Mattia Paolo Bergamini, M. Chiavico, L. Bracco, A. Moglia, M. Buffagni
The Water Balance Assessment is a methodological approach developed and applied by Eni for the identification of improvements in water management at site level. The approach is based on three steps. The following report describes each step and the application of the approach to a real case study in Tunisia. Water is a vital resource for our planet and for humankind. Biodiversity and ecosystems’ preservation, human health, and food security as well as energy production, industrial development and economic growth are all dependent on water. The consequences of climate change and the actual projections of increasing water demand will affect water availability and quality in the coming years. About the Oil & Gas sector, this industry consumes and produces significant volumes of water. For this reason, energy companies must consider sustainable options for the use of this resource, especially in water stress areas. This can be achieved through:A deep knowledge of the site water streams and of the context where the site is located.Identification of improvements and initiatives that could reduce the water risk of the site. About water safeguarding, Eni is committed to pursue the following practices:Water Conservation: Upstream Oil & Gas operations need significant quantities of water; a key element for its conservation includes the reduction of withdrawals and the efficiency in water use.Water Reuse and Valorization: Upstream Oil & Gas operations must manage large volumes of wastewater, mainly Produced Water. Design solutions shall introduce and maximize the recycle of water with the adoption of suitable treatments, to make discharges compatible with the reuse in the same production cycle or by third parties (e.g., other plants, local communities), and pursue the opportunity to reuse industrial water, instead of discharging it as wastewater. For their deployment, Eni has defined and applied a methodological approach to support the definition of improvement and optimization initiatives of water management at the site level. The approach represents an application of a "convergence approach" which, starting from an overall view of the site, identifies opportunities, further and more detailed areas of analysis, and design projects that can improve water use, management, and reuse. The methodological approach is based on the following steps:A country-based framework study on water resources, and water-related risks analysis at country and local level.A Water Balance Assessment, gathering water qualitative and quantitative information and site framework details.Definition of site initiatives for wastewater reuse and valorization, and for the optimization of water withdrawals, based on the above steps and considering local legislation. Through this approach, operational water risks exposure is analyzed in detail, allowing to address a wide range of opportunities for the improvement of water management, also through the development of new synergies with
{"title":"Water Balance Assessment for Water Management in Oil & Gas Operations: A Methodological Approach","authors":"Mattia Paolo Bergamini, M. Chiavico, L. Bracco, A. Moglia, M. Buffagni","doi":"10.2118/207448-ms","DOIUrl":"https://doi.org/10.2118/207448-ms","url":null,"abstract":"\u0000 The Water Balance Assessment is a methodological approach developed and applied by Eni for the identification of improvements in water management at site level. The approach is based on three steps. The following report describes each step and the application of the approach to a real case study in Tunisia.\u0000 Water is a vital resource for our planet and for humankind. Biodiversity and ecosystems’ preservation, human health, and food security as well as energy production, industrial development and economic growth are all dependent on water. The consequences of climate change and the actual projections of increasing water demand will affect water availability and quality in the coming years. About the Oil & Gas sector, this industry consumes and produces significant volumes of water. For this reason, energy companies must consider sustainable options for the use of this resource, especially in water stress areas. This can be achieved through:A deep knowledge of the site water streams and of the context where the site is located.Identification of improvements and initiatives that could reduce the water risk of the site.\u0000 About water safeguarding, Eni is committed to pursue the following practices:Water Conservation: Upstream Oil & Gas operations need significant quantities of water; a key element for its conservation includes the reduction of withdrawals and the efficiency in water use.Water Reuse and Valorization: Upstream Oil & Gas operations must manage large volumes of wastewater, mainly Produced Water. Design solutions shall introduce and maximize the recycle of water with the adoption of suitable treatments, to make discharges compatible with the reuse in the same production cycle or by third parties (e.g., other plants, local communities), and pursue the opportunity to reuse industrial water, instead of discharging it as wastewater.\u0000 For their deployment, Eni has defined and applied a methodological approach to support the definition of improvement and optimization initiatives of water management at the site level. The approach represents an application of a \"convergence approach\" which, starting from an overall view of the site, identifies opportunities, further and more detailed areas of analysis, and design projects that can improve water use, management, and reuse.