Day 4 Thu, August 19, 2021最新文献

{"title":"Vertical to Horizontal - Ultra Deep Azimuthal Resistivity Tool UDAR Service Helping to Maximize Production","authors":"Ahmed Zarroug El Sedeq, N. Hughes, Tore Oian, Piotr Byrski, J. Denichou, Daniel Ndubuisi Nketah, Mohamed Saher Dahroug","doi":"10.4043/31195-ms","DOIUrl":"https://doi.org/10.4043/31195-ms","url":null,"abstract":"\u0000 Dvalin field, discovered in 2010-2012. The location of this field is in the Norwegian Sea, as shown in (Figure 1). Dvalin field is an HPHT gas field in Middle Jurassic sandstone in the Garn and Ile Formations – the former being homogeneous with better reservoir properties, during the later heterogenous with low quality. (DVALIN, 2020)\u0000 The well 6507/7-Z-2 H objective is to produce hydrocarbons from the Jurassic reservoir section of the Dvalin field safely and cost-effectively. The well was planned to be drilled near vertical in the reservoir section and TD'ed at a maximum depth corresponding to the Garn Formation base.\u0000 After the productivity results from Z-3-H well came in at the low end of expectations, it was evaluated and decided to change the well profile of the Z-2-H well from vertical reservoir penetration to a horizontal profile; to have two penetrations with a minimum of 150m MD separation in the upper high permeable streak and then drop to penetrate lower high permeable streak. This decision was conducted only three days before starting the 17.5-inch section on the subject well. One Team culture was the key to achieving this significant change successfully.\u0000 The decision to change the well-profile was conducted after a thorough engineering evaluation, including offset well analysis, which was very limited as the closest horizontal well was more than 40 km away.\u0000 As the well was not planned as a horizontal well, departure between the surface location and Target Easting & Northing was minimal. Therefore, a high turn and deeper inclination build were required, which added some complexity to the well design.\u0000 One of the additional primary risks related to this change of trajectory design is deploying a more complex BHA design in the reservoir section with a full suite of LWD technologies run in an HT environment. In the planning phase, special consideration was needed to accurately simulate the expected circulating temperature and have proper procedures in place for temperature management and control.\u0000 Being the first horizontal well in the field, thus detailed planning was key for successful execution. Ultra-Deep Azimuthal Resistivity Tool (UDAR) Reservoir-Mapping capability was considered to help optimize the landing and navigate within the reservoir section. A feasibility study was conducted, and a 2-receiver Ultra Deep Azimuthal Resistivity Tool BHA configuration was selected and deployed.\u0000 During the execution, the Ultra Deep Azimuthal Resistivity Tool real-time inversion mapped the reservoir geometry, revealing resistive layers within the Garn formation, thereby facilitating optimal placement of the well to achieve the set objectives.\u0000 The well execution was largely considered flawless, with the real-time Ultra Deep Azimuthal Resistivity Tool data and corresponding interpretations facilitating decisions.","PeriodicalId":11084,"journal":{"name":"Day 4 Thu, August 19, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83829378","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 Polymer Materials for Dynamic Riser Service","authors":"C. McCord, Colin Jones","doi":"10.4043/31026-ms","DOIUrl":"https://doi.org/10.4043/31026-ms","url":null,"abstract":"\u0000 Polymer liners have been used extensively in water injection flowlines for several years, however, have only recently gained traction as a corrosion protection solution for Steel Catenary Risers and other similar rigid pipe risers as the industry moves to more novel systems.\u0000 In order to qualify a system for a dynamic service environment such as a riser, it is important to understand the system's fatigue response and characteristics to ensure that all potential failure modes are addressed. This is typically accomplished for rigid pipes via full scale resonance fatigue testing whereby a test specimen is subjected to a representative fatigue environment and point of failure determined.\u0000 Rigid pipe specimens with polymer liner installed have been trialed and reported previously. In this programme, the full-scale test strings demonstrated that all the lined system components can withstand the standard fatigue performance test curves. However, it did not confirm the boundary conditions for failure of the polymer liner, as failure of the metallic host pipe always occurred first.\u0000 A similar method can be used to test the polymer material in isolation, however given the strain levels involved and the material's inherent fatigue resistance, it was expected that the duration of testing would be impractical. It was therefore necessary to implement a test method that allowed for identification of the polymer boundary conditions within a reasonable time frame, whilst also allowing for comparison with existing fatigue testing.