Mohammad Zamani Ahmad Mahmoudi, Mitra Khalilidermani, D. Knez
Determination of the shear wave velocity, Vs, is an integral part in creation of reservoir geomechanical models. This parameter together with the compressional wave velocity and rock density are utilized to calculate the dynamic elastic moduli of the subsurface formations. In well logging, the Vs can be directly measured through the Dipole Shear Sonic Imager (DSI) logs which need special requirements and technical considerations. Therefore, many researchers have strived to develop cost-effective accurate methods for Vs estimation in the oil/gas fields. The Kharg Island offshore oilfields, located in the Persian Gulf, consist of a giant limestone reservoir called Asmari formation. In the past, numerous studies were conducted to develop mathematical relations for Vs prediction in the Asmari reservoir; however those relations were not capable of estimating the Vs values correctly. In this research, the well logging data related to a vertical offshore well was utilized to develop three mathematical relations for Vs estimation in the Asmari formation. To do this, linear regression (LR), Multivariate Regression (MLR), and Gene Expression Programing (GEP) methods were applied. Moreover, the accuracy of those relations was compared with some available empirical correlations for Vs prediction in limestone rocks. Comparing the results of those data-driven equations with the empirical equations illustrated that the results of the GEP method are more accurate than other equations. Moreover, the Pickett empirical correlation was found to be more suitable than other empirical correlations for Vs estimation in the Asmari reservoir. The methodology applied in this research is a reliable procedure to estimate the Vs in the study area as well as other geologically similar oil reservoirs. Such an application leads to generation of robust geomechanical models increasing the project success and oilfield development progression.
{"title":"Estimation of Shear Wave Velocity Using Empirical, MLR, and GEP Techniques-Case Study: Kharg Island Offshore Oilfield","authors":"Mohammad Zamani Ahmad Mahmoudi, Mitra Khalilidermani, D. Knez","doi":"10.4043/32388-ms","DOIUrl":"https://doi.org/10.4043/32388-ms","url":null,"abstract":"\u0000 Determination of the shear wave velocity, Vs, is an integral part in creation of reservoir geomechanical models. This parameter together with the compressional wave velocity and rock density are utilized to calculate the dynamic elastic moduli of the subsurface formations. In well logging, the Vs can be directly measured through the Dipole Shear Sonic Imager (DSI) logs which need special requirements and technical considerations. Therefore, many researchers have strived to develop cost-effective accurate methods for Vs estimation in the oil/gas fields. The Kharg Island offshore oilfields, located in the Persian Gulf, consist of a giant limestone reservoir called Asmari formation. In the past, numerous studies were conducted to develop mathematical relations for Vs prediction in the Asmari reservoir; however those relations were not capable of estimating the Vs values correctly. In this research, the well logging data related to a vertical offshore well was utilized to develop three mathematical relations for Vs estimation in the Asmari formation. To do this, linear regression (LR), Multivariate Regression (MLR), and Gene Expression Programing (GEP) methods were applied. Moreover, the accuracy of those relations was compared with some available empirical correlations for Vs prediction in limestone rocks. Comparing the results of those data-driven equations with the empirical equations illustrated that the results of the GEP method are more accurate than other equations. Moreover, the Pickett empirical correlation was found to be more suitable than other empirical correlations for Vs estimation in the Asmari reservoir. The methodology applied in this research is a reliable procedure to estimate the Vs in the study area as well as other geologically similar oil reservoirs. Such an application leads to generation of robust geomechanical models increasing the project success and oilfield development progression.","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":"114040133","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
G. L. Bandeira, D. Trindade, Laureano Henrique Gardi, M. Sodario, Camila Gabriela Simioni
Efforts have been made globally to reduce companies' impacts on the planet, people, and communities, which leads industries to rethink how to produce and manage their workforce. But some challenges and barriers keep businesses from embracing sustainable actions to drive change. One of them is to create healthy ESG planning. This research aimed to create a sustainability roadmap based on the Environmental, Social, and Governance (ESG) strategies in a Norwegian O&G company. The programs were segregated into three pillars based on the triple bottom line and the Sustainable Development Goals (SDGs). From this strategy's construction, ten key workstreams (WS) were developed and sponsored by a Steering Committee. The Environmental dimension [E] is related to the Energy Management & CO2 Emissions program, in which the company is committed to the challenges of climate change by reducing CO2 emissions and environmental impacts of its operations. Also, in the Waste Management program, the company is committed to reducing waste generation from its operations and promoting a circular economy approach. In the Low Carbon Solutions program, the company contributes to the decarbonization of global O&G production. For the Social dimension [S], in the Health & Safety program, the strategy corresponds to creating a world-class performance organization, strengthening business competitiveness, and achieving the zero-incident vision. In the Talent Attraction & Retention program, it is believed that people are the key to creating a successful business. In the Diversity & Equality program, the company is strongly committed to the principles of non-discriminatory practices and equal opportunities, and in the Social Responsibility program, it positively impacts the development of local communities through education. Finally, for the Governance dimension [G] are presented the Responsible Business Conduct program promoting zero tolerance for corruption, also the Compliance Obligation for HSE program to respect and comply with HSE laws and regulations. And contemplating the three dimensions in the Responsible Supply Chain program, suppliers were selected with high environmental, anti-corruption, and human rights standards. Based on the study results, recommendations are made to ensure that an ESG strategy and roadmap are effectively accommodated to ensure optimal cohesion amongst the O&G industry and the integration of their strengths that will positively impact the entire value chain and optimize the realization of organizational goals.
