Stones is a phased development that began producing in September 2016 from two subsea wells tied back to an FPSO. Full-field development includes six additional wells from two connected drill centers, and a subsea boosting system to increase production and extend the life of the field. This paper describes the technology qualification program (TQP) and execution experience, including the development, delivery and installation of the world's first ultra deepwater subsea boosting system. The paper also addresses the lessons learned from the project, from component qualification and engineering through to manufacturing and testing. The Stones field is located in the Walker Ridge area, approximately 200 miles southwest of the Louisiana coast. It consists of eight ultra-deepwater blocks at 9,579 feet water depth. As the operator, with 100% interest in the field, Shell announced its final investment decision in 2013. With reservoirs located at extreme depths, at more than 29,000 feet, subsea boosting was identified in the original project execution plan as a means to enhance recovery due to rapidly decreasing reservoir pressures. Multiple technology gaps were identified to meet the high-pressure, high-temperature (HPHT) design parameters for Stones. With a targeted design pressure of 15,000 psi, design temperature of 300 °F and nearly 10,000 feet of water depth, an extensive Technology Qualification Program (TQP) was executed to close these gaps. Six workstreams were developed to qualify the first article pump; these included valves and connectors, barrier fluid system, power system and controls. This was the start of a close cooperation between the operator and the pump system provider, whose common goal was to deploy the world's first 15 ksi ultra-deepwater pump. Following the TQP, in 2015, an engineering, procurement, and construction (EPC) contract was awarded that included a pump station with two 2.9MW pumps and a topside power drive system. The pump system has been through an extensive execution and test phase that was completed without injuries. The complete system was handed over to the operator and has been partially installed. The Stones boosting system has a daily production capacity of 60,000 bpd and will enable the operator to maintain and extend production at the field. Once the pump system is put into operation, it will significantly increase recovery at the field.
{"title":"Stones - The World's First 15 Ksi Ultra-Deepwater Subsea Pump","authors":"Arill Småland Hagland, J. Skaar","doi":"10.4043/29537-MS","DOIUrl":"https://doi.org/10.4043/29537-MS","url":null,"abstract":"\u0000 Stones is a phased development that began producing in September 2016 from two subsea wells tied back to an FPSO. Full-field development includes six additional wells from two connected drill centers, and a subsea boosting system to increase production and extend the life of the field.\u0000 This paper describes the technology qualification program (TQP) and execution experience, including the development, delivery and installation of the world's first ultra deepwater subsea boosting system. The paper also addresses the lessons learned from the project, from component qualification and engineering through to manufacturing and testing.\u0000 The Stones field is located in the Walker Ridge area, approximately 200 miles southwest of the Louisiana coast. It consists of eight ultra-deepwater blocks at 9,579 feet water depth. As the operator, with 100% interest in the field, Shell announced its final investment decision in 2013. With reservoirs located at extreme depths, at more than 29,000 feet, subsea boosting was identified in the original project execution plan as a means to enhance recovery due to rapidly decreasing reservoir pressures.\u0000 Multiple technology gaps were identified to meet the high-pressure, high-temperature (HPHT) design parameters for Stones. With a targeted design pressure of 15,000 psi, design temperature of 300 °F and nearly 10,000 feet of water depth, an extensive Technology Qualification Program (TQP) was executed to close these gaps. Six workstreams were developed to qualify the first article pump; these included valves and connectors, barrier fluid system, power system and controls. This was the start of a close cooperation between the operator and the pump system provider, whose common goal was to deploy the world's first 15 ksi ultra-deepwater pump. Following the TQP, in 2015, an engineering, procurement, and construction (EPC) contract was awarded that included a pump station with two 2.9MW pumps and a topside power drive system.\u0000 The pump system has been through an extensive execution and test phase that was completed without injuries. The complete system was handed over to the operator and has been partially installed.\u0000 The Stones boosting system has a daily production capacity of 60,000 bpd and will enable the operator to maintain and extend production at the field. Once the pump system is put into operation, it will significantly increase recovery at the field.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89766177","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}
Facies prediction is an important step in reservoir characterization and modeling. Define a representative reservoir model will enhance the process of reservoir development and will optimize the economic strategies. The lack of data is a key issue in reservoir characterizations and therefore alternative approaches have to be adopted to improve the process of reservoir characterization. In this research, clustering analysis was implemented as a statistical solution to classify reservoir facies given well logs and core data in a reservoir from the south of Iraq. In this research, data from a heterogeneous carbonate reservoir were used. The data included well log records such; GR, SP, Density, Neutron Porosity, Total Porosity, Resistivity, Induction, Shale Volume, Water Saturation, along with porosity and permeability values from core analysis. These data were integrated and analyzed through statistical tools to perform clustering analysis. The clustering analysis is an approach of finding the similarities and differences between specific groups or points in order to classify them into different classes. This concept was implemented by the use of R software, which is a quite powerful open source tool for statistical studies with variety of functions and packages. Two different clustering algorithms, K-mean approach and Calinski-Harabasz solution were used to classify reservoir facies based on the given data. The results of this research show that the reservoir facies can be predicted through different clustering analysis when well logs records are given. K-means approach has predicted the optimal facies classification to be five, while Calinski-Harabasz technique has identified three optimal reservoir facies. The difference in facies classification between the two clustering analysis approaches is attributed to the two approaches sensitivity because of the high quality rocks in all the units of this well, which makes it challenging to identify the facies as all the layers have similer reservoir properties.
