Day 2 Tue, November 01, 2022最新文献

{"title":"Improving Petroleum Real Options Calculation by the Application of Quantum Artificial Intelligence.","authors":"Heru Setyabudi, I. H. Kartowisastro, A. Trisetyarso, E. Abdurachman","doi":"10.2118/211817-ms","DOIUrl":"https://doi.org/10.2118/211817-ms","url":null,"abstract":"\u0000 Regarding the issue of carbon gas and reducing fossil energy to environmentally friendly energy, an investor certainly needs an accurate calculation model with a fast calculation time for the adjacent investment portfolio. The smart energy concept integrates information and communication to improve overall efficiency. One of the fossil energies that is still the mainstay of energy today is crude oil. However, it has price constraints that have high volatility and there will be changes in business patterns in the oil and gas industry sector. Capital planning has been a struggle for Oil and Gas companies. Computing speed has increased dramatically, but there are still problems making reasonable computation times. The problem is in the field simulation in determining how much detail can be modeled to make it accurate but maintain fast calculation times. This is a popular topic in the Oil and Gas industry these days. Real Options Quantum Computing (ROQC) tries to find trends and information not seen by traditional methods, either the Discounted Cash Flow model (DCF) and the Real Option Valuation model, of course, representing new methods of work and analysis in the future. ROQC attempts to measure the risk associated with the financial success of a project as it relates to the accuracy of the proposed capital budget and costs as well as the speed which is processed near-realtime.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130044165","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":"Single-Trip Completion Technology Development for ERD Wells","authors":"Fraser Murray, K. Wee, Yao Fernand Kouadio, Shardul Parihar, J. Wills","doi":"10.2118/211553-ms","DOIUrl":"https://doi.org/10.2118/211553-ms","url":null,"abstract":"\u0000 A well operator wanted to maximize operational efficiency for extended-reach drilling (ERD) wells of more than 45,000 ft measured depth (MD) by converting from a two-trip to a single-trip completion solution. A safety valve, field-adjustable polished bore assembly (PBA), and production packer were developed for the single-trip completion design used in both the producer and injector well environments. Strong collaboration between the well operator and completion technology supplier resulted in a tailored technology development and validation program that reduced operational risk as much as reasonably practical. The technology developer achieved several significant technical milestones during the process, which are discussed in more detail. A pre-run computational modelling strategy was developed to manage deployment risks and ensure the technology operated as designed. The analysis performed using this strategy, along with details on how this data is used to configure the technology is also discussed. Track record details are provided to demonstrate successful deployment of the new technology in a live well environment. To date, the operator has successfully deployed three systems in wells between 30,000 and 45,700 ft MD. The well operator and technology supplier continue to collaborate on ongoing and future wells, where the developed system adds significant value.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"2013 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130179513","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 Sustainable Drive in Well Intervention Operations with Case Studies","authors":"Salman Saeed Muhammad, Mustansar Raza, Hossam A. Elmoneim, A. Yousuf, Rameez Anwar, S. Khokhar, Saqib Jah Temuri, Afnan Dar Ahmed, Kamil Shehzad","doi":"10.2118/211289-ms","DOIUrl":"https://doi.org/10.2118/211289-ms","url":null,"abstract":"\u0000 Clean out using coiled tubing is the second largest application of coiled tubing after nitrogen kick-off. The advancements in coiled tubing metallurgies to intervene in complex wellbore geometries and precision of downhole simulators to predict on-site scenarios require more efficiencies from end tools that evolved from simple jetting tools to rotating jetting heads. The objective intended in the case studies performed in the Middle East and South Asia was to perform cleanout in scenarios where incumbent tools had failed in the past.\u0000 The impact of jetting action in cleanout operations decreases with an increase in stand-off distance. It was confirmed from laboratory tests that a standoff of eight times the orifice diameter and fluid velocity of 200 ft/sec is required to remove moderate to hard deposits from wellbores. Conventional jetting tools have a standoff distance of more than 40 times and fluid velocities are below 200 ft/sec thus objectives are often compromised. A new type of fluidic oscillator was utilized in the case studies discussed in the paper. Unlike pulsating effects created by 1st generation of the fluidic oscillators, the SFO type oscillator had triple jetting action namely, Helix jetting, Pulses Jetting, and Cavitational jetting.\u0000 The result of the clean-out with SFO technology was beyond expectations. It saved cost in all the case studies by an average of 35% if had been performed with incumbent technologies and increased production/injection from 30% - to 250% of the original value. Moreover, it reduced the operating times to two-thirds of conventional operations and increased the efficiency of treatment fluids which resulted in the reduction of waste of additives and extra additives to dispose of excess materials at wellsite.