The Beatrice Offshore Wind project comprises the development of 84 number 7MW turbines located in the Moray Firth in the North of Scotland. It is one of the most northerly and exposed sites globally and also the deepest site for fixed foundations for offshore wind. The paper describes the design challenges and how they were addressed. The solutions are likely to be of interest to anyone else developing a deep water offshore wind project, especially with variable soil conditions and a significant water depth range. The Beatrice WTG foundations were completed as an EPCI project with close integration between the EPCI contractor, designer, fabrication and installation teams. Across the site water depths ranged from 35-68m, however, this range was reduced when a small number of outliers were discounted. The final range was 38-55m. There was also a significant variation in soil conditions across the site and this created significant challenges when attempting to standardise the design. Global analysis of the selected structures under wind and wave conditions was performed using Sequential Coupled Analysis (SCA) with BHawC and ANSYS ASAS software packages. The analysis was performed by passing information between the turbine supplier and the substructure designer to produce coupled wind and wave loading on the integrated jacket, WTG and tower system. The jackets are the largest ever designed and installed for offshore wind. The solution developed was a 4 legged pre-piled jacket. The design was split up in to 5 clusters to address the water depth range. Associated with this a pile stick up range of 2-6m was adopted. No scour protection was used. The top half of the jacket, transition piece and much of the secondary steelwork was standardised across the site. The base dimension for the jacket and pile diameter was also standardised across the site to allow for re-use of a pre-piling template. The final foundations were installed in 2018. The grouted connection between the jacket and the pre-piles includes the first application offshore of Masterflow 9800 grout. Control of early age cycling was a key consideration in design of the jacket to pile interface. Piles were designed in accordance with the Imperial College Pile ‘ICP’ effective-stress pile design approaches for offshore foundations.
{"title":"Beatrice Offshore Wind Project, Wind Turbine Generator Foundation Design","authors":"A. MacLeay, T. Hodgson","doi":"10.4043/29500-MS","DOIUrl":"https://doi.org/10.4043/29500-MS","url":null,"abstract":"\u0000 \u0000 \u0000 The Beatrice Offshore Wind project comprises the development of 84 number 7MW turbines located in the Moray Firth in the North of Scotland. It is one of the most northerly and exposed sites globally and also the deepest site for fixed foundations for offshore wind. The paper describes the design challenges and how they were addressed. The solutions are likely to be of interest to anyone else developing a deep water offshore wind project, especially with variable soil conditions and a significant water depth range.\u0000 \u0000 \u0000 \u0000 The Beatrice WTG foundations were completed as an EPCI project with close integration between the EPCI contractor, designer, fabrication and installation teams. Across the site water depths ranged from 35-68m, however, this range was reduced when a small number of outliers were discounted. The final range was 38-55m. There was also a significant variation in soil conditions across the site and this created significant challenges when attempting to standardise the design.\u0000 Global analysis of the selected structures under wind and wave conditions was performed using Sequential Coupled Analysis (SCA) with BHawC and ANSYS ASAS software packages. The analysis was performed by passing information between the turbine supplier and the substructure designer to produce coupled wind and wave loading on the integrated jacket, WTG and tower system.\u0000 \u0000 \u0000 \u0000 The jackets are the largest ever designed and installed for offshore wind. The solution developed was a 4 legged pre-piled jacket. The design was split up in to 5 clusters to address the water depth range. Associated with this a pile stick up range of 2-6m was adopted. No scour protection was used.\u0000 The top half of the jacket, transition piece and much of the secondary steelwork was standardised across the site. The base dimension for the jacket and pile diameter was also standardised across the site to allow for re-use of a pre-piling template.\u0000 The final foundations were installed in 2018.\u0000 \u0000 \u0000 \u0000 The grouted connection between the jacket and the pre-piles includes the first application offshore of Masterflow 9800 grout.\u0000 Control of early age cycling was a key consideration in design of the jacket to pile interface.\u0000 Piles were designed in accordance with the Imperial College Pile ‘ICP’ effective-stress pile design approaches for offshore foundations.\u0000","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"31 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90670132","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}
Tor Christensen, Stig Arne Witsøe, Helge Hagen, H. Haslum
This paper describes the overall project execution of the Aasta Hansteen field development. The Aasta Hansteen Field development in 1300m water depth is the deepest field developed on the Norwegian Continental Shelf (NCS). The field is located north of the Arctic circle, in harsh environment, 300km off the coast of Northern Norway, with no other offshore installations in the area. The Aasta Hansteen field is developed with a floating Spar FPSO, using steel catenary risers and polyester mooring lines. The Aasta Hansteen platform will serve as a hub for future discoveries and field developments in the area. The rich gas is exported through a 482km long 36" pipeline (Polarled) to an onshore processing plant at Nyhamna for further processing to sales gas. From there the gas is exported to the European market. Stabilized condensate is stored in the Spar FPSO and offloaded to shuttle tankers.