{"title":"Developing an ESG Strategy and Roadmap: An Integrated Perspective in an O&G Company","authors":"G. L. Bandeira, D. Trindade, Laureano Henrique Gardi, M. Sodario, Camila Gabriela Simioni","doi":"10.4043/32600-ms","DOIUrl":"https://doi.org/10.4043/32600-ms","url":null,"abstract":"\u0000 Efforts have been made globally to reduce companies' impacts on the planet, people, and communities, which leads industries to rethink how to produce and manage their workforce. But some challenges and barriers keep businesses from embracing sustainable actions to drive change. One of them is to create healthy ESG planning.\u0000 This research aimed to create a sustainability roadmap based on the Environmental, Social, and Governance (ESG) strategies in a Norwegian O&G company. The programs were segregated into three pillars based on the triple bottom line and the Sustainable Development Goals (SDGs). From this strategy's construction, ten key workstreams (WS) were developed and sponsored by a Steering Committee.\u0000 The Environmental dimension [E] is related to the Energy Management & CO2 Emissions program, in which the company is committed to the challenges of climate change by reducing CO2 emissions and environmental impacts of its operations. Also, in the Waste Management program, the company is committed to reducing waste generation from its operations and promoting a circular economy approach. In the Low Carbon Solutions program, the company contributes to the decarbonization of global O&G production.\u0000 For the Social dimension [S], in the Health & Safety program, the strategy corresponds to creating a world-class performance organization, strengthening business competitiveness, and achieving the zero-incident vision. In the Talent Attraction & Retention program, it is believed that people are the key to creating a successful business. In the Diversity & Equality program, the company is strongly committed to the principles of non-discriminatory practices and equal opportunities, and in the Social Responsibility program, it positively impacts the development of local communities through education.\u0000 Finally, for the Governance dimension [G] are presented the Responsible Business Conduct program promoting zero tolerance for corruption, also the Compliance Obligation for HSE program to respect and comply with HSE laws and regulations. And contemplating the three dimensions in the Responsible Supply Chain program, suppliers were selected with high environmental, anti-corruption, and human rights standards.\u0000 Based on the study results, recommendations are made to ensure that an ESG strategy and roadmap are effectively accommodated to ensure optimal cohesion amongst the O&G industry and the integration of their strengths that will positively impact the entire value chain and optimize the realization of organizational goals.","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":"130186294","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}
Steven A. Rizea, J. Halkyard, J. Wodehouse, R. Blevins, Lori A. Johnston, James Adamson, Kamlesh Joshi
This paper describes concepts to minimize the plume generated by unwanted sediments collected along with manganese nodules during hydraulic mining operations. The concept consists of two novel technologies: separating all sediment from the collected nodule slurry to eliminate sediment from entering the riser and lift system, thereby reducing, or eliminating a midwater plume, and subsea electrocoagulation (EC) to create rapidly settling flocs of sediment being discharged from the seafloor collector. The first approach involves designing a gravity separator (hopper) whereby the larger particles fall through an outlet and are entrained with clean water before entering the riser, while all the sediment and water collected with the nodules exits at the hopper overflow. To prevent sediment from being entrained with the nodules, a "reverse hydrocyclone" and secondary hopper is incorporated in the underflow circuit to help maintain a positive pressure differential between the riser inlet and the hopper during operations. The second approach employs the marinization of proven wastewater treatment EC technology to create large metalliferous flocs which attract the sediment causing rapid settling when the slurry is discharged aft of the collector. Work reported here includes numerical (CFD) confirmation of the separator performance, and experimental demonstration of the EC application, as well as techno-economic assessments of the cost impacts of implementing these technologies. This work was supported by the U.S. Department of Energy, Advanced Research Projects Agency – Energy (ARPA-E), and with contributions of sediment for the EC tests by The Metals Company from the Clarion Clipperton Zone and Ocean Minerals, LLC from the Cook Islands EEZ.