\u0000 The methodological approach is based on the following steps:A country-based framework study on water resources, and water-related risks analysis at country and local level.A Water Balance Assessment, gathering water qualitative and quantitative information and site framework details.Definition of site initiatives for wastewater reuse and valorization, and for the optimization of water withdrawals, based on the above steps and considering local legislation.\u0000 Through this approach, operational water risks exposure is analyzed in detail, allowing to address a wide range of opportunities for the improvement of water management, also through the development of new synergies with ","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"28 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74609067","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}
Effective project management plays a crucial role to the success of organizations via resilient execution of activities, in terms of performance and efficiency. Due to the recent market dynamics and its associated uncertainties, affecting several segments in the oil and gas (O&G) industry, utilization of innovative contracting schemes such as Front End Engineering Design (FEED) competition, and value engineered products are becoming of great importance to achieve the project's goals optimally. This paper discusses the competitiveness and strategic benefits of employing the vendor's pre-engineered and standardized turbomachinery equipment/solutions, to meet the required functionality while maintaining the highest levels of quality and safety. Several project management concepts and tools were employed, such as SWOT analysis, to discuss the benefits of supplying vendor's pre-engineered high value and long-lead turbomachinery equipment within projects, as a cost-effective solution, in place of customized products. A Requirements-to-Implementation Mapping (RIM) exercise was also carried out to benchmark the pre-engineered solutions with the industry practices while considering the packaging requirements from well-known international and national oil companies. This paper also presents success stories of implementing pre-engineered solutions that strongly contributed in improving the management of projects from engineering to operational phase. This study works in line with the recent O&G operators’ initiatives in promoting agile approach to mitigate the forces that are impacting the industry and in turn the economy, such as COVID-19 pandemic. The study analysis, employing semi-quantitative approach, revealed that the pre-engineered solution brings to customers an improved value proposition in terms of cost, delivery, quality, safety, and aftermarket support, which contributes greatly in minimizing gold plating to achieve leaner projects. Standardized equipment is also found to be effective in minimizing the risks associated with changes and therefore improving the control on project constraints as well as simplifying the purchasing management of strategic equipment. In this respect, the use of standardization and pre-engineered activities could lead to a reduction of lead time up to 30%. The reliability of the standardized equipment will also be increased due to the proven frozen designs which have been repeatedly manufactured, tested, and supplied and therefore ensures successful and seamless project close-out. The proposed approach of mixing pre-engineered commodities to customized and configurable features based on site conditions provides the proper flexibility required by O&G industry while, simultaneously, maximizing the benefits of standardization. The strategic benefits of pre-engineered turbomachinery packages in the context of project management and supply chain process is not well recognized. This study explains these benefits to incr
{"title":"Pre-Engineered Standardized Turbomachinery Solutions: A Strategic Approach to Lean Project Management","authors":"A. Khalaf, Maher Ayed, Gianni Acquisti, E. Rizzo","doi":"10.2118/207304-ms","DOIUrl":"https://doi.org/10.2118/207304-ms","url":null,"abstract":"\u0000 Effective project management plays a crucial role to the success of organizations via resilient execution of activities, in terms of performance and efficiency. Due to the recent market dynamics and its associated uncertainties, affecting several segments in the oil and gas (O&G) industry, utilization of innovative contracting schemes such as Front End Engineering Design (FEED) competition, and value engineered products are becoming of great importance to achieve the project's goals optimally. This paper discusses the competitiveness and strategic benefits of employing the vendor's pre-engineered and standardized turbomachinery equipment/solutions, to meet the required functionality while maintaining the highest levels of quality and safety.\u0000 Several project management concepts and tools were employed, such as SWOT analysis, to discuss the benefits of supplying vendor's pre-engineered high value and long-lead turbomachinery equipment within projects, as a cost-effective solution, in place of customized products. A Requirements-to-Implementation Mapping (RIM) exercise was also carried out to benchmark the pre-engineered solutions with the industry practices while considering the packaging requirements from well-known international and national oil companies. This paper also presents success stories of implementing pre-engineered solutions that strongly contributed in improving the management of projects from engineering to operational phase. This study works in line with the recent O&G operators’ initiatives in promoting agile approach to mitigate the forces that are impacting the industry and in turn the economy, such as COVID-19 pandemic.