H. Smit, Laurie Meyer, Adrian J. Flynn, G. van Eck, Giorgia Cecino
The Cook Islands (CI) possesses within its Exclusive Economic Zone (EEZ) a massive field of polymetallic nodules representing one of the world's largest undeveloped cobalt deposits, along with large quantities of other metals critical to achieving global energy transition targets. In February of 2022 the Seabed Minerals Authority (SBMA) of the CI granted licenses to three companies to conduct nodule exploration programs. This paper describes the process adopted by Moana Minerals, one of the license holders, to define new ways of conducting exploration which are focused on addressing the greatest challenge to Deep Sea Mining (DSM) development – that of securing the social license to advance to eventual mining of the resources. While it is generally true for any DSM project, obtaining license to operate within the EEZ of a sovereign nation requires even more focus on socio-economic and cultural concerns. Hence Moana Minerals invested even before exploration license award in the completion of an Environmental and Social Impact Assessment (ESIA) scoping study. This exercise helped to define the key questions and concerns, the range of stakeholders in the ESIA process, and began to construct the Ecosystem Based Model which is the heart of our ESIA program. We describe our employment of the increasingly adopted best practice of Ecosystem Based Management (EBM), which considers the entire ecosystem and its services, and the complex associated interactions for a "whole of system" approach. We discuss how this model is used to help communicate relationships between potential stressors associated with seabed mining and ecosystem responses, as well as how it is used to identify thresholds and guide development and adaptation of ecosystem management approaches. Given the challenges of the remoteness of the Cook Islands, limited exploration assets in the region, and ongoing supply chain delays and limitations, our early analysis of how best to execute an EBM-based program concluded that a dedicated research vessel properly outfitted with a full suite of scientific gear would be key to success. We describe our program to economically develop such an exploration system through repurposing an offshore support vessel, with an aim towards maximum suitability for Cook Islands-based exploration and other deep sea exploration work in the region as well as other potential high value regional applications. Finally, we discuss operations to date using this critical exploration-enabling asset.
{"title":"Enabling Ecosystem Based Management: New Ways to Conduct Deep Sea Minerals Exploration","authors":"H. Smit, Laurie Meyer, Adrian J. Flynn, G. van Eck, Giorgia Cecino","doi":"10.4043/32244-ms","DOIUrl":"https://doi.org/10.4043/32244-ms","url":null,"abstract":"\u0000 The Cook Islands (CI) possesses within its Exclusive Economic Zone (EEZ) a massive field of polymetallic nodules representing one of the world's largest undeveloped cobalt deposits, along with large quantities of other metals critical to achieving global energy transition targets. In February of 2022 the Seabed Minerals Authority (SBMA) of the CI granted licenses to three companies to conduct nodule exploration programs. This paper describes the process adopted by Moana Minerals, one of the license holders, to define new ways of conducting exploration which are focused on addressing the greatest challenge to Deep Sea Mining (DSM) development – that of securing the social license to advance to eventual mining of the resources.\u0000 While it is generally true for any DSM project, obtaining license to operate within the EEZ of a sovereign nation requires even more focus on socio-economic and cultural concerns. Hence Moana Minerals invested even before exploration license award in the completion of an Environmental and Social Impact Assessment (ESIA) scoping study. This exercise helped to define the key questions and concerns, the range of stakeholders in the ESIA process, and began to construct the Ecosystem Based Model which is the heart of our ESIA program. We describe our employment of the increasingly adopted best practice of Ecosystem Based Management (EBM), which considers the entire ecosystem and its services, and the complex associated interactions for a \"whole of system\" approach. We discuss how this model is used to help communicate relationships between potential stressors associated with seabed mining and ecosystem responses, as well as how it is used to identify thresholds and guide development and adaptation of ecosystem management approaches. Given the challenges of the remoteness of the Cook Islands, limited exploration assets in the region, and ongoing supply chain delays and limitations, our early analysis of how best to execute an EBM-based program concluded that a dedicated research vessel properly outfitted with a full suite of scientific gear would be key to success. We describe our program to economically develop such an exploration system through repurposing an offshore support vessel, with an aim towards maximum suitability for Cook Islands-based exploration and other deep sea exploration work in the region as well as other potential high value regional applications. Finally, we discuss operations to date using this critical exploration-enabling asset.","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":"117129667","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}
Minghe Zhang, Jin Yang, Qishuai Yin, Yu Song, Yuanming Wang, Yisu Zhou, Lei Li, Yuxiang Yang
Subsea wellhead stability is an important technical issue in deepwater and ultra-deepwater oil and gas drilling operations. Since the soil under mudline is mainly silt and clay with weak cementation, the vertical friction force and horizontal displacement provided by the surface conductor are limited. The mechanical properties of subsea wellhead, including displacement and stress, are mainly distributed near the mud line. The novel expandable surface conductor can effectively enhance the vertical bearing capacity and horizontal mechanical properties of the subsea wellhead by adding annular absorbent expansion materials to the conductor surface. In this paper, ABAQUS software was used to establish a numerical simulation model of the novel expandable surface conductor. Annular expansion material was installed on the upper, middle, and lower part of the surface conductor, respectively, to analyze its influence on the mechanical properties of the subsea wellhead. At the same time, the mechanical properties of the subsea wellhead of the conventional conductor and the novel expandable conductor are compared and analyzed. The results show that the novel expandable surface conductor arranged near the mudline can effectively enhance the lateral mechanical properties of the subsea wellhead, but has little effect on the vertical bearing capacity of the wellhead, which is mainly due to the weak soil properties near the mudline. The annular expansion material in the middle and lower part of the conductor has little influence on the lateral mechanical properties of the subsea wellhead, but it is more obvious to improve the vertical bearing capacity of the wellhead, which is because the mechanical properties of the deep formation below the mudline are strong, and the horizontal displacement and bending moment of the conduit will not be transmitted to a greater depth under the mudline. At the same time, the lower end part of the expansion material has obvious influence on the vertical bearing capacity of subsea wellhead. An exploratory study on the improvement of the mechanical properties of the subsea wellhead with the novel expandable surface conductor and basic rule is carried out through the numerical simulation method, which provides theoretical guidance for the subsequent industrial design and application of the novel expandable surface conductor.
