A. J. Schroeder, J. Chitwood, J. Gillespie, Yung-Hee Lee, P. Hughes, J. Verdeil
Drag reducing agents (DRAs) are a cost-effective method to reduce pipeline pressure losses and maximize flowrates of onshore and offshore pipelines with over 40 years of proven results. With recent developments, production can also be significantly increased by injecting DRA into flow restricted subsea flowlines. This paper will provide a summary of the development and testing of a full-scale prototype subsea DRA storage and injection unit built to achieve the industry goal of alleviating flow restricted subsea pipelines. While DRA applications are proven in thousands of offshore and onshore applications, it has never been successfully injected subsea. System integration testing (SIT) is currently under way on the prototype unit, after which it will be qualified for offshore use. The technology is covered by numerous patents issued and pending in the US and other countries.
{"title":"Key Technology Qualification for Increasing Subsea Well Production via Drag Reducing Agents","authors":"A. J. Schroeder, J. Chitwood, J. Gillespie, Yung-Hee Lee, P. Hughes, J. Verdeil","doi":"10.4043/31054-ms","DOIUrl":"https://doi.org/10.4043/31054-ms","url":null,"abstract":"\u0000 Drag reducing agents (DRAs) are a cost-effective method to reduce pipeline pressure losses and maximize flowrates of onshore and offshore pipelines with over 40 years of proven results. With recent developments, production can also be significantly increased by injecting DRA into flow restricted subsea flowlines. This paper will provide a summary of the development and testing of a full-scale prototype subsea DRA storage and injection unit built to achieve the industry goal of alleviating flow restricted subsea pipelines. While DRA applications are proven in thousands of offshore and onshore applications, it has never been successfully injected subsea. System integration testing (SIT) is currently under way on the prototype unit, after which it will be qualified for offshore use. The technology is covered by numerous patents issued and pending in the US and other countries.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"23 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74000478","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}
Pierre-Jean Bibet, R. Santos, Antoine Lucas, Daniel Vunza
On Saturday the 3rd of September 2011, at 22h30 Luanda time, the first Pazflor gas/liquid Subsea Separation Unit (SSU) is put into operation, and one hybrid pump starts in production. Few weeks later, all three SSU are fully operational. In 2021, all three SSU will celebrate 10 years of successful operation. The paper relates 10 years of operational feedback of the Pazflor Subsea Separation Units with a special focus on the pumping system.
{"title":"Pazflor Subsea Separation, Ten Years After","authors":"Pierre-Jean Bibet, R. Santos, Antoine Lucas, Daniel Vunza","doi":"10.4043/31187-ms","DOIUrl":"https://doi.org/10.4043/31187-ms","url":null,"abstract":"\u0000 On Saturday the 3rd of September 2011, at 22h30 Luanda time, the first Pazflor gas/liquid Subsea Separation Unit (SSU) is put into operation, and one hybrid pump starts in production. Few weeks later, all three SSU are fully operational.\u0000 In 2021, all three SSU will celebrate 10 years of successful operation.\u0000 The paper relates 10 years of operational feedback of the Pazflor Subsea Separation Units with a special focus on the pumping system.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72627474","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. Borozdin, A. Dmitrievsky, N. Eremin, A. Arkhipov, A. Sboev, O. Chashchina-Semenova, L. Fitzner
This paper poses and solves the problem of using artificial intelligence methods for processing big volumes of geodata from geological and technological measurement stations in order to identify and predict complications during well drilling. Big volumes of geodata from the stations of geological and technological measurements during drilling varied from units to tens of terabytes. Digital modernization of the life cycle of well construction using machine learning methods contributes to improving the efficiency of drilling oil and gas wells. The clustering of big volumes of geodata from various sources and types of sensors used to measure parameters during drilling has been carried out. In the process of creating, training and applying software components with artificial neural networks, the specified accuracy of calculations was achieved, hidden and non-obvious patterns were revealed in big volumes of geological, geophysical, technical and technological parameters. To predict the operational results of drilling wells, classification models were developed using artificial intelligence methods. The use of a high-performance computing cluster significantly reduced the time spent on assessing the probability of complications and predicting these probabilities for 7-10 minutes ahead. A hierarchical distributed data warehouse has been formed, containing real-time drilling data in WITSML format using the SQL server (Microsoft). The module for preprocessing and uploading geodata to the WITSML repository uses the Energistics Standards DevKit API and Energistic data objects to work with geodata in the WITSML format. Drilling problems forecast accuracy which has been reached with developed system may significantly reduce non-productive time spent on eliminating of stuck pipe, mud loss and oil and gas influx events.
