Day 1 Tue, March 07, 2023最新文献

{"title":"4D Radar Imaging of Wellbore Geometry While Drilling","authors":"Lars Øy, Inge Bye, M. Lauritzen, Mike Herbert, Kamil Grunwald, Anne Mette Rød, Danny Kane","doi":"10.2118/212499-ms","DOIUrl":"https://doi.org/10.2118/212499-ms","url":null,"abstract":"\u0000 Despite advances in Measurement-While-Drilling / Logging-While-Drilling (MWD/LWD) technologies, the oil & gas industry has until recently lacked viable technologies and tools to measure wellbore geometry in large hole sizes (>12-1/4″) while drilling and subsequently the ability to visualize and describe the borehole shape and size in an intuitive way.\u0000 A direct mechanical measurement solution such as used on wireline, e.g., multi-finger tools, is not feasible to implement on MWD/LWD tools due to the nature of the drilling operation. Conventional technologies and methods, including acoustic- and density-based measurement methods have been used with reasonable results in smaller hole sizes (≤12-1/4″) when combined with low mud weights. However, many commercially available tools within the industry have low vertical and azimuthal resolution due to sparse sampling or sparse storing in its internal downhole memory of such caliper measurements, resulting in limited use of such data for borehole shape and size purposes. Such conventional technologies and methods have not been, or very seldom used in large hole sizes, primarily due to lack of available technologies and tools, resulting from challenges related to the sensor to wellbore interface standoff distance.\u0000 A novel Logging-While-Drilling Caliper tool based on impulse radar technology has been developed to overcome the challenges related to mud weight, sensor to wellbore standoff in oil-based muds and at the same time addressing challenges related to sparse datasets. This tool enables the oil and gas industry to accurately image borehole shape and size with both high vertical and azimuthal resolution, including within large hole sizes where there has not been any viable solution whilst drilling. The high sampling rate together with a large downhole memory (128 GB) allows the industry to evaluate the borehole shape and size as a function of time (timelapse).\u0000 An Impulse Radar Caliper tool has been pilot tested in several wells on the Norwegian Continental Shelf (NCS), in borehole sections ranging from 12-1/4″ to 17-1/2″. During the pilot testing, the Impulse Radar Caliper tool acquired wellbore shape and size measurements while drilling, and some intervals while pulling out of hole. Several wellbore features, not previously imaged in such large hole sizes, have been identified and their time-dependent development studied in detail. The results from this pilot campaign are discussed in this paper together with the 3D/4D tunnel-view visualization used to assess the processed caliper measurements.","PeriodicalId":382692,"journal":{"name":"Day 1 Tue, March 07, 2023","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132186474","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":"Low Friction Drilling Fluid Additive Technology","authors":"Nelson Akaighe, S. Zeilinger, Joshua Cutler, D. Bhandari, Jeffrey Bunquin, N. Bharadwaj","doi":"10.2118/212480-ms","DOIUrl":"https://doi.org/10.2118/212480-ms","url":null,"abstract":"\u0000 The use of lubricants is commonplace when drilling with water-based drilling fluids. They are less frequently applied when drilling with non-aqueous fluids, as the oil-based drilling fluid is thought to impart a high lubricity.\u0000 With increased reach of the wells, lubricants are also applied in non-aqueous fluids (NAF) to reduce torque and drag at high angle, for extended reach and horizontal wells to improve drilling efficiency. However, the performance of these lubricants in NAF at extended periods of elevated temperature at downhole conditions is often inconsistent, thought to be hampered by ineffective metal binding and hydrolytic instability of the lubricant molecule. This requires frequent re-dosing and therefore higher cost to maintain performance.\u0000 In order to identify a better-performing lubricant, it was necessary to better understand the fundamentals of lubrication in a drilling fluid. For example, what portion of the well contributes most to torque and drag? What is the frictional regime that dominates the lubricity between a drill pipe and its contact points?\u0000 Looking at theoretical analysis and modeling, it was found that the horizontal portion is dominated by the boundary and mixed layer friction regime, which is a combination of surface forces and fluid viscosity. Additionally, understanding of tribology from other industrial applications was employed to better design a molecule that can deliver optimum lubricity in a NAF.\u0000 This new understanding led to identifying an optimized lubricant for NAF. A lubricant derived from a plant-based raw material was specifically designed to be chemically and thermally stable, binding strongly to metal surfaces, and providing a tenacious film that reduces metal-to-metal friction factors during drilling, casing run and other completion operations.