A. Sablok, J. Kim, S. Tallavajhula, Feng Wang, Oddgeir Dalane, Aronsen Kristoffer Høyem, J. Kippenes
Aasta Hansteen, located in 1300m water depth, is the first deep water field on the Norwegian continental shelf developed with a surface platform concept. It is in the Norwegian Sea and developed using a Truss Spar FPSO. It is the world's largest Spar platform substructure facilitated for continuous personnel entrance and with a large volume of condensate storage in the hull that is offloaded to a shuttle tanker. It is the first floating platform in a North Sea/Norwegian Sea harsh environment with steel catenary risers (SCR). It is the first Spar designed to NORSOK and other Norwegian regulations. The platform was made ready with platform mooring chain and topsides installed by floatover in a fjord before being towed vertically to the field.
Aasta Hansteen位于1300米水深，是挪威大陆架上第一个采用水面平台概念开发的深水油田。它位于挪威海，使用Truss Spar FPSO进行开发。它是世界上最大的Spar平台下部结构，便于人员连续进入，并且船体内有大量凝析油储存，可以卸载到穿梭油轮上。这是北海/挪威海恶劣环境中第一个采用钢制悬链管(SCR)的浮式平台。这是第一个按照NORSOK和其他挪威法规设计的Spar。在垂直拖曳到现场之前，平台系泊链和顶部组件通过浮船安装在峡湾中。
{"title":"Aasta Hansteen Spar FPSO Substructure, Mooring, Riser and Systems Design","authors":"A. Sablok, J. Kim, S. Tallavajhula, Feng Wang, Oddgeir Dalane, Aronsen Kristoffer Høyem, J. Kippenes","doi":"10.4043/29555-MS","DOIUrl":"https://doi.org/10.4043/29555-MS","url":null,"abstract":"\u0000 Aasta Hansteen, located in 1300m water depth, is the first deep water field on the Norwegian continental shelf developed with a surface platform concept. It is in the Norwegian Sea and developed using a Truss Spar FPSO. It is the world's largest Spar platform substructure facilitated for continuous personnel entrance and with a large volume of condensate storage in the hull that is offloaded to a shuttle tanker. It is the first floating platform in a North Sea/Norwegian Sea harsh environment with steel catenary risers (SCR). It is the first Spar designed to NORSOK and other Norwegian regulations. The platform was made ready with platform mooring chain and topsides installed by floatover in a fjord before being towed vertically to the field.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79169025","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}
Digitalization in the energy industry will substantially change engineering functions in the coming years and affect work on both capital projects and operating facilities. The focus of digitalization is not merely on the digital transformation, but on the use of digital technologies to create more value in core businesses while building the appropriate organizational capability and mindset. Underpinning use of digital technologies is the move to data-centric ways of working. This paper examines the preliminary challenges experienced in the move to data-centric ways of working and covers examples in three areas: People, Process and Technology. Organizations have been digitizing for decades, but the digital revolution is only just beginning. There is mounting evidence that we are approaching a tipping point in the exponential advance of digital technology. However, the foundations on which these aspirations have been built are not that robust. The paper will focus on foundational aspects of the journey that, if done right, can accelerate the value capture of digitalization. The following are some of the example issues covered in the paper in each area: People: Restructuring organizational competencies, cultural change management and recognition and management of the generational continuum associated with the workforce. Process: Complexity of project delivery across multiple organizations in the supply chain, the move from documents to data, and impact on business models that deliver document-based content. Technology: Data standards and handover or transfer protocols, federated data repositories, plug-and-play tool integration and tool agnostic IT solutions. The conclusion is a call-to-arms directed at the entire energy Industry, i.e., operators, EPCs, suppliers, construction firms, regulators, standards bodies, etc. to collaborate and set a robust foundation that is data-centric to accelerate the digitalization revolution.