{"title":"Clustering Analysis for Improved Characterization of Carbonate Reservoirs in a Southern Iraqi Oil Field","authors":"W. Al-Mudhafar, Erfan M. Al lawe, C. I. Noshi","doi":"10.4043/29269-MS","DOIUrl":"https://doi.org/10.4043/29269-MS","url":null,"abstract":"\u0000 Facies prediction is an important step in reservoir characterization and modeling. Define a representative reservoir model will enhance the process of reservoir development and will optimize the economic strategies. The lack of data is a key issue in reservoir characterizations and therefore alternative approaches have to be adopted to improve the process of reservoir characterization. In this research, clustering analysis was implemented as a statistical solution to classify reservoir facies given well logs and core data in a reservoir from the south of Iraq.\u0000 In this research, data from a heterogeneous carbonate reservoir were used. The data included well log records such; GR, SP, Density, Neutron Porosity, Total Porosity, Resistivity, Induction, Shale Volume, Water Saturation, along with porosity and permeability values from core analysis. These data were integrated and analyzed through statistical tools to perform clustering analysis. The clustering analysis is an approach of finding the similarities and differences between specific groups or points in order to classify them into different classes. This concept was implemented by the use of R software, which is a quite powerful open source tool for statistical studies with variety of functions and packages. Two different clustering algorithms, K-mean approach and Calinski-Harabasz solution were used to classify reservoir facies based on the given data.\u0000 The results of this research show that the reservoir facies can be predicted through different clustering analysis when well logs records are given. K-means approach has predicted the optimal facies classification to be five, while Calinski-Harabasz technique has identified three optimal reservoir facies. The difference in facies classification between the two clustering analysis approaches is attributed to the two approaches sensitivity because of the high quality rocks in all the units of this well, which makes it challenging to identify the facies as all the layers have similer reservoir properties.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88708413","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The paper presents a cost benefit analysis of using polymer mooring components in the mooring system design of the Maine Aqua Ventus I (MAV1) floating offshore wind turbine (FOWT) project. Polymer components in mooring lines can offer new mooring system responses, which can be tailored to the needs of challenging mooring systems. For FOWT deployments these can deliver mooring system responsiveness at the thrust loads of the turbine, despite the high background mooring loads. MAV1 will deploy two 6MW floating offshore wind turbines off the coast of Maine and this paper compares the existing mooring system design against a polymer mooring component solution, undertaking dynamic analysis of the mooring systems across multiple sea states (including ultimate limit states, fatigue limit states and accidental limit states). The Aqua Ventus platform is modelled in Orcaflex, with multiple mooring system designs containing different polymer component responses modelled and contrasted. Results are analyzed and load analysis data used to undertake a cost benefit analysis. Cost reductions are shown across the mooring system (anchors, lines, connectors), as well as the platform and tower structures. Fatigue analysis is undertaken using a Rainflow analysis of the sea states to be experienced by the platform over its life, for both the existing and the polymer mooring configurations. Polymer mooring components which can be used throughout the renewable energy and offshore industries to manage mooring loads, and are capable of mooring any sized platform, in any challenging conditions. While the specific components modelled in this work are targeted at FOWT or tidal platforms with novel stress-strain response curves designed to suit the high background thrust load conditions, other component responses are available to deliver design load and fatigue reductions on existing catenary or TLP moored platforms. Components can be easily retrofitted into existing mooring lines or deployed in new lines. Using polymer mooring components can dramatically reduce the peak loads experienced by the platform. Previous work has looked at an OC4 FOWT model in hypothetic conditions, whereas the current paper presents new work related to a real US FOWT deployment. The paper demonstrates that >50% reductions in design loads are possible. Cyclic loads are also substantially reduced, resulting in >60% reduction in wave induced fatigue in extreme sea states. This results in operational and maintenance cost savings. The patented mooring components have been developed initially for aquaculture and wave energy applications and have now been scaled to the MN loads required by the FOWT and offshore industries. Components are certified to relevant standards and delivered to projects globally.
