Day 3 Wed, August 18, 2021最新文献

{"title":"Improved Acoustic Quick-Disconnect Technology for Mooring Operations","authors":"Jonathan Kent Longridge, J. Shield, Sarah Finn, T. Fulton","doi":"10.4043/31131-ms","DOIUrl":"https://doi.org/10.4043/31131-ms","url":null,"abstract":"\u0000 \u0000 \u0000 As the offshore oil and gas industry has changed, deep water Mobile Offshore Drilling Units (MODU) are commonly outfitted with dynamic positioning (DP) systems and on-vessel mooring equipment to facilitate drilling operations at ultra-deep and shallow water well locations. However, since many shallow water locations can experience harsh conditions and may require moorings for station-keeping performance, it is beneficial to enable a DP rig to quickly disconnect from its mooring system and avoid hazardous conditions without support vessel assistance. Providing this capability, acoustically releasable subsea mooring connectors allow a rig's mooring lines to be released remotely and almost immediately. Additionally, the ability to disconnect without Anchor Handler Vessel (AHV) assistance for mooring operations and rig transit support offers reduced risk and cost savings.\u0000 \u0000 \u0000 \u0000 A brief review of existing quick-disconnect mooring devices will be presented. It will highlight how the technology has evolved and is being used, particularly in recent years. Successes, problems, and lessons learned from past InterMoor and SRP product development will be summarized and focused attention will be given to a significant number of more recent improvements to increase the product's reliability, availability, serviceability, and robustness. Improvements to ensure reliable long-term battery life and power supply, enhance on-vessel accessibility and user-friendliness for rig personnel, and employ advanced acoustic signal transmission, reception, and device status analytics will be discussed. External modifications to reinforce its robustness during deployment and internal electromechanical changes to facilitate its serviceability will also be described.\u0000 \u0000 \u0000 \u0000 A substantially lighter and smaller acoustically releasable mooring connector was developed two years ago, tested thereafter, recently deployed on several offshore mooring campaigns, and has now been upgraded to incorporate high-fidelity electronics with the ability to release under tension loads as high as 900 tonnes. As such, this second-generation device's reliability, accessibility, and serviceability are significantly enhanced. Results from offshore deployments from recent MODU and barge mooring operations will be summarized. This technology provides a safer way to quickly disconnect mooring lines and offers cost efficiency by allowing faster rig moves from one location to the next with reduced risk.\u0000 \u0000 \u0000 \u0000 The paper will cover the work, challenges, trials, and tribulations required to bring a new product to market with cutting edge capabilities. Novel highlights will include the integration of a networked data transmission and communication system, the system's fundamental change from pneumatic to electromechanical actuation, and additional enhancements and improvements that are unique to mooring quick-disconnect devices and at the forefront of subsea technology.\u0000","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"12 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84784964","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}