\u0000 This is the first technology that used cavitational jetting in oilfield services and the first to use aforesaid jetting actions altogether in one tool. The technology adopted in the case studies doesn't have moving or rotating parts, thus eliminating the requirement to pull CT out of the hole for redressing and can perform long operations in one go. It doesn't depend on the centralization of the tool as the jetting effect is passed via kinetic energy through submersed fluids, thus can target deeper depth without limitations of the standoff. It allows a higher flow rate of liquid and gas, thus offering higher fluid velocities to perform an effective cleanout.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"53 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129395537","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":"Machine Learning Based Prediction of PVT Fluid Properties for Gas Injection Laboratory Data","authors":"K. Ghorayeb, K. Mogensen, Nour El Droubi, Samat Ramatullayev, C. Kloucha, Hussein Mustapha","doi":"10.2118/211080-ms","DOIUrl":"https://doi.org/10.2118/211080-ms","url":null,"abstract":"\u0000 Gas injection pressure-volume-temperature (PVT) laboratory data play an important role in assessing the efficiency of enhanced oil recovery (EOR) processes. Although typically there is a large conventional PVT data set, gas injection laboratory studies are relatively scarce. On the other hand, performing EOR laboratory studies may be either unnecessary in the case of EOR screening, or unfeasible in the case when reservoir fluid composition at current conditions is different from initial conditions. Given that gas injection is to be widely assessed as an optimal EOR process, there is increased demand on time- and cost-effective solutions to predict the outcome of associated gas injection lab experiments.\u0000 While machine learning (ML) is extensively used to predict black-oil properties, it is not the case for compositional reservoir properties, including those related to gas injection. Can we use the typically extensive conventional laboratory data to help predict the needed gas injection parameters? This is the core of this paper.\u0000 We present an ML-based solution that predicts pertinent gas injection studies from known fluid properties such as fluid composition and black oil properties. That is, learning from samples with gas injection laboratory studies and predicting gas injection fluid parameters for the remaining, much larger, data set.\u0000 We applied the proposed algorithms on an extensive corporate-wide database. Swelling tests were predicted using the trained ML models for samples lacking gas injection laboratory data. Several ML models were tested, and results were analyzed to select the most optimal one. We present the algorithms and the associated results. We discuss associated challenges and applicability of the proposed models for other fields and data sets.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128324137","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":"Innovative Approach to Develop an Old Complex Reservoir Bearing Multi-Billion Barrels of Reserves in a Middle-East Carbonate Field","authors":"Dania Wayel Younes, O. Keshtta, Khaled Alameri, Y. Bigno","doi":"10.2118/211325-ms","DOIUrl":"https://doi.org/10.2118/211325-ms","url":null,"abstract":"\u0000 This paper showcases the development approach recently adopted in an offshore reservoir bearing multi billion stock tank barrels of oil-in-place that solely depended on natural depletion starting from the year of 1962 until the introduction of the crestal gas injection mechanism in 1994, yet less than three percent of this potential has so far been recovered! This low recovery can be justified by the very complex nature of this reservoir varying from the expected highly fractured crest to the very poor characteristics of the matrix spreading towards the down flank, in addition to the high competition between this as a lazy reservoir and the other high potential reservoirs to produce against a high-pressure system of surface facilities. Even though the very first oil shipment in 1962 from this field was exported from this reservoir, all these surface and subsurface bottlenecks have been making its development so challenging that it had to be put to a halt yielding a hydrocarbon recovery that is less than three percent of its potential in the past 60 years.\u0000 A new development approach was adopted in this reservoir introducing the line drive water injection mechanism as a basis for all future development, in addition to introducing artificial means in order to overcome the high-pressure system of the existing surface facilities. Several uncertainties were encountered linked to this type of development plan for this type of complex reservoir such as well spacing (OP/WI), well architect (short horizontal vs. MRC/ERD vs. deviated), well completion, well productivity/eruptivity and for water injection as it is the first time to inject water in this type of reservoirs water injectivity, water quality, scale risk..etc. So, a dedicated de-risking plan was introduced & implemented to try to overcome and mitigate all these challenges and risks before full implementation of the proposed development plan.\u0000 The line drive pilot (OP/WI) plan was implemented mirroring the future long term development plan for the main purpose of proving the economical feasibility of the line drive recovery mechanism in such a reservoir while maximizing the acquisition of associated static and dynamic monitoring data. This will ultimately appraise and feed into the long-term development plan set for this reservoir while paving the way for it to reach its true potential and meet its future production target.\u0000 This paper discusses both the de-risking pilot design and its results, which overall, support the implementation of this development plan. The pilot was started with the oil producer since Aug-2020 followed by the water injection since Mar-2021.