James Olivier Blaringhem, Andy Woolgar, A. Gates, Phil Bishop, Mike Clare, A. Flohr, C. Sands, A. Lichtschlag
BORA Blue Ocean Research Alliance® aims to advance scientific knowledge of the ocean through integrating science into routine offshore operations and data collection, done in parallel to commercial work and as automated as possible. This can be through integration of novel sensors, deployment of scientific research equipment or through recognising where valuable data can be derived from other operational information. To achieve this requires deep understanding of the types of work carried out by each alliance party. BORA Blue Ocean Research Alliance® is science focussed, increasing global reach for ocean observation into areas in which Subsea7 are operating. Fundamental to the scientific value of each project is to ensure that derived data are openly accessible and aim to meet FAIR data standards (Findable, Accessible, Interoperable, Reusable), so that the findings can be re-analysed in future or contribute to wider assessments of ocean health. Building on the blend of Subsea7's global deep-water reach and the breadth of science of NOC, BORA Blue Ocean Research Alliance® is delivering new marine research on a global scale not possible before, from shallow to deep water, expanding knowledge for the benefit of society.
{"title":"Offshore Industry and Research Community Collaborating to Enable Greater Ocean Access for Scientific Research","authors":"James Olivier Blaringhem, Andy Woolgar, A. Gates, Phil Bishop, Mike Clare, A. Flohr, C. Sands, A. Lichtschlag","doi":"10.4043/32289-ms","DOIUrl":"https://doi.org/10.4043/32289-ms","url":null,"abstract":"\u0000 BORA Blue Ocean Research Alliance® aims to advance scientific knowledge of the ocean through integrating science into routine offshore operations and data collection, done in parallel to commercial work and as automated as possible. This can be through integration of novel sensors, deployment of scientific research equipment or through recognising where valuable data can be derived from other operational information. To achieve this requires deep understanding of the types of work carried out by each alliance party.\u0000 BORA Blue Ocean Research Alliance® is science focussed, increasing global reach for ocean observation into areas in which Subsea7 are operating. Fundamental to the scientific value of each project is to ensure that derived data are openly accessible and aim to meet FAIR data standards (Findable, Accessible, Interoperable, Reusable), so that the findings can be re-analysed in future or contribute to wider assessments of ocean health.\u0000 Building on the blend of Subsea7's global deep-water reach and the breadth of science of NOC, BORA Blue Ocean Research Alliance® is delivering new marine research on a global scale not possible before, from shallow to deep water, expanding knowledge for the benefit of society.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123053928","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 will study the LNG Transport opportunities from the Canadian Arctic to the Asian markets. Mackenzie Delta LNG (MDLNG) project is in the Canada's Northwest Territories (NWT) which contains publicly owned conventional natural gas reserves which could be developed for export that would provide immediate economic benefit to the Inuvialuit Settlement Region, NWT and Canada. This paper presents the results of a feasibility study undertaken to evaluate the shipping routes and ice conditions along the route from the Arctic to the Asian LNG markets. Arctic LNG carriers have been in use in the Russian Arctic for years already and we have been deeply involved in the design, development, and testing of those current LNG carriers. Russian rules are somewhat different and thus the operations would commence in Canada and US waters that would give some opportunities in the LNG Carrier design as well. In this paper we will go through the general differences in the LNG carriers design for MDLNG. Currently the plan is to build gravity-based structure (GBS) to the offshore MacKenzie Delta. The GBS would need additional ice management support and vessels. In this paper we would talk about ice management vessels needed to support the operations for loading the LNG carriers as well as talk about the recommended ice management operations. With modern technology, good design and planning, it can be shown that the LNG transportation by ships is a feasible solution compared to building pipelines across the Arctic.