本文介绍了在缅因州Aqua Ventus I (MAV1)浮式海上风力发电机(FOWT)项目的系泊系统设计中使用聚合物系泊部件的成本效益分析。系泊缆绳中的聚合物组件可以提供新的系泊系统响应，可以根据具有挑战性的系泊系统的需求进行定制。对于fot部署，尽管背景系泊载荷很高，但这些系统可以在涡轮机推力载荷下提供系泊系统响应。MAV1将在缅因州海岸部署两台6MW海上浮动风力涡轮机，本文将现有系泊系统设计与聚合物系泊组件解决方案进行比较，对系泊系统在多种海况下(包括极限状态、疲劳极限状态和意外极限状态)进行动态分析。Aqua Ventus平台是在Orcaflex中建模的，包含不同聚合物成分响应的多个系泊系统设计进行了建模和对比。结果分析和负荷分析数据用于进行成本效益分析。整个系泊系统(锚、缆绳、连接件)以及平台和塔结构的成本都有所降低。对于现有和聚合物系泊配置，使用Rainflow分析平台在其使用寿命期间所经历的海况，进行疲劳分析。聚合物系泊组件可用于整个可再生能源和海上工业，以管理系泊负载，并且能够在任何具有挑战性的条件下系泊任何大小的平台。虽然在这项工作中建模的特定组件是针对FOWT或潮汐平台的，具有新颖的应力-应变响应曲线，旨在适应高背景推力载荷条件，但其他组件响应可用于现有悬链线或张力腿平台的设计载荷和疲劳减少。组件可以很容易地改装到现有的系泊缆绳或部署在新的缆绳。使用聚合物系泊组件可以显著降低平台承受的峰值载荷。之前的工作研究了假设条件下的OC4 FOWT模型，而当前的论文提出了与真实的美国FOWT部署相关的新工作。本文论证了设计载荷降低50%以上是可能的。循环载荷也大大减少，在极端海况下，波浪引起的疲劳减少了60%以上。这样可以节省操作和维护成本。专利系泊组件最初是为水产养殖和波浪能应用而开发的，现在已经扩展到FOWT和海上工业所需的MN载荷。组件通过相关标准认证，并交付给全球的项目。
{"title":"Polymer Mooring Component for Offshore Renewable Energy","authors":"P. McEvoy, E. Johnston","doi":"10.4043/29587-MS","DOIUrl":"https://doi.org/10.4043/29587-MS","url":null,"abstract":"\u0000 The paper presents a cost benefit analysis of using polymer mooring components in the mooring system design of the Maine Aqua Ventus I (MAV1) floating offshore wind turbine (FOWT) project. Polymer components in mooring lines can offer new mooring system responses, which can be tailored to the needs of challenging mooring systems. For FOWT deployments these can deliver mooring system responsiveness at the thrust loads of the turbine, despite the high background mooring loads. MAV1 will deploy two 6MW floating offshore wind turbines off the coast of Maine and this paper compares the existing mooring system design against a polymer mooring component solution, undertaking dynamic analysis of the mooring systems across multiple sea states (including ultimate limit states, fatigue limit states and accidental limit states). The Aqua Ventus platform is modelled in Orcaflex, with multiple mooring system designs containing different polymer component responses modelled and contrasted. Results are analyzed and load analysis data used to undertake a cost benefit analysis. Cost reductions are shown across the mooring system (anchors, lines, connectors), as well as the platform and tower structures. Fatigue analysis is undertaken using a Rainflow analysis of the sea states to be experienced by the platform over its life, for both the existing and the polymer mooring configurations.\u0000 Polymer mooring components which can be used throughout the renewable energy and offshore industries to manage mooring loads, and are capable of mooring any sized platform, in any challenging conditions. While the specific components modelled in this work are targeted at FOWT or tidal platforms with novel stress-strain response curves designed to suit the high background thrust load conditions, other component responses are available to deliver design load and fatigue reductions on existing catenary or TLP moored platforms. Components can be easily retrofitted into existing mooring lines or deployed in new lines.\u0000 Using polymer mooring components can dramatically reduce the peak loads experienced by the platform. Previous work has looked at an OC4 FOWT model in hypothetic conditions, whereas the current paper presents new work related to a real US FOWT deployment. The paper demonstrates that >50% reductions in design loads are possible. Cyclic loads are also substantially reduced, resulting in >60% reduction in wave induced fatigue in extreme sea states. This results in operational and maintenance cost savings.\u0000 The patented mooring components have been developed initially for aquaculture and wave energy applications and have now been scaled to the MN loads required by the FOWT and offshore industries. Components are certified to relevant standards and delivered to projects globally.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"67 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83585821","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
In an effort to maximize the value of the Enhanced Oil Recovery(EOR) process, a condition monitoring software program aims to optimize Seawater Treatment system performance and maintenance efforts. By collecting digital inputs from sensors, instruments and controllers on the platform or vessel, you can monitor system behavior and use application expertise and data science to characterize the operational conditions which enable operators to reduce their operating costs and maximize production. Combining unparalleled process expertise with data science and software development team, a system-wide view of the Seawater Treatment (SWT) process is produced. Using current and historical data from SWT operations, ingesting into an IOT platform and, utilizing custom software program, provide full visualization of the system performance and condition monitoring of critical components within the system. One example is monitoring the sulphate removal unit (SRU) and predicting fouling types of the membranes. With this enhanced view of performance and predictive analysis, you can reduce the need for offshore supervision and troubleshooting efforts and can prevent repeat failures and unplanned downtime. Using the SRU as an example, the Seawater Treatment software program enables early stage detection of membrane fouling which allows the operator to proactively implement a fouling mitigation program. By detecting the fouling early, the operator can optimize the cleaning in place (CIP) sequences, perform timely CIP and chemical dosing to extend the life of the membranes and prevent unnecessary downtime and prevent permanent membrane damage. It has been observed through historical data that operators can save a significant amount of money per year on membrane life, downtime reduction and production penalty prevention. There are additional potential savings by using an optimized chemical injection program to manage and prevent biogrowth/scale formation in the system. To address the operator's need of optimizing Seawater Treatment and other topside process equipment, a suite of process specific software applications can be fully integrated into a digital platform, providing a framework that easily can be tailored to customer's needs to include additional features if required. Combining a comprehensive selection of wellstream processing technologies with deep understanding of fluids behavior and proven track record of digitalization, operational issues can now be uncovered and solved. This is different from typical remote monitoring initiatives in that it applies proven machine learning and predictive analytics frameworks to detect patterns and traces from the captured data to provide the earliest possible detection of future issues and provide proactive recommendations to prevent disruption to operations.
