Day 2 Wed, March 23, 2022最新文献

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Analytical Modelling of Gas Hydrates in Porous Media 多孔介质中天然气水合物的解析建模
Day 2 Wed, March 23, 2022 Pub Date : 2022-03-18 DOI: 10.4043/31645-ms
H. Rabbani, Muhammad Saad Khan, M. Qureshi, Mohammad Sohel Rahman, T. Seers, B. Lal
{"title":"Analytical Modelling of Gas Hydrates in Porous Media","authors":"H. Rabbani, Muhammad Saad Khan, M. Qureshi, Mohammad Sohel Rahman, T. Seers, B. Lal","doi":"10.4043/31645-ms","DOIUrl":"https://doi.org/10.4043/31645-ms","url":null,"abstract":"\u0000 A mathematical model is presented to predict the formation of gas hydrates in porous media under various boundary conditions. The new mathematical modeling framework is based on coupling the analytical pore network approach (APNA) and equation proposed by De La Fuente et al. [1]. Further, we also integrate thermodynamic models to capture the phase boundary at which the formation of gas hydrates takes place. The proposed analytical framework is a set of equations that are computationally inexpensive to solve, allowing us to predict the formation of gas hydrates in complex porous media. Complete governing equations are provided, and the method is described in detail to permit readers to replicate all results. To demonstrate the formation of hydrates in porous media, we analyzed the saturation of hydrates in porous media with different properties. Our model shows that the hydrate formation rate is positively related to the porous media's pore size. The hydrates were found to be preferably formed in the porous media composed of relatively larger pores, which could be attributed to the weak capillary forces resisting the formation of hydrates in porous media. The novelty of the new analytical model is the ability to predict the gas hydrates formation in porous media in a reasonable time using standard engineering computers. Furthermore, the model can aid in the estimation of natural gas hydrate reservoirs, which offer the avenue for effective methane recovery from the vast natural gas hydrate reserves in continental margins.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"52 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79545706","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}
引用次数: 0
Newly-Developed Visualized Reservoir Characterization While Drilling Technology Improves Understanding of Complex Channel Sand, Assists EOR in a Mature Oilfield in Bo Hai Bay 随钻可视化储层表征新技术提高了对渤海湾成熟油田复杂通道砂体的认识,有助于提高采收率
Day 2 Wed, March 23, 2022 Pub Date : 2022-03-18 DOI: 10.4043/31440-ms
Bin Yang, M. Nie, Hong Shen, Yu Guo Li, Nian Da Xu, Huan Zhang, Cheng De Niu
{"title":"Newly-Developed Visualized Reservoir Characterization While Drilling Technology Improves Understanding of Complex Channel Sand, Assists EOR in a Mature Oilfield in Bo Hai Bay","authors":"Bin Yang, M. Nie, Hong Shen, Yu Guo Li, Nian Da Xu, Huan Zhang, Cheng De Niu","doi":"10.4043/31440-ms","DOIUrl":"https://doi.org/10.4043/31440-ms","url":null,"abstract":"\u0000 PLxx oilfield is a mature oilfield which has been developed by horizontal wells for several years with water-injection production style. It features with shallow, complex, high challenging unconsolidated channel sand with lateral property variation due to pinch out, stacking or lamination. The thickness of pay zone changes from couple of to ten more meters which brings much high challenge to reservoir delineation while drilling and horizontal well placement execution. The oilfield locates at a faulted belt of Bo Hai Bay among which some small faults may happen. But it's difficult to be identified because of the low S/N ratio incurs from the shallow gas effect on the seismic data.\u0000 Moreover, uneven flowing zone units exist within sandstone package due to dynamic reservoir production, uncertainty of lateral sand connections and possible inter-well interventions. As such, this makes the oil-water distribution more complicated and the oil-water contact isn't uniform in the sand package.\u0000 In order to furtherly understand the complex channel sand, place the wellbore in the favorable sweet spot and enhance the oil recovery, a newly-developed visualized reservoir characterization while drilling integrated technology associated with RSS(rotary steerable system), HSVP(high speed data transmission system), RTC(remote transmission connection through Internet) and OSC(operation support center) was employed to optimize the operation efficiency during a three-wells drilling campaign in this oilfield. This newly-developed reservoir characterization technique is the industry innovative fully 9 components measuring azimuthal Electro-Magnetic propagation tool in one single sub. It provides not only the conventional propagation resistivity but also the geo-signal responses in a very quick, flexible way. In one of the case, the unique \"Dual-diagonal orthogonal T-R antenna design\" ensures the DOI (depth of investigation) as deep as 6.8meters.