{"title":"Mackenzie Delta LNG Transport and Ice Management Study","authors":"J. Salminen, Robert Hindley, S. Saarinen","doi":"10.4043/32302-ms","DOIUrl":"https://doi.org/10.4043/32302-ms","url":null,"abstract":"\u0000 This paper will study the LNG Transport opportunities from the Canadian Arctic to the Asian markets.\u0000 Mackenzie Delta LNG (MDLNG) project is in the Canada's Northwest Territories (NWT) which contains publicly owned conventional natural gas reserves which could be developed for export that would provide immediate economic benefit to the Inuvialuit Settlement Region, NWT and Canada.\u0000 This paper presents the results of a feasibility study undertaken to evaluate the shipping routes and ice conditions along the route from the Arctic to the Asian LNG markets. Arctic LNG carriers have been in use in the Russian Arctic for years already and we have been deeply involved in the design, development, and testing of those current LNG carriers. Russian rules are somewhat different and thus the operations would commence in Canada and US waters that would give some opportunities in the LNG Carrier design as well. In this paper we will go through the general differences in the LNG carriers design for MDLNG. Currently the plan is to build gravity-based structure (GBS) to the offshore MacKenzie Delta. The GBS would need additional ice management support and vessels. In this paper we would talk about ice management vessels needed to support the operations for loading the LNG carriers as well as talk about the recommended ice management operations.\u0000 With modern technology, good design and planning, it can be shown that the LNG transportation by ships is a feasible solution compared to building pipelines across the Arctic.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125008150","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 Oil and Gas industry the Subsea Pipeline Repair Connectors have been developed to provide an effective sealing and installation on damaged or leaking pipelines. This paper presents a verification methodology for Subsea Pipeline Repair to confirm a product design compliance to DNV standards. It also introduces a case study for detailed design and qualification program approach for subsea pipeline repair connector to mitigate installation and operational risks. The purpose is to assist industry to mitigate operational risks and enhance safety. As a case study, recently a type approval certification has been issued to a client for its subsea pipeline repair connector. This paper presents a risk based method towards verification of pipeline repair system, and it is focused on risk based methodology to address potential failure modes. The approach to address structural, sealing and gripping functions of the connector is discussed. DNV standards related to verification of pipeline connectors are also described in the paper. Through this paper, the potential failure modes are discussed and the design verification process is described for the subsea pipeline repair connectors. The type approval process is introduced which consists of independent design review, sample testing and verification of quality controls. The results prove the approach is effective to assist the designer to bridge the gaps, mitigate the risks, provide the integrated solutions and enhance safety. Furthermore, the end user shall be benefit for mitigating the effects of unplanned repairs, improving the field’s uptime and restoring production quickly. The novelty of this paper is the risk based verification of the pipeline repair connectors, which cost effectively helps identifying and mitigating the risks associated with failure modes and optimize the design of the pipeline repair system.
{"title":"Risk Based Verification for Subsea Pipeline Repair Connectors and a Case Study","authors":"Simon Ouyang, Fei Tang, M. Shavandi, Chen Cheng","doi":"10.4043/32412-ms","DOIUrl":"https://doi.org/10.4043/32412-ms","url":null,"abstract":"\u0000 In Oil and Gas industry the Subsea Pipeline Repair Connectors have been developed to provide an effective sealing and installation on damaged or leaking pipelines. This paper presents a verification methodology for Subsea Pipeline Repair to confirm a product design compliance to DNV standards. It also introduces a case study for detailed design and qualification program approach for subsea pipeline repair connector to mitigate installation and operational risks. The purpose is to assist industry to mitigate operational risks and enhance safety.\u0000 As a case study, recently a type approval certification has been issued to a client for its subsea pipeline repair connector. This paper presents a risk based method towards verification of pipeline repair system, and it is focused on risk based methodology to address potential failure modes. The approach to address structural, sealing and gripping functions of the connector is discussed. DNV standards related to verification of pipeline connectors are also described in the paper.