It is a challenging problem to achieve low cost and fast-track construction for new-build FPSO hulls. In order to cope with this problem, the authors developed and reported unique modular design and multi-yard construction concept, "noah-FPSO Hull" [1][2][3]. After that, the authors continued to improve its design and expanded its flexibility for harsh environment and customer's requests. As a result, new standardized fore/aft modules and cargo tank module have been developed to expand the flexibility. This paper presents the design of the newly developed modules and the feasibility for harsh environment.
{"title":"Demonstrating the Feasibility of New-Build Hull-Platform for FPSO in Various Oil Field","authors":"Yasuhiro Sogawa, Shigeru Tanaka","doi":"10.4043/29554-MS","DOIUrl":"https://doi.org/10.4043/29554-MS","url":null,"abstract":"\u0000 It is a challenging problem to achieve low cost and fast-track construction for new-build FPSO hulls. In order to cope with this problem, the authors developed and reported unique modular design and multi-yard construction concept, \"noah-FPSO Hull\" [1][2][3]. After that, the authors continued to improve its design and expanded its flexibility for harsh environment and customer's requests. As a result, new standardized fore/aft modules and cargo tank module have been developed to expand the flexibility. This paper presents the design of the newly developed modules and the feasibility for harsh environment.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 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":"90110580","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}
Dhyanjyoti Deka, Yenny Chandra, M. Campbell, M. Santala, Y. Constantinides, Joe Jin, Ilkay Darilmaz, Raja Nadathur, F. Yiu
The objective of the STREAM (Steel Riser Enhanced Analytics using Measurements) JIP is to provide a measurement based foundation for SCR and lazy wave riser modelling to ensure that the fatigue response is assessed with adequate but not overly conservative parameters. To achieve this objective, the JIP utilizes field measurements from 4 in-service SCRs and 1 SLWR in water depths from 3,000 ft to 5,000 ft. The field measurements correspond to a range of environments including hurricanes and loop currents, riser functions, sizes, VIV suppression coverages and host vessels. The processing commences with data QA, error assessment and data filtration. Riser response is categorized into wave dominated events, VIV events and others such as MIV events. As-built finite element riser models are developed and simulations are conducted using measured motions. The resulting analytical responses are compared with the measured motion and strain data to determine the level of conservatism or otherwise in typical riser wave fatigue analysis. SHEAR7 models driven by measured current profiles are used to compare predicted VIV response to observed VIV amplitudes and frequencies. Analysis results indicate that industry standard fatigue assessment is indeed conservative. Sensitivities are conducted and presented on key design parameters that are known to be conservatively used in design such as hydrodynamic coefficients and SHEAR7 inputs. A set of parameters is derived that not only reduces fatigue damage bias but also improves the reliability in predictions. Recommendations are made with regards to further refinement of analysis parameters and understanding of atypical riser responses. Measured riser response that does not conform to typical wave and VIV spectra are presented and discussed. The combined assessment of full scale field data from multiple catenary risers is an industry first. The results from this JIP offer valuable insight into riser response characterization with potential applications for SCR/SLWR life extension and more efficient new designs. Note that in this paper, the term SCR is often used a generic term to describe both the regular SCR as well as the lazy wave implementation of it, the SLWR.