{"title":"Overcoming Hurdles to Accelerate Data-Centric Ways of Working in the Energy Industry","authors":"B. Anand, K. Krishna","doi":"10.4043/29446-MS","DOIUrl":"https://doi.org/10.4043/29446-MS","url":null,"abstract":"\u0000 Digitalization in the energy industry will substantially change engineering functions in the coming years and affect work on both capital projects and operating facilities. The focus of digitalization is not merely on the digital transformation, but on the use of digital technologies to create more value in core businesses while building the appropriate organizational capability and mindset. Underpinning use of digital technologies is the move to data-centric ways of working. This paper examines the preliminary challenges experienced in the move to data-centric ways of working and covers examples in three areas: People, Process and Technology.\u0000 Organizations have been digitizing for decades, but the digital revolution is only just beginning. There is mounting evidence that we are approaching a tipping point in the exponential advance of digital technology. However, the foundations on which these aspirations have been built are not that robust. The paper will focus on foundational aspects of the journey that, if done right, can accelerate the value capture of digitalization.\u0000 The following are some of the example issues covered in the paper in each area:\u0000 People: Restructuring organizational competencies, cultural change management and recognition and management of the generational continuum associated with the workforce.\u0000 Process: Complexity of project delivery across multiple organizations in the supply chain, the move from documents to data, and impact on business models that deliver document-based content.\u0000 Technology: Data standards and handover or transfer protocols, federated data repositories, plug-and-play tool integration and tool agnostic IT solutions.\u0000 The conclusion is a call-to-arms directed at the entire energy Industry, i.e., operators, EPCs, suppliers, construction firms, regulators, standards bodies, etc. to collaborate and set a robust foundation that is data-centric to accelerate the digitalization revolution.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84397121","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
This paper describes the fabrication of the world' largest and most complex Truss Spar Platform, Aasta Hansteen, built for the Norwegian Continental Shelf (NCS) to be operated by Equinor. It was built according to NORSOK standard, Norwegian governing laws and regulations and other Company requirements. Hyundai Heavy Industries (HHI) was awarded an EPC Contract (Engineering, Procurement, and Construction) for the Topside of Spar Platform, and HHI and TechnipFMC formed a Consortium responsible for the overall delivery of the Spar Hull. TechnipFMC was responsible for the design, engineering and equipment procurement, whereas HHI was responsible for Fabrication and delivery. This paper addresses the characteristics of the design of Aasta Hansteen Spar Platform and highlights critical aspects of the Construction Method of Spar Hull at HHI's offshore yard in Ulsan, Korea.
{"title":"Aasta Hansteen Spar and Topside Fabrication","authors":"Dong Hyub Kim, Lars Cato Seberg, Stig Arne Witsøe","doi":"10.4043/29645-MS","DOIUrl":"https://doi.org/10.4043/29645-MS","url":null,"abstract":"\u0000 This paper describes the fabrication of the world' largest and most complex Truss Spar Platform, Aasta Hansteen, built for the Norwegian Continental Shelf (NCS) to be operated by Equinor. It was built according to NORSOK standard, Norwegian governing laws and regulations and other Company requirements.\u0000 Hyundai Heavy Industries (HHI) was awarded an EPC Contract (Engineering, Procurement, and Construction) for the Topside of Spar Platform, and HHI and TechnipFMC formed a Consortium responsible for the overall delivery of the Spar Hull. TechnipFMC was responsible for the design, engineering and equipment procurement, whereas HHI was responsible for Fabrication and delivery.\u0000 This paper addresses the characteristics of the design of Aasta Hansteen Spar Platform and highlights critical aspects of the Construction Method of Spar Hull at HHI's offshore yard in Ulsan, Korea.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85479153","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}
Irina Cortizo, T. Hodgson, Tom Hiorns, David Aqui, L. Jones
There are multiple stakeholders involved in the successful development of offshore wind farm projects. There are also numerous datasets that evolve along the lifecycle of the project. Understanding how all the components of a wind farm act on each other before costs are committed can reduce overall costs and timescales and produce an optimized development. This paper will describe an innovative offshore wind farm optimization approach that evaluates various development concepts to provide indicative farm design and comparative levelized cost of energy (LCOE). A digital approach has been developed to evaluate the influence of various attributes to provide indicative farm design and comparative LCOE. The optimization goal can be tailored to suit developer's preferences such as minimizing LCOE, efficient use of upfront capital expenditure (CAPEX), and development planning / phasing amongst others. This enables information such as farm layout and array spacing or identifying the optimal substructure type across a field to be determined. Input attributes such as water depth, ground conditions, wind resource, and distance from prospective grid interconnection are considered during the optimization approach. It can also consider lease financing such as royalties for unused lease area. The proposed approach can be used to inform decisions such as the capacity of the turbines to be used and overall reduce project development risk. Typical results will be shown demonstrating the power of the holistic optimization. Wind farm CAPEX, Operational Expenditure (OPEX) and LCOE