{"title":"Aasta Hansteen Spar FPSO - A Pioneer in Norwegian Deepwater","authors":"Tor Christensen, Stig Arne Witsøe, Helge Hagen, H. Haslum","doi":"10.4043/29222-MS","DOIUrl":"https://doi.org/10.4043/29222-MS","url":null,"abstract":"\u0000 This paper describes the overall project execution of the Aasta Hansteen field development.\u0000 The Aasta Hansteen Field development in 1300m water depth is the deepest field developed on the Norwegian Continental Shelf (NCS). The field is located north of the Arctic circle, in harsh environment, 300km off the coast of Northern Norway, with no other offshore installations in the area.\u0000 The Aasta Hansteen field is developed with a floating Spar FPSO, using steel catenary risers and polyester mooring lines. The Aasta Hansteen platform will serve as a hub for future discoveries and field developments in the area.\u0000 The rich gas is exported through a 482km long 36\" pipeline (Polarled) to an onshore processing plant at Nyhamna for further processing to sales gas. From there the gas is exported to the European market. Stabilized condensate is stored in the Spar FPSO and offloaded to shuttle tankers.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"7 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84287079","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}
During the 1970s, the Oil and Gas (O&G) offshore industry undertook the first few projects that exploited oil fields by using a tanker-ship as a hull to host its process plant and store the produced oil. Both the Shell project in the Castellon field in Spain and the Petrobras project in the Garoupa field in Brazil are considered pioneers of the Floating Production Storage and Offloading (FPSO) concept. The FPSO concept has many inherent advantages when compared to other types of floating facilities. However, the concept did not immediately become a preferable option for operators around the world. Throughout the 1980s, the industry did not experience a significant increase of FPSO-type projects. During this time, there was a clear preference for non-FPSO floating production units, despite the need for additional storage and a continuous export system. Additionally, port administrations treated all ship-shaped production units, including FPSOs, as tanker-ships. As such, they had to be compliant with International Maritime Organization (IMO) tanker requirements. This classification made it difficult to use FPSOs as permanent solutions to exploit offshore oil and gas fields. The IMO tanker requirements mandated that FPSOs could not stay on location longer than 3 years, although a 1-2 year extension could be granted, depending on inspections and other operational requirements. These requirements were enforced even if the operators and FPSO contractors designed the FPSO for a longer life. This paper describes the first steps, both regulatory and standardization of technical design requirements, in the approval process related to FPSO use for oil and gas fields. The paper describes how the United States (US) Environmental Impact Statement (EIS), and other initiatives between 1999 and 2001, paved the way for the US acceptance of FPSOs. Finally, the paper explains why the first FPSO in the US Gulf of Mexico (GoM) had a moored, single point, internal turret with a planned disconnection system as opposed to other design options that were evaluated and rejected.
