The paper also discusses the potential areas of future development, which include methods for pipe wall thickness measurement and data analytics, such as automated recognition approach to characterize and quantify features in the images.
{"title":"Field Implementation of Above Water Riser Robotic Inspection Tools - Reducing Safety Risk While Improving Efficiency and Effectiveness","authors":"J. Lou, A. Hoor, Wilson Zeng, M. Hull, John Wei, Chris Walton, Dave Truch, S. Silva, Bill Broman","doi":"10.4043/29651-MS","DOIUrl":"https://doi.org/10.4043/29651-MS","url":null,"abstract":"\u0000 Integrity management (IM) is an ongoing lifecycle process for ensuring safe operation and fitness for service of offshore oil and gas production systems, including riser and flowlines. Riser and flowlines offer a means of transporting fluids between subsea wells and the host platform. A key component of the riser system is above water riser hull pipes. With their proximity to topside equipment and the people on the platform, these pipes are considered safety critical, and are therefore, subject to rigorous and frequent inspections followed by an engineering assessment of the findings. A thorough knowledge of the past and current conditions of these pipes is required to manage the risk to their integrity. Traditionally, these inspections are carried out by rope access technicians. Such activities are often limited by accessibility, weather, and/or Personnel on Board (POB) availability and involve risks to inspector's safety.\u0000 This paper discusses the motivation and business driver for developing and implementing new robotic inspection technologies for above water riser inspection. The technology management process of robotic inspection tools is outlined. Comparison is made between traditional and new inspection technologies based on BP Gulf of Mexico (GoM) robotic inspection campaigns. Examples are presented to demonstrate the reduction of safety risks and improvement of inspection execution and effectiveness. The paper also discusses the potential areas of future development, which include methods for pipe wall thickness measurement and data analytics, such as automated recognition approach to characterize and quantify features in the images.","PeriodicalId":11149,"journal":{"name":"Day 1 Mon, May 06, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81716522","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 presents a summary of over 25 years of laboratory data on the monotonic and cyclic soil properties of clays in direct simple shear, triaxial compression and triaxial extension tests, at 15 deepwater Gulf of Mexico sites. The majority of the test results were obtained by three different laboratories. The data are summarized in numerous plots and diagrams, and correlations are presented to help derive soil properties relevant for deepwater foundation design. The database and guidance presented in the paper can be used in early design when site-specific soil samples are not available, or to optimize the scope of advanced laboratory testing on site-specific samples during detailed design. Although the soil samples are all from the Gulf of Mexico, the guidance is believed to be valuable also for the characterization of other non-structured, high-plasticity marine clays.
{"title":"Monotonic and Cyclic Soil Properties of Gulf of Mexico Clays","authors":"E. Liedtke, K. Andersen, Youhu Zhang, P. Jeanjean","doi":"10.4043/29622-MS","DOIUrl":"https://doi.org/10.4043/29622-MS","url":null,"abstract":"\u0000 This paper presents a summary of over 25 years of laboratory data on the monotonic and cyclic soil properties of clays in direct simple shear, triaxial compression and triaxial extension tests, at 15 deepwater Gulf of Mexico sites.\u0000 The majority of the test results were obtained by three different laboratories. The data are summarized in numerous plots and diagrams, and correlations are presented to help derive soil properties relevant for deepwater foundation design. The database and guidance presented in the paper can be used in early design when site-specific soil samples are not available, or to optimize the scope of advanced laboratory testing on site-specific samples during detailed design.\u0000 Although the soil samples are all from the Gulf of Mexico, the guidance is believed to be valuable also for the characterization of other non-structured, high-plasticity marine clays.","PeriodicalId":11149,"journal":{"name":"Day 1 Mon, May 06, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91412852","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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