\u0000 The identified lubricant was tested for compatibility with NAF, including effects on rheology, elastomers, and formation damage potential. Coefficients of friction and fluid rheology comparisons and research-related field trials are presented. The results show significant (20%) reduction in the coefficient of friction after treatment, especially after hot-rolling, indicating thermal and oxidative stability of the product.","PeriodicalId":382692,"journal":{"name":"Day 1 Tue, March 07, 2023","volume":"87 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114402053","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":"Modeling of Axial Rotary Drilling Dynamics as a Step Towards Drilling Automation","authors":"Zackary Whitlow, M. Mahjoub, Sonny Auld","doi":"10.2118/212536-ms","DOIUrl":"https://doi.org/10.2118/212536-ms","url":null,"abstract":"\u0000 Analysis of low frequency axial drilling dynamics from block velocity input to surface weight on bit (SWOB) or differential pressure outputs, shows significant regional variation. This range in dynamics poses a robustness challenge for automated drilling control systems. Many factors influence drilling dynamics such as pipe stiffness, mud properties, tortuosity, friction, bit design, and BHA geometry. A simple analytic model representing axial drilling dynamics is described and compared to a finite element drilling model and to drilling data. The analytic model shows that axial drilling dynamics may be represented by a first-order transfer function with a time constant dependent on axial stiffness and drillabillity.","PeriodicalId":382692,"journal":{"name":"Day 1 Tue, March 07, 2023","volume":"41 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124988077","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":"Gas Migration Model for Non-Newtonian Fluids Under Shut-In Well Conditions","authors":"Yaxin Liu, E. Upchurch, E. Ozbayoglu, Silvio Baldino, Danzhu Zheng, Junze Wang","doi":"10.2118/212466-ms","DOIUrl":"https://doi.org/10.2118/212466-ms","url":null,"abstract":"Addressing gas migration in a static mud column during the shut-in period is a major concern in Pressurized Mud Cap Drilling (PMCD). Significant discrepancies have been found between the field data and existing correlations for gas migration velocity, since the latter are based on either small-scale experiments or overly simplified assumptions, resulting in overly conservative estimations. To meet the Light Annular Mud (LAM) requirement for managing gas migration and to monitor the transient pressure experienced throughout the PMCD operation, an improved gas migration velocity model was developed by combining the equation of motion (bubble flow) and Taylor-bubble correlation (slug flow). In the bubble flow model, the effects of non-Newtonian fluid properties and drill pipe rotation are considered through a modified drag coefficient (CD) that incorporates the bubble Reynolds number (Reb) and dimensionless shear rate (Sr). The effect of bubble swarm is taken into account through a void fraction (αg) term. The slug flow model is based on a Taylor bubble correlation in terms of Eötvös number (Eo) and inverse viscosity number (Nf). For the first time, the dependence of Taylor bubble velocity on drill pipe rotation has been shown and correlated as a function of Sr. Predictions of the gas migration velocities in PMCD operations are made and successfully compared with the existing models and test-well experimental data. The drift flux model embedded in the new gas migration velocity model was applied to simulate the gas migration in a test well. Good agreement between the model and measured pressure results in the full-scale test-well experiments can be obtained. Its companion work (Liu et al., 2023) provides the design and calculation method of key parameters in bullheading/PMCD operations.","PeriodicalId":382692,"journal":{"name":"Day 1 Tue, March 07, 2023","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123343388","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":"Autonomous Directional Drilling Simulator Development for the Drillbotics 2021-2022 Virtual Competition","authors":"Miguel Fernández Berrocal, A. Shashel, M. Usama, Md Akber Hossain, Emre Baris Gocmen, Ali Tahir, D. Sui, F. Florence","doi":"10.2118/212507-ms","DOIUrl":"https://doi.org/10.2118/212507-ms","url":null,"abstract":"\u0000 The work focuses on the drilling control algorithms as well as Artificial Intelligence (AI) technique implementation into an in-house real-time drilling simulator developed by the Drillbotics® Virtual Rig Team from the University of Stavanger, the winner of 2021-2022 Drillbotics Competition.