tend to increase for sites that are more distant from shore, are in deeper water, or have less favorable ground conditions. The shape of the available site can also affect CAPEX and LCOE. The relationship between LCOE, CAPEX and array spacing can be inconsistent between various sites. The reductions in LCOE and CAPEX are greatly influenced by parameters such as wind resource, the bathymetry and shape of each site. Typically increasing wind farm capacity tends to improve LCOE due to economies in scale as site wide costs (permitting, design, mobilization, etc.) are distributed over more turbines counteracting detrimental effects associated with increasing farm footprints extending further offshore. LCOE reduces as turbine capacity increases within a competitive supply chain. This levels off as supply and demand diverges for turbines that require specialist providers in the supply chain. The substructures required to support the larger turbines often need some innovation which can introduce technical risks. An offshore wind farm optimization approach utilizes data from many components of a wind farm. The ability to process this efficiently enables developers to explore many configurations using various sensitivity studies. The approach is implemented through deep optimization technology, simulation and modeling methodologies to deal with high system complexity and constantly expandi
{"title":"Holistic Offshore Wind Farm Optimization Approach","authors":"Irina Cortizo, T. Hodgson, Tom Hiorns, David Aqui, L. Jones","doi":"10.4043/29241-MS","DOIUrl":"https://doi.org/10.4043/29241-MS","url":null,"abstract":"\u0000 There are multiple stakeholders involved in the successful development of offshore wind farm projects. There are also numerous datasets that evolve along the lifecycle of the project. Understanding how all the components of a wind farm act on each other before costs are committed can reduce overall costs and timescales and produce an optimized development.\u0000 This paper will describe an innovative offshore wind farm optimization approach that evaluates various development concepts to provide indicative farm design and comparative levelized cost of energy (LCOE).\u0000 A digital approach has been developed to evaluate the influence of various attributes to provide indicative farm design and comparative LCOE. The optimization goal can be tailored to suit developer's preferences such as minimizing LCOE, efficient use of upfront capital expenditure (CAPEX), and development planning / phasing amongst others.\u0000 This enables information such as farm layout and array spacing or identifying the optimal substructure type across a field to be determined. Input attributes such as water depth, ground conditions, wind resource, and distance from prospective grid interconnection are considered during the optimization approach. It can also consider lease financing such as royalties for unused lease area. The proposed approach can be used to inform decisions such as the capacity of the turbines to be used and overall reduce project development risk.\u0000 Typical results will be shown demonstrating the power of the holistic optimization.\u0000 Wind farm CAPEX, Operational Expenditure (OPEX) and LCOE tend to increase for sites that are more distant from shore, are in deeper water, or have less favorable ground conditions. The shape of the available site can also affect CAPEX and LCOE.\u0000 The relationship between LCOE, CAPEX and array spacing can be inconsistent between various sites. The reductions in LCOE and CAPEX are greatly influenced by parameters such as wind resource, the bathymetry and shape of each site.\u0000 Typically increasing wind farm capacity tends to improve LCOE due to economies in scale as site wide costs (permitting, design, mobilization, etc.) are distributed over more turbines counteracting detrimental effects associated with increasing farm footprints extending further offshore.\u0000 LCOE reduces as turbine capacity increases within a competitive supply chain. This levels off as supply and demand diverges for turbines that require specialist providers in the supply chain. The substructures required to support the larger turbines often need some innovation which can introduce technical risks.\u0000 An offshore wind farm optimization approach utilizes data from many components of a wind farm. The ability to process this efficiently enables developers to explore many configurations using various sensitivity studies. The approach is implemented through deep optimization technology, simulation and modeling methodologies to deal with high system complexity and constantly expandi","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81133334","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}
Technology has transformed the energy industry over the last 60 years. It has made processes more efficient, employees more productive and crucially, it has improved the safety of both workers and facilities. In a mature industry, such as oil and gas, operators and owners are faced with the challenge of safely and efficiently managing their ageing plant and assets. This challenge is compounded by poor historic records and information, and the potential loss of knowledge as the current workforce retires. Coupled with the increasing requirement for high levels of design assurance and confidence in solutions, and the constant pressure to deliver value, faster and cheaper; companies are constantly looking at the latest technological advances, and to other industry sectors, for possible solutions. This paper explores, through case studies, how the latest digital modelling and visualisation techniques are being innovatively deployed to enhance design, delivery and operations in the oil and gas sector. SNC-Lavalin have been uniquely deploying these technologies into the nuclear sector, where access time is highly-limited due to nuclear radiation. This learning has been brought to the oil and gas sector, and is an exemplar of cross-industry working and knowledge transfer.