{"title":"From Tanker-Ships to the First FPSO in the US GoM","authors":"C. Mastrangelo, C. M. Lan, Charles E. Smith","doi":"10.4043/29421-MS","DOIUrl":"https://doi.org/10.4043/29421-MS","url":null,"abstract":"\u0000 During the 1970s, the Oil and Gas (O&G) offshore industry undertook the first few projects that exploited oil fields by using a tanker-ship as a hull to host its process plant and store the produced oil. Both the Shell project in the Castellon field in Spain and the Petrobras project in the Garoupa field in Brazil are considered pioneers of the Floating Production Storage and Offloading (FPSO) concept. The FPSO concept has many inherent advantages when compared to other types of floating facilities. However, the concept did not immediately become a preferable option for operators around the world. Throughout the 1980s, the industry did not experience a significant increase of FPSO-type projects. During this time, there was a clear preference for non-FPSO floating production units, despite the need for additional storage and a continuous export system. Additionally, port administrations treated all ship-shaped production units, including FPSOs, as tanker-ships. As such, they had to be compliant with International Maritime Organization (IMO) tanker requirements. This classification made it difficult to use FPSOs as permanent solutions to exploit offshore oil and gas fields. The IMO tanker requirements mandated that FPSOs could not stay on location longer than 3 years, although a 1-2 year extension could be granted, depending on inspections and other operational requirements. These requirements were enforced even if the operators and FPSO contractors designed the FPSO for a longer life. This paper describes the first steps, both regulatory and standardization of technical design requirements, in the approval process related to FPSO use for oil and gas fields. The paper describes how the United States (US) Environmental Impact Statement (EIS), and other initiatives between 1999 and 2001, paved the way for the US acceptance of FPSOs. Finally, the paper explains why the first FPSO in the US Gulf of Mexico (GoM) had a moored, single point, internal turret with a planned disconnection system as opposed to other design options that were evaluated and rejected.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"65 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83454263","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. Mulunjkar, A. P. Deshpande, Stephen Claude Steinke, B. Chartier, Kuwertz Luke Alexander
Schlumberger, one of the world’s leading suppliers of oilfield technology, is a measurement and data-driven company that collects massive amounts of data in the course of its daily operations. These data, diverse in nature, are collected for use in various business and technical workflows. The data can be downhole, surface, post-analysis, and support functions from manufacturing, maintenance, asset management, and finance. Analysis of this Big Data has the potential to drive a step change in operational performance across multiple dimensions. However, accomplishing this step change is not easy to accomplish because often, the data are not well structured and are scattered across individual business systems that do not communicate well with each other. Most of the analysis of these scattered data occurs on a point basis, requiring the significant involvement of various experts and complex time-consuming manipulations. The results are short lived in that they cannot be tracked in real time and the effort expended is not applicable to other data sets or problems. Increasing data volumes, data diversity, and demand from engineers to record multiple new data attributes during the product or technology life cycle further limits the benefits of such a spot analytics process, with potentially severe impacts on the business due to inadequate decision support or missed opportunities. This paper presents a developmental model and change processes, challenges faced and resolution approaches leading to digital transformation, and finally, the resulting value creation through building data visualizations and comprehensible decision-making tools. Once the initial high-value data sets and visualizations are identified, automation opportunities can be exploited. These data sets become the foundation for predictive analysis and machine learning through artificial intelligence (AI) and Internet of things (IoT) to further influence product performance and development in support of customer needs.