{"title":"STREAM JIP – Insights into Steel Catenary Riser Response Using Measured Data","authors":"Dhyanjyoti Deka, Yenny Chandra, M. Campbell, M. Santala, Y. Constantinides, Joe Jin, Ilkay Darilmaz, Raja Nadathur, F. Yiu","doi":"10.4043/29239-MS","DOIUrl":"https://doi.org/10.4043/29239-MS","url":null,"abstract":"\u0000 The objective of the STREAM (Steel Riser Enhanced Analytics using Measurements) JIP is to provide a measurement based foundation for SCR and lazy wave riser modelling to ensure that the fatigue response is assessed with adequate but not overly conservative parameters. To achieve this objective, the JIP utilizes field measurements from 4 in-service SCRs and 1 SLWR in water depths from 3,000 ft to 5,000 ft. The field measurements correspond to a range of environments including hurricanes and loop currents, riser functions, sizes, VIV suppression coverages and host vessels.\u0000 The processing commences with data QA, error assessment and data filtration. Riser response is categorized into wave dominated events, VIV events and others such as MIV events. As-built finite element riser models are developed and simulations are conducted using measured motions. The resulting analytical responses are compared with the measured motion and strain data to determine the level of conservatism or otherwise in typical riser wave fatigue analysis. SHEAR7 models driven by measured current profiles are used to compare predicted VIV response to observed VIV amplitudes and frequencies.\u0000 Analysis results indicate that industry standard fatigue assessment is indeed conservative. Sensitivities are conducted and presented on key design parameters that are known to be conservatively used in design such as hydrodynamic coefficients and SHEAR7 inputs. A set of parameters is derived that not only reduces fatigue damage bias but also improves the reliability in predictions. Recommendations are made with regards to further refinement of analysis parameters and understanding of atypical riser responses. Measured riser response that does not conform to typical wave and VIV spectra are presented and discussed.\u0000 The combined assessment of full scale field data from multiple catenary risers is an industry first. The results from this JIP offer valuable insight into riser response characterization with potential applications for SCR/SLWR life extension and more efficient new designs.\u0000 Note that in this paper, the term SCR is often used a generic term to describe both the regular SCR as well as the lazy wave implementation of it, the SLWR.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"17 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75660616","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}
Thomas B. Charlton, S. Kegg, J. Morgan, L. Zerpa, C. Koh, E. May, Z. Aman
This study provides valuable insights into hydrate management strategies as the industry transitions away from complete hydrate avoidance, particularly for the development of deep-water reservoirs with stricter economic margins. Transient simulation tools, such as the deployed hydrate deposition model, extend our ability to estimate blockage likelihood from heuristics to quantitative predictions. The model is applied to an insulated subsea tieback to identify the optimal no-touch-time (NTT) and depressurization pressure (DPP) following an unplanned shutdown. Two water-production scenarios are considered, from the lowest expected to the highest manageable rates. A complete hydrate blockage is predicted when the NTT was extended several hours beyond the nominal value for the highest water-to-gas ratio (WGR). Complete blockages are predicted for both low and high WGRs when the flowline is only partially depressurized, however, longer cooldown times for the high WGR case (due to greater volumes of residual liquids) meant a blockage took more than twice as long to occur than for the low WGR case. Fully depressurized restarts are both difficult and time consuming, leading to hydrate volume fractions (with respect to the pipe volume) exceeding 30 vol.%. An alternative hydrate management strategy is identified for cases with high volumes of water production, in which the flowline is only partially depressurized once the nominal NTT has elapsed, utilising the increased heat capacity of residual liquids. This reduces the quantity of gas sent to flare and simplifies the restart procedure.
{"title":"Application of a Transient Deposition Model for Hydrate Management in a Subsea Gas-Condensate Tieback","authors":"Thomas B. Charlton, S. Kegg, J. Morgan, L. Zerpa, C. Koh, E. May, Z. Aman","doi":"10.4043/29237-MS","DOIUrl":"https://doi.org/10.4043/29237-MS","url":null,"abstract":"\u0000 This study provides valuable insights into hydrate management strategies as the industry transitions away from complete hydrate avoidance, particularly for the development of deep-water reservoirs with stricter economic margins. Transient simulation tools, such as the deployed hydrate deposition model, extend our ability to estimate blockage likelihood from heuristics to quantitative predictions. The model is applied to an insulated subsea tieback to identify the optimal no-touch-time (NTT) and depressurization pressure (DPP) following an unplanned shutdown. Two water-production scenarios are considered, from the lowest expected to the highest manageable rates. A complete hydrate blockage is predicted when the NTT was extended several hours beyond the nominal value for the highest water-to-gas ratio (WGR). Complete blockages are predicted for both low and high WGRs when the flowline is only partially depressurized, however, longer cooldown times for the high WGR case (due to greater volumes of residual liquids) meant a blockage took more than twice as long to occur than for the low WGR case. Fully depressurized restarts are both difficult and time consuming, leading to hydrate volume fractions (with respect to the pipe volume) exceeding 30 vol.%. An alternative hydrate management strategy is identified for cases with high volumes of water production, in which the flowline is only partially depressurized once the nominal NTT has elapsed, utilising the increased heat capacity of residual liquids. This reduces the quantity of gas sent to flare and simplifies the restart procedure.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"27 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84449613","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. J. Schroeder, J. Chitwood, M. York, Ben Alexander, Todd Holtz