\u0000 The reservoir boundaries such as the top, the bottom or the oil-water contact were distinctly characterized and the horizontal drainage section was precisely navigated within the profitable pay zone. The post-well reservoir characterization result is comparable with the seismic profile and very helpful to understand the dynamic reservoir flowing zone unit. The excellent performance is also reflected in the oil production; the initial oil production was increased from 40 m3/day to 69m3/day which is 75% higher than expected. Minimum 25% of oil recovery will be enhanced as forecast.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"25 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86315512","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}
引用次数: 0
Noise Logging Application for Well Integrity Evaluation: A Case Study in Peninsular Malaysia 噪声测井在井完整性评价中的应用:以马来西亚半岛为例
Day 2 Wed, March 23, 2022 Pub Date : 2022-03-18 DOI: 10.4043/31401-ms
L. J. Saw, Hanalim Linda, Tolioe Amelio William
{"title":"Noise Logging Application for Well Integrity Evaluation: A Case Study in Peninsular Malaysia","authors":"L. J. Saw, Hanalim Linda, Tolioe Amelio William","doi":"10.4043/31401-ms","DOIUrl":"https://doi.org/10.4043/31401-ms","url":null,"abstract":"\u0000 \u0000 \u0000 Field-X was first discovered in 1979, comprising of saturated oil reservoirs with several shallower non-associated gas reservoirs. Field-X is currently producing from several oil producers. X8 well was recently drilled, completed, and produce from A and B reservoirs. However, 5 months later, the oil rate has been reduced by half with gas oil ratio (GOR) increased up to 5 times. Consequently, the well had to be shut-in due to reservoir management plan (RMP) violation. X9 well was drilled and completed, but 5 years later the well started experiencing the sustained production casing pressure (PCP) and was forced to shut-in in the following year with the locked-in potential of both A and B reservoirs.\u0000 To diagnose the root cause of high GOR (HGOR) in X8 well and sustained PCP in X9 well, the Spectral Noise Log (SNL) was deployed. The main advantage of utilizing SNL is its capability of detecting fluid movement behind tubing and casing. High differential pressure creates lots of fluid movement, which generates higher noise amplitude. Meanwhile, smaller pores or leaks generate higher frequency noise that can be easily picked up by SNL.\u0000 SNL tool was run in flowing condition for X8 well and the results indicated the HGOR zones were mainly contributed by the shallower B05 sand which was flowing through the leaked 4-1/2″ liner packer. Temperature deflections also indicated that the liner packer seal was leaking and B05 reservoir was contributing to the production. The liner packer leak and B05 reservoir flow would not have been detected by conventional production logging tools as the flow was happening beyond the tubing and casing. For X9 well, SNL was run in the wellbore whilst pumping water via annulus, through the leaks and flowing back up the tubing. Three tubing leaks were successfully detected from the SNL run, whereas previous conventional noise log only managed to detect 2 leaks. It is possible that the third small leak was very small, hence the conventional tool was unable to detect it.\u0000 X8 well successfully back online with 8.4% rate increase than last production with GOR reduced back to initial GOR and X9 well successfully back online as per last production rate. The liner packers which are not permanent barriers for reservoir isolation and allocation can be validated, moreover, verifying that tubing leakage is mainly contributed by tubing joints, which can be used as the main input in tubing materials selection in the future.\u0000 Well integrity issues can cause significant loss of production, oil spill or worst case, even loss of lives. Proper selection in data acquisition tools helps to accurately diagnose well integrity issues that can be swiftly addressed. In the low oil price environment, skimming down on data acquisition costs may not uncover the true underlying well issues or reservoir issues, but might jeopardize future projects to be undertaken in years to come.\u0000","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"248 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73536042","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}
引用次数: 0