\u0000 Through this paper, the potential failure modes are discussed and the design verification process is described for the subsea pipeline repair connectors. The type approval process is introduced which consists of independent design review, sample testing and verification of quality controls. The results prove the approach is effective to assist the designer to bridge the gaps, mitigate the risks, provide the integrated solutions and enhance safety. Furthermore, the end user shall be benefit for mitigating the effects of unplanned repairs, improving the field’s uptime and restoring production quickly.\u0000 The novelty of this paper is the risk based verification of the pipeline repair connectors, which cost effectively helps identifying and mitigating the risks associated with failure modes and optimize the design of the pipeline repair system.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131462896","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. Aguiar, Laura Lima Angelo dos Santos, J. P. Tocantins, Jodi Ross, Rafael Meda, Shashank Garg
In Brazil, pre-salt assets account for 70% of the national oil and gas production. Even after 15 years of Brazilian pre-salt exploration and development, modelling these complex reservoirs remains a challenging and uncertain task. With such high geological uncertainty, drilling campaigns experience unplanned bottomhole-assembly (BHA) trips due to severe shock and vibration, low rate of penetration (ROP), and premature polycrystalline diamond compact (PDC) drill-bit cutting structure damage. This paper presents a case study of the successful use of an acoustic logging-while-drilling (LWD) borehole image log for drilling optimization. The ultrasonic image was acquired at high-resolution (0.2 in.), displaying clear rock formation textural and hardness variations. These contrasts are the key for understanding and simulation of drill bit-rock interaction; therefore, using the high-resolution LWD borehole image log has the potential to optimize and reduce uncertainty in the operator's upcoming drilling campaign.
{"title":"Using LWD Borehole Image Iinterpretation for Drilling Optimization: A Brazilian Pre-Salt Case Study","authors":"R. Aguiar, Laura Lima Angelo dos Santos, J. P. Tocantins, Jodi Ross, Rafael Meda, Shashank Garg","doi":"10.4043/32549-ms","DOIUrl":"https://doi.org/10.4043/32549-ms","url":null,"abstract":"\u0000 In Brazil, pre-salt assets account for 70% of the national oil and gas production. Even after 15 years of Brazilian pre-salt exploration and development, modelling these complex reservoirs remains a challenging and uncertain task. With such high geological uncertainty, drilling campaigns experience unplanned bottomhole-assembly (BHA) trips due to severe shock and vibration, low rate of penetration (ROP), and premature polycrystalline diamond compact (PDC) drill-bit cutting structure damage.\u0000 This paper presents a case study of the successful use of an acoustic logging-while-drilling (LWD) borehole image log for drilling optimization. The ultrasonic image was acquired at high-resolution (0.2 in.), displaying clear rock formation textural and hardness variations. These contrasts are the key for understanding and simulation of drill bit-rock interaction; therefore, using the high-resolution LWD borehole image log has the potential to optimize and reduce uncertainty in the operator's upcoming drilling campaign.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131772603","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}
Sean A. Murray, Clara Casanovas, Z. Tan, Euan Trousdale, Jian Liu, Juliana Patrocinio, Linfa Zhu, Mario Augusto Lopes de Castro
Due to their non-linear bending response, low bending stiffness and potentially high axial expansion coefficients, buried unbonded flexible pipes can be susceptible to Upheaval Buckling (UHB). The traditional industry approach is to prevent UHB by providing sufficient download to limit upwards movement of the pipe to very small levels (normally within the mobilisation distance of the soil). Since unbonded flexible pipes offer little resistance to bending, the required download to prevent UHB of unbonded flexible pipes can be significant resulting in prohibitive rock-dump requirements. However, by design, unbonded flexible pipes can accommodate large bending deformations without compromising the cross-sectional integrity of the pipe. The objective of this paper is to propose an approach which takes advantage of the pipes capability to accommodate large deformations and to minimize download requirements. This paper presents a comprehensive literature review of the state-of-the-art methods currently adopted in industry for the assessment of UHB of buried unbonded flexible pipelines. An alternative approach which permits significant upwards movement of the flexible pipe, taking advantage of the pipes ability to accommodate such movements, is also presented. A comparison of the potential failure modes, mechanisms and consequences associated with these approaches are studied and acceptance criteria are proposed. Parametric finite element analysis studies are performed to compare the flexible pipe behaviour and download requirements using the traditional approach and the proposed alternative approach. This paper presents case studies which demonstrate that significant savings in the volume of rock-dump can be safely made when permitting large deformations when compared to the traditional UHB prevention approach.