\u0000 In order to achieve this, a small-scale fatigue testing programme was setup in line with ISO 18489, whereby pre-notched dumbbell samples would be prepared and tested, firstly at 23°C but also at 0°C and 60°C to not only allow comparison with existing full-scale data, but also allow determination of suitability across the full temperature range expected in service.\u0000 Testing results have demonstrated that the polymer's fatigue resistance far exceeds that of the steel pipe, even with the inclusion of pre-initiated cracking in the samples. The testing was able to provide key data on parameters and their influence on the material's fatigue life such as temperature, stress and strain.\u0000 Further to this, an additional test programme was setup to evaluate the influence that the vertical orientation of the riser has on the polymer liner system. In this test programme, the interaction force between the steel pipe and polymer liner was assessed to establish the necessary design criteria to ensure that the interaction force always exceeds the vertical self-weight of the liner.\u0000 Testing results demonstrated that the steel pipe/liner interaction force exceeded the equivalent self-weight of the liner eliminating potential failure modes associated with creep. As a result, the vertical orientation of the riser does not present a risk to the integrity of the liner system.","PeriodicalId":11084,"journal":{"name":"Day 4 Thu, August 19, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81549038","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":"Mitigating Wellhead Fatigue While Reducing HSE Risk, Deck Spread, Deployment Time, and Crew Size","authors":"G. Ulland, Gunnar Hilsen, Stefano Croatto","doi":"10.4043/31047-ms","DOIUrl":"https://doi.org/10.4043/31047-ms","url":null,"abstract":"\u0000 Subsea wellhead systems have a design fatigue life that is expected to withstand the damage incurred from stress caused by cyclic loading during its operation. Wellhead fatigue is a critical factor when drilling offshore wells because the condition of the wellhead determines the length of time drilling activities can be carried out safely.\u0000 The presence of the BOP on top of the wellhead affects fatigue life. Initially, these units were designed for 6-in. and 10-in. diameter casing and weighed slightly less than 1,400 lb. [ASME, 2003) Over time, BOPs evolved, and today's units are considerably larger and heavier than their predecessors, weighing in at approximately 400 metric tons. This increase in size and weight on the wellhead negatively impacts fatigue life.\u0000 In recent years, the oil and gas industry has begun to look for ways to reduce wellhead fatigue to extend the life of the wellhead and expand the margins for safe drilling operations. A new ROV-operated Wellhead Load Relief (WLR) system, developed specifically to mitigate fatigue, uses special tensioners that are tethered individually to the BOP. Each tensioner contains a hydraulic spooling unit with a lock- and-pull mechanism that allows the ROV to tighten adjustable tethers subsea, pulling them from slack to a maximum tension of 35 metric tons.\u0000 This approach to installation is a departure from common industry practice, which necessitates the configuration of the predetermined tether lengths on the topside. The ROV-operated WLR system described in this paper is a compact, high-capacity BOP tethering system suitable for both template and seabed anchoring. It provides a new and efficient way of tethering the BOP to avoid wellhead fatigue and delivers additional benefits that include minimized HSE risk, a smaller deck spread, decreased deployment time, and a smaller crew.\u0000 The WLR system was operated subsea for the first time in December 2019. By precisely tensioning each tether and limiting the load transferred to the wellhead, the WLR significantly lessened wellhead fatigue, resulting in an almost complete halt in BOP movement.\u0000 This new technology enables the operator to make optimal use of the fatigue life of the wellhead without compromising efficiency or safety.","PeriodicalId":11084,"journal":{"name":"Day 4 Thu, August 19, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75772902","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":"Simulated Full Lifetime Response Data of a Turret-Moored FPSO for Training AI Using HPC","authors":"H. Lim, Hyoungchul Kim, Bonjun Koo, D. Sidarta","doi":"10.4043/30963-ms","DOIUrl":"https://doi.org/10.4043/30963-ms","url":null,"abstract":"\u0000 Typically, limited operational time and data are available to adequately train artificial intelligence (AI) models for new field developments. Simulation data has the potential to train AI, but it must be sufficiently accurate, reliable and comprehensive. The main objective of this research is to generate and customize response data of a turret-moored Floating Production Storage and Offloading (FPSO) vessel for AI training.\u0000 Direct time-domain simulation, covering the entire service life (e.g. 100,000 simulations, each representing 3 hours, for 35 years) of a floating platform, has become practical using High Performance Computing (HPC). In this study, 21-year hindcast Gulf of Mexico environmental data with 3-hour intervals for the Gulf of Mexico are simulated, and the responses of a turret-moored FPSO are analyzed using a fully coupled time domain analysis method. The FPSO and turret are modeled as independent bodies and connected through a bearing connection model, which allows rotation of the FPSO with respect to its mooring system.