Comparison Between the Pseudo-Analytical and Finite Difference Method for Seismic Modelling and Imaging 地震模拟与成像伪解析法与有限差分法之比较
Day 2 Wed, March 23, 2022 Pub Date : 2022-03-18 DOI: 10.4043/31687-ms
M. Muhammed, M. Isa, S. Mishra
{"title":"Comparison Between the Pseudo-Analytical and Finite Difference Method for Seismic Modelling and Imaging","authors":"M. Muhammed, M. Isa, S. Mishra","doi":"10.4043/31687-ms","DOIUrl":"https://doi.org/10.4043/31687-ms","url":null,"abstract":"\u0000 Seismic forward modelling is typically done using the finite difference (FD) approach. However, this method suffers from numerical dispersion problems which translates into less focused stacks and a decrease in bandwidth coverage. To mitigate this problem, the pseudo analytical method formulated by Etgen and Brandersberg-Dahl in 2009 was utilized. This paper demonstrates that pseudo analytics’ pseudo differential operator that utilizes velocity interpolation allows it to be more robust towards varying velocity and grid sizes while providing better amplitudes for shot gathers compared to the FD modelling scheme. FD and pseudo analytically generated gathers were then migrated using the reverse time migration (RTM) algorithm and showed that the pseudo analytically generated shot gathers were better at preserving shallower and higher frequency reflectors while at the same time better suppressed migration artifacts at the steeply dipping salt flank. The pseudo analytically generated gathers also provided an improved amplitude spectrum compared to FD especially in the lower frequency range of around 25-50 Hz. Various test cases demonstrate that the pseudo analytical method was shown to be a viable alternative to the typically used FD method in imaging at challenging geological environments such as salt.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"13 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75226832","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}
引用次数: 0
Magnetometer Survey: Multi-Discipline Collaboration Impacting Bottom Line 磁力计调查:影响底线的多学科合作
Day 2 Wed, March 23, 2022 Pub Date : 2022-03-18 DOI: 10.4043/31628-ms
Muhd Akram Kamaruzaman, Mohd Saifullah Din, Ernyza Endot, P. Sim, Chrissie Lojikim, C. Chang, Mohd Faiz Mohd Ramli
{"title":"Magnetometer Survey: Multi-Discipline Collaboration Impacting Bottom Line","authors":"Muhd Akram Kamaruzaman, Mohd Saifullah Din, Ernyza Endot, P. Sim, Chrissie Lojikim, C. Chang, Mohd Faiz Mohd Ramli","doi":"10.4043/31628-ms","DOIUrl":"https://doi.org/10.4043/31628-ms","url":null,"abstract":"\u0000 Central Luconia has been explored with hundreds of well since the 1950s. During that time, all offshore wells were drilled using hyperbolic positioning system which has lower accuracy compare to current satellite positioning system, which was only introduced in early 1990s. With this knowledge, the old exploration well's locations (which was drilled in 1970s) pose potential hazards in terms of seabed obstruction and potential well collision during the future development wells drilling. Without a reliable seismic to well tie, interpreter has difficulty in identifying the top of carbonate event for depth conversion, thus impacting the well delivery, static model building and subsurface reserves estimation.\u0000 Onsite verification was carried out using a multibeam echosounder (MBES), a Side Scan Sonar (SSS), and a Sub Bottom Profiler (SBP) in accordance with standard site survey procedures, but the existing wellhead location was unable to be detected because the wells had been abandoned and cut off at the seabed level. Magnetometer was deployed to further investigate the existing wellhead location; the sensor was towed approximately about three (3) times water depth from the stern of the vessel and altitude 10m from the seabed. To navigate the towed sensor, Ultra Short Baseline (USBL) transponder was attached close to the sensor to get real time underwater positioning. Five (5) survey lines were designed centered at the suspected existing wellhead location with the coverage of 60m radius. During data acquisition, the magnetic anomalies were recorded in the system via receiver and total magnetic data was used for further analysis to derive the as-found wellhead location. During the interpretation, the area of ambient magnetic field distortion was identified and marked as anomaly which represents \"area of suspected wellhead\". The magnitude and pattern of such distortion was used for interpretation and combined with the coordinates from the positioning system (surface and underwater) onboard the survey vessel.