{"title":"Numerical Simulation of Subsea Wellhead Bearing Capacity in Deepwater with Novel Expandable Surface Conductor Foundation","authors":"Minghe Zhang, Jin Yang, Qishuai Yin, Yu Song, Yuanming Wang, Yisu Zhou, Lei Li, Yuxiang Yang","doi":"10.4043/32618-ms","DOIUrl":"https://doi.org/10.4043/32618-ms","url":null,"abstract":"\u0000 Subsea wellhead stability is an important technical issue in deepwater and ultra-deepwater oil and gas drilling operations. Since the soil under mudline is mainly silt and clay with weak cementation, the vertical friction force and horizontal displacement provided by the surface conductor are limited. The mechanical properties of subsea wellhead, including displacement and stress, are mainly distributed near the mud line.\u0000 The novel expandable surface conductor can effectively enhance the vertical bearing capacity and horizontal mechanical properties of the subsea wellhead by adding annular absorbent expansion materials to the conductor surface. In this paper, ABAQUS software was used to establish a numerical simulation model of the novel expandable surface conductor. Annular expansion material was installed on the upper, middle, and lower part of the surface conductor, respectively, to analyze its influence on the mechanical properties of the subsea wellhead. At the same time, the mechanical properties of the subsea wellhead of the conventional conductor and the novel expandable conductor are compared and analyzed.\u0000 The results show that the novel expandable surface conductor arranged near the mudline can effectively enhance the lateral mechanical properties of the subsea wellhead, but has little effect on the vertical bearing capacity of the wellhead, which is mainly due to the weak soil properties near the mudline. The annular expansion material in the middle and lower part of the conductor has little influence on the lateral mechanical properties of the subsea wellhead, but it is more obvious to improve the vertical bearing capacity of the wellhead, which is because the mechanical properties of the deep formation below the mudline are strong, and the horizontal displacement and bending moment of the conduit will not be transmitted to a greater depth under the mudline. At the same time, the lower end part of the expansion material has obvious influence on the vertical bearing capacity of subsea wellhead.\u0000 An exploratory study on the improvement of the mechanical properties of the subsea wellhead with the novel expandable surface conductor and basic rule is carried out through the numerical simulation method, which provides theoretical guidance for the subsequent industrial design and application of the novel expandable surface conductor.","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":"122238340","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 Bureau of Ocean Energy Management (BOEM), an agency within the U.S. Department of the Interior, has responsibility over both energy and non-energy mineral development on the United States Outer Continental Shelf (OCS) under the OCS Lands Act ("OCSLA"). BOEM’s Marine Minerals Program (MMP) manages federal offshore mineral deposits through non-competitive, negotiated agreements for federal sand and gravel ("sand") used in coastal restoration efforts and the competitive leasing of critical and hard economic minerals ("critical minerals"). As the sole federal steward of OCS critical minerals, BOEM MMP is responsible for understanding where critical minerals are located, identifying and understanding their environments, managing activities that affect these resources, and implementing pertinent federal policies. Fulfilling these responsibilities involves the collection and analysis of environmental, geological, and geophysical data; supporting the science needed to understand the impacts of resource-related authorized activities on the biological, physical, and sociocultural environments; encouraging emerging technologies that can reduce the environmental impact of activities; and communicating with stakeholders to foster an understanding of existing federal regulations and potential needs to revise the legal framework. Four U.S. federal rules in the Code of Federal Regulations (CFR) currently inform MMP’s procedures: 30 CFR 580 (prospecting for minerals), 30 CFR 581 (leasing of minerals), 30 CFR 582 (operations in the OCS related to minerals), and 30 CFR 583 (negotiated noncompetitive agreements for sand). Other federal laws and regulations are also pertinent, particularly those supporting the National Environmental Policy Act, Endangered Species Act, National Historic Preservation Act, Marine Mammal Protection Act, Coastal Zone Management Act, Clean Air Act, Federal Water Pollution Control Act, and Magnuson Stevens Fishery Conservation and Management Act.