This paper summarizes results and lessons learned from qualification of a full scale subsea chemical storage and injection system. It also presents compelling findings from case studies that demonstrate the system can deliver significant savings compared to host platform chemical storage and umbilical delivery. Successful deployment of this new technology will initially provide, in brownfield applications, a very attractive alternative to an umbilical replacement, particularly later in field life when production rates and percent oil tend to be much lower, where economics may all together preclude installing a new umbilical and result in pre-mature field abandonment. The need for umbilical replacement might be triggered by a number of situations such as umbilical tube plugging or damage, or changing production composition requiring additional/different chemical treatments. In greenfield applications remote chemical storage and injection will greatly facilitate development of hundreds of smaller deepwater resources and billions of barrels of oil equivalent (BOE) by enabling safe, cost-effective long distance tie-backs to existing infrastructure out of traditional reach of umbilicals. Current shallow water deployment case studies indicate that transferring chemical storage and injection equipment weight from host facility deck to subsea and eliminating the need for on-deck personnel to maintain equipment generates positive economics and help achieve industry objects of ‘de-manning’ offshore facilities.
{"title":"Qualification and Case Studies Subsea Chemical Storage and Injection Unit","authors":"A. J. Schroeder, J. Chitwood, M. York, Ben Alexander, Todd Holtz","doi":"10.4043/29307-MS","DOIUrl":"https://doi.org/10.4043/29307-MS","url":null,"abstract":"\u0000 This paper summarizes results and lessons learned from qualification of a full scale subsea chemical storage and injection system. It also presents compelling findings from case studies that demonstrate the system can deliver significant savings compared to host platform chemical storage and umbilical delivery. Successful deployment of this new technology will initially provide, in brownfield applications, a very attractive alternative to an umbilical replacement, particularly later in field life when production rates and percent oil tend to be much lower, where economics may all together preclude installing a new umbilical and result in pre-mature field abandonment. The need for umbilical replacement might be triggered by a number of situations such as umbilical tube plugging or damage, or changing production composition requiring additional/different chemical treatments. In greenfield applications remote chemical storage and injection will greatly facilitate development of hundreds of smaller deepwater resources and billions of barrels of oil equivalent (BOE) by enabling safe, cost-effective long distance tie-backs to existing infrastructure out of traditional reach of umbilicals. Current shallow water deployment case studies indicate that transferring chemical storage and injection equipment weight from host facility deck to subsea and eliminating the need for on-deck personnel to maintain equipment generates positive economics and help achieve industry objects of ‘de-manning’ offshore facilities.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"32 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83193205","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 ChichakKelly, C. Khandekar, T ChristofelBrian, T DoaneJoseph, Alexander Vandish
One of the most serious flow assurance challenges encountered during oil and gas production is the deposition of paraffins on formation surfaces, flowlines, as well as on other processing equipment. Paraffin deposition can cause problems in the production system that includes blocked pipelines, lower production rates, solids-accumulation, and increased remediation time and costs. Several thermal, mechanical, and chemical methods are used to mitigate these challenges, and, of the chemical techniques available, paraffin inhibitors are deployed to mitigate the deposition problem. Several classes of polymers have been developed into paraffin inhibitors to delay the onset of paraffin precipitation and alter the crystal morphology of the precipitated paraffin particles – these combined phenomena reduce the extent of deposition. While these polymers control wax deposition, several challenges remain for their use in both cold and deep-water environments. Many of these polymers exhibit reduced solubility in common solvents used to formulate treatment products, and, as a consequence can only be blended at low concentrations for use in harsh environments. A real demand exists for new paraffin inhibitors that have enhanced formulation-stability at much higher concentrations suitable for use under low-temperature and high pressure environmental conditions. This paper describes the developmental work and performance evaluation of a novel series of polymers specifically developed for use in low-temperature environments.