\u0000 The general total magnetic field reading is ranging between 40920nT and 41130nT with the magnetic anomaly/wellhead had magnetic value from 100nT to 115nT. The total magnetic field analytical signal value is ranging from 0 to 3.5. The target magnetic anomaly refers to the area with greatest analytical signal value where it is also the area with most drastic change of the total magnetic field. From the survey results, the as-found wellhead position varies from 48m - 53m compared to existing wellhead position. With the confirmation on the old wellhead location, this helps to derisk the well collisions study for future development well and also improves the seismic to well tie analysis to provide higher confidence in the Top Carbonate pick and a better inverted seismic match in the reservoir interval for properties distribution.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"91 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75926617","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}
引用次数: 0
Integrated Well Test Interpretation Approach for Complicated Carbonate Reservoirs: A Field Case 复杂碳酸盐岩储层综合试井解释方法:现场实例
Day 2 Wed, March 23, 2022 Pub Date : 2022-03-18 DOI: 10.4043/31528-ms
Yongjie Liu, Zhaobo Sun, Renfeng Yang
{"title":"Integrated Well Test Interpretation Approach for Complicated Carbonate Reservoirs: A Field Case","authors":"Yongjie Liu, Zhaobo Sun, Renfeng Yang","doi":"10.4043/31528-ms","DOIUrl":"https://doi.org/10.4043/31528-ms","url":null,"abstract":"\u0000 The main characteristic of the complicated carbonate reservoirs is notably strong heterogeneity, leading to a high uncertainty in formation parameter evaluation [1,2]. In general, logging, core analysis and pressure transient analysis (PTA) are used to evaluate the reservoir parameters of carbonate rocks. However, core and logging analysis can be used to get static parameters in the range of centimeter to meter, while PTA can obtain static and dynamic parameters in the range of hundreds of meters to several kilometers, such as skin coefficient, boundary conditions, permeability and cross flow coefficient. Therefore, the PTA results are more practical and reliable. However, the well test curve shows similar characteristics for multi-layers reservoirs, dual-medium reservoirs, and carbonate reservoirs with lithology mixed sedimentation lithology [3,4]. It is important to reduce the parameter evaluation multiplicity.\u0000 However, many scholars did not consider the multiplicity of PTA interpretation in practical application, which led to large errors in the results [5,7]. Therefore, this paper comprehensively summarizes all the reasons leading to the depression of pressure derivative curve, and puts forward the corresponding identification approach, which has been applied in Abu Ghirab reservoir well test interpretation and created conditions for improving the accuracy of PTA.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"79 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87102555","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}
引用次数: 0
The Deployment of Deep Learning Models for Performance Optimization and Failure Prevention of Electric Submersible Pumps 深度学习模型在电潜泵性能优化和故障预防中的应用
Day 2 Wed, March 23, 2022 Pub Date : 2022-03-18 DOI: 10.4043/31612-ms
Silpakorn Dachanuwattana, Suwitcha Ratanatanyong, T. Wasanapradit, Pojana Vimolsubsin, Sawin Kulchanyavivat
{"title":"The Deployment of Deep Learning Models for Performance Optimization and Failure Prevention of Electric Submersible Pumps","authors":"Silpakorn Dachanuwattana, Suwitcha Ratanatanyong, T. Wasanapradit, Pojana Vimolsubsin, Sawin Kulchanyavivat","doi":"10.4043/31612-ms","DOIUrl":"https://doi.org/10.4043/31612-ms","url":null,"abstract":"\u0000 Real-time sensors are crucial for monitoring electrical submersible pump (ESP) operation. However, manually analyzing the whole data from these sensors is virtually impossible due to its overwhelming volume. Artificial intelligence (AI) is a game-changing tool that can leverage the big data from ESP sensors more efficiently. Coupled with ESP knowledge, AI could reveal insights into ESP behaviors, well performances, and reservoirs dynamics, leading to ESP life extension and better production optimization.\u0000 In this paper, we present the development and deployment of an AI workflow to enhance ESP surveillance. The workflow is developed in-house using the Python programming language and consists of the following four main modules:\u0000 Data ingestion – to ingest all ESP-relevant databases Data preprocess – to transform the databases in the format ready for AI modelling AI modelling – to experiment several AI models, e.g., to detect ESP critical events, and predict ESP run life. Deployment – To automatically notify ESP critical events and visualize insight from the AI models\u0000 The application of a hierarchical clustering algorithm reveals that the ESP run life in our fields are most influenced by gas production. Then, after more than 1000 runs of experiments, we achieve a deep learning model to predict whether an ESP will fail within the next 90 days. We also develop a module to automate nodal analysis as part of the AI workflow. Combining this physics-based model with a data-driven approach, the resulting AI models can accurately detect ESP critical events, such as ESP degradation, imminent gas lock, and sand production.