\u0000 The designed simulator consists of a topside model capable of calculating block position, surface hookload, surface torque, and bottom hole pressure. To achieve drilling efficiency, a formation-based rate of penetration (ROP) optimization module is running in real-time, where the safe-operational windows are considered to reduce/avoid drilling accidents, like stick-slip, axial vibrations, poor hole cleaning, and low efficiency etc. The obtained optimal WOB and RPM by solving such ROP optimization are used as setpoints and then fed into the rotary steerable system module (RSS module) to steer the bit following a planned path. Such path is designed with multiple Bezier curves that can pass given target coordinates and maintain low dogleg severity (DLS). Furthermore, the high-tech AI methodologies are integrated to the simulator to smartly manage downhole pressure via perceiving and interpreting the data, learning through the trial, training through given policy, and taking optimal actions offered by the AI-agent.\u0000 The simulator is demonstrated to be a powerful and user-friendly tool for path design and optimization, real-time path control, and drilling performance optimization. It provides interactive and automatic operations of steering a bit passing multiple given target points and optimizing drilling behaviors to achieve high efficiency and low costs. From the results, the simulated (real-time) trajectory steered by the automatic RSS module integrating with surface drilling/control modules has small deviations from the planned trajectory. In the meanwhile, the simulator can precisely detect formation changes, accurately control the downhole pressure, and automatically optimize the drilling speed.\u0000 The progress of the whole simulation can be followed through the web-based graphical user interface (GUI) remotely, where the depth-base data view, time-base data view and 3D graphical wellbore trajectories are visualized. After drilling, data analytics is conducted so that useful information from operational drilling data can be extracted and subsequently evaluated for post well-analysis.","PeriodicalId":382692,"journal":{"name":"Day 1 Tue, March 07, 2023","volume":"77 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130129093","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":"Evaluation of Stress Distribution in Subsea Wellheads Installed in Caisson","authors":"Lucas Cantinelli Sevillano, S. Sangesland, Tor Berge Gjersvik, A. Faanes","doi":"10.2118/212553-ms","DOIUrl":"https://doi.org/10.2118/212553-ms","url":null,"abstract":"\u0000 The wellhead is a pressure containing vessel at the top of well and acts as the mechanical connection between well and blowout preventer (BOP), or Christmas tree. Wellheads in subsea wells are subjected to dynamic loading, and consequently fatigue damage, whenever a riser connects a well to a floating vessel. This paper investigates the load distribution and stresses along the components of subsea wellheads installed in a caisson, as an alternative to mitigate wellhead fatigue.\u0000 To prevent fatigue-related incidents, operators, suppliers, and classification societies have collaborated to improve the evaluation of wellhead fatigue. A detailed finite element model (FEM) of the wellhead is used to simulate the mechanical response of the system and calculate stress levels at relevant spots. The simulations presented in this study follow the industry's recommended practices to investigate the potential of reducing the loading on wellhead fatigue hot spots by having a caisson installed around the conductor. Different parameters were established to evaluate the sensitivity of the system's response and determine the optimal mechanical configuration.\u0000 Caissons have been used to place the wellhead and the Christmas tree below the mudline level, as a protective measure against icebergs in Arctic regions and trawl nets in fishing areas. The results of the presented study case indicate that this practice may be of benefit to subsea wellheads in general. The interactions with the caisson and the thick cement ring between conductor and caisson near the mudline may alter the response of the wellhead to the environmental loads transferred by the riser. While the magnitude of the loading itself is not reduced, its distribution along the wellhead components is. As a result, stresses on wellhead spots particularly vulnerable to fatigue failure, such as welds, may be reduced, while stresses on other, less vulnerable, locations of the wellhead may increase, which still results in a net gain to the overall service life of the product.\u0000 Installation of a subsea wellhead in a caisson is a potential fatigue mitigating measure applicable to new wells, either in satellite or clustered configuration. The industry's established experience with similar equipment may expedite the adoption of this measure.","PeriodicalId":382692,"journal":{"name":"Day 1 Tue, March 07, 2023","volume":"57 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124536327","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":"Proven Well Stabilization Technology for Trouble-Free Drilling and Cost Savings in Pressurized Permeable Formations","authors":"Genaro Quiroz Broca, G. Gomez, Octavio Blanco, R. Maldonado, Jené Rockwood","doi":"10.2118/212543-ms","DOIUrl":"https://doi.org/10.2118/212543-ms","url":null,"abstract":"\u0000 Case studies have shown the benefits of applying a unique wellbore stabilization technology to solve lost circulation events occurring in varying pressurize, permeable, and fragile formations. Leveraging this technology can increase successful drilling in geologically complex areas while avoiding conventional solutions that are both costly and and, in some cases, do not solve the causes of non-productive time.