{"title":"Novel Low-Temperature Stable Paraffin Inhibitors for Subsea Application","authors":"S ChichakKelly, C. Khandekar, T ChristofelBrian, T DoaneJoseph, Alexander Vandish","doi":"10.4043/29254-MS","DOIUrl":"https://doi.org/10.4043/29254-MS","url":null,"abstract":"\u0000 One of the most serious flow assurance challenges encountered during oil and gas production is the deposition of paraffins on formation surfaces, flowlines, as well as on other processing equipment. Paraffin deposition can cause problems in the production system that includes blocked pipelines, lower production rates, solids-accumulation, and increased remediation time and costs.\u0000 Several thermal, mechanical, and chemical methods are used to mitigate these challenges, and, of the chemical techniques available, paraffin inhibitors are deployed to mitigate the deposition problem. Several classes of polymers have been developed into paraffin inhibitors to delay the onset of paraffin precipitation and alter the crystal morphology of the precipitated paraffin particles – these combined phenomena reduce the extent of deposition. While these polymers control wax deposition, several challenges remain for their use in both cold and deep-water environments. Many of these polymers exhibit reduced solubility in common solvents used to formulate treatment products, and, as a consequence can only be blended at low concentrations for use in harsh environments. A real demand exists for new paraffin inhibitors that have enhanced formulation-stability at much higher concentrations suitable for use under low-temperature and high pressure environmental conditions.\u0000 This paper describes the developmental work and performance evaluation of a novel series of polymers specifically developed for use in low-temperature environments.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"250 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76738348","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}
Electrical intelligent completion systems are designed for reservoir management and production control of different zones within a well. The operating conditions expose the tools (hereinafter referred to as "stations") within the system to harsh conditions—high temperatures, high pressures, gas, and sand particles. Over time, exposure to such conditions can lead to component, module, station, or system failure, resulting in the possibility of deferred production or nonproductive time. To improve system reliability, the downhole and surface components of the system are equipped with sensors. The capability of such systems to acquire and transmit data related to the health of the system, its modules, and its components is a novel approach. Acquired data is transmitted through a cloud-based Internet of Things (IoT) framework for station health monitoring and health degradation predictions. The high frequency of data acquisition in combination with a large number of stations can lead to huge volumes of data. Manual monitoring and processing of large-scale data can become very inefficient and unmanageable and consequently, there is a need to develop intelligent algorithms for processing data to make actionable decisions and to adhere to a sustainable workflow. This paper describes the data pipeline established through cloud-based architecture for automating the monitoring, dashboard creation, and health prediction for the electric motor actuator (EMA) module, using historical health data of the downhole electronics. In addition, a predictive approach consisting of feature engineering, event (actuation) extraction, and supervised machine learning algorithms is discussed and illustrated through example data sets and results.