{"title":"Operational Excellence and Product Reliability Enhancement Through Big Data Analytics","authors":"A. Mulunjkar, A. P. Deshpande, Stephen Claude Steinke, B. Chartier, Kuwertz Luke Alexander","doi":"10.4043/29513-MS","DOIUrl":"https://doi.org/10.4043/29513-MS","url":null,"abstract":"\u0000 Schlumberger, one of the world’s leading suppliers of oilfield technology, is a measurement and data-driven company that collects massive amounts of data in the course of its daily operations. These data, diverse in nature, are collected for use in various business and technical workflows. The data can be downhole, surface, post-analysis, and support functions from manufacturing, maintenance, asset management, and finance. Analysis of this Big Data has the potential to drive a step change in operational performance across multiple dimensions. However, accomplishing this step change is not easy to accomplish because often, the data are not well structured and are scattered across individual business systems that do not communicate well with each other. Most of the analysis of these scattered data occurs on a point basis, requiring the significant involvement of various experts and complex time-consuming manipulations. The results are short lived in that they cannot be tracked in real time and the effort expended is not applicable to other data sets or problems. Increasing data volumes, data diversity, and demand from engineers to record multiple new data attributes during the product or technology life cycle further limits the benefits of such a spot analytics process, with potentially severe impacts on the business due to inadequate decision support or missed opportunities.\u0000 This paper presents a developmental model and change processes, challenges faced and resolution approaches leading to digital transformation, and finally, the resulting value creation through building data visualizations and comprehensible decision-making tools.\u0000 Once the initial high-value data sets and visualizations are identified, automation opportunities can be exploited. These data sets become the foundation for predictive analysis and machine learning through artificial intelligence (AI) and Internet of things (IoT) to further influence product performance and development in support of customer needs.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"12 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79548657","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}
Manuel Parente, Mark Stevens, J. Ferreira, Rafael O Simão, Mariana Dionisio
Recent advances have made it possible to include augmented reality (AR) technology in the subsea intervention process to overcome problems commonly encountered during remotely operated vehicle (ROV) operations in deep water. Newly developed AR technology uses a state-of-the-art 3D engine to accurately model subsea assets and a geographic information system (GIS) to precisely determine the relative location of assets in the field, creating a virtual 3D visualization of the subsea facilities. ROV operations are enhanced by superimposing the virtual environment onto the live feed of the ROV's pilot camera. Merging real-time camera images with AR and other data streams augments visibility, improves safety, increases efficiency, and reduces overall costs. The use of AR technology for subsea operations is enabled by advanced software to digitalize subsea assets, cloud computing to run applications and store data, satellite communications to link offshore operations to onshore decision-makers, command centers that support remote operations, and simulation techniques for pre-job planning and ROV pilot training. Since testing began in 2015, the AR-enhanced process has been applied in deepwater fields in the Gulf of Mexico and North Sea. Looking ahead, it is expected that the experience using AR and structured data sets for improved subsea activity will lead to fully autonomous operations controlled by artificial intelligence to achieve project objectives with lower risk and greater efficiency.
{"title":"Subsea Digitalization: From the Virtual World into the Real World—Using Augmented Reality in Offshore Operations","authors":"Manuel Parente, Mark Stevens, J. Ferreira, Rafael O Simão, Mariana Dionisio","doi":"10.4043/29312-MS","DOIUrl":"https://doi.org/10.4043/29312-MS","url":null,"abstract":"\u0000 Recent advances have made it possible to include augmented reality (AR) technology in the subsea intervention process to overcome problems commonly encountered during remotely operated vehicle (ROV) operations in deep water. Newly developed AR technology uses a state-of-the-art 3D engine to accurately model subsea assets and a geographic information system (GIS) to precisely determine the relative location of assets in the field, creating a virtual 3D visualization of the subsea facilities.\u0000 ROV operations are enhanced by superimposing the virtual environment onto the live feed of the ROV's pilot camera. Merging real-time camera images with AR and other data streams augments visibility, improves safety, increases efficiency, and reduces overall costs.\u0000 The use of AR technology for subsea operations is enabled by advanced software to digitalize subsea assets, cloud computing to run applications and store data, satellite communications to link offshore operations to onshore decision-makers, command centers that support remote operations, and simulation techniques for pre-job planning and ROV pilot training.\u0000 Since testing began in 2015, the AR-enhanced process has been applied in deepwater fields in the Gulf of Mexico and North Sea.\u0000 Looking ahead, it is expected that the experience using AR and structured data sets for improved subsea activity will lead to fully autonomous operations controlled by artificial intelligence to achieve project objectives with lower risk and greater efficiency.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"82 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74956858","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}