{"title":"Making Deep Sea Mining Cleaner and Greener","authors":"Steven A. Rizea, J. Halkyard, J. Wodehouse, R. Blevins, Lori A. Johnston, James Adamson, Kamlesh Joshi","doi":"10.4043/32535-ms","DOIUrl":"https://doi.org/10.4043/32535-ms","url":null,"abstract":"\u0000 This paper describes concepts to minimize the plume generated by unwanted sediments collected along with manganese nodules during hydraulic mining operations. The concept consists of two novel technologies: separating all sediment from the collected nodule slurry to eliminate sediment from entering the riser and lift system, thereby reducing, or eliminating a midwater plume, and subsea electrocoagulation (EC) to create rapidly settling flocs of sediment being discharged from the seafloor collector. The first approach involves designing a gravity separator (hopper) whereby the larger particles fall through an outlet and are entrained with clean water before entering the riser, while all the sediment and water collected with the nodules exits at the hopper overflow. To prevent sediment from being entrained with the nodules, a \"reverse hydrocyclone\" and secondary hopper is incorporated in the underflow circuit to help maintain a positive pressure differential between the riser inlet and the hopper during operations. The second approach employs the marinization of proven wastewater treatment EC technology to create large metalliferous flocs which attract the sediment causing rapid settling when the slurry is discharged aft of the collector. Work reported here includes numerical (CFD) confirmation of the separator performance, and experimental demonstration of the EC application, as well as techno-economic assessments of the cost impacts of implementing these technologies. This work was supported by the U.S. Department of Energy, Advanced Research Projects Agency – Energy (ARPA-E), and with contributions of sediment for the EC tests by The Metals Company from the Clarion Clipperton Zone and Ocean Minerals, LLC from the Cook Islands EEZ.","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":"130139356","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}
Deep-seabed mud containing a high concentration of rare-earth elements, including yttrium, has been discovered in the western North Pacific Ocean near Minami-Torishima Island, Japan. However, production of the rare-earth rich mud is challenging because of its location at water depths of over 6000 m. We propose a new subsea lifting system for deep-seabed rare-earth rich mud. The lifting system consists of a small diameter marine riser and an inner work string. At the lower end of the work string, a hydraulic jet pump is equipped so that rare-earth rich mud slurry can be easily sucked from a sea-bottom mud collecting device and lifted through the riser annulus. The jet pump is driven with power fluid pumped from a floating mining vessel. To evaluate the suction performance of the jet pump and the flow assurance in the annulus, numerical simulations were performed for various kinds of power fluid rates and jet pump configurations. The simulation results suggested that the proposed lifting system could, in principle, lift slurry containing rare-earth rich mud continuously to a surface floating vessel. Also, the hydraulic jet pump mechanism could be optimized to maximize the suction caused by the Venturi depressurization effect and to achieve a commercially feasible mud lifting rate of 3500 ton/day. For a pump configuration with three pairs of diffusers and suction lines, a drive fluid flow rate of 700 gal/min was found to be sufficient to meet the economic production criteria.
{"title":"Subsea Lifting System for Deep-Seabed Rare-Earth Rich Mud","authors":"Ryuta Kitago, S. Naganawa, Elvar K Bjarkason","doi":"10.4043/32327-ms","DOIUrl":"https://doi.org/10.4043/32327-ms","url":null,"abstract":"\u0000 Deep-seabed mud containing a high concentration of rare-earth elements, including yttrium, has been discovered in the western North Pacific Ocean near Minami-Torishima Island, Japan. However, production of the rare-earth rich mud is challenging because of its location at water depths of over 6000 m. We propose a new subsea lifting system for deep-seabed rare-earth rich mud. The lifting system consists of a small diameter marine riser and an inner work string. At the lower end of the work string, a hydraulic jet pump is equipped so that rare-earth rich mud slurry can be easily sucked from a sea-bottom mud collecting device and lifted through the riser annulus. The jet pump is driven with power fluid pumped from a floating mining vessel. To evaluate the suction performance of the jet pump and the flow assurance in the annulus, numerical simulations were performed for various kinds of power fluid rates and jet pump configurations. The simulation results suggested that the proposed lifting system could, in principle, lift slurry containing rare-earth rich mud continuously to a surface floating vessel. Also, the hydraulic jet pump mechanism could be optimized to maximize the suction caused by the Venturi depressurization effect and to achieve a commercially feasible mud lifting rate of 3500 ton/day. For a pump configuration with three pairs of diffusers and suction lines, a drive fluid flow rate of 700 gal/min was found to be sufficient to meet the economic production criteria.","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":"131990560","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}
Stephen Varnell, A. Trandafir, V. Fortiz, A. Broughton, Craig Scherschel, Deanne Hargrave, Eric Swanson, Jack Fraser
This study illustrates a ground model approach used to characterize the complex site conditions within the Atlantic Shores Offshore Wind Farm Lease Area. The ground model is the result of the integration of geophysical, geological, geotechnical, and benthic (environmental) data to evaluate marine geohazards and summarize seafloor and sub-seafloor conditions. The ground model is provided in a Geographic Information Systems (GIS) format which can be interactively used for Wind Turbine Generator siting, design, and construction. Various components of the ground model including seafloor sediments and morphology, subsurface geologic features, stratigraphy, soil provinces, and soil profiles are presented and discussed. Soil province variability across the Lease Area has been successfully delineated in detail through the ground model methodology presented in this paper. Geotechnical properties of various identified soil units are generally favorable for a variety of potential foundation types and installation methods. This is one paper in a collaborative series that demonstrates the value of an integrated geoscience approach considering regulatory requirements and project design essentials.