{"title":"Upheaval Buckling of Unbonded Flexible Pipes: An Alternative Approach","authors":"Sean A. Murray, Clara Casanovas, Z. Tan, Euan Trousdale, Jian Liu, Juliana Patrocinio, Linfa Zhu, Mario Augusto Lopes de Castro","doi":"10.4043/32279-ms","DOIUrl":"https://doi.org/10.4043/32279-ms","url":null,"abstract":"\u0000 Due to their non-linear bending response, low bending stiffness and potentially high axial expansion coefficients, buried unbonded flexible pipes can be susceptible to Upheaval Buckling (UHB). The traditional industry approach is to prevent UHB by providing sufficient download to limit upwards movement of the pipe to very small levels (normally within the mobilisation distance of the soil). Since unbonded flexible pipes offer little resistance to bending, the required download to prevent UHB of unbonded flexible pipes can be significant resulting in prohibitive rock-dump requirements. However, by design, unbonded flexible pipes can accommodate large bending deformations without compromising the cross-sectional integrity of the pipe. The objective of this paper is to propose an approach which takes advantage of the pipes capability to accommodate large deformations and to minimize download requirements.\u0000 This paper presents a comprehensive literature review of the state-of-the-art methods currently adopted in industry for the assessment of UHB of buried unbonded flexible pipelines. An alternative approach which permits significant upwards movement of the flexible pipe, taking advantage of the pipes ability to accommodate such movements, is also presented. A comparison of the potential failure modes, mechanisms and consequences associated with these approaches are studied and acceptance criteria are proposed. Parametric finite element analysis studies are performed to compare the flexible pipe behaviour and download requirements using the traditional approach and the proposed alternative approach.\u0000 This paper presents case studies which demonstrate that significant savings in the volume of rock-dump can be safely made when permitting large deformations when compared to the traditional UHB prevention approach.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130554359","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}
Marcelo B Rosa, Israel Bruno da Silva Orrico, L. D. A. H. Neto, L. F. Rocha, Daniel Henrique Liberal de Moura
Five years after Mero Field commercial declaration, around 200.000 bbl/d are being produced, with an expected production peak over 600.000 bbl/d to be reached in the next years. Successful results are being achieved with a reservoir-oriented strategy to minimize risks and maximize value. The main aspects of this strategy, which aims at attaining a recoverable oil volume of more than 3 billion barrels, is described in this work. Mero's development strategy combines two main phases: the first focused on data acquisition for definition of the global development plan and flexibilities necessary for further optimizations and the second focused on the plan implementation using the flexibilities to optimize results during deployment. On the first step, a development plan with four 180.000 bbl/d production systems and a FPSO of 50.000 bbl/d was conceived, with produced high CO2 content gas full reinjection (WAG) as the recovery method. However, relevant reservoir uncertainties remained, which required actions for guaranteeing that risks could be mitigated and opportunities could be seized during the projects’ execution. Some of the applied strategies were: an itinerant EWT unit allocated on main dynamic uncertainty areas, the anticipation of a few development wells in strategical reservoir positions, the use of flexible EPCI contracts allowing a range of possible flowlines extension acquisition, and an integrated multidisciplinary rigs schedule using preceding wells data to define next locations final position. Anticipated wells along with EWTs were important to appraise critical reservoir regions and to verify communication between different reservoir zones. Seismic data improvements enabled a better reservoir characterization. However, only during the second phase of the above-mentioned development strategy, using all the gathered information together was it possible to identify in a more precise manner relevant aspects, such as the presence and location of igneous bodies in the reservoir zone, a new area of the reservoir to be drained, and the aquifer characteristics. With knowledge evolution, reducing uncertainties and confirming opportunities, changes in drainage plan were then accomplished after FID, using the EPCI flexibilities milestones, defining the final wellhead locations and well trajectories closer to each project's first oil. The first three Mero projects have already gone through this optimization process with expected gains up to two hundred million barrels of additional oil recovery. A balance between audacious strategies for project and profit acceleration and flexibility strategies for path correction and optimization has been fundamental for the development of complex fields, such as the pre-salt ones. The strategy herein presented is leading to a successful development of Mero Field and may be used for the development of other offshore projects to maximize recovery and economics.