{"title":"Optimizing Seawater Treatment Operations with Condition Monitoring Software","authors":"A. Wilcox, R. Mikkelsen, Pei Ling Esther Lian","doi":"10.4043/29567-MS","DOIUrl":"https://doi.org/10.4043/29567-MS","url":null,"abstract":"\u0000 In an effort to maximize the value of the Enhanced Oil Recovery(EOR) process, a condition monitoring software program aims to optimize Seawater Treatment system performance and maintenance efforts. By collecting digital inputs from sensors, instruments and controllers on the platform or vessel, you can monitor system behavior and use application expertise and data science to characterize the operational conditions which enable operators to reduce their operating costs and maximize production.\u0000 Combining unparalleled process expertise with data science and software development team, a system-wide view of the Seawater Treatment (SWT) process is produced. Using current and historical data from SWT operations, ingesting into an IOT platform and, utilizing custom software program, provide full visualization of the system performance and condition monitoring of critical components within the system. One example is monitoring the sulphate removal unit (SRU) and predicting fouling types of the membranes. With this enhanced view of performance and predictive analysis, you can reduce the need for offshore supervision and troubleshooting efforts and can prevent repeat failures and unplanned downtime.\u0000 Using the SRU as an example, the Seawater Treatment software program enables early stage detection of membrane fouling which allows the operator to proactively implement a fouling mitigation program. By detecting the fouling early, the operator can optimize the cleaning in place (CIP) sequences, perform timely CIP and chemical dosing to extend the life of the membranes and prevent unnecessary downtime and prevent permanent membrane damage. It has been observed through historical data that operators can save a significant amount of money per year on membrane life, downtime reduction and production penalty prevention. There are additional potential savings by using an optimized chemical injection program to manage and prevent biogrowth/scale formation in the system.\u0000 To address the operator's need of optimizing Seawater Treatment and other topside process equipment, a suite of process specific software applications can be fully integrated into a digital platform, providing a framework that easily can be tailored to customer's needs to include additional features if required. Combining a comprehensive selection of wellstream processing technologies with deep understanding of fluids behavior and proven track record of digitalization, operational issues can now be uncovered and solved. This is different from typical remote monitoring initiatives in that it applies proven machine learning and predictive analytics frameworks to detect patterns and traces from the captured data to provide the earliest possible detection of future issues and provide proactive recommendations to prevent disruption to operations.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"401 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84849876","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}
Maintaining produced water quality is a critical environmental target, and legislative requirement, for the oil and gas industry. Design and operation of effective produced water separation systems requires understanding and management of a range of complex multiphase flow phenomena, especially where gas flotation processes are used. This paper presents a novel modelling approach, using Computational Fluid Dynamics (CFD), developed to simulate gas flotation processes. The approach aims to predict the gas-oil coalescence process using a simple and time-efficient method. In the flotation process, small gas bubbles, introduced to the produced water, coalesce with the oil droplets present in the water. The combined gas-oil particles have more buoyancy than the oil droplets alone and separate more effectively from the water. While CFD approaches have been applied to improve the design and operation of a wide range of separation and compact and induced-gas flotation systems, it has typically been too technically challenging and time-consuming to attempt to capture the coalescence process involved in flotation in such simulations at a system level. Often, designers and engineers have to make use of general flow characteristics, behaviours and indicators to imply the flotation efficiency of a given design, with many combining simulations and physical testing to provide greater confidence in design and operating decisions. The approach presented in this work aims to predict the gas flotation process and coalescence efficiency, using a simplified approach by combining multiphase flow simulations, using Simcenter STAR-CCM+, representing both the small oil droplets and the gas bubbles. In the approach, the local concentration of oil droplets in water and in gas is tracked throughout a given produced water system. Oil is transferred between the water and the gas phases representing the coalescence process. The rate of transfer is governed by a model which depends on local flow conditions such as bubble size, probability of adhering and detaching and surface area of gas bubbles available for coalescence. The approach is applicable to both compact flotation and induced-gas flotation systems and the results of the approach give direct comparisons of oil in water concentration both through a system and in the water exiting. The oil concentration leaving the vessel is reported, thus directly quantifying the effectiveness of the vessel; this is an improvement over other approaches using CFD where flow characteristics are used as proxies to infer the separation effectiveness. In using flow characterisctics alone there is potential for critical aspects or counter-intuitive mechanisms to mislead engineers. It is hoped that the method presented will enable engineers and designers involved in the development, design and operation of produced water systems to more-fully understand both the complex fluid mechanics and efficiency of the flotation processes.