\u0000 The study analysis, employing semi-quantitative approach, revealed that the pre-engineered solution brings to customers an improved value proposition in terms of cost, delivery, quality, safety, and aftermarket support, which contributes greatly in minimizing gold plating to achieve leaner projects. Standardized equipment is also found to be effective in minimizing the risks associated with changes and therefore improving the control on project constraints as well as simplifying the purchasing management of strategic equipment. In this respect, the use of standardization and pre-engineered activities could lead to a reduction of lead time up to 30%. The reliability of the standardized equipment will also be increased due to the proven frozen designs which have been repeatedly manufactured, tested, and supplied and therefore ensures successful and seamless project close-out. The proposed approach of mixing pre-engineered commodities to customized and configurable features based on site conditions provides the proper flexibility required by O&G industry while, simultaneously, maximizing the benefits of standardization.\u0000 The strategic benefits of pre-engineered turbomachinery packages in the context of project management and supply chain process is not well recognized. This study explains these benefits to incr","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"217 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72805025","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. A. Al Mesaabi, G. Cambois, J. Cowell, D. Arnold, Mohamed Fawzi Boukhanfra, Saeed Hamad Al Karbi, M. Mahgoub, Khalid Obaid
In 2017 ADNOC decided to cover the entire Abu Dhabi Emirate, onshore and offshore, with high- resolution and high-fold 3D seismic. Acquisition of the world's largest continuous seismic survey started in late 2018 and is around 77% complete at the time of writing. Data processing is well under way and interpretation of the first delivered 3D cubes is ongoing. Now is an opportune time to review the status of this gigantic project and draw preliminary lessons. Comparison with legacy data shows a massive improvement in deep imaging, which was one of the main objectives of this survey. The basement can clearly be interpreted, while it is hardly visible on legacy data being covered with high energy multiples. A thorough analysis demonstrated that increased offset is the main reason for the uplift. The large fold and the low frequency sweep also help recover signal down to 3 Hz. This extends the bandwidth in the low frequencies by one to two octaves compared to legacy data, which tremendously benefits structural interpretation and stratigraphic inversion.
{"title":"Lessons Learned From the World's Largest Continuous Onshore and Offshore 3D Seismic Survey","authors":"S. A. Al Mesaabi, G. Cambois, J. Cowell, D. Arnold, Mohamed Fawzi Boukhanfra, Saeed Hamad Al Karbi, M. Mahgoub, Khalid Obaid","doi":"10.2118/208009-ms","DOIUrl":"https://doi.org/10.2118/208009-ms","url":null,"abstract":"\u0000 In 2017 ADNOC decided to cover the entire Abu Dhabi Emirate, onshore and offshore, with high- resolution and high-fold 3D seismic. Acquisition of the world's largest continuous seismic survey started in late 2018 and is around 77% complete at the time of writing. Data processing is well under way and interpretation of the first delivered 3D cubes is ongoing. Now is an opportune time to review the status of this gigantic project and draw preliminary lessons.\u0000 Comparison with legacy data shows a massive improvement in deep imaging, which was one of the main objectives of this survey. The basement can clearly be interpreted, while it is hardly visible on legacy data being covered with high energy multiples. A thorough analysis demonstrated that increased offset is the main reason for the uplift. The large fold and the low frequency sweep also help recover signal down to 3 Hz. This extends the bandwidth in the low frequencies by one to two octaves compared to legacy data, which tremendously benefits structural interpretation and stratigraphic inversion.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"15 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77162715","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 discusses how the application of large, gas turbine-based power blocks (>50,000-hp) in pipeline compression stations can contribute to lower capital costs, improved lifecycle performance, and reduced carbon emissions. For illustrative purposes, two compression facility power block configurations (nine 30,0000-hp trains vs. five 55,000-hp trains) are compared on the basis of capital expenditures (CapEx), operating expenditures (OpEx), availability, efficiency, and operating flexibility. A summary of the study's results are as follows: – Net present value (NPV) analyses show that 5x55,000-hp ISO trains can result in up to $50 million reduction in CAPEX vs 9x30,000-hp ISO trains – By having fewer trains, operations & maintenance (O&M) costs can be reduced by as much as 20% – Lifetime fuel savings with a 5x55,000-hp train configuration vs. 9x30,000-hp trains are estimated at $40 million, owing to the increased operating flexibility of modern gas turbines, even at partial loads. The paper will also present considerations for digitalization, modular construction, and package integration – with a particular focus on how these measures can be leveraged to lower execution risk and enhance the lifecycle performance of gas turbine-driven compression trains.