{"title":"How Digital Engineering and Cross-Industry Knowledge Transfer is Reducing Project Execution Risks in Oil and Gas","authors":"S. Evans","doi":"10.4043/29458-MS","DOIUrl":"https://doi.org/10.4043/29458-MS","url":null,"abstract":"\u0000 Technology has transformed the energy industry over the last 60 years. It has made processes more efficient, employees more productive and crucially, it has improved the safety of both workers and facilities.\u0000 In a mature industry, such as oil and gas, operators and owners are faced with the challenge of safely and efficiently managing their ageing plant and assets. This challenge is compounded by poor historic records and information, and the potential loss of knowledge as the current workforce retires. Coupled with the increasing requirement for high levels of design assurance and confidence in solutions, and the constant pressure to deliver value, faster and cheaper; companies are constantly looking at the latest technological advances, and to other industry sectors, for possible solutions.\u0000 This paper explores, through case studies, how the latest digital modelling and visualisation techniques are being innovatively deployed to enhance design, delivery and operations in the oil and gas sector. SNC-Lavalin have been uniquely deploying these technologies into the nuclear sector, where access time is highly-limited due to nuclear radiation. This learning has been brought to the oil and gas sector, and is an exemplar of cross-industry working and knowledge transfer.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80183241","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. Vipulanandan, G. Panda, A. Maddi, G. K. Wong, Ahmed Aldughather
In this study, commercially available styrene butadiene rubber (SBR) polymer up to 3% was added to the highly sensing chemo-thermo-piezoresistive smart cement with a water-to-cement ratio of 0.38 to investigate the effects on the sensing properties. Series of quality control, curing and high pressure high temperature (HPHT) experiments were performed to evaluate the smart cement behavior with and without the SBR polymer. Addition of 1% and 3% SBR polymer increased the initial resistivity by 4% and 12% respectively and hence this parameter can be used for quality control in the field. Vipulanandan p-q curing model was used to predict the changes in resistivity with curing time. Addition of 1% and 3% SBR polymer also increased the compressive strength of the smart cement by 18% and 32% after 1 day of curing respectively, The piezoresistivity of smart cement with the addition of SBR polymer after 1 day of curing was over 500 times (50,000%) higher than the regular cement failure strain of 0.2%. The Vipulanandan p-q piezoresistivity model also predicted the experimental results very well. Addition of SBR polymer reduced the fluid losses 30 minutes and 24 hours after curing. The fluid loss was predicted using the Vipulanandan fluid loss model and compared it to the API model. The smart cement with and without SBR polymer detected the gas leak during initial slurry condition and after solidification. Addition of SBR polymer reduced the gas leak. During the gas leak in the piezoresisitive smart cement slurry the resistivity change was positive and for the solid smart cement the resistivity change was negative. During gas leak in the smart cement slurry the resistivity increase was about 45% and it reduced to 30% with the addition of 3% SBR polymer at pressure gradient of 2000 psi/ft. During gas leak in the solidified smart cement the resistivity reduced, opposite to the piezoresistive response to compressive stress, by about 30% and it reduced to 12% with the addition of 3% SBR polymer at a pressure gradient of 2000 psi/ft. Vipulanandan fluid flow model, generalized Dary's Law, predicted the non-linear responses of gas leak velocity (discharge per unit area) to the applied pressure gradient. Also electrical resistivity changes can be used to predict the gas leak velocity in the smart cement with and without SBR polymer.