{"title":"Practical Method for Simulating Flotation for Produced Water System Design","authors":"M. Straw, D. Fielding, E. Kay, S. Lo, T. Eppinger","doi":"10.4043/29466-MS","DOIUrl":"https://doi.org/10.4043/29466-MS","url":null,"abstract":"\u0000 Maintaining produced water quality is a critical environmental target, and legislative requirement, for the oil and gas industry. Design and operation of effective produced water separation systems requires understanding and management of a range of complex multiphase flow phenomena, especially where gas flotation processes are used.\u0000 This paper presents a novel modelling approach, using Computational Fluid Dynamics (CFD), developed to simulate gas flotation processes. The approach aims to predict the gas-oil coalescence process using a simple and time-efficient method.\u0000 In the flotation process, small gas bubbles, introduced to the produced water, coalesce with the oil droplets present in the water. The combined gas-oil particles have more buoyancy than the oil droplets alone and separate more effectively from the water. While CFD approaches have been applied to improve the design and operation of a wide range of separation and compact and induced-gas flotation systems, it has typically been too technically challenging and time-consuming to attempt to capture the coalescence process involved in flotation in such simulations at a system level. Often, designers and engineers have to make use of general flow characteristics, behaviours and indicators to imply the flotation efficiency of a given design, with many combining simulations and physical testing to provide greater confidence in design and operating decisions.\u0000 The approach presented in this work aims to predict the gas flotation process and coalescence efficiency, using a simplified approach by combining multiphase flow simulations, using Simcenter STAR-CCM+, representing both the small oil droplets and the gas bubbles. In the approach, the local concentration of oil droplets in water and in gas is tracked throughout a given produced water system. Oil is transferred between the water and the gas phases representing the coalescence process. The rate of transfer is governed by a model which depends on local flow conditions such as bubble size, probability of adhering and detaching and surface area of gas bubbles available for coalescence.\u0000 The approach is applicable to both compact flotation and induced-gas flotation systems and the results of the approach give direct comparisons of oil in water concentration both through a system and in the water exiting. The oil concentration leaving the vessel is reported, thus directly quantifying the effectiveness of the vessel; this is an improvement over other approaches using CFD where flow characteristics are used as proxies to infer the separation effectiveness. In using flow characterisctics alone there is potential for critical aspects or counter-intuitive mechanisms to mislead engineers.\u0000 It is hoped that the method presented will enable engineers and designers involved in the development, design and operation of produced water systems to more-fully understand both the complex fluid mechanics and efficiency of the flotation processes.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90153924","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
A new subsea water treatment system for injection water has been developed and has undergone several phases of testing. A full-scale water treatment module has been built and is currently being tested at the Ekofisk field offshore Norway to determine its viability under North Sea field conditions. A hybrid configuration approach is used, as the test is based on utilizing existing infrastructure to minimize project cost. The subsea water treatment system was therefore installed next to a fixed platform and connected to topsides through a flexible hose for water supply and an umbilical for power and communication of the subsea water treatment module. The disinfected water is lifted to the platform deck through a retrieveable lift pump, and the treated water is then analyzed before injection into the reservoir through a high-pressure pump and converted production well. The primary objective with the test is to replicate the results from a similar full-scale version that was tested in sheltered environments in a fjord on the Norwegian west coast, which would verify the water treatment module's performance and reliability through seasonal variations and thereby demonstrate its ability to deliver injection water of a quality in real offshore conditions. The secondary objective is related to Ekofisk requirements and reservoir related impacts of injecting water treated by this new submerged water treatment technology. The results from this test will not become available until second half of 2019. The commissioning phase has been completed, and the results achieved so far are within expectations, with high disinfection capabilities and equipment regularity. The particle content in the water was generally higher than previous inshore testing, which was not a surprise due to the harsh environment and relatively shallow water (∼70m) in the Ekofisk Area. The project has recently moved into the longterm testing phase. The results from this phase will become available second half of 2019.