本文提出并解决了利用人工智能方法对地质和技术测量站的大量地质数据进行处理，以识别和预测钻井过程中的复杂问题。钻井期间，来自地质和技术测量站的大量地质数据从单位到数十tb不等。利用机器学习方法实现油井建设生命周期的数字化现代化，有助于提高油气井的钻井效率。对钻井过程中用于测量参数的各种来源和类型的传感器的大量地理数据进行了聚类。在利用人工神经网络创建、训练和应用软件组件的过程中，达到了规定的计算精度，揭示了大量地质、地球物理、技术和工艺参数中隐藏的和不明显的规律。为了预测钻井作业效果，采用人工智能方法建立了分类模型。高性能计算集群的使用大大减少了评估并发症概率和提前7-10分钟预测这些概率所花费的时间。利用SQL server (Microsoft)建立了一个分层分布式数据仓库，以WITSML格式存储实时钻井数据。用于预处理和上传地理数据到WITSML存储库的模块使用Energistics Standards DevKit API和Energistic数据对象来处理WITSML格式的地理数据。该系统已达到钻井问题预测精度，可显著减少用于消除卡钻、泥浆漏失和油气流入事件的非生产时间。
{"title":"Drilling Problems Forecast Based on Neural Network","authors":"S. Borozdin, A. Dmitrievsky, N. Eremin, A. Arkhipov, A. Sboev, O. Chashchina-Semenova, L. Fitzner","doi":"10.4043/30984-ms","DOIUrl":"https://doi.org/10.4043/30984-ms","url":null,"abstract":"\u0000 This paper poses and solves the problem of using artificial intelligence methods for processing big volumes of geodata from geological and technological measurement stations in order to identify and predict complications during well drilling. Big volumes of geodata from the stations of geological and technological measurements during drilling varied from units to tens of terabytes. Digital modernization of the life cycle of well construction using machine learning methods contributes to improving the efficiency of drilling oil and gas wells. The clustering of big volumes of geodata from various sources and types of sensors used to measure parameters during drilling has been carried out. In the process of creating, training and applying software components with artificial neural networks, the specified accuracy of calculations was achieved, hidden and non-obvious patterns were revealed in big volumes of geological, geophysical, technical and technological parameters. To predict the operational results of drilling wells, classification models were developed using artificial intelligence methods. The use of a high-performance computing cluster significantly reduced the time spent on assessing the probability of complications and predicting these probabilities for 7-10 minutes ahead. A hierarchical distributed data warehouse has been formed, containing real-time drilling data in WITSML format using the SQL server (Microsoft). The module for preprocessing and uploading geodata to the WITSML repository uses the Energistics Standards DevKit API and Energistic data objects to work with geodata in the WITSML format. Drilling problems forecast accuracy which has been reached with developed system may significantly reduce non-productive time spent on eliminating of stuck pipe, mud loss and oil and gas influx events.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"21 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81660223","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
With recent oil and gas discoveries in deepwater offshore, these regions have become the hotspots for oil and gas exploration. It is for this reason that major pipelay contractors are developing more advanced construction vessels with high lay tension capacity, payload and high specification dynamic positioning (DP) systems to operate at even deeper water depths. It is shown that at water depths of greater than 1000 m, one of the major construction costs is fuel consumption, which is directly related to the level of thrust and hold back tension the laybarge is required to maintain during pipelay operations. Furthermore, the fuel consumption and the resulting carbon footprint, is shown to increase disproportionally as the laybarge thrust increases at deeper water depths. For example, a deepwater laybarge (DP3 class) with a typical operating power of 40MWe can consume 130 metric tonnes of diesel fuel per day (1.5 kg/s) with carbon dioxide equivalent emissions (CO2e) of 3,200 kg per tonne of fuel. This is a substantial measure of emissions, typical of a pipelay vessel during pipe lay operations. It is for this reason that American and European air pollutant emission inventory guidelines expect environmental impact documents for all marine activities, including construction, to be calculated and submitted to relevant environmental protection agencies. By comparison, a typical car will produce around 4,600 kg of CO2e per year. Currently, deepwater pipeline engineering and design is based on relevant offshore design codes and standards, e.g. DNV-GL and API. Within the framework of those codes and standards, a design approach is presented within this paper that shows that, by properly combining pipe strength and stiffness characteristics with pipelay construction loads, a unique bending strain limit can be defined that would lead to the most economical solution that minimizes the vessel thrust and thereby radically reduce fuel consumption and associated CO2e emissions during pipelay activities. This unique design approach would be of interest to operators, pipe manufacturers as well as the pipelay contractors. Because of the construction economy and the minimizing of the carbon footprint, this approach is an attractive design method to all concerned parties, including environmental protection agencies. Since the design approach promotes higher steel grades, it would be very much in the interest of pipe mills to further develop and elevate the use of higher steel grades higher than the present widely used API 5L, X-65. Pipelay contractors will benefit by installing pipe with lower levels of thruster power, resulting in safer and a more reliable station keeping and, most significantly, a lower fuel consumption.