{"title":"Characterizing Smart Cement Modified with Styrene Butadiene Polymer for Quality Control, Curing and to Control and Detect Fluid Loss and Gas Leaks Using Vipulanandan Models","authors":"C. Vipulanandan, G. Panda, A. Maddi, G. K. Wong, Ahmed Aldughather","doi":"10.4043/29581-MS","DOIUrl":"https://doi.org/10.4043/29581-MS","url":null,"abstract":"\u0000 In this study, commercially available styrene butadiene rubber (SBR) polymer up to 3% was added to the highly sensing chemo-thermo-piezoresistive smart cement with a water-to-cement ratio of 0.38 to investigate the effects on the sensing properties. Series of quality control, curing and high pressure high temperature (HPHT) experiments were performed to evaluate the smart cement behavior with and without the SBR polymer. Addition of 1% and 3% SBR polymer increased the initial resistivity by 4% and 12% respectively and hence this parameter can be used for quality control in the field. Vipulanandan p-q curing model was used to predict the changes in resistivity with curing time. Addition of 1% and 3% SBR polymer also increased the compressive strength of the smart cement by 18% and 32% after 1 day of curing respectively, The piezoresistivity of smart cement with the addition of SBR polymer after 1 day of curing was over 500 times (50,000%) higher than the regular cement failure strain of 0.2%. The Vipulanandan p-q piezoresistivity model also predicted the experimental results very well. Addition of SBR polymer reduced the fluid losses 30 minutes and 24 hours after curing. The fluid loss was predicted using the Vipulanandan fluid loss model and compared it to the API model. The smart cement with and without SBR polymer detected the gas leak during initial slurry condition and after solidification. Addition of SBR polymer reduced the gas leak. During the gas leak in the piezoresisitive smart cement slurry the resistivity change was positive and for the solid smart cement the resistivity change was negative. During gas leak in the smart cement slurry the resistivity increase was about 45% and it reduced to 30% with the addition of 3% SBR polymer at pressure gradient of 2000 psi/ft. During gas leak in the solidified smart cement the resistivity reduced, opposite to the piezoresistive response to compressive stress, by about 30% and it reduced to 12% with the addition of 3% SBR polymer at a pressure gradient of 2000 psi/ft. Vipulanandan fluid flow model, generalized Dary's Law, predicted the non-linear responses of gas leak velocity (discharge per unit area) to the applied pressure gradient. Also electrical resistivity changes can be used to predict the gas leak velocity in the smart cement with and without SBR polymer.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76707758","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}
Eduardo Oazen, T. D. F. D. Santos, Gabriel Rodrigues Cabral, Vinicius Garcia Do Prado
Offshore oil development projects are complex and require high capital investment. The application of methodologies that seek optimization of economic parameters of projects became particularly important since 2014, when oil barrel prices plummeted. At that moment, some projects required modifications to regain economical attractivity. The recovery of project profitability depended on the break-even oil price criterion fulfillment (typically USD 40-45) among other requirements. This paper presents a methodology developed by Petrobras to increase the profitability of offshore projects in conceptual design phase while meeting the technical and safety minimum requirements. Successful solutions provided by the Petrobras team, enabled through this methodology, to make more than 15 projects economically viable are presented. The solutions include phased development, reuse of flexible lines from declining production wells, application of new technologies (including boosting and processing), use of innovative subsea architectures, procedures to increase ramp-up speed, long tie-backs, etc. This article is focused on subsea engineering solutions.