{"title":"Subsea Water Treatment Pilot Testing at the Ekofisk Field in the North Sea","authors":"Eirik Dirdal","doi":"10.4043/29552-MS","DOIUrl":"https://doi.org/10.4043/29552-MS","url":null,"abstract":"\u0000 A new subsea water treatment system for injection water has been developed and has undergone several phases of testing. A full-scale water treatment module has been built and is currently being tested at the Ekofisk field offshore Norway to determine its viability under North Sea field conditions.\u0000 A hybrid configuration approach is used, as the test is based on utilizing existing infrastructure to minimize project cost. The subsea water treatment system was therefore installed next to a fixed platform and connected to topsides through a flexible hose for water supply and an umbilical for power and communication of the subsea water treatment module. The disinfected water is lifted to the platform deck through a retrieveable lift pump, and the treated water is then analyzed before injection into the reservoir through a high-pressure pump and converted production well.\u0000 The primary objective with the test is to replicate the results from a similar full-scale version that was tested in sheltered environments in a fjord on the Norwegian west coast, which would verify the water treatment module's performance and reliability through seasonal variations and thereby demonstrate its ability to deliver injection water of a quality in real offshore conditions.\u0000 The secondary objective is related to Ekofisk requirements and reservoir related impacts of injecting water treated by this new submerged water treatment technology. The results from this test will not become available until second half of 2019.\u0000 The commissioning phase has been completed, and the results achieved so far are within expectations, with high disinfection capabilities and equipment regularity. The particle content in the water was generally higher than previous inshore testing, which was not a surprise due to the harsh environment and relatively shallow water (∼70m) in the Ekofisk Area.\u0000 The project has recently moved into the longterm testing phase. The results from this phase will become available second half of 2019.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"68 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88681986","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Floating LNG (FLNG) has led to more compact plant layouts, a move to more modular construction methods, and marinization of traditional land based equipment. These developments have led to advancements in coil wound heat exchanger (CWHE) designs. This includes designing for blast loading, accounting for the fatigue impact of wave induced accelerations, new materials and coating systems for a marine environment, and novel base designs to take advantage of the modular construction. This paper describes these changes and the innovations in design and fabrication that will meet these new requirements and challenges.
{"title":"Design Advancements for FLNG Coil Wound Heat Exchanger Technology","authors":"J. McConville, J. Dally","doi":"10.4043/29248-MS","DOIUrl":"https://doi.org/10.4043/29248-MS","url":null,"abstract":"\u0000 Floating LNG (FLNG) has led to more compact plant layouts, a move to more modular construction methods, and marinization of traditional land based equipment. These developments have led to advancements in coil wound heat exchanger (CWHE) designs. This includes designing for blast loading, accounting for the fatigue impact of wave induced accelerations, new materials and coating systems for a marine environment, and novel base designs to take advantage of the modular construction. This paper describes these changes and the innovations in design and fabrication that will meet these new requirements and challenges.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88712547","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}
C. Monteverde, Marco Novello, Karstein Kristiansen
Over the past few years a specific programme has focused on the development of subsea separators and a subsea water treatment and injection process composed of several modules and requiring a certain amount of new subsea technology (subsea barrier fluid-less water injection pumps, filters, special water analyzers, etc.). One of these technologies is the all-electric subsea control system. The all-electric versus the electro-hydraulic solution was selected for its inherent capability to:enable long step-out distances;run logics such as sequences and fast closed control loops involving subsea proportional valves;handle high frequency of simultaneous valve actuations;implement safety functions, including SIL certified, when required. Within the ongoing industrialization programme of the new technologies, a Joint Development Agreement has been put in place between two partners for the qualification of the open framework platform for the control of subsea processes. The development is pursued according to the API 17N and DNV RP-A203 requirements. The subsea control system is developed according to the approach to interface standardization, which is aimed at guaranteeing:–the interchangeability of modules coming from different vendors;–the reduction of physical interfaces;–the optimization of IMR intervention time. The technology mainly consists of:a qualified basic component platform to be used for project-based assembly;a complete set of tools such as web-server, condition monitoring server, integrated software development environment, etc.;a standard and user-friendly approach for software application development, based on P&ID graphic, in order to facilitate the sharing of software information between contractor and clients;standard industrial communication protocols (no proprietary protocols) accessible to all users, which are designed for easy interfacing of the control system with third party equipment. The JDA activity has concluded the Q1 qualification tests of electronic components and Q2 tests of electronic assemblies, pursuant to API 17F, as well as all the other qualification activities (tests and analyses) relevant to the non-electronic components (e.g. 40kVA subsea electrical transformer), according to the relevant technology qualification plan. Additional software packages have also been developed and successfully tested using the Test Driven Development (TDD) method. The qualification will be completed by Q1 2019 with integration tests of:–Topside Control System;–Subsea Power and Communication Distribution Manager;–Subsea Control Unit. The integration tests will allow to reach TRL 4 of the above subsea equipment, in accordance with API 17N.