{"title":"Evaluating Small vs. Large Power Blocks for Pipeline Compression Stations","authors":"Gautam Chhibber, Mayank Kumar Dave","doi":"10.2118/207479-ms","DOIUrl":"https://doi.org/10.2118/207479-ms","url":null,"abstract":"\u0000 This paper discusses how the application of large, gas turbine-based power blocks (>50,000-hp) in pipeline compression stations can contribute to lower capital costs, improved lifecycle performance, and reduced carbon emissions. For illustrative purposes, two compression facility power block configurations (nine 30,0000-hp trains vs. five 55,000-hp trains) are compared on the basis of capital expenditures (CapEx), operating expenditures (OpEx), availability, efficiency, and operating flexibility. A summary of the study's results are as follows:\u0000 – Net present value (NPV) analyses show that 5x55,000-hp ISO trains can result in up to $50 million reduction in CAPEX vs 9x30,000-hp ISO trains – By having fewer trains, operations & maintenance (O&M) costs can be reduced by as much as 20% – Lifetime fuel savings with a 5x55,000-hp train configuration vs. 9x30,000-hp trains are estimated at $40 million, owing to the increased operating flexibility of modern gas turbines, even at partial loads.\u0000 The paper will also present considerations for digitalization, modular construction, and package integration – with a particular focus on how these measures can be leveraged to lower execution risk and enhance the lifecycle performance of gas turbine-driven compression trains.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"17 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77989103","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
In recent years, the global buckling assessment of offshore pipelines in High Pressure-High Temperature (HPHT) condition become increasingly challenging since more complex pipeline system arrangement e.g. pipe(s) or cable(s) is strapped onto a larger pipeline, are rapidly utilized in many areas. Yet, the detailed guideline to assess the buckle of bundles remains unclear, therefore this study will focus to investigate on a methodical and reproducible approach to analyze in-service buckling behavior of bundled offshore pipeline system. The global buckling behavior of bundled offshore pipeline system in this study is investigated using commercial Finite Element (FE) software. Two carbon steel pipelines with different diameter are bundled and the buckling behavior is studied under the influence of buckle triggers. In the actual condition, the rogue buckle trigger is generated from OOS (out of straightness) or imperfection e.g. due to laying tolerance. Varying dimension parameter such as diameter ratio between the main pipeline and strapped pipeline are considered to understand the impact of this parameter on the buckle behavior. The study begins with a comparison of the results using numerical and analytical approaches on a straight pipeline in an unbuckled condition for validation purposes. The design parameters including wall thickness, process data, and pipe-soil interaction data, are varied since it influences the buckle behavior. In addition, some design parameter such as material properties and pipeline length will be adopted from a typical offshore pipeline project and the values are fixed so the exercise can focus on the most governing parameters. Following this, two numerical modelling methods, the equivalent properties method and the connector method, are presented in this study to simulate bundled systems. With a good agreement between the analytical and numerical approach, some buckle trigger is introduced on the numerical model of the bundled pipeline so the system is able to buckle and the behavior can be evaluated further. The strain level, lateral displacement, axial feed-in and pipe integrity shall be reported in the post-buckle conditions for both main pipe and strapped pipe as per current code and standard requirement. With more reliable results of buckling assessment for bundled pipeline system, it gives technical confidence and a major saving in both Capital Expenditure (CAPEX) and Operational Expenditure (OPEX). Industry has put serious effort through various Joint Industry Projects (JIP) to develop the global buckling assessment guideline in order to ensure long term integrity operation. Although the JIP guideline is predominantly for single pipeline system, similar assessment is demanded also for bundled pipeline system which described in this study. Key findings of the assessment are presented along with an overview of the design process and the typical mitigation techniques to be considered for similar subsea pipeline proj
{"title":"Global Buckling Characteristics of Offshore Bundled Pipeline System","authors":"D. Yurindatama, Nawin Singh, Vinod Pillai","doi":"10.2118/207223-ms","DOIUrl":"https://doi.org/10.2118/207223-ms","url":null,"abstract":"\u0000 In recent years, the global buckling assessment of offshore pipelines in High Pressure-High Temperature (HPHT) condition become increasingly challenging since more complex pipeline system arrangement e.g. pipe(s) or cable(s) is strapped onto a larger pipeline, are rapidly utilized in many areas. Yet, the detailed guideline to assess the buckle of bundles remains unclear, therefore this study will focus to investigate on a methodical and reproducible approach to analyze in-service buckling behavior of bundled offshore pipeline system. The global buckling behavior of bundled offshore pipeline system in this study is investigated using commercial Finite Element (FE) software. Two carbon steel pipelines with different diameter are bundled and the buckling behavior is studied under the influence of buckle triggers. In the actual condition, the rogue buckle trigger is generated from OOS (out of straightness) or imperfection e.g. due to laying tolerance. Varying dimension parameter such as diameter ratio between the main pipeline and strapped pipeline are considered to understand the impact of this parameter on the buckle behavior. The study begins with a comparison of the results using numerical and analytical approaches on a straight pipeline in an unbuckled condition for validation purposes. The design parameters including wall thickness, process data, and pipe-soil interaction data, are varied since it influences the buckle behavior. In addition, some design parameter such as material properties and pipeline length will be adopted from a typical offshore pipeline project and the values are fixed so the exercise can focus on the most governing parameters. Following this, two numerical modelling methods, the equivalent properties method and the connector method, are presented in