{"title":"Solutions to Increase the Economic Attractiveness of Offshore Projects - Petrobras Experience in Subsea Design","authors":"Eduardo Oazen, T. D. F. D. Santos, Gabriel Rodrigues Cabral, Vinicius Garcia Do Prado","doi":"10.4043/29339-MS","DOIUrl":"https://doi.org/10.4043/29339-MS","url":null,"abstract":"\u0000 Offshore oil development projects are complex and require high capital investment. The application of methodologies that seek optimization of economic parameters of projects became particularly important since 2014, when oil barrel prices plummeted. At that moment, some projects required modifications to regain economical attractivity. The recovery of project profitability depended on the break-even oil price criterion fulfillment (typically USD 40-45) among other requirements.\u0000 This paper presents a methodology developed by Petrobras to increase the profitability of offshore projects in conceptual design phase while meeting the technical and safety minimum requirements. Successful solutions provided by the Petrobras team, enabled through this methodology, to make more than 15 projects economically viable are presented. The solutions include phased development, reuse of flexible lines from declining production wells, application of new technologies (including boosting and processing), use of innovative subsea architectures, procedures to increase ramp-up speed, long tie-backs, etc. This article is focused on subsea engineering solutions.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82230735","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}
Ingrid Ezechiello da Silva, Vivian Karla Castelo Branco Louback Machado Balthar, R. D. T. Filho, Gabriella de Medeiros de Sá Cavalcante, R. Santos
The plug and Abandonment (P&A) are the final stage of the life cycle of an oil well. This implies that the plugging material must withstand the chemicals, temperature and well pressure to ensure its long-term integrity. Portland cement is the most used material as a safety barrier in P&A operations. However, the extreme conditions of the well have challenged the mechanical properties of Portland Cement. In this context, the present work aims to identify the adequate systems as permanent plugging material and to characterize them with a qualification process based on international references and experimental validation. Hence, four systems were tested for plug cementing operation with composition variations under pre-defined ageing conditions. Class G Portland cement slurry was used as reference to allow comparison of mechanical properties (compressive strength and tensile strength) between flexible cement paste, a system containing a mixture of Class G Portland Cement with epoxy resin and finally a system with epoxy resin only. Samples containing Class G Portland Cement were cured for 14 days under well bottom conditions (3000 psi and temperature of 174 degrees Fahrenheit) and cured for 14 days at well temperature (using a thermal bath). Samples containing resin were cured for 14 days under well bottom conditions (3000 psi and temperature of 150 degrees Fahrenheit) and cured for 14 days at well temperature (using a thermal bath). Finally, the samples were aged for 60 days in a thermal bath at well temperature and exposed to the brine which is the completion fluid composition which will be above and below in contact with the well barrier in a P & A operation. The results of the compressive strength tests of the samples aged in brine showed tha in some systems tested the reduction of the modulus of elasticity occurred, however, it was also observed the increase of the modulus of elasticity in another system. The same was true of the results of tensile strength tests of aged samples, the increase of rupture loading in some systems and reduction in the other ones were observed. The mechanical tests of the samples before and after ageing were performed to define the best system to be used in a well abandonment operation aiming for long-term integrity.
{"title":"Mechanical Properties of Cementitious and Non-Cementitious System After Ageing Tests for Well Abandonment Cementing Operations","authors":"Ingrid Ezechiello da Silva, Vivian Karla Castelo Branco Louback Machado Balthar, R. D. T. Filho, Gabriella de Medeiros de Sá Cavalcante, R. Santos","doi":"10.4043/29445-MS","DOIUrl":"https://doi.org/10.4043/29445-MS","url":null,"abstract":"\u0000 The plug and Abandonment (P&A) are the final stage of the life cycle of an oil well. This implies that the plugging material must withstand the chemicals, temperature and well pressure to ensure its long-term integrity. Portland cement is the most used material as a safety barrier in P&A operations. However, the extreme conditions of the well have challenged the mechanical properties of Portland Cement. In this context, the present work aims to identify the adequate systems as permanent plugging material and to characterize them with a qualification process based on international references and experimental validation.