{"title":"Performance and Health Monitoring, Prognostics and Contingency for Electrical Completion Systems, Designed on Purpose","authors":"Mihitha Nutakki, M. Faur, D. Viassolo, I. Gour","doi":"10.4043/29663-MS","DOIUrl":"https://doi.org/10.4043/29663-MS","url":null,"abstract":"\u0000 Electrical intelligent completion systems are designed for reservoir management and production control of different zones within a well. The operating conditions expose the tools (hereinafter referred to as \"stations\") within the system to harsh conditions—high temperatures, high pressures, gas, and sand particles. Over time, exposure to such conditions can lead to component, module, station, or system failure, resulting in the possibility of deferred production or nonproductive time. To improve system reliability, the downhole and surface components of the system are equipped with sensors. The capability of such systems to acquire and transmit data related to the health of the system, its modules, and its components is a novel approach.\u0000 Acquired data is transmitted through a cloud-based Internet of Things (IoT) framework for station health monitoring and health degradation predictions. The high frequency of data acquisition in combination with a large number of stations can lead to huge volumes of data. Manual monitoring and processing of large-scale data can become very inefficient and unmanageable and consequently, there is a need to develop intelligent algorithms for processing data to make actionable decisions and to adhere to a sustainable workflow.\u0000 This paper describes the data pipeline established through cloud-based architecture for automating the monitoring, dashboard creation, and health prediction for the electric motor actuator (EMA) module, using historical health data of the downhole electronics. In addition, a predictive approach consisting of feature engineering, event (actuation) extraction, and supervised machine learning algorithms is discussed and illustrated through example data sets and results.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"133 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77613974","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}
Sand is a limiting design factor for facilities in terms of operability, throughput, and maintenance. These effects are more critical when dealing with subsea processing due to the equipment access and risk exposure. Technologies for erosion management, sand separation, and solids disposal are well proven for surface facilities. For example, the wellhead desander, located upstream of the choke, effectively separates sand from the multiphase well flow and can be marinized for subsea use. However, the crucial question is "What to do with the sand?" This white paper provides a focal point for the discussion on sand management in subsea processing. The broad categories for dealing with sand include neutralization of the effects, improvements in conventional design, and separation with disposal. These categories have been analyzed based on the conventional design, treatment of the solids, and removal of the solids. More than thirty discrete treatment routes were surveyed, including conventional production limits, flow path modification, chemical treatment, sand cleaning, mechanical attrition, slurry fracture injection, and accretion disposal. Many of these technologies have analogues in other particulate processing industries that can be adapted to upstream oil and gas production. This work is part of ongoing research in Facilities Sand Management with the goal of improving the hydrocarbon recovery through inclusionary sand production.
{"title":"The Subsea Sand Management Challenge – What to Do with the Sand?","authors":"C. Rawlins, J. Ditria","doi":"10.4043/29278-MS","DOIUrl":"https://doi.org/10.4043/29278-MS","url":null,"abstract":"\u0000 Sand is a limiting design factor for facilities in terms of operability, throughput, and maintenance. These effects are more critical when dealing with subsea processing due to the equipment access and risk exposure. Technologies for erosion management, sand separation, and solids disposal are well proven for surface facilities. For example, the wellhead desander, located upstream of the choke, effectively separates sand from the multiphase well flow and can be marinized for subsea use. However, the crucial question is \"What to do with the sand?\" This white paper provides a focal point for the discussion on sand management in subsea processing. The broad categories for dealing with sand include neutralization of the effects, improvements in conventional design, and separation with disposal. These categories have been analyzed based on the conventional design, treatment of the solids, and removal of the solids. More than thirty discrete treatment routes were surveyed, including conventional production limits, flow path modification, chemical treatment, sand cleaning, mechanical attrition, slurry fracture injection, and accretion disposal. Many of these technologies have analogues in other particulate processing industries that can be adapted to upstream oil and gas production. This work is part of ongoing research in Facilities Sand Management with the goal of improving the hydrocarbon recovery through inclusionary sand production.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"44 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":"73853550","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 Aasta Hansteen Subsea Production System is a part of a new major deep water gas development located in the Norwegian Sea, north of the Arctic Circle and 300 km from shore, west of the city of Bodø in Norway. With a water depth of 1300m, this development is a new water depth record in Norwegian waters and it is characterized by its remote location and harsh environment. The objective of this paper is to present the concept selections, technology development, design and fabrication for the subsea production system including umbilical and workover system. The paper demonstrates the importance of solid preparation in early phase planning, continuous implementation of lessons learned and an extensive test program in order to verify the new technical solutions for the Aasta Hansteen subsea deepwater development. This included development of a new mono-pile "toast rack" template designed for guideline less installation of manifolds and X-mas tree systems. This paper also presents a new deep water Workover system, involving an extensive qualification program and several new technical features such as a new safety joint, heave compensator and automated make-up of riser joints and more, in order to improve operational efficiency and increase safety under given challenging conditions. The paper also addresses a full scale wellhead testing in order to verify the design for fatigue performance. Several novel technologies were qualified and implemented as part of the Aasta Hansteen Subsea Production System to adapt to deep water operations, to enhance HSE performance and improve efficiency of the system. The experience is that the new technologies and new system solutions have improved HSE performance, operational performance and installation friendliness.