{"title":"Optimized Completions Design Using Retrofit Autonomous Inflow Control Devices","authors":"E. Nnebocha, Akinola Akinbola, O. Kakayor, Adetayo Odutayo, Tunji Olukayode, Olawale Oguntayo, C. Onwuchekwa, A. Dikshit, A. Nkanga, Temitope Ilusemeti, Amrendra Kumar, Aleksander Rudic, O. Olagunju, Richmond Nduka Nwaokwu, Chidi Henry Ugboaja","doi":"10.4043/31301-ms","DOIUrl":"https://doi.org/10.4043/31301-ms","url":null,"abstract":"\u0000 Discovered in 1964, the Beta Field in the Niger Delta sedimentary basin consists of 25 stacked hydrocarbon-bearing reservoirs located between 5,500 and 12,000 feet true vertical depth subsea (TVDSS). A total of 26 wells have been drilled in the field, of which 11 are presently on production. Oil production peaked at 8,900 stock-tank barrels per day shortly after field start-up and has been on the decline. More than 40 years since production start-up, the Beta Field remains a relatively immature, distinctly underdeveloped asset. Only about 59 million stock tank barrel (STB), or 8% of its estimated stock-tank oil initially in place of 740 million STB, had been produced by the end of 2017. Two horizontal wells were planned in the field to provide additional drainage points and increase field production. However, a production forecast of the planned wells showed potential early water breakthrough and high water cut because of unfavorable mobility ratios of a slightly viscous oil and proximity to oil/water contact (OWC). To mitigate the production challenges and improve the reservoir sweep, autonomous inflow control devices (AICDs) were selected to be installed on the sandface completion.\u0000 These wells were drilled and completed during the COVID-19 pandemic, bringing additional challenges in equipment availability and logistics with potential to derail the successful completion of these wells within the required timeline. An innovative retrofit screen design, leveraging detailed engineering design and remote collaboration, enabled the conversion of ICD sand control screens to cyclonic AICD screens.\u0000 AICD nozzle placement was optimized using a reservoir-centric workflow that integrates the full reservoir model with the sandface completion. Real-time interpretation of the data enabled computation of porosity-permeability and saturation estimates from logging-while-drilling (LWD) logs, which was then used in updating the reservoir model in near-real time. Using a segmented well modeling approach and a refined flow distribution from heel to toe, AICD nozzle placement was optimized in real time utilizing LWD measurements from open hole along the horizontal drain, aiding the design and configuration of the AICDs.\u0000 The Beta-7 and Beta-8 wells were successfully drilled, completed, and put on production. The horizontal drains were landed within 5 to 10 feet of the top of the reservoir, maintaining at least 20-ft distance from the OWC. The forecasted simulation showed possible water influx from the toe of the horizontal as opposed to the heel because of existing water leg and high permeability at the toe. This was supported by high water-cut production from that zone in the nearby wells. This insight from the full-field simulation model enabled an informed decision on the AICD design.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"22 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88160125","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}

{"title":"Experimental Investigation of FPSO Roll Motion Response Coupled with Sloshing in a Pair of Two Row Cargo Tanks","authors":"J. Igbadumhe, M. Fürth, Jack Bonoli, J. Dzielski","doi":"10.4043/31258-ms","DOIUrl":"https://doi.org/10.4043/31258-ms","url":null,"abstract":"\u0000 Floating Production Storage and Offloading Units (FPSOs) will continue to be in high demand because of their numerous advantages; such as, their ability to offer early production and operate in ultra-deep water locations, while remaining easy to relocate to meet changing needs. By design, slack cargo tanks are almost always present in FPSOs due to continuous loading and offloading operations; however, the presence of slack cargo impacts the seakeeping stability abilities of FPSOs. There are limited published experimental data on coupled sloshing with seakeeping of stationary vessels, and existing studies on this have focused on single row cargo tanks which is seldom the case in FPSOs. The aim of this paper is to study roll motion coupled with sloshing in partially-filled pair of two-row tanks of a stationary FPSO model exposed to regular beam waves. The model tests was performed in the Davidson Laboratory towing tank at Stevens Institute of Technology. The FPSO model response in roll was measured, and the time histories of sloshing oscillation were measured on the starboard and port side of one of the stern cargo tanks. The results show that varying internal cargo sloshing leads to unpredictable motion response of floating vessels that should be accounted for in the design and offloading operations of FPSO.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"7 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85258213","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}

{"title":"Qualification of Wax Control System","authors":"Øivind Stangeland, Sigbjørn Daasvatn, Y. Novoseltsev","doi":"10.4043/31303-ms","DOIUrl":"https://doi.org/10.4043/31303-ms","url":null,"abstract":"\u0000 A cold flow plant consists of a Water Management System (WMS) for separation and treatment of produced water, and a Wax Control System (WCS) for making solid wax particles that can travel through the long tieback line without further deposition on the pipe wall. Pre-conditioning to a level of 1-2% remaining water implies that avoidance of hydrate formation can be handled by reasonable volumes and traditional chemical methods.\u0000 The Wax Control System enable a temperature independent transport of oil dominated flows by continuous removal of deposited wax from the pipe wall, allowing the solid wax particles to travel with the flow in the export line without any risk of further deposition of wax along the export pipeline. The technical qualification work included design and operation of a Pigging Loop that allowed continuously removal / handling of wax within a bundled pipeline.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"35 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90998225","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}