\u0000 Hence, four systems were tested for plug cementing operation with composition variations under pre-defined ageing conditions. Class G Portland cement slurry was used as reference to allow comparison of mechanical properties (compressive strength and tensile strength) between flexible cement paste, a system containing a mixture of Class G Portland Cement with epoxy resin and finally a system with epoxy resin only. Samples containing Class G Portland Cement were cured for 14 days under well bottom conditions (3000 psi and temperature of 174 degrees Fahrenheit) and cured for 14 days at well temperature (using a thermal bath). Samples containing resin were cured for 14 days under well bottom conditions (3000 psi and temperature of 150 degrees Fahrenheit) and cured for 14 days at well temperature (using a thermal bath).\u0000 Finally, the samples were aged for 60 days in a thermal bath at well temperature and exposed to the brine which is the completion fluid composition which will be above and below in contact with the well barrier in a P & A operation. The results of the compressive strength tests of the samples aged in brine showed tha in some systems tested the reduction of the modulus of elasticity occurred, however, it was also observed the increase of the modulus of elasticity in another system. The same was true of the results of tensile strength tests of aged samples, the increase of rupture loading in some systems and reduction in the other ones were observed.\u0000 The mechanical tests of the samples before and after ageing were performed to define the best system to be used in a well abandonment operation aiming for long-term integrity.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82295399","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
J. Elzinga, A. Mesu, E. V. Eekelen, M. Wochner, E. Jansen, M. Nijhof
Offshore wind is a quickly-emerging market resulting from the worldwide transition towards renewable energies. Whilst this transition has countless environmental benefits, the negative aspects pertaining to underwater noise generated during wind park construction are coming under increased public scrutiny. A number of countries have responded to this environmental and social concern by establishing underwater noise regulations. Construction using current piling techniques often requires the use of underwater noise mitigation systems to meet these legislative requirements. These systems can be applied at the piling source, near pile or far from pile. Under the Underwater Noise Abatement System (UNAS) program, partially sponsored by the Dutch government’s ‘Rijksdienst voor Ondernemend Nederland’ (RVO), a new noise mitigation system has been tested. The UNAS consortium consists of three partners: Van Oord Offshore Wind Projects, AdBm Technologies, and TNO (Netherlands Organization for Applied Scientific Research). The noise mitigation system, here after referred to as NMS, consists of a slatted system containing Helmholtz resonators which is deployed around a monopile in a similar method to venetian blinds. Scaled tests of the NMS at Butendiek and Luchterduinen Offshore Wind Parks showed potential for full-scale deployment. The full-scale test of the NMS was executed in the fall of 2018. A configuration where the vertical spacing of the slats was 0.67 m yielded a 7 to 8 dB SEL re 1 μPa2s reduction compared to the unmitigated scenario, while combining the NMS with a big bubble curtain (BBC) resulted in a 14 to 15 dB SEL reduction compared to the unmitigated situation. This reduction range, as well as a smooth offshore operational performance, puts the NMS in line with other near pile mitigation systems. Deployment of the NMS appears a feasible option to ensure underwater noise compliance in various nation’s legislation.
海上风电是全球向可再生能源转型的一个快速新兴市场。虽然这种转变有无数的环境效益，但与风力发电场建设过程中产生的水下噪音有关的负面影响正受到越来越多的公众关注。一些国家通过制定水下噪音条例对这一环境和社会问题作出了反应。使用当前打桩技术的建筑通常需要使用水下噪音缓解系统来满足这些立法要求。这些系统可应用于桩源、近桩或远桩处。在水下降噪系统(UNAS)项目下，一种新的降噪系统已经进行了测试，该项目部分由荷兰政府的“Rijksdienst voor Ondernemend Nederland”(RVO)资助。UNAS财团由三个合作伙伴组成:Van Oord海上风电项目、AdBm技术和TNO(荷兰应用科学研究组织)。降噪系统，在这里被称为NMS，由一个包含亥姆霍兹谐振器的板条系统组成，该系统以类似于百叶窗的方法部署在单桩周围。在Butendiek和Luchterduinen海上风电场进行的大规模测试表明，NMS具有全面部署的潜力。该系统的全面测试于2018年秋季进行。在垂直间距为0.67 m的情况下，与未缓解的情况相比，NMS的SEL降低了7到8 dB，减少了1 μPa2s，而将NMS与大气泡幕(BBC)相结合，与未缓解的情况相比，SEL降低了14到15 dB。这种减少范围，以及平稳的海上作业性能，使NMS与其他近桩缓解系统保持一致。在各国的立法中，部署NMS是确保水下噪声合规性的可行选择。
{"title":"Manuscript Title: Installing Offshore Wind Turbine Foundations Quieter: A Performance Overview of the First Full-Scale Demonstration of the AdBm Underwater Noise Abatement System","authors":"J. Elzinga, A. Mesu, E. V. Eekelen, M. Wochner, E. Jansen, M. Nijhof","doi":"10.4043/29613-MS","DOIUrl":"https://doi.org/10.4043/29613-MS","url":null,"abstract":"\u0000 Offshore wind is a quickly-emerging market resulting from the worldwide transition towards renewable energies. Whilst this transition has countless environmental benefits, the negative aspects pertaining to underwater noise generated during wind park construction are coming under increased public scrutiny. A number of countries have responded to this environmental and social concern by establishing underwater noise regulations. Construction using current piling techniques often requires the use of underwater noise mitigation systems to meet these legislative requirements. These systems can be applied at the piling source, near pile or far from pile. Under the Underwater Noise Abatement System (UNAS) program, partially sponsored by the Dutch