\u0000 To deploy the AI workflow, we build a dashboard to effectively visualize actionable insights from the AI models on our local server. The workflow sends notifications of ESP critical events to users for prompt troubleshooting actions and collects user feedbacks for improvement of the AI models in the next model development cycle.\u0000 This paper demonstrates a holistic approach to develop a closed-loop ESP surveillance workflow that integrates the powers of AI, automation, and ESP knowledge including nodal analysis. The AI workflow potentially creates value of several million dollars or higher per year by extending ESP run lives and optimizing production. The lessons learnt from this AI workflow development are shared to assist the development and deploying of similar AI methods throughout the oil and gas industry.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"26 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81173676","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}
引用次数: 1
Floating Offshore Wind Energy – Brief Review of Prospects, Project Development Life Cycle, Policy and Technology Challenges and Project Management Complexity 浮式海上风能——展望、项目开发生命周期、政策和技术挑战以及项目管理复杂性的简要回顾
Day 2 Wed, March 23, 2022 Pub Date : 2022-03-18 DOI: 10.4043/31543-ms
Prasannakumar K. Purayil, Sujith Pratap Chandran
{"title":"Floating Offshore Wind Energy – Brief Review of Prospects, Project Development Life Cycle, Policy and Technology Challenges and Project Management Complexity","authors":"Prasannakumar K. Purayil, Sujith Pratap Chandran","doi":"10.4043/31543-ms","DOIUrl":"https://doi.org/10.4043/31543-ms","url":null,"abstract":"Interest in Floating Offshore Wind Farm (FOWF) is regaining momentum as countries and energy producers vie for economic and innovative solutions to decarbonize products and operations with net zero targets in perspective. Typically tapping offshore wind is costlier in comparison to land based solutions, despite the flexibility it offers due to remote operations away from populated areas. Floating wind farms offer an attractive mix of flexibility and cost effectiveness by eliminating the need for large supporting structures and enabling further deep-sea installations and access to stronger winds. While floating wind turbine technology is promising, it needs further maturation along with favorable policy implementation on the part of regulators to make floating wind farms attractive to operators/investors. This paper investigates Technology, Project Management challenges and opportunities from a large, Joint Venture capital project context with net zero target perspectives. Conceptually, floating wind energy is generated by a cluster of floating wind turbines, as against conventional fixed-bottom turbines which account for the majority of wind installations today. Several recent technological advancements have led to innovative floating wind solutions and also driven the costs downward. However, technological challenges like mooring and anchoring systems suited for harsh environments and policy challenges still present barriers to increased investment decisions. In both cases, synergies could potentially be harnessed from existing Oil & Gas deep sea technology. This paper will attempt to address such technology and policy challenges, as well as project management perspectives in maturing floating wind technology. Further, the project development lifecycle will be analyzed from stakeholder and risk management, technology maturation, decision making, and complexity management perspectives. While alleviating cost and flexibility challenges related to stick-built fixed-base solutions, floating technologies may have strategic potential to unlock the full potential of offshore wind and to serve as a vehicle to achieve green transition goals. This paper summarizes the potential risks and opportunities from political, economic, socio-cultural, technological, legal and environmental (PESTLE) points of view. Potential stakeholder influences and a decision quality matrix will be identified and documented. FOWF, PESTLE, Project Management, Complexity Management","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82819832","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}