this study to simulate bundled systems. With a good agreement between the analytical and numerical approach, some buckle trigger is introduced on the numerical model of the bundled pipeline so the system is able to buckle and the behavior can be evaluated further. The strain level, lateral displacement, axial feed-in and pipe integrity shall be reported in the post-buckle conditions for both main pipe and strapped pipe as per current code and standard requirement. With more reliable results of buckling assessment for bundled pipeline system, it gives technical confidence and a major saving in both Capital Expenditure (CAPEX) and Operational Expenditure (OPEX). Industry has put serious effort through various Joint Industry Projects (JIP) to develop the global buckling assessment guideline in order to ensure long term integrity operation. Although the JIP guideline is predominantly for single pipeline system, similar assessment is demanded also for bundled pipeline system which described in this study. Key findings of the assessment are presented along with an overview of the design process and the typical mitigation techniques to be considered for similar subsea pipeline proj","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"45 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76375096","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 presents the latest developments in Transport and Installation methods for Topsides up to 38,500mt. For such heavy-weight structures Boskalis introduces a solution by combining the beneficial features of a Heavy Transport Vessel dry-transportation with the advantages of a DP2 Barge float-over installation. This unique Transport and Installation approach, a so called "Piggyback T&I", may be characterized as follows:
{"title":"Upscaling Float-over Installation","authors":"Rory van Doorn, Sebastiaan Polkamp","doi":"10.2118/207741-ms","DOIUrl":"https://doi.org/10.2118/207741-ms","url":null,"abstract":"\u0000 This paper presents the latest developments in Transport and Installation methods for Topsides up to 38,500mt.\u0000 For such heavy-weight structures Boskalis introduces a solution by combining the beneficial features of a Heavy Transport Vessel dry-transportation with the advantages of a DP2 Barge float-over installation.\u0000 This unique Transport and Installation approach, a so called \"Piggyback T&I\", may be characterized as follows:","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80239963","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}
As COVID-19 quickly spread across the globe to reach pandemic levels, companies across every industry had to quickly adapt their business practices to allow employees to connect virtually and work remotely. This addressed new complications in several areas, including contact tracing. This paper reviews an approach that Siemens Energy took to remove the errors and inefficiencies in manually conducting contact tracing by automating the process using an end-to-end case manager app. The app, which provides full transparency, analytics, and support, fully digitizes contact tracing from each employee's mobile device or computer. We discuss the features of the app, how it has been used in the UAE region, and the benefits that the company has realized in automating contact tracing—including faster tracing time, improved accuracy, and greater compliance with UAE COVID requirements. In just a few months’ time, the app went from an idea to a fully-developed and widely used application—which is now approved for use in company facilities and business units around the world.
{"title":"COVID-19 Case Manager App for Oil & Gas Companies","authors":"Shamrose Yaqoob, Salman Ali Khan","doi":"10.2118/207329-ms","DOIUrl":"https://doi.org/10.2118/207329-ms","url":null,"abstract":"\u0000 As COVID-19 quickly spread across the globe to reach pandemic levels, companies across every industry had to quickly adapt their business practices to allow employees to connect virtually and work remotely. This addressed new complications in several areas, including contact tracing. This paper reviews an approach that Siemens Energy took to remove the errors and inefficiencies in manually conducting contact tracing by automating the process using an end-to-end case manager app.\u0000 The app, which provides full transparency, analytics, and support, fully digitizes contact tracing from each employee's mobile device or computer. We discuss the features of the app, how it has been used in the UAE region, and the benefits that the company has realized in automating contact tracing—including faster tracing time, improved accuracy, and greater compliance with UAE COVID requirements.\u0000 In just a few months’ time, the app went from an idea to a fully-developed and widely used application—which is now approved for use in company facilities and business units around the world.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"45 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79742370","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}
Analysis of 15 years results of remote occupational health care in oil and gas production industries. Continuous observation, statistical analysis of morbidity, mortality, and treatment results in industrial personnel at different endpoints depending on the variability of care models. Cost-efficacy analysis of several occupational health interventions. Targeted polls of Customers. Dynamics of new Customers. The best practices which provide the maximum efficacy include risk assessment and risk management, action planning for emergencies, telemedicine, education, registry maintenance. Each of all these gave a 10-100-fold rise in Customer satisfaction, seriously improved medical statistics. Telemedicine implies both: the delivery of highly specialized diagnostic technologies directly to the industrial production site, where a GP or paramedic is present, and it implements the direct replacement of medics with gadgets at the patient's bedside. Education involves hands-on training for both industrial personnel at remote sites and for medical professionals who provide care. The 2020-21 COVID19 pandemic was a great real stress test for remote health models when systemic integrated management procedures played a pivotal role in ensuring smooth industry operation due to the high quality of back medical services. Modern efficient models of medical care for remote industries are necessarily comprehensive, modular, adaptive, and rely on personnel health registers. Remote health practices gain a 5-15% rise in price every year, but it pays off in greater labor productivity and in improving the health of industry personnel.