\u0000 The numerical model, which has been validated through model tests, is utilized for simulating the entire service life responses of a turret-moored FPSO. The results provide 61,360 cases of 3-hour time series data with 6 degrees of freedom (DOF) responses for both the turret and FPSO, mooring tensions, and interaction loads between the turret and FPSO. Significantly, the large yaw response, which is a unique characteristic of a turret-moored FPSO, is accurately captured. Moreover, the simulated data set is sufficiently large for AI training, and the real time predictions of a turret-moored FPSO are discussed.","PeriodicalId":11084,"journal":{"name":"Day 4 Thu, August 19, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83670965","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":"Industry's First Sidetrack in 12-1/4-in Casing Enables Operator to Re-Establish Production in GOM","authors":"Tom Emelander","doi":"10.4043/31245-ms","DOIUrl":"https://doi.org/10.4043/31245-ms","url":null,"abstract":"\u0000 In a Gulf of Mexico (GOM) ultradeepwater well, liner integrity issues forced an operator to consider milling a conventional casing exit to sidetrack as deep as possible to re-establish production. Milling a window in 12 -1/4-in. heavy wall casing above the liner hanger had never been achieved before because of the thickness and grade of casing. A successful installation would require significant preplanning and testing to prove capability before real-world application.\u0000 The service provider recommended an off-the-shelf solution to accommodate a 12 -1/4-in. casing exit. It was determined that the best fit for the application would be the standard equipment used for exits out of 10 -3/4-in. casing, given the similar internal diameters (IDs). Despite never having performed an installation in this casing size, the provider had a successful run history for exits in heavy weight casing strings. Job challenges included avoiding cutting a casing connection, managing swarf, milling through a centralizer, and achieving a low dogleg for production packers. Additional challenges included torque limitations, mill gauge, and the limestone formation.\u0000 An 8-in. outside diameter (OD) system with mechanical anchor and 9 -7/8-in. OD mills was sent to a test well designed to replicate the target section of the offshore well. Based on determinations made in the planning phase, milling of the window and rathole would be staged in two trips. Additionally, a replica drilling bottom hole assembly (BHA), 8 -5/8-in. casing, and a replica production packer would need to pass through the window to ensure both window quality and low enough dogleg. Dogleg data was acquired through multiple logging runs during the 10-day operation. The installation went as planned, along with an additional custom window elongation run to decrease the dogleg severity to approximately 4.5°/100 -ft (30m). Having successfully validated the equipment for the application, the operator and servicer prover were comfortable moving onto the GOM well. Considering the test results, the team planned to mill the window and rathole in one trip. They achieved the 22 -ft long window and 15 -ft rathole in one run that lasted 26 hours. This installation is the first sidetrack conducted with a whipstock in 12 -1/4-in. casing.\u0000 This paper shows that a safe, reliable casing exit installation is possible in difficult applications, such as uniquely heavy wall casing, even though it may previously have been considered impossible. This successful application provides the industry with contingency options in similar scenarios.","PeriodicalId":11084,"journal":{"name":"Day 4 Thu, August 19, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79129964","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":"A Numerical Investigation of Low Salinity Polymer Flooding Effects from a Geochemical Perspective","authors":"Omar Chaabi, E. Al-Shalabi, W. Alameri","doi":"10.4043/31191-ms","DOIUrl":"https://doi.org/10.4043/31191-ms","url":null,"abstract":"\u0000 Low salinity polymer (LSP) flooding is getting more attention due to its potential of enhancing both displacement and sweep efficiencies. Modeling LSP flooding is challenging due to the complicated physical processes and the sensitivity of polymers to brine salinity. In this study, a coupled numerical model has been implemented to allow investigating the polymer-brine-rock geochemical interactions associated with LSP flooding along with the flow dynamics. MRST was coupled with the geochemical software IPhreeqc. The effects of polymer were captured by considering Todd-Longstaff mixing model, inaccessible pore volume, permeability reduction, polymer adsorption as well as salinity and shear rate effects on polymer viscosity. Regarding geochemistry, the presence of polymer in the aqueous phase was considered by adding a new solution specie and related chemical reactions to PHREEQC database files. Thus, allowing for modeling the geochemical interactions related to the presence of polymer.