引用次数: 0
Performance Evaluation of W Shape Dynamic Inter-Array Cable Configuration for Floating Offshore Wind Turbine 海上浮式风力机W型动态间阵电缆结构性能评价
Day 2 Wed, March 23, 2022 Pub Date : 2022-03-18 DOI: 10.4043/31344-ms
L. Shi, Wanzhe Yang, Kai Chen, Guojun Yu, Canwei Jin, Lingxiao Ni, B. Jing, Zhendi Hu
{"title":"Performance Evaluation of W Shape Dynamic Inter-Array Cable Configuration for Floating Offshore Wind Turbine","authors":"L. Shi, Wanzhe Yang, Kai Chen, Guojun Yu, Canwei Jin, Lingxiao Ni, B. Jing, Zhendi Hu","doi":"10.4043/31344-ms","DOIUrl":"https://doi.org/10.4043/31344-ms","url":null,"abstract":"\u0000 Floating wind farms has been a global trend in utilizing offshore wind resources. With the development of floating offshore wind turbine (FOWT), dynamic inter-array cable would be required to connect between floating structures. W shape is a kind of dynamic cable configuration that shape the cable floating in midwater and connect between floating platforms. This paper tends to look into W shape dynamic cable configuration performance in extreme environmental conditions. The sensitivity of buoyancy and cable length is evaluated, which provides information for future development of such kind of configuration.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"129 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85757711","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}
引用次数: 1
Predictive Modelling of Carbon Dioxide Injectivity Using SVR-Hybrid 基于SVR-Hybrid的二氧化碳注入率预测模型
Day 2 Wed, March 23, 2022 Pub Date : 2022-03-18 DOI: 10.4043/31472-ms
Mutia Kharunisa Mardhatillah, M. A. Md Yusof, A. Sa'id, Iqmal Irsyad Mohammad Fuad, Yen Adams Sokama- Neuyam, Nur Asyraf Md Akhir
{"title":"Predictive Modelling of Carbon Dioxide Injectivity Using SVR-Hybrid","authors":"Mutia Kharunisa Mardhatillah, M. A. Md Yusof, A. Sa'id, Iqmal Irsyad Mohammad Fuad, Yen Adams Sokama- Neuyam, Nur Asyraf Md Akhir","doi":"10.4043/31472-ms","DOIUrl":"https://doi.org/10.4043/31472-ms","url":null,"abstract":"Southeast Asia is increasingly gaining attention as a promising geological site for permanent CO2 sequestration in deep saline aquifers. During CO2 injection into saline reservoirs, the reaction between injected CO2, the resident formation brine, and the reservoir rock could cause injectivity change due to salt precipitation, mineral dissolution, and fine particles migration. The underlying mechanisms have been extensively studied, both experimentally and numerically and the governing parameters have been identified and studied. However, the current models that have been widely adopted to investigate reactive transport and its impact on CO2 injectivity have fundamental limitations when applied to solve small, high dimensional, and non-linear data. The objective of this study is to develop efficient and robust predictive models using support vector regression (SVR) integrated with hyperparameter tuning optimization algorithms, including genetic algorithm (GA). To develop the model, 44 datasets are used to predict the CO2 injectivity change with its influencing variables such as brine salinity, injection flow rate, particle size, and particle concentration. The performance for each model is analyzed and compared with previous models by determination of coefficient (R2), adjusted determination of coefficient (R¯2), average absolute percentage error (AAPE), root mean square error (RMSE) and mean absolute error (MAE). The model with the highest R2 is selected as the predictive model for CO2 injectivity impairment during CO2 sequestration in a saline aquifer. The results revealed that both SVR and GA-SVR are able to capture the precise correlation between measured and predicted data. However, the GA-SVR model slightly outperformed the SVR model by a higher R2 value of 0.9923 compared to SVR with R2 value of 0.9918. Based on SHAP value analysis, brine salinity had the highest impact on CO2 injectivity change, followed by injection flow rate, particle concentration, and jamming ratio. It was also found that hybridization of genetic algorithm with support vector regression does improve the model performance contrary to single algorithm and contributes to the determination of the most impactful factors that induce CO2 injectivity change. The proposed model can be upscaled and integrated into field-scale models to improve the optimization of CO2 injectivity in deep saline reservoirs.","PeriodicalId":11081,"journal":{"name":"Day 2 Wed, March 23, 2022","volume":"3 3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83479651","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}
引用次数: 1
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