{"title":"Mero Giant Field: A Successful Case of Recovery Optimization During Development","authors":"Marcelo B Rosa, Israel Bruno da Silva Orrico, L. D. A. H. Neto, L. F. Rocha, Daniel Henrique Liberal de Moura","doi":"10.4043/32450-ms","DOIUrl":"https://doi.org/10.4043/32450-ms","url":null,"abstract":"\u0000 Five years after Mero Field commercial declaration, around 200.000 bbl/d are being produced, with an expected production peak over 600.000 bbl/d to be reached in the next years. Successful results are being achieved with a reservoir-oriented strategy to minimize risks and maximize value. The main aspects of this strategy, which aims at attaining a recoverable oil volume of more than 3 billion barrels, is described in this work.\u0000 Mero's development strategy combines two main phases: the first focused on data acquisition for definition of the global development plan and flexibilities necessary for further optimizations and the second focused on the plan implementation using the flexibilities to optimize results during deployment. On the first step, a development plan with four 180.000 bbl/d production systems and a FPSO of 50.000 bbl/d was conceived, with produced high CO2 content gas full reinjection (WAG) as the recovery method. However, relevant reservoir uncertainties remained, which required actions for guaranteeing that risks could be mitigated and opportunities could be seized during the projects’ execution.\u0000 Some of the applied strategies were: an itinerant EWT unit allocated on main dynamic uncertainty areas, the anticipation of a few development wells in strategical reservoir positions, the use of flexible EPCI contracts allowing a range of possible flowlines extension acquisition, and an integrated multidisciplinary rigs schedule using preceding wells data to define next locations final position. Anticipated wells along with EWTs were important to appraise critical reservoir regions and to verify communication between different reservoir zones. Seismic data improvements enabled a better reservoir characterization. However, only during the second phase of the above-mentioned development strategy, using all the gathered information together was it possible to identify in a more precise manner relevant aspects, such as the presence and location of igneous bodies in the reservoir zone, a new area of the reservoir to be drained, and the aquifer characteristics. With knowledge evolution, reducing uncertainties and confirming opportunities, changes in drainage plan were then accomplished after FID, using the EPCI flexibilities milestones, defining the final wellhead locations and well trajectories closer to each project's first oil. The first three Mero projects have already gone through this optimization process with expected gains up to two hundred million barrels of additional oil recovery.\u0000 A balance between audacious strategies for project and profit acceleration and flexibility strategies for path correction and optimization has been fundamental for the development of complex fields, such as the pre-salt ones. The strategy herein presented is leading to a successful development of Mero Field and may be used for the development of other offshore projects to maximize recovery and economics.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115101120","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}
José Rincon, Ivan Greenlee, Russell Hamerski, Joseph Rayborn, Jacob Schexnayder, Elena Tran
In 2009, the Vito field was discovered in more than 4,000 ft of water approximately 150 miles offshore from New Orleans, Louisiana. The project produces from reservoirs nearly 30,000 feet below sea level. This paper outlines the approach taken to develop the Vito facilities operating model (Operating Model) and prepare for start-up and ramp-up. This paper is part of a Vito Project series at OTC 2023, and the other papers are listed in the references. In 2015 the project faced significant financial hurdles and went through a refresh of the concept design to reduce cost and simplify while maintaining safety as a top priority. This re-design resulted in reduced redundancy and operational flexibility including reducing host personnel on board (POB) capacity to 60 personnel. To prepare to start-up and operate the facility with this simplified design, a proactive approach was adopted across four key areas: Operating Model, maintenance strategy, digital building blocks, and start-up ramp-up (SURU) planning. An Operating Model was developed to enable efficient execution of maintenance and operations activities with the reduced POB. This