{"title":"Integrated Assessment of Seafloor and Subsurface Site Conditions at Atlantic Shores Offshore Wind Farm Development","authors":"Stephen Varnell, A. Trandafir, V. Fortiz, A. Broughton, Craig Scherschel, Deanne Hargrave, Eric Swanson, Jack Fraser","doi":"10.4043/32431-ms","DOIUrl":"https://doi.org/10.4043/32431-ms","url":null,"abstract":"\u0000 This study illustrates a ground model approach used to characterize the complex site conditions within the Atlantic Shores Offshore Wind Farm Lease Area. The ground model is the result of the integration of geophysical, geological, geotechnical, and benthic (environmental) data to evaluate marine geohazards and summarize seafloor and sub-seafloor conditions. The ground model is provided in a Geographic Information Systems (GIS) format which can be interactively used for Wind Turbine Generator siting, design, and construction. Various components of the ground model including seafloor sediments and morphology, subsurface geologic features, stratigraphy, soil provinces, and soil profiles are presented and discussed. Soil province variability across the Lease Area has been successfully delineated in detail through the ground model methodology presented in this paper. Geotechnical properties of various identified soil units are generally favorable for a variety of potential foundation types and installation methods. This is one paper in a collaborative series that demonstrates the value of an integrated geoscience approach considering regulatory requirements and project design essentials.","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":"130868854","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}
D. Doolittle, Eric Swanson, Craig Scherschel, E. Revelas, Kathryn Rovang, Stephen Varnell
Offshore wind developers obtain extensive geophysical, geotechnical, and habitat data during Site Characterization activities. Integration and delivery of this information to a diverse group of stakeholders and Government agencies is required. We present an integrated benthic habitat mapping approach tailored to regional geology and ground conditions and discuss how various data was utilized to deliver multiple components of the permitting process. Multiple data sets were integrated and presented via a web-based GIS platform to aid delivery, visualization, and communication. Our unified approach to benthic habitat mapping and delivery of products to stakeholders was instrumental in successfully coalescing multiple performers to develop their individual deliverables in a cohesive and rapid manner. This approach reduced risk to schedule and budget, without sacrificing data density or quality. Four annual (2019–2022) benthic surveys were acquired to support Site Characterization and subsequent permitting processes. High-Resolution Geophysical data were collected concomitantly with the 2020 benthic survey data and used to refine subsequent 2021 and 2022 benthic survey designs. Benthic survey data consisted of grab sample tests (grain size), macrofaunal taxonomy, sediment profile and plan view imagery (SPI-PV), video imagery from each grab station, and towed video transects. Acoustic data products were processed and interpreted to create polygons of seafloor sediment coverage over the ASOW study area and ground-truthed with physical sampling, video, and digital still imagery to refine and validate acoustic data into a mappable model of essential fish and benthic habitats. Seafloor morphology and seabed sediment interpretations were coalesced into a benthic habitat model that displayed substrates consisting mostly of mobile sand sheets, with interspersed areas of gravelly sand and discrete patches of gravel. Overlying the substrate model was a range of benthic features and morphologies, including sand ridges, sand waves, megaripples, ripples, areas of depressional marks, hummocky seafloor, interbedded surficial sediments, irregular seafloor, and localized relief features. From these data, classified maps of Coastal Marine Ecological Standard (CMECS) substrates and fish habitats were made. Additional CMECS classification of benthic biotic components were mapped, showing the taxonomic communities that are present in each substrate. Seabed sediment modeling and morphological trends were dynamically studied and compiled into an interpreted and GIS-friendly dataset that enabled rapid online transfer to subject matter experts tasked with quantifying the benthic ecosystem across the development area. The methods and modeling that were produced by expert refinement of geophysical data to reflect the physically observed habitat structures allowed for dynamic minimum mapping unit variability while also isolating and identifying key areas of interest for ben