government’s ‘Rijksdienst voor Ondernemend Nederland’ (RVO), a new noise mitigation system has been tested. The UNAS consortium consists of three partners: Van Oord Offshore Wind Projects, AdBm Technologies, and TNO (Netherlands Organization for Applied Scientific Research). The noise mitigation system, here after referred to as NMS, consists of a slatted system containing Helmholtz resonators which is deployed around a monopile in a similar method to venetian blinds. Scaled tests of the NMS at Butendiek and Luchterduinen Offshore Wind Parks showed potential for full-scale deployment. The full-scale test of the NMS was executed in the fall of 2018. A configuration where the vertical spacing of the slats was 0.67 m yielded a 7 to 8 dB SEL re 1 μPa2s reduction compared to the unmitigated scenario, while combining the NMS with a big bubble curtain (BBC) resulted in a 14 to 15 dB SEL reduction compared to the unmitigated situation. This reduction range, as well as a smooth offshore operational performance, puts the NMS in line with other near pile mitigation systems. Deployment of the NMS appears a feasible option to ensure underwater noise compliance in various nation’s legislation.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88746662","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 much-anticipated new INCOSE Systems Engineering Competency Framework was published in July 2018. This paper and associated presentation describes how individuals in oil and gas companies can use a practical evidence-based approach with the new framework to enhance their overall engineering and systems engineering expertise. The framework consists of 36 competencies across five groups: Core, Technical, Management, Professional, and Integrating. In addition to a description and explanation of why it is important, each competency includes a set of evidence-based indicators across five levels of competence: Awareness, Supervised Practitioner, Practitioner, Lead Practitioner and Expert. The indicators are considered evidence-based because they describe the evidence that individuals should provide in order to determine their level of competence. An individual's competence enables them to properly execute a particular process or activity described by the competency with a certain proficiency. It also includes understanding and making the most of the relationships between and among the various competencies and their activities, understanding the individual's specific roles in supporting the overall enterprise, in this case the oil and gas industry, and understanding the behavioral skills required to ensure the competencies and their associated activities are executed effectively in those roles. In addition, by applying this evidence-based approach, individuals can use the indicators to help identify and then acquire the necessary knowledge, skills, abilities, behaviors and experiences that lead to higher levels of competence in the various competencies, thereby enhancing their own systems engineering effectiveness in their oil and gas careers and beyond.
{"title":"Implementing the New INCOSE Systems Engineering Competency Framework Using an Evidence Based Approach for Oil and Gas Companies","authors":"D. Gelosh","doi":"10.4043/29318-MS","DOIUrl":"https://doi.org/10.4043/29318-MS","url":null,"abstract":"\u0000 The much-anticipated new INCOSE Systems Engineering Competency Framework was published in July 2018. This paper and associated presentation describes how individuals in oil and gas companies can use a practical evidence-based approach with the new framework to enhance their overall engineering and systems engineering expertise. The framework consists of 36 competencies across five groups: Core, Technical, Management, Professional, and Integrating. In addition to a description and explanation of why it is important, each competency includes a set of evidence-based indicators across five levels of competence: Awareness, Supervised Practitioner, Practitioner, Lead Practitioner and Expert. The indicators are considered evidence-based because they describe the evidence that individuals should provide in order to determine their level of competence. An individual's competence enables them to properly execute a particular process or activity described by the competency with a certain proficiency. It also includes understanding and making the most of the relationships between and among the various competencies and their activities, understanding the individual's specific roles in supporting the overall enterprise, in this case the oil and gas industry, and understanding the behavioral skills required to ensure the competencies and their associated activities are executed effectively in those roles. In addition, by applying this evidence-based approach, individuals can use the indicators to help identify and then acquire the necessary knowledge, skills, abilities, behaviors and experiences that lead to higher levels of competence in the various competencies, thereby enhancing their own systems engineering effectiveness in their oil and gas careers and beyond.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72979683","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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