{"title":"Carbon Footprint Minimization for Deepwater Pipelay Construction","authors":"R. Young, Manou Kashani","doi":"10.4043/31105-ms","DOIUrl":"https://doi.org/10.4043/31105-ms","url":null,"abstract":"\u0000 With recent oil and gas discoveries in deepwater offshore, these regions have become the hotspots for oil and gas exploration. It is for this reason that major pipelay contractors are developing more advanced construction vessels with high lay tension capacity, payload and high specification dynamic positioning (DP) systems to operate at even deeper water depths. It is shown that at water depths of greater than 1000 m, one of the major construction costs is fuel consumption, which is directly related to the level of thrust and hold back tension the laybarge is required to maintain during pipelay operations. Furthermore, the fuel consumption and the resulting carbon footprint, is shown to increase disproportionally as the laybarge thrust increases at deeper water depths. For example, a deepwater laybarge (DP3 class) with a typical operating power of 40MWe can consume 130 metric tonnes of diesel fuel per day (1.5 kg/s) with carbon dioxide equivalent emissions (CO2e) of 3,200 kg per tonne of fuel. This is a substantial measure of emissions, typical of a pipelay vessel during pipe lay operations. It is for this reason that American and European air pollutant emission inventory guidelines expect environmental impact documents for all marine activities, including construction, to be calculated and submitted to relevant environmental protection agencies. By comparison, a typical car will produce around 4,600 kg of CO2e per year.\u0000 Currently, deepwater pipeline engineering and design is based on relevant offshore design codes and standards, e.g. DNV-GL and API. Within the framework of those codes and standards, a design approach is presented within this paper that shows that, by properly combining pipe strength and stiffness characteristics with pipelay construction loads, a unique bending strain limit can be defined that would lead to the most economical solution that minimizes the vessel thrust and thereby radically reduce fuel consumption and associated CO2e emissions during pipelay activities.\u0000 This unique design approach would be of interest to operators, pipe manufacturers as well as the pipelay contractors. Because of the construction economy and the minimizing of the carbon footprint, this approach is an attractive design method to all concerned parties, including environmental protection agencies. Since the design approach promotes higher steel grades, it would be very much in the interest of pipe mills to further develop and elevate the use of higher steel grades higher than the present widely used API 5L, X-65. Pipelay contractors will benefit by installing pipe with lower levels of thruster power, resulting in safer and a more reliable station keeping and, most significantly, a lower fuel consumption.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"12 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76451908","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 oil and gas sector is facing a changing market with new pressures to which it must learn to adapt. One of the biggest changes in expectations is the increased focus being placed on carbon emissions. Many consumers, investors, and lawmakers see reforms to the oil and gas industry as one of the most important avenues toward reducing carbon emissions and curbing climate change, and accordingly, a large number of companies have already made ambitious pledges towards carbon neutrality. New technologies may offer the best avenue for oil and gas companies to reduce their carbon emissions and meet those neutrality goals. Digital technologies—and in particular, artificial intelligence—can aid in decarbonization even with relatively small investments, primarily by enabling large increases in efficiency and reducing unscheduled downtime and the need for flaring. This paper discusses how artificial intelligence-powered predictive maintenance can be applied to reduce carbon emissions, and a case study illustrating a real-world deployment of this technology.