\u0000 Coupling the two simulators was successfully performed, verified, and validated through several case studies. The coupled MRST-IPhreeqc simulator allows for modeling a wide variety of geochemical reactions including aqueous, mineral precipitation/dissolution, and ion exchange reactions. Capturing these reactions allows for real time tracking of the aqueous phase salinity and its effect on polymer rheological properties. The coupled simulator was verified against PHREEQC for a realistic reactive transport scenario. Furthermore, the coupled simulator was validated through history matching a single-phase LSP coreflood from the literature. This paper provides an insight into the geochemical interactions between partially hydrolyzed polyacrylamide (HPAM) and aqueous solution chemistry (salinity and hardness), and their related effect on polymer viscosity. This work is also considered as a base for future two-phase polymer solution and oil interactions, and their related effect on oil recovery.","PeriodicalId":11084,"journal":{"name":"Day 4 Thu, August 19, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76792014","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 Barrier Fluidless, Sealless Seawater Canned Motor Pumps","authors":"D. Stover, Christian Pagani","doi":"10.4043/31122-ms","DOIUrl":"https://doi.org/10.4043/31122-ms","url":null,"abstract":"\u0000 The oil and gas industry continues to push toward subsea pumping technologies that minimize required support systems and increase system reliability. Canned motor technology has been applied successfully in other applications to achieve similar objectives including driving a subsea twin-screw pump. Applied subsea, canned motors eliminate the need for any barrier fluids within the motor, the myriad of systems and complexities necessary to store and replenish these fluids, and the mechanical shaft seals required to prevent the leaking and/or contamination of these fluids within the motors.\u0000 As a direct adaptation of proven applications, see Figure 1, subsea water treatment is ideal for canned motor technology. Therefore, a development has been initiated and environment qualification testing of the first truly barrier fluidless, sealless subsea pump solution is complete.\u0000 This purpose of the paper is to highlight the novel elements of this technology, review the system configuration, and document the system performance in accordance with the TRL 4 qualification initiative.","PeriodicalId":11084,"journal":{"name":"Day 4 Thu, August 19, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73406041","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":"An AI-Based Detection System for Mooring Line Failure","authors":"D. Sidarta, N. Tcherniguin, P. Bouchard, H. Lim, Mengchen Kang, Aurelien Leridon","doi":"10.4043/31120-ms","DOIUrl":"https://doi.org/10.4043/31120-ms","url":null,"abstract":"\u0000 Safe and productive offshore operations are of utmost importance, with monitoring the integrity of mooring lines on floating offshore platforms being one of the key factors. The conventional method uses sensors installed on mooring components, which may fail over time and can be costly to replace. Alternative methods using dry and non-intrusive monitoring systems offer a lot of potentials to the industry.\u0000 An alternative method that uses only Differential Global Positioning System (DGPS) data has been proposed by Sidarta et al. (2018, 2019), and it does not require any information on environmental conditions. This alternative method is based on monitoring shifts in the low-frequency periods and mean yaw angles as a function of vessel positions, mass and added mass. The method utilizes Artificial Intelligence, specifically Artificial Neural Network (ANN), for the detection of mooring line failure, which is a pattern recognition and classification problem. The ANN model learns to recognize and classify patterns of intact mooring lines and those of a broken line. One of the proposed models is a group identification model, in which the model identifies the mooring group that has a broken line.\u0000 This paper shows that an ANN model can be quite robust and tolerant in dealing with conditions that are somewhat different from its training. As an example, an ANN model for detecting mooring line failure on a spread moored FPSO has been trained using MLTSIM hydrodynamic simulations with quasi static model of the mooring lines and risers to significantly reduce the computational time to generate the ANN training data. The trained ANN model can properly function when tested using fully coupled OrcaFlex hydrodynamic simulations with environmental conditions that are not included in the training. Moreover, although the ANN model has been trained using simulations with a completely removed line, the trained model can still function for a line broken at the bottom.