{"title":"Critical and Hard Minerals Management on the United States Outer Continental Shelf","authors":"P. Knorr","doi":"10.4043/32640-ms","DOIUrl":"https://doi.org/10.4043/32640-ms","url":null,"abstract":"\u0000 The Bureau of Ocean Energy Management (BOEM), an agency within the U.S. Department of the Interior, has responsibility over both energy and non-energy mineral development on the United States Outer Continental Shelf (OCS) under the OCS Lands Act (\"OCSLA\"). BOEM’s Marine Minerals Program (MMP) manages federal offshore mineral deposits through non-competitive, negotiated agreements for federal sand and gravel (\"sand\") used in coastal restoration efforts and the competitive leasing of critical and hard economic minerals (\"critical minerals\").\u0000 As the sole federal steward of OCS critical minerals, BOEM MMP is responsible for understanding where critical minerals are located, identifying and understanding their environments, managing activities that affect these resources, and implementing pertinent federal policies. Fulfilling these responsibilities involves the collection and analysis of environmental, geological, and geophysical data; supporting the science needed to understand the impacts of resource-related authorized activities on the biological, physical, and sociocultural environments; encouraging emerging technologies that can reduce the environmental impact of activities; and communicating with stakeholders to foster an understanding of existing federal regulations and potential needs to revise the legal framework.\u0000 Four U.S. federal rules in the Code of Federal Regulations (CFR) currently inform MMP’s procedures: 30 CFR 580 (prospecting for minerals), 30 CFR 581 (leasing of minerals), 30 CFR 582 (operations in the OCS related to minerals), and 30 CFR 583 (negotiated noncompetitive agreements for sand). Other federal laws and regulations are also pertinent, particularly those supporting the National Environmental Policy Act, Endangered Species Act, National Historic Preservation Act, Marine Mammal Protection Act, Coastal Zone Management Act, Clean Air Act, Federal Water Pollution Control Act, and Magnuson Stevens Fishery Conservation and Management Act.","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":"123202626","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 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 provides an overview of the Hull & Mooring system, executing a minimum technical scope to produce a simplistic design. This paper is part of a Vito Project series at OTC 2023, and the other papers are listed in the references. The original Vito project execution strategy was to replicate the Shell mega-project of Appomattox. As the industry and market began to change in 2015, the project faced significant financial hurdles, and the project team decided to refresh the design concept to reduce cost and simplify. The team regrouped to propose a smaller semi-submersible Floating Production System (FPS) with a simplistic mooring design. The Topsides was designed to be lifted as a single module, with a payload of less than 10,000 st to enable competitive tendering process. The redesigned FPS concept was moored with 12 taut, chain – polyester – chain mooring line system utilizing an in-line mooring tensioner, removing the traditional mechanically complicated and space demanding "on-vessel" winch systems. Vito employed a passive hull system, with all ballasting occurring over the top without hull penetrations. There were no pump rooms within the hull as equipment is accessed from top of column, removing the need for regular hull access to maintain equipment. The hull compartmentation also followed a simple approach, containing only 12 ballast tanks to reduce fabrication cost. The hull design also included simplified ring stiffening for columns which eliminated the traditional orthogonally stiffened systems. Additionally, the structure utilized an upper column frame structure to support the topsides deck and served as a bracing for supporting columns at the top for squeeze-pry loads and bracing for supporting columns during dry tow. The simplification of the stiffening system and topsides deck support design reduced interfaces between hull and topsides and also opened up options for fabrication of topsides and hull. Key challenges included developing installation methods without traditional FPS mooring chain jacks and increasing installation options by not requiring a large installation derrick barge and enabling use of common anchor handler vessels. The project experienced fabrication delays due to COVID-19, which required creative solutions transporting the FPS from Singapore to the Gulf of Mexico. The design team enabled the use of various heavy transportation vessels (HTV), ultimately settling on a smaller HTV modified with four 25 ft outriggers.