{"title":"Improving Offshore Platform Production With Artificial Intelligence","authors":"P. Herve","doi":"10.4043/31073-ms","DOIUrl":"https://doi.org/10.4043/31073-ms","url":null,"abstract":"\u0000 The oil and gas sector is facing a changing market with new pressures to which it must learn to adapt. One of the biggest changes in expectations is the increased focus being placed on carbon emissions. Many consumers, investors, and lawmakers see reforms to the oil and gas industry as one of the most important avenues toward reducing carbon emissions and curbing climate change, and accordingly, a large number of companies have already made ambitious pledges towards carbon neutrality.\u0000 New technologies may offer the best avenue for oil and gas companies to reduce their carbon emissions and meet those neutrality goals. Digital technologies—and in particular, artificial intelligence—can aid in decarbonization even with relatively small investments, primarily by enabling large increases in efficiency and reducing unscheduled downtime and the need for flaring. This paper discusses how artificial intelligence-powered predictive maintenance can be applied to reduce carbon emissions, and a case study illustrating a real-world deployment of this technology.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"150 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75961059","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. S. Hubbard, Leon Geoffrey Staaden, Derek John Scales, Andrew Tran
The objective of this study was to determine the highest flowrate through a client's existing flowline without top-of-line condensation rates exceeding a critical value of 0.25 g/m2.s. Automation of the workflow allowed a large combination of operating conditions to be analysed within a shorter timeframe than a traditional flow assurance analysis process. A multiparameter case matrix was developed to analyse the full range of process and environmental variables. A proprietary multiphase flow assurance software in the cloud was used to develop a reference case model. Then a software script was developed to read in the reference case model's code and produce input files for 1,080 cases. All cases were run within 30 minutes in the cloud. Another software script then extracted key data from the 1,080 output files into a single Excel spreadsheet to enable data visualisation and identification of a simple and effective flow rate criterion to limit condensation rates. Automation of the workflow allowed all combinations of variables to be analysed within a shorter timeframe compared to the traditional flow assurance analysis process, which usually analyses a somewhat limited number of suspected worst-case scenarios selected based on engineering judgement. The bulk data resulting from the automated workflow enabled a single integrity limit criterion to be applied with a high level of confidence, namely the fluid temperature measured at a subsea corrosion probe. This simplified integrity limit allows the operators to easily maximise production for any combination of process and environmental conditions, whilst maintaining confidence that they are not exceeding the critical condensation rate.