\u0000 A unique wellbore stabilization technology has been proven effective in offshore wells in areas that are known to present small vugs, natural fissures, formation failure, wellbore erosion, and the associated drilling problems of lost circulation, poor cementing quality, problems running pipe, etc. When compared with the cost and operational lack of success offered by conventional \"solutions\" versus the relative low-cost and operational successes of the unique wellbore stabilization technology, the choice is clear – where use is appropriate, the stabilization technology has provided a greater success rate and trouble-free drilling operations at a lower cost than traditional solutions.\u0000 The unique wellbore stabilization product is designed to address microfractures (as small as 3 µm) up to much larger fractures (3,000 µm). The product can be added to oil-based or water-based fluids at functional levels without adversely impacting the fluid rheology. Once in the drilling fluid, the stabilization product forms a pressure-sensitive layer on the formation wall to isolate the drilling fluid from the wellbore and stop fluid invasion that leads to formation failure, uncontrollable lost circulation, and well control issues. Once drilling is completed, the drop in pressure differential of the wellbore fluid allows the protective particles in the drilling fluid to lift off with the initiation of production. In the Campeche wells, one early study showed a 36% reduction in drilling time and 24% reduction in cost.\u0000 This paper discusses the various options explored and detail the technical analysis that preceded the application of the wellbore stability technology. Case studies are presented to illustrate the effectiveness of the fluid technology in drilling three wells which encountered variable pressure regimes, from the highly pressurized Paleocene at around 5,000 m to underlying low-pressure sandstones. These three wells and their offsets represent the successful application of this low-invasion technology in major drilling basins where lost circulation events would normally incur major operational expenses and non-productive time (NPT).","PeriodicalId":382692,"journal":{"name":"Day 1 Tue, March 07, 2023","volume":"539 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124265642","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":"Design and Calculation of Process Parameters in Bullheading and Pressurized Mud Cap Drilling","authors":"Yaxin Liu, E. Upchurch, E. Ozbayoglu, Silvio Baldino, Junze Wang, Danzhu Zheng","doi":"10.2118/212455-ms","DOIUrl":"https://doi.org/10.2118/212455-ms","url":null,"abstract":"\u0000 This study aims to provide the design and calculation method of key parameters in bullheading/PMCD operations. An improved gas migration velocity model in closed well conditions was developed based on the combination of the equation of motion (bubble flow) and Taylor bubble correlation (slug flow). A detailed derivation of the model can be found in our companion work (Liu et al. 2023). Experiments of Taylor bubble countercurrent behavior in an eccentric 6 in. × 4 in. annulus were conducted. Fluid rheology, annulus inclination, and internal pipe rotational speed were varied to provide a clearer understanding of Taylor bubble physics under non-Newtonian countercurrent flow and its implications for effectively managing upward gas migration that can occur in a wellbore during drilling operations in fractured or vugular rock formations. Computational Fluid Dynamics (CFD) simulations were performed to estimate the velocity of Taylor bubble in vertical annuli with downward fluid flow and a new closure relation for distribution parameter, C0, was proposed. The drift flux model embedded in the new gas migration velocity model was applied to simulate the dynamics of bullheading/PMCD. Good agreement between the model and published data was obtained. The effect of different bullheading rates on surface pressure and gas fraction in PMCD operation was examined.","PeriodicalId":382692,"journal":{"name":"Day 1 Tue, March 07, 2023","volume":"18 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122767678","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":"Gas Tight Mechanical Casing Anulus Packer Enables Compliance with Well Design and Barrier Requirements for Re-Entry Multilateral Application in 20+ Year Old Well on Norwegian Continental Shelf","authors":"Brett Hrabovsky, U. Koberg, Keino Roxman, Jan Ove Fagna","doi":"10.2118/212570-ms","DOIUrl":"https://doi.org/10.2118/212570-ms","url":null,"abstract":"\u0000 With continually increasing drilling costs, the importance of utilizing existing slots in offshore platforms has never been higher in increasing average rate of recovery from the Norwegian Continental Shelf. Utilizing existing slots for new targets that were once inaccessible due to a multitude of reasons including technology limitations, value justification, among others pose many challenges for the operator.