{"title":"Vito Project: Hull / Mooring Design & Platform Installation","authors":"Darin Johnson, C. Heyl, R. Kamal, Yile Li","doi":"10.4043/32503-ms","DOIUrl":"https://doi.org/10.4043/32503-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 provides an overview of the Hull & Mooring system, executing a minimum technical scope to produce a simplistic design. This paper is part of a Vito Project series at OTC 2023, and the other papers are listed in the references.\u0000 The original Vito project execution strategy was to replicate the Shell mega-project of Appomattox. As the industry and market began to change in 2015, the project faced significant financial hurdles, and the project team decided to refresh the design concept to reduce cost and simplify. The team regrouped to propose a smaller semi-submersible Floating Production System (FPS) with a simplistic mooring design. The Topsides was designed to be lifted as a single module, with a payload of less than 10,000 st to enable competitive tendering process.\u0000 The redesigned FPS concept was moored with 12 taut, chain – polyester – chain mooring line system utilizing an in-line mooring tensioner, removing the traditional mechanically complicated and space demanding \"on-vessel\" winch systems. Vito employed a passive hull system, with all ballasting occurring over the top without hull penetrations. There were no pump rooms within the hull as equipment is accessed from top of column, removing the need for regular hull access to maintain equipment. The hull compartmentation also followed a simple approach, containing only 12 ballast tanks to reduce fabrication cost. The hull design also included simplified ring stiffening for columns which eliminated the traditional orthogonally stiffened systems. Additionally, the structure utilized an upper column frame structure to support the topsides deck and served as a bracing for supporting columns at the top for squeeze-pry loads and bracing for supporting columns during dry tow. The simplification of the stiffening system and topsides deck support design reduced interfaces between hull and topsides and also opened up options for fabrication of topsides and hull.\u0000 Key challenges included developing installation methods without traditional FPS mooring chain jacks and increasing installation options by not requiring a large installation derrick barge and enabling use of common anchor handler vessels. The project experienced fabrication delays due to COVID-19, which required creative solutions transporting the FPS from Singapore to the Gulf of Mexico. The design team enabled the use of various heavy transportation vessels (HTV), ultimately settling on a smaller HTV modified with four 25 ft outriggers.","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":"122705399","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 King's Quay facility was fabricated and commissioned in South Korea and installed in the Gulf of Mexico to receive production from the Khaleesi, Mormont and Samurai fields. A mixture of project and operations personnel were tasked with executing deliverables to ensure a successful progression from engineering, construction, commissioning and operations to ultimately achieve first oil in April 2022. The facility design was based on an existing design already under operation, with modifications limited to improving safety and reliability and reducing emissions. The subsea umbilicals, risers and flowlines (SURF) contract was awarded to include mooring and installation work, minimizing interfaces and reducing risk exposure to the operator. Technical functions fell under one project delivery team, ensuring decisions were made based on the overall benefit to the project rather than individual disciplines. Operations were involved early on during the construction phase in South Korea, and took ownership to integrate improvements throughout the project lifecycle. Subsurface design allowed for a shift from single zone to commingled production to maximize net present value (NPV) and reduce well design complexity. SURF components were standardized as much as possible across all three fields to allow for flexibility during the installation phase. Between the on-site construction team and a strong cohort of local inspectors, the facility left the shipyard on schedule and 97% complete, with minimal carry-over work in the Gulf of Mexico, and over 3.5 million work hours without a lost time incident. With the project team relying on industry-standard designs and best practices, they were able to optimize cost, schedule and functionality based on fit-for-purpose equipment designs. The flexibility of installation allowed the minimizing of simultaneous operations (SIMOPS) between pipelay and drilling activities. In the event of SIMOPS, communication protocols were established and strictly followed, minimizing non-productive time. Murphy's King's Quay development achieved first oil in April 2022, less than three years after the project's final investment decision (FID). This paper will highlight the execution plan and lessons learned to maintain continuity through all phases of the project to deliver a facility and subsea infrastructure ahead of schedule while achieving 97% uptime, with production rates exceeding expectations within six months of start-up.