{"title":"Integrated and Adaptable Approach to Mapping Benthic Habitats to Support Offshore Wind Development off the Mid-Atlantic Outer Continental Shelf","authors":"D. Doolittle, Eric Swanson, Craig Scherschel, E. Revelas, Kathryn Rovang, Stephen Varnell","doi":"10.4043/32390-ms","DOIUrl":"https://doi.org/10.4043/32390-ms","url":null,"abstract":"\u0000 Offshore wind developers obtain extensive geophysical, geotechnical, and habitat data during Site Characterization activities. Integration and delivery of this information to a diverse group of stakeholders and Government agencies is required. We present an integrated benthic habitat mapping approach tailored to regional geology and ground conditions and discuss how various data was utilized to deliver multiple components of the permitting process. Multiple data sets were integrated and presented via a web-based GIS platform to aid delivery, visualization, and communication. Our unified approach to benthic habitat mapping and delivery of products to stakeholders was instrumental in successfully coalescing multiple performers to develop their individual deliverables in a cohesive and rapid manner. This approach reduced risk to schedule and budget, without sacrificing data density or quality.\u0000 Four annual (2019–2022) benthic surveys were acquired to support Site Characterization and subsequent permitting processes. High-Resolution Geophysical data were collected concomitantly with the 2020 benthic survey data and used to refine subsequent 2021 and 2022 benthic survey designs. Benthic survey data consisted of grab sample tests (grain size), macrofaunal taxonomy, sediment profile and plan view imagery (SPI-PV), video imagery from each grab station, and towed video transects. Acoustic data products were processed and interpreted to create polygons of seafloor sediment coverage over the ASOW study area and ground-truthed with physical sampling, video, and digital still imagery to refine and validate acoustic data into a mappable model of essential fish and benthic habitats.\u0000 Seafloor morphology and seabed sediment interpretations were coalesced into a benthic habitat model that displayed substrates consisting mostly of mobile sand sheets, with interspersed areas of gravelly sand and discrete patches of gravel. Overlying the substrate model was a range of benthic features and morphologies, including sand ridges, sand waves, megaripples, ripples, areas of depressional marks, hummocky seafloor, interbedded surficial sediments, irregular seafloor, and localized relief features. From these data, classified maps of Coastal Marine Ecological Standard (CMECS) substrates and fish habitats were made. Additional CMECS classification of benthic biotic components were mapped, showing the taxonomic communities that are present in each substrate.\u0000 Seabed sediment modeling and morphological trends were dynamically studied and compiled into an interpreted and GIS-friendly dataset that enabled rapid online transfer to subject matter experts tasked with quantifying the benthic ecosystem across the development area. The methods and modeling that were produced by expert refinement of geophysical data to reflect the physically observed habitat structures allowed for dynamic minimum mapping unit variability while also isolating and identifying key areas of interest for ben","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":"128107118","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}
Geothermal energy is a baseload power generation system which uses the high temperature of the deep layers below the Earth’s surface. It has traditionally relied on very high temperature wells, usually at temperatures over 180°C, but no less than 100°C (Ref 5). The largest geothermal plant in the US, The Geysers Plant in California, uses steam that is over 250°C (Ref 4). The systems are costly and available locations limited by the depth required to achieve these temperatures. Using organic Rankine cycle technology much lower temperatures can be and are used to generate electricity. Ocean Thermal Energy Conversion (OTEC) famously runs on a 20°C temperature difference, with the hot side being about 25°C and the cold side being 5°C or colder. This paper will provide a practical design and thermodynamic analysis of a system designed to run at no more than 100°C. This is a temperature that can be encountered at a reasonable depth onshore and offshore. In the Gulf of Mexico many of the legacy reservoirs are hotter than this (Ref 6). Offshore we will also take advantage of the immense heat sink that is the ocean. The system will utilize well derived heat and cold water to run a power cycle. It is expected that low temperature geothermal will be a practical source for offshore baseload power. One possible use is to power oil and gas platforms, which as they transition need green energy. Unlike wind offshore geothermal will not need battery backup, and once the field has played out, geothermal can then be used to supply power to shore or other nearby platforms. Novel/Additive Information: The system will use both novel well configurations and a novel organic Rankine cycle system for power.