Aasta Hansteen海底生产系统是一个新的深水天然气开发项目的一部分，该项目位于挪威海，位于北极圈以北，距离挪威城市Bodø以西300公里。该开发项目水深1300米，是挪威水域的新水深记录，其特点是地理位置偏远，环境恶劣。本文的目的是介绍水下生产系统的概念选择、技术开发、设计和制造，包括脐带和修井系统。为了验证Aasta Hansteen海底深水开发的新技术解决方案，在早期规划、持续实施经验教训和广泛的测试计划中进行坚实准备的重要性。这包括开发一种新的单桩“烤面包架”模板，该模板设计用于减少歧管和X-mas树系统的安装指南。本文还介绍了一种新的深水修井系统，包括广泛的认证程序和一些新的技术特征，如新的安全接头、升沉补偿器和隔水管接头的自动组装等，以提高作业效率，提高在给定挑战性条件下的安全性。本文还进行了全尺寸井口测试，以验证设计的疲劳性能。Aasta Hansteen海底生产系统采用了几项新技术，以适应深水作业，提高HSE性能，提高系统效率。经验表明，新技术和新系统解决方案提高了HSE性能、操作性能和安装友好性。
{"title":"Aasta Hansteen Subsea Production System for Deep Water and Harsh Environment","authors":"S. Lindseth, E. Røsby, Brynjar Vist, K. Aarnes","doi":"10.4043/29561-MS","DOIUrl":"https://doi.org/10.4043/29561-MS","url":null,"abstract":"\u0000 The Aasta Hansteen Subsea Production System is a part of a new major deep water gas development located in the Norwegian Sea, north of the Arctic Circle and 300 km from shore, west of the city of Bodø in Norway. With a water depth of 1300m, this development is a new water depth record in Norwegian waters and it is characterized by its remote location and harsh environment.\u0000 The objective of this paper is to present the concept selections, technology development, design and fabrication for the subsea production system including umbilical and workover system. The paper demonstrates the importance of solid preparation in early phase planning, continuous implementation of lessons learned and an extensive test program in order to verify the new technical solutions for the Aasta Hansteen subsea deepwater development. This included development of a new mono-pile \"toast rack\" template designed for guideline less installation of manifolds and X-mas tree systems. This paper also presents a new deep water Workover system, involving an extensive qualification program and several new technical features such as a new safety joint, heave compensator and automated make-up of riser joints and more, in order to improve operational efficiency and increase safety under given challenging conditions. The paper also addresses a full scale wellhead testing in order to verify the design for fatigue performance.\u0000 Several novel technologies were qualified and implemented as part of the Aasta Hansteen Subsea Production System to adapt to deep water operations, to enhance HSE performance and improve efficiency of the system. The experience is that the new technologies and new system solutions have improved HSE performance, operational performance and installation friendliness.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"355 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76493758","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 Internet of Things (IoT) — combined with advances in sensor technology, data analytics, and artificial intelligence (AI) — has paved the way for significant efficiency and productivity gains in the oil and gas industry. One application, in particular, has been proven to benefit from these technologies: electrical submersible pumps (ESPs). It's well understood across the E&P industry that nearly all wells must eventually incorporate some form of artificial lift to continue production, and ESPs drive about half of that. Although ESPs are designed to operate in harsh conditions, such as corrosive liquids, extreme temperatures, and under intense pressures, they can fail. Costs for repair or replacement are high but are usually dwarfed by the cost of lost production. In some cases, especially offshore, that cost can run into millions of dollars per day, including idle operational resources and output losses. This paper explores a unique AI-based application that enables operators to preempt costly ESP failures, while optimizing production at the same time. To illustrate, a use case will be shared. As a proof-of-concept and later a pilot project in an onshore oilfield, 30 ESPs driven by pumps ranging in power from as low as 200 kW to as high as 500 kW were deployed and monitored using an AI-supported predictive maintenance model. The positive results are applicable to offshore applications. In one case, the probability of an ESP failure was determined 12 days before an actual failure of the ESP occurred.