{"title":"The King's Quay Project – A Best Practice Model to Deliver Major Offshore Projects Ahead of Schedule and Under Budget","authors":"B. Arciero, R. James","doi":"10.4043/32159-ms","DOIUrl":"https://doi.org/10.4043/32159-ms","url":null,"abstract":"\u0000 The King's Quay facility was fabricated and commissioned in South Korea and installed in the Gulf of Mexico to receive production from the Khaleesi, Mormont and Samurai fields. A mixture of project and operations personnel were tasked with executing deliverables to ensure a successful progression from engineering, construction, commissioning and operations to ultimately achieve first oil in April 2022.\u0000 The facility design was based on an existing design already under operation, with modifications limited to improving safety and reliability and reducing emissions. The subsea umbilicals, risers and flowlines (SURF) contract was awarded to include mooring and installation work, minimizing interfaces and reducing risk exposure to the operator. Technical functions fell under one project delivery team, ensuring decisions were made based on the overall benefit to the project rather than individual disciplines. Operations were involved early on during the construction phase in South Korea, and took ownership to integrate improvements throughout the project lifecycle. Subsurface design allowed for a shift from single zone to commingled production to maximize net present value (NPV) and reduce well design complexity. SURF components were standardized as much as possible across all three fields to allow for flexibility during the installation phase.\u0000 Between the on-site construction team and a strong cohort of local inspectors, the facility left the shipyard on schedule and 97% complete, with minimal carry-over work in the Gulf of Mexico, and over 3.5 million work hours without a lost time incident. With the project team relying on industry-standard designs and best practices, they were able to optimize cost, schedule and functionality based on fit-for-purpose equipment designs. The flexibility of installation allowed the minimizing of simultaneous operations (SIMOPS) between pipelay and drilling activities. In the event of SIMOPS, communication protocols were established and strictly followed, minimizing non-productive time.\u0000 Murphy's King's Quay development achieved first oil in April 2022, less than three years after the project's final investment decision (FID). This paper will highlight the execution plan and lessons learned to maintain continuity through all phases of the project to deliver a facility and subsea infrastructure ahead of schedule while achieving 97% uptime, with production rates exceeding expectations within six months of start-up.","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":"127997295","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}
Mohammad Zarrin Mehr, D. Molyneux, Jennifer Smith, R. Pelot, F. Goerlandt, Robert Brown
Given the complexity of Search and Rescue (SAR) activities in the coastal regions of Eastern Canada and the Arctic, there is a need to objectively assess system capabilities at a high level to determine the expected rescue time for multiple scenarios and system configurations. This paper outlines a new macro-scale generalized SAR model to simulate the main activities within the SAR system in Eastern Canada and the Arctic. The model uses discrete event simulation to represent the SAR operations and a probabilistic Monte Carlo approach to incorporate uncertainties in performance data for the different components of the system. Algorithms are first developed to identify the major decision-relevant components of SAR response, including the time to interpret emergency notifications and mobilize helicopter resources, the operability of assets in given environmental conditions, and the proximity and capability of resources. Following this, the model is coded in MATLAB, using a time-stepping approach, enabling changes in the scenario, asset status, and system configuration at any time step. Case scenarios are used as initial verification, beginning with a simplistic approach, and building complexity in the model parameters. For this paper, we will discuss simple and complex scenarios which are based on common incident occurrences and SAR system operational details in eastern Canada's coastal regions and the Arctic. We assess the sensitivity of the overall SAR system to various input parameters to better understand how factors such as the Location of Incident (LOI) and number of People in Distress (PID) influence SAR response time in remote coastal areas, as well as the impact of refueling station locations for more distant and longer duration scenarios.
{"title":"A Macro-Scale Generalized Search and Rescue (SAR) Model for the Coastal Regions of Eastern Canada and the Arctic","authors":"Mohammad Zarrin Mehr, D. Molyneux, Jennifer Smith, R. Pelot, F. Goerlandt, Robert Brown","doi":"10.4043/32486-ms","DOIUrl":"https://doi.org/10.4043/32486-ms","url":null,"abstract":"\u0000 Given the complexity of Search and Rescue (SAR) activities in the coastal regions of Eastern Canada and the Arctic, there is a need to objectively assess system capabilities at a high level to determine the expected rescue time for multiple scenarios and system configurations. This paper outlines a new macro-scale generalized SAR model to simulate the main activities within the SAR system in Eastern Canada and the Arctic. The model uses discrete event simulation to represent the SAR operations and a probabilistic Monte Carlo approach to incorporate uncertainties in performance data for the different components of the system. Algorithms are first developed to identify the major decision-relevant components of SAR response, including the time to interpret emergency notifications and mobilize helicopter resources, the operability of assets in given environmental conditions, and the proximity and capability of resources. Following this, the model is coded in MATLAB, using a time-stepping approach, enabling changes in the scenario, asset status, and system configuration at any time step. Case scenarios are used as initial verification, beginning with a simplistic approach, and building complexity in the model parameters.\u0000 For this paper, we will discuss simple and complex scenarios which are based on common incident occurrences and SAR system operational details in eastern Canada's coastal regions and the Arctic. We assess the sensitivity of the overall SAR system to various input parameters to better understand how factors such as the Location of Incident (LOI) and number of People in Distress (PID) influence SAR response time in remote coastal areas, as well as the impact of refueling station locations for more distant and longer duration scenarios.","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":"131275617","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}
M. Abdi, M. Paulin, T. King, Chad Fowlow, David Robbins
This paper presents opportunities and challenges associated with a natural gas pipeline from offshore to a proposed LNG facility onshore/nearshore Newfoundland. Pipelines offshore Newfoundland to landfall have been studied for almost four decades but none have been constructed to date. Challenges include design methodology, protection from icebergs and trenching technology to afford that protection. Evaluation of icebergs gouging the seabed and the impact on such a pipeline are presented and evaluated. Potential pipeline routing has been assessed to minimize risk of direct contact from a gouging iceberg keel. Risks to the pipeline may come from direct contact or through subgouge deformation beneath the keel. Risk was evaluated using an iceberg subsea contact model, updated to reflect the current iceberg regime, developed as part of an ongoing project titled "Subsea Ice Interaction Barrier to Energy Development (SIIBED)". The paper also touches on aspects of a gas gathering system and regulatory considerations.