model leverages multiskilling of onsite personnel and enabling digital technologies. The limited POB necessitated development of a maintenance strategy that is both lean and comprehensive with high utilization of the base crew. With local performance standards as the foundation of the strategy, a Reliability Centered Maintenance (RCM) study was performed to validate and further optimize the defined strategy, which relies heavily on asst specific maintenance tasks and onshore sparing due to minimal redundancy and space on host for spares. Digital Twin technology has been leveraged to create a virtual mirror image of the Vito facility that is a central repository of equipment data and documentation. This enables virtual planning of work which reduces POB needs by providing the ability to perform walkdowns, take measurements and identify access issues without being on site. Augmented reality technology supplements this by streaming the viewpoint of offshore staff directly to onshore teams to perform troubleshooting, diagnose issues, and inspect without requiring physical presence. To manage well start-up and to optimize long term recovery, a start-up ramp-up model was implemented with a focus on proactive actions to optimize start-up. This led to long term lease of onshore caverns to eliminate requirements for temporary unloading equipment during start-up. A phased commissioning and start-up plan was developed with gas buyback brought on ahead of well start-up to pressure up vessels and commission compressors. Additionally, a real time simulator was built to test procedures, train personnel and walkthrough the start-up plan.
{"title":"Vito Operating Model & Start-Up Ramp Up (SURU)","authors":"José Rincon, Ivan Greenlee, Russell Hamerski, Joseph Rayborn, Jacob Schexnayder, Elena Tran","doi":"10.4043/32496-ms","DOIUrl":"https://doi.org/10.4043/32496-ms","url":null,"abstract":"\u0000 In 2009, the Vito field was discovered in more than 4,000 ft of water approximately 150 miles offshore from New Orleans, Louisiana. The project produces from reservoirs nearly 30,000 feet below sea level. This paper outlines the approach taken to develop the Vito facilities operating model (Operating Model) and prepare for start-up and ramp-up. This paper is part of a Vito Project series at OTC 2023, and the other papers are listed in the references.\u0000 In 2015 the project faced significant financial hurdles and went through a refresh of the concept design to reduce cost and simplify while maintaining safety as a top priority. This re-design resulted in reduced redundancy and operational flexibility including reducing host personnel on board (POB) capacity to 60 personnel. To prepare to start-up and operate the facility with this simplified design, a proactive approach was adopted across four key areas: Operating Model, maintenance strategy, digital building blocks, and start-up ramp-up (SURU) planning.\u0000 An Operating Model was developed to enable efficient execution of maintenance and operations activities with the reduced POB. This model leverages multiskilling of onsite personnel and enabling digital technologies. The limited POB necessitated development of a maintenance strategy that is both lean and comprehensive with high utilization of the base crew. With local performance standards as the foundation of the strategy, a Reliability Centered Maintenance (RCM) study was performed to validate and further optimize the defined strategy, which relies heavily on asst specific maintenance tasks and onshore sparing due to minimal redundancy and space on host for spares.\u0000 Digital Twin technology has been leveraged to create a virtual mirror image of the Vito facility that is a central repository of equipment data and documentation. This enables virtual planning of work which reduces POB needs by providing the ability to perform walkdowns, take measurements and identify access issues without being on site. Augmented reality technology supplements this by streaming the viewpoint of offshore staff directly to onshore teams to perform troubleshooting, diagnose issues, and inspect without requiring physical presence.\u0000 To manage well start-up and to optimize long term recovery, a start-up ramp-up model was implemented with a focus on proactive actions to optimize start-up. This led to long term lease of onshore caverns to eliminate requirements for temporary unloading equipment during start-up. A phased commissioning and start-up plan was developed with gas buyback brought on ahead of well start-up to pressure up vessels and commission compressors. Additionally, a real time simulator was built to test procedures, train personnel and walkthrough the start-up plan.