{"title":"Novel Experimental Method to Determine the Performance of Vacuum Insulated Tubing VIT for Deepwater Applications","authors":"I. Ceyhan, S. Vasantharajan, P. Suryanarayana, U. B. Sathuvalli, A. Helou, P. Barde","doi":"10.4043/31260-ms","DOIUrl":"https://doi.org/10.4043/31260-ms","url":null,"abstract":"\u0000 Vacuum insulated tubing (VIT) is a specialized tubular designed to minimize heat loss from production or injection fluids to the environment in oil, gas and geothermal wells. VIT strings are used in deepwater wells for flow assurance or to mitigate annular pressure buildup. VIT use requires accurate knowledge of its insulating performance. Although VIT performance can be estimated from analytical tools, such as finite element analysis (FEA), an experimental approach provides a more direct measurement and can be used to validate analytical tools. We have developed a new experimental method to address this need.\u0000 In this method, one or two VIT joints are placed in an ice-water bath. A precisely measured flow of heated air flows inside the VIT. The temperature change of the flowing air is measured between the inlet and outlet of the VIT test specimen. The insulating performance of the VIT is then calculated from this temperature difference using heat exchanger theory with effectiveness-number of transfer units (&#ξ03B5;-NTU) approach. A proportional-integral-derivative (PID) controller is used to control the air temperature at the VIT inlet by regulating power to the heater.\u0000 This paper illustrates the data reduction method and uncertainty analysis using sample test data. The method allows for rapid measurement of VIT performance at many different temperatures, with the air flow rate being used to optimize the test sensitivity and to reduce experimental uncertainty. As currently designed, the apparatus is able to test single- and double-joint VITs with effective body conductivities between 0.002-0.1 W/m/°C (0.001-0.06 Btu/hr/ft/°F) and temperatures up to 400°C (750°F); however, the design allows the apparatus to be modified easily for higher or lower conductivities.\u0000 Although designed for VIT, this method may be applied to other types of tubulars. Currently, there is no widely accepted standard method for experimental testing of VIT performance, and it is hoped that this new method may evolve to an industry standard.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"9 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89137986","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}

{"title":"Minimising the Risk of Hydrogen Embrittlement HE and Hydrogen Assisted Stress Cracking HASC Within Steel Lifting Products Used in the Marine Environment","authors":"Ben Burgess","doi":"10.4043/31314-ms","DOIUrl":"https://doi.org/10.4043/31314-ms","url":null,"abstract":"\u0000 Hydrogen Embrittlement (HE) and Hydrogen Assisted Stress Cracking (HASC) are processes that detrimentally affect certain steels. These processes are understood and well documented.\u0000 In recent years there has been an accumulation of product failures involving steel lifting components in the offshore industry. These failures have individually been investigated and confirmed as the result of Hydrogen Embrittlement (HE) and Hydrogen Assisted Stress Cracking (HASC).\u0000 There continues to be an assumption that steel lifting components that comply with international standards are suitable for use offshore, however the corrosive environment and effects of dynamic load amplification on lifting components in the offshore environment significantly increase their susceptibility to HE and HASC.\u0000 Our intention is to provide the offshore industry with technical guidance on the correct material selection in steel lifting components, over and above the requirements of international standards, to mitigate the risk of failure caused by Hydrogen Embrittlement (HE) and Hydrogen Assisted Stress Cracking (HASC).\u0000 Our research highlights that a high-grade steel's hardness and toughness is critical. The definition of toughness in metallurgy and lifting is the ability of the material to absorb energy and to plastically ‘deform’ without fracturing.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"33 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80011903","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}