{"title":"A Grand Banks Gas Pipeline; Opportunities and Challenges","authors":"M. Abdi, M. Paulin, T. King, Chad Fowlow, David Robbins","doi":"10.4043/32616-ms","DOIUrl":"https://doi.org/10.4043/32616-ms","url":null,"abstract":"\u0000 This paper presents opportunities and challenges associated with a natural gas pipeline from offshore to a proposed LNG facility onshore/nearshore Newfoundland. Pipelines offshore Newfoundland to landfall have been studied for almost four decades but none have been constructed to date. Challenges include design methodology, protection from icebergs and trenching technology to afford that protection.\u0000 Evaluation of icebergs gouging the seabed and the impact on such a pipeline are presented and evaluated. Potential pipeline routing has been assessed to minimize risk of direct contact from a gouging iceberg keel. Risks to the pipeline may come from direct contact or through subgouge deformation beneath the keel. Risk was evaluated using an iceberg subsea contact model, updated to reflect the current iceberg regime, developed as part of an ongoing project titled \"Subsea Ice Interaction Barrier to Energy Development (SIIBED)\".\u0000 The paper also touches on aspects of a gas gathering system and regulatory considerations.","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":"129775086","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}
Degaul Nana Nzoutchoua, C. Johnson, Jean Yengoua Tenin, Matthieu Lonca, Edevaldo Andrade e Sousa, Jamel Zghal
Foamed cement was successfully used in the riserless section of an ultradeepwater well located in 11,900ft water depth. Foamed cement was selected to minimize operating costs and provide flexibility to adjust slurry density on a short notice. The seawater column exerted 5,319.1-psi hydrostatic pressure on the annulus. Consequently, nitrogen (N2) density could no longer be neglected. This paper presents simulations performed in preparation for the job, operational considerations, and post-job evaluation. The lead slurry needed a density of 1.25 SG and develops a compressive strength of at least 300 psi within 48 hr. Considering the cost and challenges associated with outsourcing resources under current Covid-19 pandemic restrictions, the foamed cement system was preferred over chemical- or particle- extended cement or blend systems. The N2 ratio for the foamed cement slurry system was 700 scf/bbl. With a base slurry pumping rate of 5 bbl/min, the required N2 pumping rate was 3,500 scf/min, which was greater than the capability of a single N2 pump (3,000-scf/min rate). Because the rig deck space could not accommodate three N2 pumps, one pump would serve as backup; thus, the final plan consisted of using two N2 pumps simultaneously. Two parallel foamed slurry treating lines were rigged up to reduce the fluid velocity in a single line. All laboratory testing was conducted locally. Additives used in the foamed slurry were environmentally friendly. A proprietary process-control system was used during the cementing operation and automatically synchronized the N2 pumps and foam pump rates with the base slurry rate. The cementing crew consisted of 11 individuals, including 2 client representatives. The entire pumping operation was completed in 10 hr. A total base slurry volume of 1016.2 bbl was continuously mixed and pumped at the density of 13.35 lbm/gal (1.60 SG). The resulting foamed slurry volume was 1387.0 bbl with an average foam quality of 27.8% and foamed slurry density of 10.5 lbm/gal (1.26 SG). A total of 119 metric tonne of class G cement and 30,711 L of N2 were consumed during the pumping operation. The lead slurry was followed by 603.9 bbl of 15.86 lbm/gal (1.90 SG) class G cement tail slurry and 349.7 bbl of seawater for displacement. The final surface pressure was 594.6 psi. The lead slurry reached the seabed and the float shoe check was positive. No casing subsidence was observed. Using foamed cement slurry in such extreme conditions demonstrated its robustness and reliability. Through formalized and methodical risk assessment, the team was able to identify and implement mitigating measures that led to an outstanding result. This application also confirmed that N2 density should not be neglected when high-hydrostatic pressure is involved.