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131138749","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":"De-Salting Train Transformers Retrofitting and Optimization Study to Achieve Flexibility and Efficiency in Saudi Aramco","authors":"H. A. Bajuaifer, Ashiff Khan, Khaled N. Mutairi, Amir A. Kothawala","doi":"10.2118/211140-ms","DOIUrl":"https://doi.org/10.2118/211140-ms","url":null,"abstract":"\u0000 This paper covers and evaluates a retrofit work for desalting trains grids in Saudi Aramco Khurais facility to accommodate water cut increases due to field maturity. The main objective of this retrofit work is to accommodate the increase in water cut (emulsified and free water) while enhancing the de-salting process with minimum modification scope and cost effective approach.\u0000 This Paper is intended to:\u0000 Presents the retrofit basis and compare old and new grids design. Presents the results of this optimization study along graphical representations. Highlights how this initiative increased the desalting trains efficiency and redundancy.\u0000 The basic concept of the retrofit work is to change the grids in electrostatic separation vessels from the conventional tapered configuration to straight configuration. The original configuration was tapered configuration that is intended to maximize separation and balance the load on all transformers however the limitations of this configuration is in case of one grid shorted all other transformers will be shorted. Despite the available transformers capacity, however as the water cut increases the chances of water carry-over increases as well as emulsions which results in multiple outages of de-salting trains. Straightening the grids will help avoiding total outages of the transformer, so in case of one grid shorted, other two grids will be running with a higher load which provides redundancy, reliability and guaranteeing the quality targets.\u0000 This modifications were evaluated from safety, process, electrical and cost life cycle point of view and assessed post retrofitting for 1 year against there pre-defined success majors that includes:\u0000 Outage hours of dehydrator and/ or de-salter (Target less than 5 hours per quarter). Demulsifer chemical consumptions (Target reduction by 10% or more annually) Quality specification (Target maintaining BS&W and Salts within crude specifications of 0.2% and 10 PTB respectively even in case of 1 or 2 transformers shorted.\u0000 This modifications succeeded in achieving the predefined targets in addition to a cost saving equivalent to US$ 120,000 due to demulsifer injection reductions (i.e Regular and emergency dosage).\u0000 Figure 1 shows the change in grids configurations before and after retrofit work","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"76 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122186362","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":"Middle East Capital Projects Struggle with Schedule Performance","authors":"Daoud Kiomjian, Rolando Gachter","doi":"10.2118/210813-ms","DOIUrl":"https://doi.org/10.2118/210813-ms","url":null,"abstract":"\u0000 Schedule predictability has always been a problematic aspect of capital projects. This is particularly true for the GCC region, as IPA's data indicate that execution durations are typically longer than planned in the quickly developing region. Longer execution durations become particularly problematic for oil and gas projects, a predominant industry for projects in the GCC. The number of oil and gas projects in the GCC will likely grow due to the current boom in oil prices. Hydrocarbon projects will also have higher global visibility as some National Oil Companies are becoming public entities and planning such projects will put them under more scrutiny. In this work, we will explore scheduling practices driving oil and gas projects in the GCC region. We will particularly focus on the factors falling within the control of organizations and project teams.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"25 6","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"120837586","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":"Optimizing Rig Scheduling Through AI","authors":"J. Thatcher, M. Eldred, A. Suboyin, Abdul Rehman, David Maya","doi":"10.2118/211671-ms","DOIUrl":"https://doi.org/10.2118/211671-ms","url":null,"abstract":"\u0000 Traditionally, a significant amount of time is invested in producing the most optimal drilling schedule to deliver the targets considering various constraints and changing priorities. This paper demonstrates how Artificial Intelligence (AI) can generate an optimal Rig Schedule while improving on conventional planning techniques. This includes adding additional value through increase in production, freeing up assets and reduction in fuel consumption, driving cost reductions further enabling supply-chain debottlenecking.\u0000 This paper presents a real-world application and solution of the general set of optimization problems such as the Knapsack Algorithm and Vehicle Routing Problems (VRP) for optimizing rig mobilization with added real-world complexities and constraints. A dynamic system allows more than just scheduling against demand/supply as it also self-calibrates the schedule through new real-time requests and real-time situation analysis based on location, availability, and other relevant constraints.\u0000 Based on in-house case studies conducted and compared with traditional approaches for rig scheduling and optimization, the presented solution can reportedly achieve a 99% reduction in time needed for generating key results. Compared to conventional drilling scheduling methodologies, there are no or minimal white spaces for the resource allocation strategies presented by the AI solution with a potential reduction in the asset utilization (with a reduction of 5%) along with being able to reduce total distance traveled and the fuel burned (carbon emissions) assuming standard mobilization patterns based on historical data, with a reduction ranging between 11-24% as a minimum depending on the scenarios selected.