{"title":"Offshore Health Innovations","authors":"K. Logunov, S. Antipov, A. Karpov","doi":"10.2118/207945-ms","DOIUrl":"https://doi.org/10.2118/207945-ms","url":null,"abstract":"\u0000 \u0000 \u0000 Analysis of 15 years results of remote occupational health care in oil and gas production industries.\u0000 \u0000 \u0000 \u0000 Continuous observation, statistical analysis of morbidity, mortality, and treatment results in industrial personnel at different endpoints depending on the variability of care models. Cost-efficacy analysis of several occupational health interventions. Targeted polls of Customers. Dynamics of new Customers.\u0000 \u0000 \u0000 \u0000 The best practices which provide the maximum efficacy include risk assessment and risk management, action planning for emergencies, telemedicine, education, registry maintenance. Each of all these gave a 10-100-fold rise in Customer satisfaction, seriously improved medical statistics. Telemedicine implies both: the delivery of highly specialized diagnostic technologies directly to the industrial production site, where a GP or paramedic is present, and it implements the direct replacement of medics with gadgets at the patient's bedside. Education involves hands-on training for both industrial personnel at remote sites and for medical professionals who provide care. The 2020-21 COVID19 pandemic was a great real stress test for remote health models when systemic integrated management procedures played a pivotal role in ensuring smooth industry operation due to the high quality of back medical services.\u0000 \u0000 \u0000 \u0000 Modern efficient models of medical care for remote industries are necessarily comprehensive, modular, adaptive, and rely on personnel health registers. Remote health practices gain a 5-15% rise in price every year, but it pays off in greater labor productivity and in improving the health of industry personnel.\u0000","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"23 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89683251","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}
W. Liew, El Khalil Mohamed M’Bareck Heboul, Mohamad Shahril Majid Bin Allapitchai, S. Sellapan, Ahmad Luqman Bin Johan, Ahmad Hafizi Bin Ahmad Zaini, Mohd Hairi Bin Abdul Razak, Puteri Dharmilla Syafawati Binti Dharma Dian, Ahmad Zharif Bin Abdullah, William Zomerdijk
Wells plug & abandonment was carried out in a deepwater field (Field C) offshore West Africa. There were 15 deepwater subsea wells in this field. Thirteen of the wells were completed with Open Water Vertical Xmas Tree (OXT) while remaining two were completed with Enhanced Vertical Xmas Tree (EVXT). In the wells with Open Water Vertical Xmas Tree (OXT), the upper completion tubing and hanger were ran together with the Xmas Tree in a single run. This posed challenges to Operator in retrieving the Xmas Tree. This paper will discuss the novel approach used by Operator in the OXT retrieval. Due to the design of OXT which was different from most of the vertical Xmas Trees (XT) in the world, there were a few challenges in the process of XTs retrieval. If the XTs and upper completion tubing were retrieved in reversal of the way it was completed, it will exposed the well to prolonged duration of single barrier until a BOP can be latched on for subsequent activities. On top of that, the Original Equipment Manufacturer's Completion Workover Riser (CWOR) system and Support Landing Structure (SLS) was not available in full package to be utilized in this project. Furthermore, there were constraints on the rig moonpool space, handling of OXT on surface and clashes between the rig's BOP and existing subsea structures. In managing the risk of well exposure to single proven and monitored barrier during the process of OXT retrieval, Operator has evaluated a few options and came out with a novel approach in the OXT retrieval which managed to minimize exposure time and reduce risk in operations. In contrary to the original principle of well completion here, after a barrier was established in the well, the OXTs was retrieved separately from the upper completion tubing to allow rig BOP to be latched onto wellhead in shortest possible time. To achieve this objective, operations was planned to be carried out on a dual activity derrick rig. Meanwhile, a non-OEM rental CWOR system was used together with Tree Running Tool from the OEM CWOR system to access the wells for intervention work and subsequently retrieve the OXTs. By doing this, the combined CWOR stack exceeded the height limitation at the rig's moonpool. Some modifications were carried out to allow the operations to happen. A novel approach was also used to handle the OXT on surface without the OEM Support Landing Structure - which simplified the operations and reduced HSE risks. Solution was also put into place to enable latching of the rig BOP onto wellheads on Drill Centre although there were risk of clashing initially.