{"title":"Successful Application of Foamed Cement Slurry in an Ultradeepwater Well of 11,900-ft Water Depth (Claiming World Record)","authors":"Degaul Nana Nzoutchoua, C. Johnson, Jean Yengoua Tenin, Matthieu Lonca, Edevaldo Andrade e Sousa, Jamel Zghal","doi":"10.4043/32386-ms","DOIUrl":"https://doi.org/10.4043/32386-ms","url":null,"abstract":"\u0000 Foamed cement was successfully used in the riserless section of an ultradeepwater well located in 11,900ft water depth. Foamed cement was selected to minimize operating costs and provide flexibility to adjust slurry density on a short notice. The seawater column exerted 5,319.1-psi hydrostatic pressure on the annulus. Consequently, nitrogen (N2) density could no longer be neglected. This paper presents simulations performed in preparation for the job, operational considerations, and post-job evaluation.\u0000 The lead slurry needed a density of 1.25 SG and develops a compressive strength of at least 300 psi within 48 hr. Considering the cost and challenges associated with outsourcing resources under current Covid-19 pandemic restrictions, the foamed cement system was preferred over chemical- or particle- extended cement or blend systems. The N2 ratio for the foamed cement slurry system was 700 scf/bbl. With a base slurry pumping rate of 5 bbl/min, the required N2 pumping rate was 3,500 scf/min, which was greater than the capability of a single N2 pump (3,000-scf/min rate). Because the rig deck space could not accommodate three N2 pumps, one pump would serve as backup; thus, the final plan consisted of using two N2 pumps simultaneously. Two parallel foamed slurry treating lines were rigged up to reduce the fluid velocity in a single line.\u0000 All laboratory testing was conducted locally. Additives used in the foamed slurry were environmentally friendly. A proprietary process-control system was used during the cementing operation and automatically synchronized the N2 pumps and foam pump rates with the base slurry rate. The cementing crew consisted of 11 individuals, including 2 client representatives. The entire pumping operation was completed in 10 hr. A total base slurry volume of 1016.2 bbl was continuously mixed and pumped at the density of 13.35 lbm/gal (1.60 SG). The resulting foamed slurry volume was 1387.0 bbl with an average foam quality of 27.8% and foamed slurry density of 10.5 lbm/gal (1.26 SG). A total of 119 metric tonne of class G cement and 30,711 L of N2 were consumed during the pumping operation. The lead slurry was followed by 603.9 bbl of 15.86 lbm/gal (1.90 SG) class G cement tail slurry and 349.7 bbl of seawater for displacement. The final surface pressure was 594.6 psi. The lead slurry reached the seabed and the float shoe check was positive. No casing subsidence was observed.\u0000 Using foamed cement slurry in such extreme conditions demonstrated its robustness and reliability. Through formalized and methodical risk assessment, the team was able to identify and implement mitigating measures that led to an outstanding result. This application also confirmed that N2 density should not be neglected when high-hydrostatic pressure is involved.","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":"130234463","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The objective of this paper is to present a groundbreaking case study for a Novel Articulation Tool utilized by a deepwater Operator to address the significant riserless drilling operations risks associated with extreme environmental conditions off the coast of South Africa. The Luiperd prospect, located 175 kilometers off the southern coast of South Africa in 1760 m (5774 ft) of water, experiences strong prevailing surface currents and harsh weather year-round. These extreme environmental conditions required careful planning for open water operations to mitigate the associated risks for rig equipment potentially exceeding maximum bending moments or reaching fatigue life limits among other concerns. For the previously operated offset well, the Operator used drift running techniques during riserless drilling to deploy casing and drilling assemblies in open water to limit their exposure time to strong surface currents. The application of this technique in single derrick mode resulted in safe but slow and costly drilling. For the Luiperd prospect, one of the measures taken by the Operator to mitigate environmental risks was the use of a Novel Articulation Tool to minimize the bending stresses applied to the subsea wellhead running tools (WHRT) and landing string while running the conductor pipe and the surface casing. This articulation tool is based on a ball-and-socket concept which provides zero rotational stiffness up to 15 degrees in any direction while exceeding operational requirements for through-torque, tensile and working pressure ratings. The Luiperd well was successfully drilled during Q3 2020 using the Deepsea Stavanger mobile offshore drilling unit (MODU). During the well's riserless drilling operations two Novel Articulation Tools were used, one being made up just above the subsea WHRT and another being placed within the drill pipe landing string in the MODU's moon pool. Because the Novel Articulation Tool effectively eliminated the highest bending moments that would otherwise act upon the landing string and WHRT, it de-coupled the MODU from the conductor and surface casings run on the Auxiliary Well Center (AWC), enabling dual derrick operations which were not possible for the offset well. The use of this technology saved multiple drift runs and more than 10 days of rig time for the Luiperd well compared with the offset. A maximum 317 MT (700,000 lbs) of surface casing and landing string was suspended beneath the upper articulation tool. Both articulation tools were in continuous use for 75 hours with 4.3 knots of current and up to 5 m (16 ft) significant wave height (Hs). Although the Luiperd well was drilled in a unique offshore environment, similar conditions are prevalent across the world's deepwater basins, including the West of Shetland area in the UK and in the Gulf of Mexico where loop currents present a regular challenge. The subject Novel Articulation Tool can reduce operational risks and provide step change improve