{"title":"Automation of Large Parametric Flow Assurance Analyses in the Cloud","authors":"R. S. Hubbard, Leon Geoffrey Staaden, Derek John Scales, Andrew Tran","doi":"10.4043/30937-ms","DOIUrl":"https://doi.org/10.4043/30937-ms","url":null,"abstract":"\u0000 The objective of this study was to determine the highest flowrate through a client's existing flowline without top-of-line condensation rates exceeding a critical value of 0.25 g/m2.s. Automation of the workflow allowed a large combination of operating conditions to be analysed within a shorter timeframe than a traditional flow assurance analysis process.\u0000 A multiparameter case matrix was developed to analyse the full range of process and environmental variables. A proprietary multiphase flow assurance software in the cloud was used to develop a reference case model. Then a software script was developed to read in the reference case model's code and produce input files for 1,080 cases. All cases were run within 30 minutes in the cloud. Another software script then extracted key data from the 1,080 output files into a single Excel spreadsheet to enable data visualisation and identification of a simple and effective flow rate criterion to limit condensation rates.\u0000 Automation of the workflow allowed all combinations of variables to be analysed within a shorter timeframe compared to the traditional flow assurance analysis process, which usually analyses a somewhat limited number of suspected worst-case scenarios selected based on engineering judgement.\u0000 The bulk data resulting from the automated workflow enabled a single integrity limit criterion to be applied with a high level of confidence, namely the fluid temperature measured at a subsea corrosion probe. This simplified integrity limit allows the operators to easily maximise production for any combination of process and environmental conditions, whilst maintaining confidence that they are not exceeding the critical condensation rate.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"69 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76032143","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}
G. Toguyeni, J. Fernandez-Vega, R. Jones, Martin Gallegillo, J. Banse
A solution to prevent liner wrinkling in Mechanically Lined Pipes (MLP) with a standard 3.0mm thick liner during reeling, without the use of pressurisation, has been developed in the form of the GluBi® lined pipe. The liner being adhesively bonded to the outer pipe, its integrity is maintained despite the global plastic strain applied by the installation method. This new linepipe product has been qualified for offshore use through testing accompanied by a detailed Finite Element Analysis programme to fully capture the pipe and adhesive behaviours under and range of temperatures and loading conditions. The objective of this analysis program was to investigate the reelability of the GluBi® pipe. The instalability was defined as the capability of the pipe to tolerate cyclic plastic deformation representative of a typical pipeline installation by reeling without the formation of wrinkling of the CRA liner, and to maintain the integrity of the adhesive layer, particularly near the weld overlay at the pipe ends. Important areas of the GluBi® pipe design are the pipe extremities, particularly the transition between the liner and the weld overlay length. A detailed Finite Element model of the pipe was created. It captured all stages of the pipe manufacturing: pipe lining, hydrostatic expansion, adhesive curing, overlay weld deposition and reeling simulation. The pipe modelled was 312.1mm OD × 19.7mm WT SMLS 450 with a nominal 3.0mm thick Alloy 625 liner. An important validation work was performed to obtain a precise material response of the adhesive layer between liner and outer pipe. The adhesive mechanical properties were thus assessed in shearing and peeling over a range of temperatures covering all possible manufacturing and installation conditions. The model's elements and adhesive property modelling were validated against physical test results. Sensitivity analyses were done on the adhesive curing temperature, the geometry of the adhesive transition between the liner and the overlay weld at the pipe ends and on the liner thickness. The model was subjected to reeling simulation corresponding to Subsea 7's reel-lay vessels. The liner's integrity post reeling was assessed according to a range of acceptance criteria. These studies made it possible to establish parameter ranges for the safe installation of the linepipe.
{"title":"Reelability Assessment of Adhesively Bonded Mechanically Lined Pipe","authors":"G. Toguyeni, J. Fernandez-Vega, R. Jones, Martin Gallegillo, J. Banse","doi":"10.4043/31088-ms","DOIUrl":"https://doi.org/10.4043/31088-ms","url":null,"abstract":"\u0000 A solution to prevent liner wrinkling in Mechanically Lined Pipes (MLP) with a standard 3.0mm thick liner during reeling, without the use of pressurisation, has been developed in the form of the GluBi® lined pipe. The liner being adhesively bonded to the outer pipe, its integrity is maintained despite the global plastic strain applied by the installation method. This new linepipe product has been qualified for offshore use through testing accompanied by a detailed Finite Element Analysis programme to fully capture the pipe and adhesive behaviours under and range of temperatures and loading conditions.\u0000 The objective of this analysis program was to investigate the reelability of the GluBi® pipe. The instalability was defined as the capability of the pipe to tolerate cyclic plastic deformation representative of a typical pipeline installation by reeling without the formation of wrinkling of the CRA liner, and to maintain the integrity of the adhesive layer, particularly near the weld overlay at the pipe ends.