D. Edelson, Manoj Jegannathan, T. Harris, Basil Theckumpurath, Henning Selstad, Bjørn Krokeide, Morten Person
This paper presents the overview of the Pre-Service operations for the Aasta Hansteen field development. The paper also covers the execution challenges, supporting engineering and procedures followed for the various activities. The Aasta Hansteen Field development at a water depth of 1300m is the deepest field on the Norwegian Continental Shelf (NCS). The field is remotely located north of the Arctic Circle, in a particularly harsh environment 300km off the coast of Northern Norway, with 140km to the closest offshore installation. In the past, the pre-service marine operations for Spar platforms were completed at the offshore field locations. The Aasta Hansteen development presented the opportunity to complete the entire pre-service operations in the sheltered waters of the deep Norwegian fjords, making it a unique, first-of-a-kind inshore pre-service operations for a Spar platform ever executed. This advantage also helped to significantly reduce the cost and complexity of the pre-service operations effort for the project. There were several firsts in the industry for the Aasta Hansteen Spar platform, namely; Largest and heaviest Spar delivered, First Spar in Norwegian waters and subject to Norwegian rules, first full pre-service scope inshore in a fjord, first requirement for Structural Tank Inspection on a Spar Hull, first requirement for a Submergence Test, largest topside catamaran mating at 22,500 Te. Many of these firsts heavily influenced the planning and execution of the Pre-Service Operations for this project. The significance of these are also highlighted in this paper.
{"title":"Aasta Hansteen Spar Inshore Pre-Service Operations","authors":"D. Edelson, Manoj Jegannathan, T. Harris, Basil Theckumpurath, Henning Selstad, Bjørn Krokeide, Morten Person","doi":"10.4043/29539-MS","DOIUrl":"https://doi.org/10.4043/29539-MS","url":null,"abstract":"\u0000 This paper presents the overview of the Pre-Service operations for the Aasta Hansteen field development. The paper also covers the execution challenges, supporting engineering and procedures followed for the various activities.\u0000 The Aasta Hansteen Field development at a water depth of 1300m is the deepest field on the Norwegian Continental Shelf (NCS). The field is remotely located north of the Arctic Circle, in a particularly harsh environment 300km off the coast of Northern Norway, with 140km to the closest offshore installation.\u0000 In the past, the pre-service marine operations for Spar platforms were completed at the offshore field locations. The Aasta Hansteen development presented the opportunity to complete the entire pre-service operations in the sheltered waters of the deep Norwegian fjords, making it a unique, first-of-a-kind inshore pre-service operations for a Spar platform ever executed. This advantage also helped to significantly reduce the cost and complexity of the pre-service operations effort for the project.\u0000 There were several firsts in the industry for the Aasta Hansteen Spar platform, namely; Largest and heaviest Spar delivered, First Spar in Norwegian waters and subject to Norwegian rules, first full pre-service scope inshore in a fjord, first requirement for Structural Tank Inspection on a Spar Hull, first requirement for a Submergence Test, largest topside catamaran mating at 22,500 Te. Many of these firsts heavily influenced the planning and execution of the Pre-Service Operations for this project. The significance of these are also highlighted in this paper.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"12 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77500791","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}
Previous research indicated that interconnecting offshore platforms in the Gulf of Mexico with wind energy and the onshore grid can provide significant advantages. This research considered groups of offshore wind turbines as energy hubs to provide electricity to nearby offshore platforms, including the evaluation of energy deficits caused by wind wakes. The proposed research idea allows platforms to improve energy efficiency, save fuel, reduce air pollution, and increase income by selling surplus energy. The energy output of these wind turbines was estimated considering wake effects. Diverse layouts were modeled applying meteorological and geographical data integrated with wind wake models to solve a realistic wind farm layout optimization problem. The research created a methodology to optimize a group of offshore wind turbines performance in the Gulf of Mexico, minimizing negative interference while maximizing power output. Results indicated that an important number of locations of offshore oil and gas platforms were able to provide adequate levels of wind energy. Variable wind directions cause changes on the behavior of the turbulent wakes. Therefore, the layout of wind turbines needs to be optimized to minimize negative interaction while maximizing power output under different wind conditions. Furthermore, the analysis revealed the feasibility of installing, in particular optimal locations, wind farms that would simultaneously serve several offshore platforms in close proximity (as hubs) while the system remains connected to the onshore grid.