{"title":"Deepwater Operator Saves Multiple Days of Riserless Drilling Operations Using Novel Articulation Tool","authors":"Tyler R. Reynolds, A. Cavé, Tristam P. Horn","doi":"10.4043/32205-ms","DOIUrl":"https://doi.org/10.4043/32205-ms","url":null,"abstract":"\u0000 The objective of this paper is to present a groundbreaking case study for a Novel Articulation Tool utilized by a deepwater Operator to address the significant riserless drilling operations risks associated with extreme environmental conditions off the coast of South Africa.\u0000 The Luiperd prospect, located 175 kilometers off the southern coast of South Africa in 1760 m (5774 ft) of water, experiences strong prevailing surface currents and harsh weather year-round. These extreme environmental conditions required careful planning for open water operations to mitigate the associated risks for rig equipment potentially exceeding maximum bending moments or reaching fatigue life limits among other concerns.\u0000 For the previously operated offset well, the Operator used drift running techniques during riserless drilling to deploy casing and drilling assemblies in open water to limit their exposure time to strong surface currents. The application of this technique in single derrick mode resulted in safe but slow and costly drilling.\u0000 For the Luiperd prospect, one of the measures taken by the Operator to mitigate environmental risks was the use of a Novel Articulation Tool to minimize the bending stresses applied to the subsea wellhead running tools (WHRT) and landing string while running the conductor pipe and the surface casing. This articulation tool is based on a ball-and-socket concept which provides zero rotational stiffness up to 15 degrees in any direction while exceeding operational requirements for through-torque, tensile and working pressure ratings.\u0000 The Luiperd well was successfully drilled during Q3 2020 using the Deepsea Stavanger mobile offshore drilling unit (MODU). During the well's riserless drilling operations two Novel Articulation Tools were used, one being made up just above the subsea WHRT and another being placed within the drill pipe landing string in the MODU's moon pool.\u0000 Because the Novel Articulation Tool effectively eliminated the highest bending moments that would otherwise act upon the landing string and WHRT, it de-coupled the MODU from the conductor and surface casings run on the Auxiliary Well Center (AWC), enabling dual derrick operations which were not possible for the offset well.\u0000 The use of this technology saved multiple drift runs and more than 10 days of rig time for the Luiperd well compared with the offset. A maximum 317 MT (700,000 lbs) of surface casing and landing string was suspended beneath the upper articulation tool. Both articulation tools were in continuous use for 75 hours with 4.3 knots of current and up to 5 m (16 ft) significant wave height (Hs).\u0000 Although the Luiperd well was drilled in a unique offshore environment, similar conditions are prevalent across the world's deepwater basins, including the West of Shetland area in the UK and in the Gulf of Mexico where loop currents present a regular challenge. The subject Novel Articulation Tool can reduce operational risks and provide step change improve","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":"130313218","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 a study conducted to evaluate the centerline weld cracking observed on primary structural Node's fillet weld joint connections made of 440MPa Yield Strength Steel using Flux Cored Arc Welding (FCAW) process in the offshore structures during the fabrication and assembly. Non-Destructive Examination (NDE) – Magnetic Particle Inspection (MPI) was selected to inspect the fillet weld joint connections because RT or UT is not practical. Considering the possibility of delayed cracking, fillet welds were inspected using MPI after 3 days of weld completion, and MPI examination has not captured any indication. The significance of cracks observed on these initial MPI examined weld joint connections was noticed by visual inspection after 3 weeks of weld completion, thus, the extent of NDE was conducted and observed the long-delayed cracks, which doubts the possibility of long incubation time of cracking. The laboratory examination of the weld center line crack sample had been performed to acquire the key evidences to verify the damage mechanism as a cold cracking. In this paper, the identification of the major causes of Cold cracking, the discussion of the possible causes of long incubation time, and the optimization of the weld joint design had been studied. It also covers the correction methodology that needs to be adopted to prevent the recurrence.
{"title":"Study of Cold Cracking on Offshore Platform Structural Fillet Welds from 440MPa Yield Strength Steel and its Prevention","authors":"Subindas Melapurakkal Mohandas, Minsu Cho","doi":"10.4043/32488-ms","DOIUrl":"https://doi.org/10.4043/32488-ms","url":null,"abstract":"\u0000 This paper presents a study conducted to evaluate the centerline weld cracking observed on primary structural Node's fillet weld joint connections made of 440MPa Yield Strength Steel using Flux Cored Arc Welding (FCAW) process in the offshore structures during the fabrication and assembly. Non-Destructive Examination (NDE) – Magnetic Particle Inspection (MPI) was selected to inspect the fillet weld joint connections because RT or UT is not practical. Considering the possibility of delayed cracking, fillet welds were inspected using MPI after 3 days of weld completion, and MPI examination has not captured any indication. The significance of cracks observed on these initial MPI examined weld joint connections was noticed by visual inspection after 3 weeks of weld completion, thus, the extent of NDE was conducted and observed the long-delayed cracks, which doubts the possibility of long incubation time of cracking. The laboratory examination of the weld center line crack sample had been performed to acquire the key evidences to verify the damage mechanism as a cold cracking. In this paper, the identification of the major causes of Cold cracking, the discussion of the possible causes of long incubation time, and the optimization of the weld joint design had been studied. It also covers the correction methodology that needs to be adopted to prevent the recurrence.","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":"133311941","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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