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130638316","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 utilization of ordinary Portland cement (OPC) in well cementing is accompanied by technical and environmental problems, leading researchers to explore alternative materials that address these issues and promote eco-friendliness. Geopolymer technology, widely used in construction and other industries, has not yet been fully implemented in oil and gas well cementing. Industrial waste materials, such as Class F fly ash (FFA), can be utilized to improve cement properties or create new cement binders. Hematite is used as a weighting agent to increase cement slurry density. However, heavy particle sedimentation in cement and geopolymer slurries is a significant issue that leads to heterogenous properties along the cemented section. This study introduces a new class of geopolymers that use both hematite and Micromax as weighting materials for high-density well cementing applications. One system only used hematite, while the other used both hematite and Micromax in an effort to eliminate sedimentation issues associated with hematite in geopolymers. The effects of adding Micromax on different FFA geopolymer properties were also evaluated. The study evaluated mixability, rheology, and pumpability to determine the mix design, which was then used to examine other properties such as strength, and density variation. The results showed that adding Micromax to hematite reduced the average density variation from 12.5% to 3.9%. Micromax addition also decreased plastic viscosity by 44.5% and fluid loss by 10.5%. Both systems performed closely in terms of strength.
{"title":"High Density Geopolymers: A Step Forward Towards Low Carbon Footprint Cementing Operations","authors":"A. E. Abdelaal, S. Elkatatny","doi":"10.4043/32341-ms","DOIUrl":"https://doi.org/10.4043/32341-ms","url":null,"abstract":"\u0000 The utilization of ordinary Portland cement (OPC) in well cementing is accompanied by technical and environmental problems, leading researchers to explore alternative materials that address these issues and promote eco-friendliness. Geopolymer technology, widely used in construction and other industries, has not yet been fully implemented in oil and gas well cementing. Industrial waste materials, such as Class F fly ash (FFA), can be utilized to improve cement properties or create new cement binders. Hematite is used as a weighting agent to increase cement slurry density. However, heavy particle sedimentation in cement and geopolymer slurries is a significant issue that leads to heterogenous properties along the cemented section. This study introduces a new class of geopolymers that use both hematite and Micromax as weighting materials for high-density well cementing applications. One system only used hematite, while the other used both hematite and Micromax in an effort to eliminate sedimentation issues associated with hematite in geopolymers. The effects of adding Micromax on different FFA geopolymer properties were also evaluated. The study evaluated mixability, rheology, and pumpability to determine the mix design, which was then used to examine other properties such as strength, and density variation. The results showed that adding Micromax to hematite reduced the average density variation from 12.5% to 3.9%. Micromax addition also decreased plastic viscosity by 44.5% and fluid loss by 10.5%. Both systems performed closely in terms of strength.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134124058","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}
Andre luiz Bevilaqua Santana, E. Semedo, Jose Maria Castilho, P. T. Fernandes, Wendell Dias Pinto, Luis Carlos Eduardo Castro, William Albuquerque Da Silva
The collection of flexible pipelines and umbilicals in Petrobras covers a considerably high volume of operations. In particular, the growing demand for decommissioning, combined with the Diverless Synergy initiative, has boosted mobilization for the advancement and optimization of collection operations. Result of the integration between the different company sectors and assets involved, through the availability of resources, the process of development and evolution of tools that provide cost reduction and operational safety is presented in this article as we can see in the Motivation Plan (Fig.1)