{"title":"A New All Electric Subsea Control System Development","authors":"C. Monteverde, Marco Novello, Karstein Kristiansen","doi":"10.4043/29356-MS","DOIUrl":"https://doi.org/10.4043/29356-MS","url":null,"abstract":"\u0000 Over the past few years a specific programme has focused on the development of subsea separators and a subsea water treatment and injection process composed of several modules and requiring a certain amount of new subsea technology (subsea barrier fluid-less water injection pumps, filters, special water analyzers, etc.). One of these technologies is the all-electric subsea control system.\u0000 The all-electric versus the electro-hydraulic solution was selected for its inherent capability to:enable long step-out distances;run logics such as sequences and fast closed control loops involving subsea proportional valves;handle high frequency of simultaneous valve actuations;implement safety functions, including SIL certified, when required.\u0000 Within the ongoing industrialization programme of the new technologies, a Joint Development Agreement has been put in place between two partners for the qualification of the open framework platform for the control of subsea processes.\u0000 The development is pursued according to the API 17N and DNV RP-A203 requirements.\u0000 The subsea control system is developed according to the approach to interface standardization, which is aimed at guaranteeing:–the interchangeability of modules coming from different vendors;–the reduction of physical interfaces;–the optimization of IMR intervention time.\u0000 The technology mainly consists of:a qualified basic component platform to be used for project-based assembly;a complete set of tools such as web-server, condition monitoring server, integrated software development environment, etc.;a standard and user-friendly approach for software application development, based on P&ID graphic, in order to facilitate the sharing of software information between contractor and clients;standard industrial communication protocols (no proprietary protocols) accessible to all users, which are designed for easy interfacing of the control system with third party equipment.\u0000 The JDA activity has concluded the Q1 qualification tests of electronic components and Q2 tests of electronic assemblies, pursuant to API 17F, as well as all the other qualification activities (tests and analyses) relevant to the non-electronic components (e.g. 40kVA subsea electrical transformer), according to the relevant technology qualification plan. Additional software packages have also been developed and successfully tested using the Test Driven Development (TDD) method.\u0000 The qualification will be completed by Q1 2019 with integration tests of:–Topside Control System;–Subsea Power and Communication Distribution Manager;–Subsea Control Unit.\u0000 The integration tests will allow to reach TRL 4 of the above subsea equipment, in accordance with API 17N.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"21 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81330755","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
A fully unmanned surface vessel/remotely operated vehicle (USV/ROV) system—controlled remotely from shore and providing inspection and light intervention services—could deliver many benefits during offshore operations including increased safety, cost effectiveness, and data quality. Development of an unmanned solution also faces many challenges in ensuring the system's fitness for purpose. System developers must address a range of inter-related issues including system reliability; operational risks and mitigations; monitoring and analyzing performance of key hardware system; safety policies; determination of required level of control for the many activities and failsafe functionalities; potential regulatory requirements; and a path to adoption that satisfies all stakeholders. Solutions to the challenges of unmanned operations must consider the operational philosophies, governance policies and risk tolerance of the many stakeholders because acceptance of such solutions are not always straightforward. Many of the component technologies of the unmanned system are available and proven, but new solutions also need to be developed. ROVs piloted from onshore control centers and operations by unmanned surface vessels are not uncommon today. With no personnel on board to resolve problems, reliability must be increased from current levels, failsafe autonomy and increased ROV/USV functionality must be included in the USV/ROV system. The system's design also must provide for safe transfer of people from a manned vessel to the USV in the event that troubleshooting and more extensive maintenance are required. This paper reviews these challenges based on performing a series of traditional analyses: concept of operation reviews defined key operational functions; hazard analyses identified potential failure modes and their respective mitigation; reliability assessments to understand the current level of reliability for USV and ROV systems and requirements for multi-day missions; current and pending regulations were reviewed to identify their impact on technical specifications and operational procedures.