{"title":"Qualification of a New Multiphase Pump. the Setting of a New Standard","authors":"A. Hofstad, Tarje Olderheim, M. Almgren, M. Rondon, E. Thibaut, Pierre-Jean Bibet","doi":"10.4043/30955-ms","DOIUrl":"https://doi.org/10.4043/30955-ms","url":null,"abstract":"\u0000 The recent trend in the oil industry is to save CAPEX and exploit every offshore field to increase production and maximize reserves. Also, deeper water and longer step-out is a challenge for new fields. The most adapted technology to unlock these reserves is the use of subsea boosting like a multiphase pump on the seafloor. Subsea boosting has been used for decades with well proven results, but up to now, some limitations in power and lift pressure exist. This new multiphase pump development has increased the potential pressure generation manyfold from the typical ΔP of 50 bar (725 psi) at the beginning of the project.\u0000 Developing such a powerful two-phase pump driven by a liquid-filled motor requires a unique combination of expertise in machinery engineering, electrical engineering, fluid mechanics and rotor dynamics. The objective of the co-authors is to share this experience by bringing some insights on what it takes to develop, test, and qualify such specific product. Outlines of the methodology will be described, key results will be detailed, and lessons learnt will be presented.\u0000 The new design was fully tested first component-wise and then for a full-size prototype. A wide process envelope was mapped during the final qualification program with 3,000 points tested in the range 2,000-6,000 RPM and 0 - 100% GVF (Gas Volume Fraction). Qualification tests concluded with more than 2,000 cumulative hours.\u0000 The main challenges in this program were the development of an innovative multiphase impeller and the qualification of the first MPP (MultiPhase Pump) with a back-to-back configuration. Concerning the motor, the development includes a high speed 6,000 RPM, 6 MW liquid-filled induction motor and a new stator winding insulation cable.\u0000 With this new product, the pump market is ready to overcome challenges to produce deeper and further reservoirs in a constant evolutive oil and gas market.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"38 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88341386","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}

{"title":"Subsea Tree Fatigue Mitigation Solutions For Shallow Water Drilling","authors":"M. Sonawane, M. Ge, Steven Johnson, M. Campbell","doi":"10.4043/31282-ms","DOIUrl":"https://doi.org/10.4043/31282-ms","url":null,"abstract":"\u0000 The offshore drilling industry is advancing technologies to extend deep water drilling technologies and attain feasibility of operations at deeper depths and higher pressures. However, shallow water operations themselves pose a certain unique set of challenges that need to be addressed with customized and innovative solutions. While shallow water poses certain benefits and conveniences to the operations, like ease of retrieval and better access to wells, there are significant challenges in terms of operational down time caused by limited operability and poor drilling riser and subsea hardware fatigue performance.\u0000 Shallow water operations do not have the advantage of deep water drilling where the motions and loads imparted to the subsea blowout preventer (BOP) are relatively decoupled and damped out by hydrodynamic damping from the significant length of the water column. Thus, the vessel motions and wave hydrodynamic loads imparted on the riser are transferred to the wellhead and subsea hardware. In this paper the fatigue challenges encountered for drilling wells in 530 ft water depth from a sixth generation moored semi-submersible rig are explored. The fatigue loading is critical for the subsea tree connector which is characterized by a high stress amplification factor (SAF). Multiple riser space-out solutions were evaluated including fairings, helically-grooved buoyancy, joints with rope, and modifications to the telescopic joint each of which will be presented in the paper along with combination of different damping parameters to optimize the fatigue performance.\u0000 The paper will present the subsea tree connector fatigue performance for different riser space-out options and make recommendations for future operations with similar conditions. Other challenges encountered in fatigue evaluation will be discussed. This will highlight the current assumptions and unknowns in data that can form the subject of evaluation for a future joint industry study.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"8 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73164766","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}