\u0000 This ANN model is an ANN-based status detection model, which is one of the key components in the ALANN (Anchor Lines monitoring using Artificial Neural Networks) System. The system also composes of an ANN-based system evaluation model, an algorithm-based status detection program and an event detection program. A series of fully coupled dynamic simulations have been used to test the ALANN System. Most of the simulations have a single mooring line failure that occurs randomly during simulation, and the failed line varies for different simulations. Each simulation lasts for six hours. The ALANN System uses a two-hour time window at a time and moves every 20 minutes. The tests demonstrate how each component of the ALANN System contributes to and improves the robustness of the overall solution.","PeriodicalId":11084,"journal":{"name":"Day 4 Thu, August 19, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77584247","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":"Water Disposal Wells Injectivity Enhanced by Well Treatment Optimization","authors":"W. Mei, A. Al-Anazi, K. Yateem","doi":"10.4043/31185-ms","DOIUrl":"https://doi.org/10.4043/31185-ms","url":null,"abstract":"\u0000 Produced water is always an unwanted by-product for any hydrocarbon producing process. Underground disposal of the produced formation water has many benefits such as minimum or no damage to the environment. However, formation damage arising from injection of water containing impurities is usually of great concerns and poses challenges for maintaining good injectivity of disposal wells. Well stimulation is probably one of the most effective treatment to restore the injection of impaired wells. Therefore, well treatment and optimization always play an important role in cost saving and injectivity improvement.\u0000 Although many treatments such as acidizing and mutual solvent have been developed as a standard practice and are widely employed in the oil and gas industry, there is no universal treatment recipe which may be used to effectively stimulate a well without doing any well specific studies. To effectively tackle the injection rate decline issue in water disposal wells, understanding the process, quality of injection water and the nature of the in-situ properties of the formation is vitally important. Therefore, analysis of the formation minerals and lithology, produced water, well performance and field stimulation histories had been thoroughly reviewed and examined to understand the root causes and the mechanisms underlying the rate reduction and how to improve the injectivity. Laboratory experiments had then been organized and conducted for evaluating and optimizing the treatment. Fit-for-purpose well treatments were finally designed and executed for field evaluation. Once the field treatment was done, a thorough review and benchmarking of the treatment job had been performed to capture the lessons learned. More laboratory evaluation may be necessarily carried out for further improvement in the next well treatment.\u0000 Applying the above process to the treatment of water disposal wells, a new well specific matrix stimulation treatment had been developed and applied to a few water disposal wells over the last few years. When compared with the outcomes of other types of treatment in history, the injection gain from this type of treatment was significant with a maximum 400% injection increase. Moreover, the improved injectivity had longer effective duration up to 26 months so far. Still a few wells have no signs of injection rate drop. The benefits are obviously enormous in terms of cost saving and injection gain.\u0000 Effectiveness of a well specific treatment is rooted into the thorough understanding of the physical and chemical interaction between alien fluids and the in-situ formation. Laboratory evaluation is an important key to the development of a successful treatment recipe, which was showcased by the work presented in this paper. This would enrich the expertise of petroleum professionals in the limited stimulation practice of the water disposal wells.","PeriodicalId":11084,"journal":{"name":"Day 4 Thu, August 19, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78896878","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":"A Novel Subsea Actuator to Electrify Small-Bore Valve","authors":"A. Orth, Gottfried Hendrix, M. Kubacki, Pedro Joao Duarte da Silva, Juliano Victor De Negri","doi":"10.4043/31083-ms","DOIUrl":"https://doi.org/10.4043/31083-ms","url":null,"abstract":"\u0000 This paper presents the development and qualification of a novel Subsea Electric Actuator, especially designed for rotary small-bore valves. One of the main challenges was to design an electric actuator which is as compact as the existing hydraulic actuators, but able to provide a fail-safe mechanism by field-proven springs and full integration of all necessary components, including the electric drive and controls, inside of a compact enclosure. Furthermore, the design team had to considerably reduce its power consumption and weight in comparison to existing solutions. Finally, the system was designed for lean manufacturing, allowing considerable cost-saving benefits for all the partners due to extensive standardization work. The paper shows the engineering requirements obtained by interviewing different users, the design methodology applied and the qualification of the new system up to TRL 3 with Digital Twin and Rapid Prototyping. Finally, an outlook is presented with the planned TRL 4 and TRL 5 qualification tests and a summary of the technical and economic benefits for the users of this novel Subsea Valve Actuator.","PeriodicalId":11084,"journal":{"name":"Day 4 Thu, August 19, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83123445","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}