{"title":"Low Temperature Geothermal for Offshore Use","authors":"I. Furtado, Roy Robinson","doi":"10.4043/32292-ms","DOIUrl":"https://doi.org/10.4043/32292-ms","url":null,"abstract":"\u0000 Geothermal energy is a baseload power generation system which uses the high temperature of the deep layers below the Earth’s surface. It has traditionally relied on very high temperature wells, usually at temperatures over 180°C, but no less than 100°C (Ref 5). The largest geothermal plant in the US, The Geysers Plant in California, uses steam that is over 250°C (Ref 4). The systems are costly and available locations limited by the depth required to achieve these temperatures. Using organic Rankine cycle technology much lower temperatures can be and are used to generate electricity. Ocean Thermal Energy Conversion (OTEC) famously runs on a 20°C temperature difference, with the hot side being about 25°C and the cold side being 5°C or colder.\u0000 This paper will provide a practical design and thermodynamic analysis of a system designed to run at no more than 100°C. This is a temperature that can be encountered at a reasonable depth onshore and offshore. In the Gulf of Mexico many of the legacy reservoirs are hotter than this (Ref 6).\u0000 Offshore we will also take advantage of the immense heat sink that is the ocean. The system will utilize well derived heat and cold water to run a power cycle.\u0000 It is expected that low temperature geothermal will be a practical source for offshore baseload power. One possible use is to power oil and gas platforms, which as they transition need green energy. Unlike wind offshore geothermal will not need battery backup, and once the field has played out, geothermal can then be used to supply power to shore or other nearby platforms.\u0000 Novel/Additive Information: The system will use both novel well configurations and a novel organic Rankine cycle system for power.","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":"115402707","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. Mattarucco, Alberto Trevisan, C. Giudicianni, Francesco Lucchese, Gianluca Toso
Subsea pipeline repair connectors have been used in the oil & gas industry for many years and are considered a valid and safe way of repairing major damages and restoring the original pipeline condition in case of an emergency repair; they can also be used for tie-ins to allow extensions by connection of new pipeline sections to an existing one and they have an extensive track record mainly on carbon steel pipelines but are fit also for stainless steel and duplex pipelines. The increasing number of subsea pipelines with internal CRA cladding which have been deployed in recent years and are foreseen in the future poses new technological challenges since conventional sealing solutions are not suitable for or have limitations in this specific application: in this case the repair connector not only needs to be designed to be compliant with the sour product but it also needs to protect the pipeline carbon steel wall from coming into contact with the internal fluid. This paper presents a new concept of a pipeline repair connector that has been developed from the beginning specifically to target repairs on sour service lines and in particular on clad lines. This innovative repair connector is based on a metal to metal sealing technology that offers permanent repair without any reduction of the pipeline's internal diameter, provides a versatile diver/diver-less solution, can deal with multiple wall thicknesses and can also be applied to other types of pipelines, such as those for sour service with internal corrosion allowance since it can manage pipe wall thickness reduction over time. The design of the mechanical connector has been carried out in compliance with DNV pipeline codes after a comprehensive technology qualification testing campaign under DNV certification and focused on medium size pipes. A full-scale 26″ prototype connector has been designed and fabricated for completing the qualification testing program including all required pressure and loading conditions. FEM analyses of the testing configurations have been carried out for comparison with test data so to validate the FEM models and extend results to other sizes within a predefined range. The matching between the experimental data and FEM calculations has allowed setting up a Type Approval process with DNV and, after a design effort covering various pipeline sizes and types, the connector will be certified for a wide range of large bore pipelines and design conditions and be ready for release to the market.
{"title":"A Novel Subsea Connector for Repairing Clad Pipelines","authors":"R. Mattarucco, Alberto Trevisan, C. Giudicianni, Francesco Lucchese, Gianluca Toso","doi":"10.4043/32193-ms","DOIUrl":"https://doi.org/10.4043/32193-ms","url":null,"abstract":"\u0000 Subsea pipeline repair connectors have been used in the oil & gas industry for many years and are considered a valid and safe way of repairing major damages and restoring the original pipeline condition in case of an emergency repair; they can also be used for tie-ins to allow extensions by connection of new pipeline sections to an existing one and they have an extensive track record mainly on carbon steel pipelines but are fit also for stainless steel and duplex pipelines. The increasing number of subsea pipelines with internal CRA cladding which have been deployed in recent years and are foreseen in the future poses new technological challenges since conventional sealing solutions are not suitable for or have limitations in this specific application: in this case the repair connector not only needs to be designed to be compliant with the sour product but it also needs to protect the pipeline carbon steel wall from coming into contact with the internal fluid. This paper presents a new concept of a pipeline repair connector that has been developed from the beginning specifically to target repairs on sour service lines and in particular on clad lines.\u0000 This innovative repair connector is based on a metal to metal sealing technology that offers permanent repair without any reduction of the pipeline's internal diameter, provides a versatile diver/diver-less solution, can deal with multiple wall thicknesses and can also be applied to other types of pipelines, such as those for sour service with internal corrosion allowance since it can manage pipe wall thickness reduction over time.