{"title":"Operational Adoption Challenges to USV/ROV Services","authors":"P. Moles, Mathieu Ladreux, L. Karl","doi":"10.4043/29569-MS","DOIUrl":"https://doi.org/10.4043/29569-MS","url":null,"abstract":"\u0000 A fully unmanned surface vessel/remotely operated vehicle (USV/ROV) system—controlled remotely from shore and providing inspection and light intervention services—could deliver many benefits during offshore operations including increased safety, cost effectiveness, and data quality. Development of an unmanned solution also faces many challenges in ensuring the system's fitness for purpose. System developers must address a range of inter-related issues including system reliability; operational risks and mitigations; monitoring and analyzing performance of key hardware system; safety policies; determination of required level of control for the many activities and failsafe functionalities; potential regulatory requirements; and a path to adoption that satisfies all stakeholders.\u0000 Solutions to the challenges of unmanned operations must consider the operational philosophies, governance policies and risk tolerance of the many stakeholders because acceptance of such solutions are not always straightforward. Many of the component technologies of the unmanned system are available and proven, but new solutions also need to be developed. ROVs piloted from onshore control centers and operations by unmanned surface vessels are not uncommon today. With no personnel on board to resolve problems, reliability must be increased from current levels, failsafe autonomy and increased ROV/USV functionality must be included in the USV/ROV system. The system's design also must provide for safe transfer of people from a manned vessel to the USV in the event that troubleshooting and more extensive maintenance are required.\u0000 This paper reviews these challenges based on performing a series of traditional analyses: concept of operation reviews defined key operational functions; hazard analyses identified potential failure modes and their respective mitigation; reliability assessments to understand the current level of reliability for USV and ROV systems and requirements for multi-day missions; current and pending regulations were reviewed to identify their impact on technical specifications and operational procedures.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"10 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90991438","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. Ingebrigtsen, S. Vatland, J. Pretlove, Henning Nesheim
ABB is running a joint project with Equinor, Total and Chevron to develop technologies for subsea power transmission, distribution and conversion. The output will form a critical part of future advanced subsea field developments. Started in 2013, the project reached a major milestone in late 2017 when the first full-scale prototype of the variable speed drive (VSD) passed a shallow water test. Final preparations are now underway for a 3000-hour test of the complete subsea power system with two VSDs in a parallel configuration combined with subsea switchgear and controls. The new solution will ultimately mean operators can free up topside space, or use no topside installation whatsoever, yielding significant cost and safety benefits. It is an extremely challenging endeavour, not only due to the harsh conditions to which the equipment will be subjected, but also because of the considerable reliability required. The equipment, the medium voltage (MV) switchgear, control and low voltage (LV) distribution equipment and the VSDs, must be able to run without intervention for many years. The VSD's successful shallow-water test is the subject of a separate OTC paper; here, we present the highlights in the context of the wider project and particularly the steps taken to build confidence along the way that the proposed solution will be fit for purpose when fully launched. Readers will gain insights into the key steps of this cutting-edge project. These include modifying prototypes of the equipment based on rounds of simulations, laboratory assessments (eg accelerated aging, vibration and shock testing) and water testing. As such an undertaking has never been achieved before, it is a journey with considerable learnings to be shared not only upon completion but also en-route. As we approach the goal which is anticipated by the end of 2019, it is appropriate to begin to share what we have learnt as we have been going the distance.
{"title":"ABB Subsea Power JIP – Going the Distance","authors":"S. Ingebrigtsen, S. Vatland, J. Pretlove, Henning Nesheim","doi":"10.4043/29550-MS","DOIUrl":"https://doi.org/10.4043/29550-MS","url":null,"abstract":"\u0000 ABB is running a joint project with Equinor, Total and Chevron to develop technologies for subsea power transmission, distribution and conversion. The output will form a critical part of future advanced subsea field developments. Started in 2013, the project reached a major milestone in late 2017 when the first full-scale prototype of the variable speed drive (VSD) passed a shallow water test. Final preparations are now underway for a 3000-hour test of the complete subsea power system with two VSDs in a parallel configuration combined with subsea switchgear and controls.\u0000 The new solution will ultimately mean operators can free up topside space, or use no topside installation whatsoever, yielding significant cost and safety benefits. It is an extremely challenging endeavour, not only due to the harsh conditions to which the equipment will be subjected, but also because of the considerable reliability required. The equipment, the medium voltage (MV) switchgear, control and low voltage (LV) distribution equipment and the VSDs, must be able to run without intervention for many years.\u0000 The VSD's successful shallow-water test is the subject of a separate OTC paper; here, we present the highlights in the context of the wider project and particularly the steps taken to build confidence along the way that the proposed solution will be fit for purpose when fully launched. Readers will gain insights into the key steps of this cutting-edge project. These include modifying prototypes of the equipment based on rounds of simulations, laboratory assessments (eg accelerated aging, vibration and shock testing) and water testing.\u0000 As such an undertaking has never been achieved before, it is a journey with considerable learnings to be shared not only upon completion but also en-route. As we approach the goal which is anticipated by the end of 2019, it is appropriate to begin to share what we have learnt as we have been going the distance.","PeriodicalId":10968,"journal":{"name":"Day 3 Wed, May 08, 2019","volume":"91 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83968503","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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