\u0000 Important areas of the GluBi® pipe design are the pipe extremities, particularly the transition between the liner and the weld overlay length. A detailed Finite Element model of the pipe was created. It captured all stages of the pipe manufacturing: pipe lining, hydrostatic expansion, adhesive curing, overlay weld deposition and reeling simulation. The pipe modelled was 312.1mm OD × 19.7mm WT SMLS 450 with a nominal 3.0mm thick Alloy 625 liner. An important validation work was performed to obtain a precise material response of the adhesive layer between liner and outer pipe. The adhesive mechanical properties were thus assessed in shearing and peeling over a range of temperatures covering all possible manufacturing and installation conditions. The model's elements and adhesive property modelling were validated against physical test results.\u0000 Sensitivity analyses were done on the adhesive curing temperature, the geometry of the adhesive transition between the liner and the overlay weld at the pipe ends and on the liner thickness. The model was subjected to reeling simulation corresponding to Subsea 7's reel-lay vessels. The liner's integrity post reeling was assessed according to a range of acceptance criteria. These studies made it possible to establish parameter ranges for the safe installation of the linepipe.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"58 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87914521","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 objective of this paper is to present a 4-point bend test of 5LPP (Five Layer Polypropylene) concrete coated pipe. This is the first of its kind of bend test for a complex coating combination of 5LPP and concrete layers. The bend tests have been carried out to simulate S-Lay installation loading conditions to assess the coating integrity of the pipeline during installation. This paper reports the test arrangements including instrumentation, load schedule, test procedure and the challenges involved. Finally, the preliminary results and conclusions of the tests are documented. Two separate full scale four-point bend tests are carried out to study the behavior of the 5LPP concrete coated pipe. The purpose of the first test is to understand the complex behavior of the 5LPP/CWC coated test pipe and validate previously made industry standard assumptions regarding the calculated coated joint stiffness. The purpose of the second test is to observe the coating integrity of the test joint and slippage behavior due to the simulated installation conditions (overbend and sagbend bending moments and/or corresponding curvatures). The nonlinear moment-curvature for the concrete coated pipe is estimated based on an analytical approach taking into consideration plane bending theory and slippage behavior of the coating layers. The moment-curvature is used to prepare the load schedule for the tests. The test string consists of a test joint (40ft) welded to half joints at the ends. The bend test is performed using industry established full scale 4-point bend test arrangements. A global finite element model is used to simulate the tests using the analytical moment-curvature of the concrete coated pipe. The stiffness of the test pipe is calculated using the first bend test and compared against the analytical stiffness. The second test is carried out by applying loads corresponding to an estimated maximum overbend bending moment and then the test string is unloaded and rebent in opposite direction by applying loads corresponding to an estimated maximum sagbend bending moment. The results of the second test are documented at each load step and the integrity of the coating is measured against specified concrete coating damage criteria for tension as well as compression. Finally, field observations from the actual installation operation are compared against the bend test results. Conclusions are presented to address various aspects of concrete coated pipe for S-Lay installations.
{"title":"Four Point Bend Test of 5LPP – Concrete Coated Pipe","authors":"Sachin Mathakari, Cameran Cox, Phillip Rattenbury","doi":"10.4043/31181-ms","DOIUrl":"https://doi.org/10.4043/31181-ms","url":null,"abstract":"\u0000 The objective of this paper is to present a 4-point bend test of 5LPP (Five Layer Polypropylene) concrete coated pipe. This is the first of its kind of bend test for a complex coating combination of 5LPP and concrete layers. The bend tests have been carried out to simulate S-Lay installation loading conditions to assess the coating integrity of the pipeline during installation. This paper reports the test arrangements including instrumentation, load schedule, test procedure and the challenges involved. Finally, the preliminary results and conclusions of the tests are documented.\u0000 Two separate full scale four-point bend tests are carried out to study the behavior of the 5LPP concrete coated pipe. The purpose of the first test is to understand the complex behavior of the 5LPP/CWC coated test pipe and validate previously made industry standard assumptions regarding the calculated coated joint stiffness. The purpose of the second test is to observe the coating integrity of the test joint and slippage behavior due to the simulated installation conditions (overbend and sagbend bending moments and/or corresponding curvatures). The nonlinear moment-curvature for the concrete coated pipe is estimated based on an analytical approach taking into consideration plane bending theory and slippage behavior of the coating layers. The moment-curvature is used to prepare the load schedule for the tests. The test string consists of a test joint (40ft) welded to half joints at the ends. The bend test is performed using industry established full scale 4-point bend test arrangements.