{"title":"A Novel Approach to First in the World Retrieval of Open Water Vertical Xmas Tree","authors":"W. Liew, El Khalil Mohamed M’Bareck Heboul, Mohamad Shahril Majid Bin Allapitchai, S. Sellapan, Ahmad Luqman Bin Johan, Ahmad Hafizi Bin Ahmad Zaini, Mohd Hairi Bin Abdul Razak, Puteri Dharmilla Syafawati Binti Dharma Dian, Ahmad Zharif Bin Abdullah, William Zomerdijk","doi":"10.2118/207376-ms","DOIUrl":"https://doi.org/10.2118/207376-ms","url":null,"abstract":"\u0000 Wells plug & abandonment was carried out in a deepwater field (Field C) offshore West Africa. There were 15 deepwater subsea wells in this field. Thirteen of the wells were completed with Open Water Vertical Xmas Tree (OXT) while remaining two were completed with Enhanced Vertical Xmas Tree (EVXT). In the wells with Open Water Vertical Xmas Tree (OXT), the upper completion tubing and hanger were ran together with the Xmas Tree in a single run. This posed challenges to Operator in retrieving the Xmas Tree. This paper will discuss the novel approach used by Operator in the OXT retrieval.\u0000 Due to the design of OXT which was different from most of the vertical Xmas Trees (XT) in the world, there were a few challenges in the process of XTs retrieval. If the XTs and upper completion tubing were retrieved in reversal of the way it was completed, it will exposed the well to prolonged duration of single barrier until a BOP can be latched on for subsequent activities. On top of that, the Original Equipment Manufacturer's Completion Workover Riser (CWOR) system and Support Landing Structure (SLS) was not available in full package to be utilized in this project. Furthermore, there were constraints on the rig moonpool space, handling of OXT on surface and clashes between the rig's BOP and existing subsea structures.\u0000 In managing the risk of well exposure to single proven and monitored barrier during the process of OXT retrieval, Operator has evaluated a few options and came out with a novel approach in the OXT retrieval which managed to minimize exposure time and reduce risk in operations. In contrary to the original principle of well completion here, after a barrier was established in the well, the OXTs was retrieved separately from the upper completion tubing to allow rig BOP to be latched onto wellhead in shortest possible time. To achieve this objective, operations was planned to be carried out on a dual activity derrick rig. Meanwhile, a non-OEM rental CWOR system was used together with Tree Running Tool from the OEM CWOR system to access the wells for intervention work and subsequently retrieve the OXTs. By doing this, the combined CWOR stack exceeded the height limitation at the rig's moonpool. Some modifications were carried out to allow the operations to happen. A novel approach was also used to handle the OXT on surface without the OEM Support Landing Structure - which simplified the operations and reduced HSE risks. Solution was also put into place to enable latching of the rig BOP onto wellheads on Drill Centre although there were risk of clashing initially.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"32 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88147506","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 is based on successful implementation of procedural automation of Ethane (C2) recovery - rejection mode change using Yokogawa's Exapilot software, wherein ADNONC Gas Processing Habshan 5 & Sulphur management approved the implementation based on similar success of the Sulphur Recover Unit start-up/shutdown procedural automation & company's drive for digitalisation. Scope was to develop modules for automating C2 Recovery /Rejection change over procedure in NGL unit using M/s Yokogawa Exapilot software. These automated procedures aimed to standardize said mode change over operations by incorporating the operating know how and the expertise of skilled-experienced operators into the Exapilot system as a set of Standard Operating Procedures (SOPs) that are executed in right operating sequence for enhanced operating efficiency. Two main procedures & associated modules were designed, engineered and built using Exapilot to enable single-click change over automation for NGL units. Those were validated with operation and deployed in the Exapilot Server and were integrated with the Operator Consoles (HIS) for access, and was supplemented with operator training. Ethane Recovery to Rejection Mode Change Ethane Rejection to Recovery Mode Change Besides standardization and reduced change over time, this improved the critical asset integrity and lifespan of NGL section equipment by advocating systematic operations. Following benefits including major take away from this project: ➢ Standardized the mode change-over procedures & minimized human error by the digitalization of paper documentation procedures into electronic workflow