{"title":"Feasibility Analysis on Using a Group of Wind Turbines as a Hub to Supply Electricity to Offshore Oil and Gas Platforms in the Gulf of Mexico","authors":"Francisco Haces-Fernandez, Hua Li, David Ramirez","doi":"10.4043/29580-MS","DOIUrl":"https://doi.org/10.4043/29580-MS","url":null,"abstract":"\u0000 Previous research indicated that interconnecting offshore platforms in the Gulf of Mexico with wind energy and the onshore grid can provide significant advantages. This research considered groups of offshore wind turbines as energy hubs to provide electricity to nearby offshore platforms, including the evaluation of energy deficits caused by wind wakes. The proposed research idea allows platforms to improve energy efficiency, save fuel, reduce air pollution, and increase income by selling surplus energy. The energy output of these wind turbines was estimated considering wake effects. Diverse layouts were modeled applying meteorological and geographical data integrated with wind wake models to solve a realistic wind farm layout optimization problem. The research created a methodology to optimize a group of offshore wind turbines performance in the Gulf of Mexico, minimizing negative interference while maximizing power output. Results indicated that an important number of locations of offshore oil and gas platforms were able to provide adequate levels of wind energy. Variable wind directions cause changes on the behavior of the turbulent wakes. Therefore, the layout of wind turbines needs to be optimized to minimize negative interaction while maximizing power output under different wind conditions. Furthermore, the analysis revealed the feasibility of installing, in particular optimal locations, wind farms that would simultaneously serve several offshore platforms in close proximity (as hubs) while the system remains connected to the onshore grid.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"7 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87116052","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
R. G. Pestana, Vinicius Sales Rocha, D. Braga, Eric Ribeiro Oliveira
This paper presents the technical analysis, simulation and work carried out in planning and executing an open sea workover riser operation for decommissioning a well from a dynamically positioned (DP) vessel in shallow waters, on southeastern Brazil. The main challenge in using a DP rig in this situation is the risk of thruster blackout, resuling in a driftoff scenario. In shallow waters, the system safe allowable vessel driftoff is usually strict, resulting in tight Red Alarm Offsets or even making the operation unfeasible. Real time monitoring and analysis may be used to obtain dynamic optimized Red Alarm Offsets during an operation, but simulations must be performed for operational planning. Statistical treatment of a database of measured and simulated metocean conditions led to reduced environmental loadcases than usually considered in standard industry analysis, while retaining an acceptable safety level. Modification of the riser control system also resulted in reduced Emergency Disconnection Sequence (EDS) time, resulting in broader Red Alarm Offset results. The methodology herein presented may be refined even further, in order to make possible the use of DP vessels in even shallower water scenarios.