\u0000 A global finite element model is used to simulate the tests using the analytical moment-curvature of the concrete coated pipe. The stiffness of the test pipe is calculated using the first bend test and compared against the analytical stiffness. The second test is carried out by applying loads corresponding to an estimated maximum overbend bending moment and then the test string is unloaded and rebent in opposite direction by applying loads corresponding to an estimated maximum sagbend bending moment. The results of the second test are documented at each load step and the integrity of the coating is measured against specified concrete coating damage criteria for tension as well as compression. Finally, field observations from the actual installation operation are compared against the bend test results. Conclusions are presented to address various aspects of concrete coated pipe for S-Lay installations.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"29 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82705937","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}
Guy Mencarelli, Jean-Philippe Bourbon, K. Forbord, David Gibson
The Ærfugl field is close to the existing Skarv development located in Norwegian Sea, making it a tie-back opportunity. The hydrate management and operational savings were major drivers for the subsea system design requiring the use of an electrically heated trace flowline (EHTF). The scope of this paper is to present how the EHTF technology has been further developed, qualified and industrialized during the execution of the Ærfugl project. It will also illustrate how a unique collaborative model between an Operator, an SPS Contractor and an EPCI Contractor contributed to the delivery of the first heated Pipe in Pipe system on a sizable project. Starting from a conceptual technology selection to the project delivery, numerous qualifications were performed to validate the EHTFsystem design and ease its industrialization. The development of a new technology starts from the component design through system qualification up to the installation phase. It is of prime importance that all the different phases of the system life cycle are equally considered, as being interdependent. By using this holistic design approach right from the start of the qualification phase, the final product eventually meets all the requirements, from the component specification to the system performance. The collaborative model in place on the Ærfugl project allowed the efficient integration of the Operator at each different step of the design, qualification and industrialization process resulting in delivery schedule savings when compared to a conventional project delivery approach. Several important development activities took place during the Ærfugl project and the holistic design approach backed by robust system engineering processes enabled a smooth and efficient workflow supporting the onshore fabrication and offshore installation readiness activities. Several fabrication challenges were overcome during the project to safely deliver the EHTF solution with a continuous focus on quality and this paper will also cover the most relevant ones. Following the Ærfugl project execution, the EHTF technology, supported by a unique collaborative model with the operator, is now fully qualified, and deployed offshore based on robust and reliable manufacturing and installation methods.
{"title":"Electrically Heated Trace Flowline on Ærfugl Project - A journey from Product Qualification to Offshore Campaign","authors":"Guy Mencarelli, Jean-Philippe Bourbon, K. Forbord, David Gibson","doi":"10.4043/31078-ms","DOIUrl":"https://doi.org/10.4043/31078-ms","url":null,"abstract":"\u0000 The Ærfugl field is close to the existing Skarv development located in Norwegian Sea, making it a tie-back opportunity. The hydrate management and operational savings were major drivers for the subsea system design requiring the use of an electrically heated trace flowline (EHTF).\u0000 The scope of this paper is to present how the EHTF technology has been further developed, qualified and industrialized during the execution of the Ærfugl project. It will also illustrate how a unique collaborative model between an Operator, an SPS Contractor and an EPCI Contractor contributed to the delivery of the first heated Pipe in Pipe system on a sizable project.\u0000 Starting from a conceptual technology selection to the project delivery, numerous qualifications were performed to validate the EHTFsystem design and ease its industrialization. The development of a new technology starts from the component design through system qualification up to the installation phase. It is of prime importance that all the different phases of the system life cycle are equally considered, as being interdependent. By using this holistic design approach right from the start of the qualification phase, the final product eventually meets all the requirements, from the component specification to the system performance.\u0000 The collaborative model in place on the Ærfugl project allowed the efficient integration of the Operator at each different step of the design, qualification and industrialization process resulting in delivery schedule savings when compared to a conventional project delivery approach. Several important development activities took place during the Ærfugl project and the holistic design approach backed by robust system engineering processes enabled a smooth and efficient workflow supporting the onshore fabrication and offshore installation readiness activities.\u0000 Several fabrication challenges were overcome during the project to safely deliver the EHTF solution with a continuous focus on quality and this paper will also cover the most relevant ones.\u0000 Following the Ærfugl project execution, the EHTF technology, supported by a unique collaborative model with the operator, is now fully qualified, and deployed offshore based on robust and reliable manufacturing and installation methods.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"202 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83554541","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}