{"title":"Hydrate Management Strategy for Subsea Development in Gulf of Mexico","authors":"Samaneh Soroush, Debbie Lu, T. Golczynski, C. White, Tony Spratt","doi":"10.4043/30998-ms","DOIUrl":"https://doi.org/10.4043/30998-ms","url":null,"abstract":"\u0000 Gas hydrate formation in natural gas systems and subsea infrastructure can block pipelines and instruments, restrict flow, and lead to safety and environmental hazards in production and/or transportation systems. These problems can lead to substantial economic and HSE risks. Therefore, understanding how, when and where hydrate formation occurs are important factors in developing the hydrate management strategies. This paper addresses the hydrate management strategy in one of the subsea developments in the Gulf of Mexico (GOM). The effects of salinity, water cut, and amount of methanol on hydrate formation and plugging risk were studied in this paper. The experimental results and modeling in advanced thermodynamics software showed that an increase in the concentration of methanol and salts in the autoclave cell leads to a shift of the equilibrium curves, reducing subcooling and hydrate volume fraction while increasing induction time. The results also show that for some under-inhibited systems, the volume fraction of the hydrate slurry is low enough to allow for safe transportation of fluids during various operational conditions.","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"56 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74218807","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}

{"title":"The Use of Offshore Wind to Reduce Greenhouse Gas Emissions in Offshore Hydrocarbon Production - A Case Study","authors":"D. McLaurin, M. Paulin, Cheng-shuang Peng, Rama Yadlapati","doi":"10.4043/30993-ms","DOIUrl":"https://doi.org/10.4043/30993-ms","url":null,"abstract":"\u0000 The move to reduce greenhouse gas emissions in the offshore hydrocarbons production industry has resulted in a growing interest in the possibility of using offshore wind to reduce on-platform power generation. However, the integration of floating wind power into a brownfield development project offshore has not yet been undertaken nor has any operating greenfield projects incorporated floating wind electrification into their design. A number of smaller pilot projects exist in the floating offshore wind area consisting of single prototype floating towers to demonstrate a design concept, but these are providing power back to shore. Where electrification of offshore facilities has taken place, they have utilized shore-based power. In this paper, the authors present a case study of electrifying brownfield and greenfield oil and gas production facilities via offshore wind farms and the technical challenges associated with this transformation.\u0000 Intecsea has recently completed a generic investigation into the electrification of floating offshore oil and gas host facilities offshore Newfoundland, Canada using floating wind power. Electrification of floating host facilities eliminates or reduces the requirement for local power generation via turbine generators at the host facility, decreasing operational expenditure and total emissions from the facility. This work has included the investigation of existing offshore wind projects, equipment requirements and technical readiness, floating wind array best practices, greenhouse gas emissions reduction and required capital expenditure (capex).\u0000 In this paper, the authors present a case study of electrifying floating brownfield and greenfield oil and gas production facilities using offshore wind farms and the technical challenges associated with this transformation.\u0000 Challenges identified for the electrification of floating offshore facilities include:\u0000 challenges associated with dynamic cabling at different water depths determination of best cable configuration and array layout determination of the best suited support structure (floating foundation) sizing of generator (can have a significant effect on the tower's performance) best anchoring solutions; optimization of power tie-in and storage insufficient real estate or weight capacity (for brownfield applications).\u0000 The authors provide details on wind farm requirements and tie-in for electrification of offshore production facilities for different scenarios. A summary of modifications/additions required at a brownfield host facility for power supply by wind power array are presented. Related to floating production facilities, an investigation of ongoing project work related to dynamic, disconnectable cables which will operate in the upper end of MVAC, HVAC or HVDC range has been carried out and is presented. For cases selected, avoided GHG emissions and associated capex are estimated and presented.\u0000 The use of offshore floating wind to supplement/replace on p","PeriodicalId":11184,"journal":{"name":"Day 3 Wed, August 18, 2021","volume":"66 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75092860","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}