\u0000 The design of the mechanical connector has been carried out in compliance with DNV pipeline codes after a comprehensive technology qualification testing campaign under DNV certification and focused on medium size pipes. A full-scale 26″ prototype connector has been designed and fabricated for completing the qualification testing program including all required pressure and loading conditions. FEM analyses of the testing configurations have been carried out for comparison with test data so to validate the FEM models and extend results to other sizes within a predefined range. The matching between the experimental data and FEM calculations has allowed setting up a Type Approval process with DNV and, after a design effort covering various pipeline sizes and types, the connector will be certified for a wide range of large bore pipelines and design conditions and be ready for release to the market.","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":"124835643","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. Santra, A. Trandafir, Morgan D. John, J. E. Fisher
We present a geological and geotechnical assessment of the outer continental shelf (OCS) of northern Gulf of Mexico, relevant to prospective offshore wind energy developers for identifying geohazards and developing a reconnaissance level understanding of foundation zone geotechnical conditions. The information provided in this paper is considered helpful in designing appropriate geophysical and geotechnical site investigation campaigns, and in preliminary evaluations of suitability of various foundation concepts for offshore wind infrastructure during the planning stage of lease area development. The generalized assessment of site conditions was conducted using an integrated approach that involved review of various published geological and geomorphological studies on shallow sediment distribution and shallow stratigraphy along with relevant published geotechnical information and in-house experience with geotechnical conditions in Gulf of Mexico. Published geological maps showing distribution of seafloor sediments with different characteristics, as well as maps and digital data on geohazards and geomorphic features associated with various depositional or erosional processes have been evaluated. Relevant stratigraphic information was synthesized in relation to geotechnical characteristics of various soil layers encountered at geotechnical investigation locations. This process culminated in the development of a map showing distribution of potential geohazards in the study area, as well as a map illustrating various soil provinces which represent areas of likely similar geotechnical conditions within the foundation zone. In addition to a regional overview, special emphasis is placed in this paper on the geological and geotechnical assessment of site conditions for the clastic shelf portion of the northern Gulf of Mexico. The assessment revealed that the entire clastic shelf west and east of Mississippi Delta is favorable for offshore wind energy development. The shelf within the present-day Mississippi Delta appears as less favorable. Geotechnical assessment of foundation zone conditions within the clastic shelf of Northern Gulf of Mexico culminated into three soil provinces characterized by distinct generalized soil profiles displaying the variation in thickness of individual soil units within each soil province. Representative ranges of geotechnical parameters for each soil unit are also presented and discussed.
{"title":"Overview of Geological and Geotechnical Conditions of Northern Gulf of Mexico with Emphasis on the Clastic Shelf - An Offshore Wind Energy Development Perspective","authors":"M. Santra, A. Trandafir, Morgan D. John, J. E. Fisher","doi":"10.4043/32548-ms","DOIUrl":"https://doi.org/10.4043/32548-ms","url":null,"abstract":"\u0000 We present a geological and geotechnical assessment of the outer continental shelf (OCS) of northern Gulf of Mexico, relevant to prospective offshore wind energy developers for identifying geohazards and developing a reconnaissance level understanding of foundation zone geotechnical conditions. The information provided in this paper is considered helpful in designing appropriate geophysical and geotechnical site investigation campaigns, and in preliminary evaluations of suitability of various foundation concepts for offshore wind infrastructure during the planning stage of lease area development.\u0000 The generalized assessment of site conditions was conducted using an integrated approach that involved review of various published geological and geomorphological studies on shallow sediment distribution and shallow stratigraphy along with relevant published geotechnical information and in-house experience with geotechnical conditions in Gulf of Mexico. Published geological maps showing distribution of seafloor sediments with different characteristics, as well as maps and digital data on geohazards and geomorphic features associated with various depositional or erosional processes have been evaluated. Relevant stratigraphic information was synthesized in relation to geotechnical characteristics of various soil layers encountered at geotechnical investigation locations. This process culminated in the development of a map showing distribution of potential geohazards in the study area, as well as a map illustrating various soil provinces which represent areas of likely similar geotechnical conditions within the foundation zone.\u0000 In addition to a regional overview, special emphasis is placed in this paper on the geological and geotechnical assessment of site conditions for the clastic shelf portion of the northern Gulf of Mexico. The assessment revealed that the entire clastic shelf west and east of Mississippi Delta is favorable for offshore wind energy development. The shelf within the present-day Mississippi Delta appears as less favorable. Geotechnical assessment of foundation zone conditions within the clastic shelf of Northern Gulf of Mexico culminated into three soil provinces characterized by distinct generalized soil profiles displaying the variation in thickness of individual soil units within each soil province. Representative ranges of geotechnical parameters for each soil unit are also presented and discussed.","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":"121809976","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