{"title":"Applying Artificial Intelligence to Optimize Oil and Gas Production","authors":"Christoph Kandziora","doi":"10.4043/29384-MS","DOIUrl":"https://doi.org/10.4043/29384-MS","url":null,"abstract":"\u0000 The Internet of Things (IoT) — combined with advances in sensor technology, data analytics, and artificial intelligence (AI) — has paved the way for significant efficiency and productivity gains in the oil and gas industry. One application, in particular, has been proven to benefit from these technologies: electrical submersible pumps (ESPs). It's well understood across the E&P industry that nearly all wells must eventually incorporate some form of artificial lift to continue production, and ESPs drive about half of that. Although ESPs are designed to operate in harsh conditions, such as corrosive liquids, extreme temperatures, and under intense pressures, they can fail. Costs for repair or replacement are high but are usually dwarfed by the cost of lost production. In some cases, especially offshore, that cost can run into millions of dollars per day, including idle operational resources and output losses. This paper explores a unique AI-based application that enables operators to preempt costly ESP failures, while optimizing production at the same time. To illustrate, a use case will be shared. As a proof-of-concept and later a pilot project in an onshore oilfield, 30 ESPs driven by pumps ranging in power from as low as 200 kW to as high as 500 kW were deployed and monitored using an AI-supported predictive maintenance model. The positive results are applicable to offshore applications. In one case, the probability of an ESP failure was determined 12 days before an actual failure of the ESP occurred.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 2019","volume":"206 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-04-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78122706","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 wide-scale deployment of analytics to support the well construction processes based on rig data has opened a host of opportunities to improve performance, quality, and safety at all levels in the offshore drilling industry. As automation and high-stakes decision making starts to rely more on these types of classifiers, a topic of consideration is the validation methods employed during their development to ensure accuracy and precision, requiring the best available methods to help data scientists evaluate their soundness, features and limitations, and explain to key stakeholders who may not be familiar with such techniques. In the particular case of drilling states determination from signal data, there may be cases where the ground truth records are either at lower resolution than desired, or where some degree of uncertainty on the labeling exist, techniques such as inter-rater reliability (IRR) or inter-rater agreement (IRA) can help to demonstrate consistency among observational decision provided by multiple sources and be used as a way to show the level of agreement between, for example, a proposed drilling state generator classifier using drillfloor data and existing IADC codes from available logs at the same time. This approach can be used to help decisions on further development of the particular classifier before committing to stricter model validation. This paper will show examples of these techniques applied to automatic generation of certain IADC codes using signal data vs log records, and how IRR/IRA can help inform the quality of the results.
{"title":"Validating Drilling States Classifiers with Suboptimal Datasets","authors":"Luis R. Pereira","doi":"10.4043/29415-MS","DOIUrl":"https://doi.org/10.4043/29415-MS","url":null,"abstract":"\u0000 The wide-scale deployment of analytics to support the well construction processes based on rig data has opened a host of opportunities to improve performance, quality, and safety at all levels in the offshore drilling industry. As automation and high-stakes decision making starts to rely more on these types of classifiers, a topic of consideration is the validation methods employed during their development to ensure accuracy and precision, requiring the best available methods to help data scientists evaluate their soundness, features and limitations, and explain to key stakeholders who may not be familiar with such techniques. In the particular case of drilling states determination from signal data, there may be cases where the ground truth records are either at lower resolution than desired, or where some degree of uncertainty on the labeling exist, techniques such as inter-rater reliability (IRR) or inter-rater agreement (IRA) can help to demonstrate consistency among observational decision provided by multiple sources and be used as a way to show the level of agreement between, for example, a proposed drilling state generator classifier using drillfloor data and existing IADC codes from available logs at the same time. This approach can be used to help decisions on further development of the particular classifier before committing to stricter model validation. This paper will show examples of these techniques applied to automatic generation of certain IADC codes using signal data vs log records, and how IRR/IRA can help inform the quality of the results.","PeriodicalId":10948,"journal":{"name":"Day 2 Tue, May 07, 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":"88791614","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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