{"title":"Well Intervention in Shallow Waters with Dynamically Positioned Vessels: A Study Case for Southeastern Brazil","authors":"R. G. Pestana, Vinicius Sales Rocha, D. Braga, Eric Ribeiro Oliveira","doi":"10.4043/29478-MS","DOIUrl":"https://doi.org/10.4043/29478-MS","url":null,"abstract":"\u0000 This paper presents the technical analysis, simulation and work carried out in planning and executing an open sea workover riser operation for decommissioning a well from a dynamically positioned (DP) vessel in shallow waters, on southeastern Brazil. The main challenge in using a DP rig in this situation is the risk of thruster blackout, resuling in a driftoff scenario. In shallow waters, the system safe allowable vessel driftoff is usually strict, resulting in tight Red Alarm Offsets or even making the operation unfeasible. Real time monitoring and analysis may be used to obtain dynamic optimized Red Alarm Offsets during an operation, but simulations must be performed for operational planning. Statistical treatment of a database of measured and simulated metocean conditions led to reduced environmental loadcases than usually considered in standard industry analysis, while retaining an acceptable safety level. Modification of the riser control system also resulted in reduced Emergency Disconnection Sequence (EDS) time, resulting in broader Red Alarm Offset results. The methodology herein presented may be refined even further, in order to make possible the use of DP vessels in even shallower water scenarios.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 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":"85885941","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}
Tom Erik Henriksen, Kenneth Aarset, Helge Bråthen Myrvang, H. Haslum, Rolf Morten Nes
This paper describes the offshore marine operations for the Aasta Hansteen field development. The Aasta Hansteen Field development at a water depth of 1300m is the deepest field on the Norwegian Continental Shelf (NCS). The field is remotely located north of the Arctic Circle, in a particularly harsh environment 300km off the coast of Northern Norway, with 140km to the closest offshore installation. For further details regarding the field development, reference is made to (Christensen T.; 2019). The field consists of a subsea production system producing gas and condensate through steel catenary risers (SCR) connected to a Truss Spar FPSO, and a gas export SCR and pipeline transporting the gas to the onshore plant at Nyhamna at the west coast of Norway. This paper will present key aspects and success criteria’s important for the planning, design and execution of the Aasta Hansteen marine operations.
{"title":"Aasta Hansteen Offshore Marine Operations – Deep, Remote and Harsh","authors":"Tom Erik Henriksen, Kenneth Aarset, Helge Bråthen Myrvang, H. Haslum, Rolf Morten Nes","doi":"10.4043/29350-MS","DOIUrl":"https://doi.org/10.4043/29350-MS","url":null,"abstract":"\u0000 This paper describes the offshore marine operations for the Aasta Hansteen field development.\u0000 The Aasta Hansteen Field development at a water depth of 1300m is the deepest field on the Norwegian Continental Shelf (NCS). The field is remotely located north of the Arctic Circle, in a particularly harsh environment 300km off the coast of Northern Norway, with 140km to the closest offshore installation. For further details regarding the field development, reference is made to (Christensen T.; 2019).\u0000 The field consists of a subsea production system producing gas and condensate through steel catenary risers (SCR) connected to a Truss Spar FPSO, and a gas export SCR and pipeline transporting the gas to the onshore plant at Nyhamna at the west coast of Norway.\u0000 This paper will present key aspects and success criteria’s important for the planning, design and execution of the Aasta Hansteen marine operations.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 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":"86092853","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}
Results of a pilot project conducted in partnership with the American Petroleum Institute (API) and the International Council on Systems Engineering (INCOSE) are presented. The pilot examines potential business efficiencies and compliance improvements from the implementation of a structured data approach to the management and verification of requirements specified in API standards. It further explores an approach for developing digital requirements from published standards owned and maintained by international Standards Development Organizations (SDOs). SDOs create and maintain their standards based on a process which relies on consensus from technical experts throughout the world. This process encourages wide spread adoption resulting in improvements to both safety and reliability across the applicable industry. The project explored approaches to guide technical consensus committees in the structure and realization of their standards such that they more directly support the digital transformation.
{"title":"Systems Engineering and Industry Standards in the Age of Digital Technology","authors":"R. McAfoos, K. Stout, Rey Climacosa","doi":"10.4043/29305-MS","DOIUrl":"https://doi.org/10.4043/29305-MS","url":null,"abstract":"\u0000 Results of a pilot project conducted in partnership with the American Petroleum Institute (API) and the International Council on Systems Engineering (INCOSE) are presented. The pilot examines potential business efficiencies and compliance improvements from the implementation of a structured data approach to the management and verification of requirements specified in API standards. It further explores an approach for developing digital requirements from published standards owned and maintained by international Standards Development Organizations (SDOs). SDOs create and maintain their standards based on a process which relies on consensus from technical experts throughout the world. This process encourages wide spread adoption resulting in improvements to both safety and reliability across the applicable industry. The project explored approaches to guide technical consensus committees in the structure and realization of their standards such that they more directly support the digital transformation.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"23 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90072194","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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