process. Procedural Automation like Exapilot is powerful tool for digital transformation of batch/discrete operation like unit/equipment start-up/shutdown or grade/mode change over. ➢ Reduced inherent delay due to manual change over. Hence, minimizing the loss-opportunities & operating cost. Besides this tool can be used as training tool (when used in offline mode) which help operator succession plan & effective knowledge transfer ➢ Automated critical operation such as temperature/flow ramping, improved equipment integrity and prolonged equipment life. Procedural Automation using Exapilot thus can improve operation efficiency, asset integrity, equipment or material life span This paper presents a success story of procedural automation of batch operation in continuation of similar success in SRU start-up & shutdown automation. This tool along with proper integration work with DCS, has opened door for automation/digitalization in batch operation in continuous process not only in other sites of ADNOC Gas Processing and other ADNOC Group Companies but also in other industries that helps companies to enhance efficiency and fulfil their digitalization journey. Though Exapilot software belongs to M/s Yokogawa, however other DCS systems have similar software such as Honeywell DCS EPKS has E-procedure for procedural automation.
{"title":"Procedural Automation of Ethane Recovery to Rejection in NGL Trains","authors":"Subhendu Sengupta, Vincent Goveas","doi":"10.2118/208159-ms","DOIUrl":"https://doi.org/10.2118/208159-ms","url":null,"abstract":"\u0000 This paper is based on successful implementation of procedural automation of Ethane (C2) recovery - rejection mode change using Yokogawa's Exapilot software, wherein ADNONC Gas Processing Habshan 5 & Sulphur management approved the implementation based on similar success of the Sulphur Recover Unit start-up/shutdown procedural automation & company's drive for digitalisation.\u0000 Scope was to develop modules for automating C2 Recovery /Rejection change over procedure in NGL unit using M/s Yokogawa Exapilot software.\u0000 These automated procedures aimed to standardize said mode change over operations by incorporating the operating know how and the expertise of skilled-experienced operators into the Exapilot system as a set of Standard Operating Procedures (SOPs) that are executed in right operating sequence for enhanced operating efficiency.\u0000 Two main procedures & associated modules were designed, engineered and built using Exapilot to enable single-click change over automation for NGL units. Those were validated with operation and deployed in the Exapilot Server and were integrated with the Operator Consoles (HIS) for access, and was supplemented with operator training.\u0000 Ethane Recovery to Rejection Mode Change Ethane Rejection to Recovery Mode Change\u0000 Besides standardization and reduced change over time, this improved the critical asset integrity and lifespan of NGL section equipment by advocating systematic operations.\u0000 Following benefits including major take away from this project:\u0000 ➢ Standardized the mode change-over procedures & minimized human error by the digitalization of paper documentation procedures into electronic workflow process. Procedural Automation like Exapilot is powerful tool for digital transformation of batch/discrete operation like unit/equipment start-up/shutdown or grade/mode change over. ➢ Reduced inherent delay due to manual change over. Hence, minimizing the loss-opportunities & operating cost. Besides this tool can be used as training tool (when used in offline mode) which help operator succession plan & effective knowledge transfer ➢ Automated critical operation such as temperature/flow ramping, improved equipment integrity and prolonged equipment life. Procedural Automation using Exapilot thus can improve operation efficiency, asset integrity, equipment or material life span\u0000 This paper presents a success story of procedural automation of batch operation in continuation of similar success in SRU start-up & shutdown automation. This tool along with proper integration work with DCS, has opened door for automation/digitalization in batch operation in continuous process not only in other sites of ADNOC Gas Processing and other ADNOC Group Companies but also in other industries that helps companies to enhance efficiency and fulfil their digitalization journey. Though Exapilot software belongs to M/s Yokogawa, however other DCS systems have similar software such as Honeywell DCS EPKS has E-procedure for procedural automation.","PeriodicalId":10959,"journal":{"name":"Day 3 Wed, November 17, 2021","volume":"20 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-12-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84424802","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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