Paraffin buildup is a fact of life in many oil and gas production fields. When downhole reservoirs lose pressure or temperature, paraffin precipitates and builds up on everything from pipe to valves to instrumentation to the walls in vessels. This buildup slows the process, constricts lines, and clogs instruments. Chemical treatments to keep paraffin from precipitating out of the fluid are widely known, but expensive. In addition to treating the liquid, producers should also consider treating the devices in the flow line to resist buildup. This paper will show how using nano-material to treat surfaces of components in the flow line—such as sensitive instruments, vessels, meters, valves—can slow or stop the buildup of these contaminants. By changing the bonding energy of the surface metal, these nano surface treatments hinder the ability of contaminants to adhere to a surface. These treatments do not affect mechanical, optical, or electrical properties of the treated devices. The discussion will include technical differences between a "coating" and "surface treatment" and the impact of these differences on a flow process. The paper will highlight environments that are best suited for these nano surface treatments and the different application methods available for treating devices. Data will showcase the performance of nano surface treatments in common applications, such as Coriolis meters, turbine meters, valves, flow and level devices. Producers have seen significant extension in the functional life of these devices and achieved significant operational savings. The paper will discuss how this data applies to other applications such as vessels, chemical reactors, filters, and more. In conclusion, nano-materials offer new and novel ways to maintain flow through valves, sensitive instruments, and other critical components in a flow line. Surface treatments, using nano-materials are easily applied, have a permanent effect on the surface energy of the metal, and do not hinder the optical, mechanical, or electrical properties of treated devices. Benefits of these treatments include reduced maintenance downtime and cost, improved performance of critical instrumentation and increased reliability of flow meters and valves.
{"title":"Using Nano-Materials to Change Metal Surface Characteristics and Slow the Buildup of Paraffins, Asphaltenes and Other Oil-Based Contaminants","authors":"A. Patil, Todd A Mathias, Sharon Drees","doi":"10.4043/30926-ms","DOIUrl":"https://doi.org/10.4043/30926-ms","url":null,"abstract":"\u0000 Paraffin buildup is a fact of life in many oil and gas production fields. When downhole reservoirs lose pressure or temperature, paraffin precipitates and builds up on everything from pipe to valves to instrumentation to the walls in vessels. This buildup slows the process, constricts lines, and clogs instruments. Chemical treatments to keep paraffin from precipitating out of the fluid are widely known, but expensive. In addition to treating the liquid, producers should also consider treating the devices in the flow line to resist buildup.\u0000 This paper will show how using nano-material to treat surfaces of components in the flow line—such as sensitive instruments, vessels, meters, valves—can slow or stop the buildup of these contaminants. By changing the bonding energy of the surface metal, these nano surface treatments hinder the ability of contaminants to adhere to a surface. These treatments do not affect mechanical, optical, or electrical properties of the treated devices.\u0000 The discussion will include technical differences between a \"coating\" and \"surface treatment\" and the impact of these differences on a flow process. The paper will highlight environments that are best suited for these nano surface treatments and the different application methods available for treating devices. Data will showcase the performance of nano surface treatments in common applications, such as Coriolis meters, turbine meters, valves, flow and level devices. Producers have seen significant extension in the functional life of these devices and achieved significant operational savings. The paper will discuss how this data applies to other applications such as vessels, chemical reactors, filters, and more.\u0000 In conclusion, nano-materials offer new and novel ways to maintain flow through valves, sensitive instruments, and other critical components in a flow line. Surface treatments, using nano-materials are easily applied, have a permanent effect on the surface energy of the metal, and do not hinder the optical, mechanical, or electrical properties of treated devices. Benefits of these treatments include reduced maintenance downtime and cost, improved performance of critical instrumentation and increased reliability of flow meters and valves.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"75 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89530288","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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