{"title":"Challenges to Recover Subsea Umbilicals in Decommissioning Projects","authors":"Andre luiz Bevilaqua Santana, E. Semedo, Jose Maria Castilho, P. T. Fernandes, Wendell Dias Pinto, Luis Carlos Eduardo Castro, William Albuquerque Da Silva","doi":"10.4043/32214-ms","DOIUrl":"https://doi.org/10.4043/32214-ms","url":null,"abstract":"\u0000 The collection of flexible pipelines and umbilicals in Petrobras covers a considerably high volume of operations. In particular, the growing demand for decommissioning, combined with the Diverless Synergy initiative, has boosted mobilization for the advancement and optimization of collection operations. Result of the integration between the different company sectors and assets involved, through the availability of resources, the process of development and evolution of tools that provide cost reduction and operational safety is presented in this article as we can see in the Motivation Plan (Fig.1)","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129825759","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}
Incidents of loss of position for semi-sumersible vessels have been found to be caused by wave-drift loads. For a semi, the wave-drift loads can be significantly larger than predicted by conventional methods based on potential theory, due to viscous loads on the columns. In addition, the wave-drift load may increase due to the presence of current. A DP system will give much stronger damping than a mooring system of similar restoring stiffness. This will alter the characteristic of the vessel's low frequency motion, which will tend to be exponentially distributed. A consequence of this is that the extreme wave-driven vessel excursions will be large in comparison with the average motion. A marine operation can only be carried out provided the critical variables of response stay below given limits with a sufficiently large probability. To estimate probabilities of limit non-exceedance, simulation of 100 hours of vessel motion is carried out for a number of sea states. Weibull distributions are then fitted to the response data and further used for extreme value calculation. Although the processes of wave frequency (1st order, WF) motion and the low frequency (2nd-order, LF) wave-induced motion are totally different, Weibull distributions could successfully be fitted to the total (LF+WF) motion. The fitted Weibull distributions were close to the exponential distribution, which they should for a strongly damped vessel. From the Weibull distributions quantiles of vessel motion could be calculated for given probabilities of limit non-exceedance. Examples of how this information can be used in interrupt criteria for marine operations are given.
{"title":"Interrupt Criteria for DP-Operated Facilities","authors":"K. E. Kaasen, H. Ludvigsen, L. Bjørheim","doi":"10.4043/32457-ms","DOIUrl":"https://doi.org/10.4043/32457-ms","url":null,"abstract":"\u0000 Incidents of loss of position for semi-sumersible vessels have been found to be caused by wave-drift loads. For a semi, the wave-drift loads can be significantly larger than predicted by conventional methods based on potential theory, due to viscous loads on the columns. In addition, the wave-drift load may increase due to the presence of current.\u0000 A DP system will give much stronger damping than a mooring system of similar restoring stiffness. This will alter the characteristic of the vessel's low frequency motion, which will tend to be exponentially distributed. A consequence of this is that the extreme wave-driven vessel excursions will be large in comparison with the average motion.\u0000 A marine operation can only be carried out provided the critical variables of response stay below given limits with a sufficiently large probability. To estimate probabilities of limit non-exceedance, simulation of 100 hours of vessel motion is carried out for a number of sea states. Weibull distributions are then fitted to the response data and further used for extreme value calculation. Although the processes of wave frequency (1st order, WF) motion and the low frequency (2nd-order, LF) wave-induced motion are totally different, Weibull distributions could successfully be fitted to the total (LF+WF) motion. The fitted Weibull distributions were close to the exponential distribution, which they should for a strongly damped vessel.\u0000 From the Weibull distributions quantiles of vessel motion could be calculated for given probabilities of limit non-exceedance. Examples of how this information can be used in interrupt criteria for marine operations are given.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130179061","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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