S. Karner, J. A. Giddings, Tomas O'Kane, Matt Durrant, B. Darby, K. G.
Thirteen ExxonMobil-operated gas development wells were drilled from 2012 to 2015 at the onshore Hides and Angore gas fields, Papua New Guinea (PNG), as part of the PNG LNG drilling program. Prior to drilling the PNG LNG wells, four wells had penetrated the Hides structure and one well had penetrated Angore. This paper focuses on pressure-stress interpretations at Angore, using drilling observations and data collected from the final three wells of the PNG LNG drilling program. The pressure-stress analyses of the PNG LNG Angore wells incorporated data collected while drilling, post-drill geologic and structural interpretations, and utilized a variety of geomechanical concepts that were constrained by the well data. Post-drill formation pressures were either estimated (e.g. from petrophysical trends, mud-log data, cavings analysis, formation fluid influxes) or directly measured using downhole pressure tools (reservoir only). Rock stresses were estimated or inferred from geomechanical relationships that were constrained by wellbore data (e.g. leak-off tests, mud weights), wellbore geometry (e.g. ovalization related to breakout), cavings analysis, and drilling events (e.g. lost returns, ballooning). The Angore well pads were constructed on Miocene Darai Limestone. Below the Darai Limestone, the wells penetrated a clastic section consisting of Cretaceous Ieru Formation (Haito, Ubea, Giero, Bawia, Juha, Alene Members), early Cretaceous Toro sandstone reservoir, and Jurassic Imburu Formation. The initial exploration well (Angore 1A drilled by BP in 1990) encountered a complex pressure-stress depth profile that was comparable to nearby offset wells. Hydrostatic pressure occurs below the water table (in the Darai Limestone) and continues into the Ubea Member. The clay-rich lower Ubea Member supports the onset of a pressure ramp that reaches maximum excess pressure in the Giero Member. Elevated excess pressures persist to the lower Alene Member at which point a pressure regression occurs into the Toro Sandstone and upper Imburu Formation. The first Angore well of the PNG LNG program (Angore B1) encountered a level of structural complexity together with extreme pressures and stresses that were not anticipated prior to drilling. Due to these complexities, the target reservoir was not reached and the well was plugged and suspended. Two subsequent wells (Angore A1 and A2) encountered similar tectonic complexity, but successfully drilled through the extreme conditions to reach the reservoir. The analyses from Angore support a geomechanical model that involves an interplay between structural history and mechanical stratigraphy, insofar as: 1) formation pressure and stress regime varies with depth and lithology; 2) stratigraphic mechanical properties and structural geometry allow for a non-Andersonian stress state (minimum stress exceeded overburden); 3) stress magnitude may be controlled by fault geometry/timing and formation excess pr
{"title":"Pressure-Stress Evaluation of Wells Drilled at the Angore Field, Western Fold Belt, PNG","authors":"S. Karner, J. A. Giddings, Tomas O'Kane, Matt Durrant, B. Darby, K. G.","doi":"10.4043/32166-ms","DOIUrl":"https://doi.org/10.4043/32166-ms","url":null,"abstract":"\u0000 \u0000 \u0000 Thirteen ExxonMobil-operated gas development wells were drilled from 2012 to 2015 at the onshore Hides and Angore gas fields, Papua New Guinea (PNG), as part of the PNG LNG drilling program. Prior to drilling the PNG LNG wells, four wells had penetrated the Hides structure and one well had penetrated Angore. This paper focuses on pressure-stress interpretations at Angore, using drilling observations and data collected from the final three wells of the PNG LNG drilling program.\u0000 \u0000 \u0000 \u0000 The pressure-stress analyses of the PNG LNG Angore wells incorporated data collected while drilling, post-drill geologic and structural interpretations, and utilized a variety of geomechanical concepts that were constrained by the well data. Post-drill formation pressures were either estimated (e.g. from petrophysical trends, mud-log data, cavings analysis, formation fluid influxes) or directly measured using downhole pressure tools (reservoir only). Rock stresses were estimated or inferred from geomechanical relationships that were constrained by wellbore data (e.g. leak-off tests, mud weights), wellbore geometry (e.g. ovalization related to breakout), cavings analysis, and drilling events (e.g. lost returns, ballooning).\u0000 \u0000 \u0000 \u0000 The Angore well pads were constructed on Miocene Darai Limestone. Below the Darai Limestone, the wells penetrated a clastic section consisting of Cretaceous Ieru Formation (Haito, Ubea, Giero, Bawia, Juha, Alene Members), early Cretaceous Toro sandstone reservoir, and Jurassic Imburu Formation. The initial exploration well (Angore 1A drilled by BP in 1990) encountered a complex pressure-stress depth profile that was comparable to nearby offset wells. Hydrostatic pressure occurs below the water table (in the Darai Limestone) and continues into the Ubea Member. The clay-rich lower Ubea Member supports the onset of a pressure ramp that reaches maximum excess pressure in the Giero Member. Elevated excess pressures persist to the lower Alene Member at which point a pressure regression occurs into the Toro Sandstone and upper Imburu Formation. The first Angore well of the PNG LNG program (Angore B1) encountered a level of structural complexity together with extreme pressures and stresses that were not anticipated prior to drilling. Due to these complexities, the target reservoir was not reached and the well was plugged and suspended. Two subsequent wells (Angore A1 and A2) encountered similar tectonic complexity, but successfully drilled through the extreme conditions to reach the reservoir.\u0000 \u0000 \u0000 \u0000 The analyses from Angore support a geomechanical model that involves an interplay between structural history and mechanical stratigraphy, insofar as: 1) formation pressure and stress regime varies with depth and lithology; 2) stratigraphic mechanical properties and structural geometry allow for a non-Andersonian stress state (minimum stress exceeded overburden); 3) stress magnitude may be controlled by fault geometry/timing and formation excess pr","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":"130430094","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}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：