\u0000 One of these challenges specifically relates to compliance with current well design criteria and barrier requirements. As our industry has evolved, more stringent design criteria and additional well barrier requirements ensuring well integrity have become commonplace. In addition, integrity reduction of previously installed downhole components must be accounted for. Utilizing casing strings and polished bore receptacles (PBR's) that have been installed and exposed to harsh downhole environments for 20 + years create a need for innovative solutions\u0000 Through this paper we will demonstrate how through proper planning and equipment selection the operator was able to successfully install a gas tight mechanical casing annulus packer in a tieback string. This provided mechanical isolation of the previous casing string that had been exposed to years of wear. Traditional solutions of a tieback seal stem stung into a PBR were not possible due to expected condition of the seal surface in the PBR from years of down hole exposure. The rigorous qualification and validation program of the packer led to its selection in this application. Acceptance criteria of ISO 14310: V0 was used as the basis for testing. This included testing in a casing joint that had been previously installed in a well for 25+ years, mimicking downhole environments for this application.\u0000 The annulus packer was installed integral to the tieback casing and activation was combined with subsequent installation of multi-lateral junction equipment. Requiring no dedicated runs for installation or activation provided additional value for the operator. The packer was tested as per well design criteria which allowed the operator to proceed with well construction and continue to new target with upmost confidence in barrier compliance and well integrity.","PeriodicalId":382692,"journal":{"name":"Day 1 Tue, March 07, 2023","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123419500","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":"Integrated Ship Energy Flowchart: A digital twin to mitigate GHG emissions","authors":"Elias Elias Yfantis, Constantina Ioannou, A. Paradeisiotis","doi":"10.5957/some-2023-009","DOIUrl":"https://doi.org/10.5957/some-2023-009","url":null,"abstract":"The alarming rate of climate change accentuates the need to reduce greenhouse gas (GHG) emissions produced from anthropogenic activities and consequently the consumption of fossil fuels. The transportation sector is one of the most energy-demanding activities, consisting around 27% of the global primary energy demand and one of the major contributors of GHG emissions to the atmosphere, while shipping transportation accounts for nearly 12% of its CO2 emissions. Decarbonization is vital for emission mitigation using innovative technologies, policies, and incentives at a local and international level. In this context, the presented Integrated Ship Energy Flowchart (ISEF), aims to create a digital twin of a ship and carry out deterministic calculations, such as engine power requirements and by extension fuel consumption and emissions, by modelling the various components of a ship’s energy flow. Most modeling approaches depend on tracking data from automatic identification systems (AIS) and commercial vessel databases, accompanied with prohibitive costs for many, as well as missing vessel characteristics. ISEF, on the other hand, aims to fill in the gap in case of missing or costly to obtain data while maintaining the flexibility to utilize field data if available. This is done by providing representative vessel characteristics, detailed engine modeling and simulating components such as environmental conditions (sea-state, wind). At the same time, ISEF develops a library of vessel data including ship particulars, engine and route information among others. Thus, it is also suitable for the validation of tracking information and machine learning or other deterministic algorithms. Additionally, this library will enable the development of a statistically representative ship describing the international fleet. This will therefore improve projection algorithms utilized in calculations and aid the evaluation of mitigation options regarding decarbonisation in terms of the overall fleet. Such a model also enables the investigation of alternative fuels and fuel mixtures, route optimization, and inclusion of cold ironing amongst others. The current objectives include the validation of the core modelling implementation via comparisons with available raw data to serve as a reference case and build the necessary libraries. Therefore, a case study of a specific ship utilizing real navigational data will be used to demonstrate the capabilities of the algorithm.","PeriodicalId":382692,"journal":{"name":"Day 1 Tue, March 07, 2023","volume":"69 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126424102","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}