\u0000 This case study provides a novel approach to the scheduling of rigs that leverages artificial intelligence for complex fleet and schedule management that provides an opportunity to generate best plans to meet KPI's with significant reduction in assets required and fuel burned (energy efficiency) during mobilization; but also provides a higher level of input into operations and could in future provide real time input into operational activity plans minimizing overall costs and input to streamline supply chain from layers of conservatism.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116415873","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":"Enhancing Drilling and Production Through a Digital Twin Methodology","authors":"Titto Thomas Philip, S. Ziatdinov","doi":"10.2118/211120-ms","DOIUrl":"https://doi.org/10.2118/211120-ms","url":null,"abstract":"\u0000 In recent years digitalization has become one of the fastest growing disciplines in the oil and gas industry. Digital solutions reduce project costs, improve personnel and process safety. However, underestimation of the deployment complexity can also bring severe damage to the project execution, unnecessary delays, and ramp-up costs. To minimize negative effects and smoothen delivery process digital twins provide for oil and gas the opportunity to create a digital representation of the equipment, processes, and people behavior.\u0000 Drilling is a very capital-intensive part of the oil and gas industry. It usessophisticated heavy machineries and typical rig contains various equipment from different vendors.Moreover, drilling process by itself has a lot of uncertainties and depends on human behaviors. Thismix makes most service and operating companies very cautious in introducing new technologies.Therefore, any solutions that can smoothen delivery process and minimize or even avoid any hitchesduring deployment bring a lot of benefits to the industry. Digital twin methodology is an ideal way toaccelerate new technologies deployment through offline full-scale digital testing.\u0000 The paper highlights efforts to assist operators and drillingcontractors to create a methodology to optimize usage of their assets and improve their processes, using a combination of Systems Architype model and Systems Development lifecycle (SDLC), both well-established methodologies for systems development. Thefocus is on performance improvement, non-productive time reduction, oil and gas productionmaximization. Through emulating rig equipment, drilling process and personnel behavior it is possible toidentify the most critical parameters which guarantee reaching technical limits. Application of digital twin isan iterative process and typically includes several steps. Starting with setting targets, like negative impactreduction of the drilling process on subsequent production. Following by determination of the optimaldrilling parameters based on either historical or modelled data both from drilling and production. Theseparameters are the basis for the new drilling methodology. All deviations from existing drillingmethodologies and generic programs must be carefully analyzed and implemented. Finally drillingmethodology built using digital twin is ready for implementation in real world. The received data is goingto the next iteration to improve the methodology. This approach allows us to train personnel for field specificsituations without risking expensive mistakes in the real world.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"93 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127061789","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":"Challenges in High Sour Gas Field Development and Non-Metallics Opportunities in Upstream Processes","authors":"Khaled H. Almuhammadi, Anwar Md. Parvez, Mustafa Buali, O. D. Salazar Vidal, A. Bukhamseen","doi":"10.2118/211374-ms","DOIUrl":"https://doi.org/10.2118/211374-ms","url":null,"abstract":"\u0000 High sour fields beyond 10% H2S concentration are considered one of the severe environments that require suitable tubular components and accessories in upstream environment to ensure sustainable production. Such environments represent a challenging operating envelop where durability and safety are the top concerns due to higher H2S concentration at a higher partial pressure and higher temperature (HPHT). The risk is amplified for the wells with higher than 10% H2S concentration, namely the High H2S wells, and those exceeding 25% H2S concentration which are typically labeled as Ultra-High H2S wells. Corrosion in gas operations can be aggravated in downhole where high H2S at higher temperatures pose additional challenges. Selection of proper material to ensure a sustainable well condition is one of the important elements for the development of these HPHT gas wells. Various challenges were identified, including the selection of cost-effective material which is capable of withstanding short and long term H2S and CO2 partial pressures as well as control generalized CO2 corrosion, sulfide stress cracking (SSC), and stress-oriented hydrogen induced cracking (SOHIC).\u0000 With the advancement of Non-Metallics (NM) materials in several applications across the O&G sector, it holds a promise to provide an alternative material solution in lieu of CRA alloy material for the HPHT downhole applications. NM materials are lightweight and they can be designed to withstand higher strength capability in addition to their outstanding corrosion resistance properties in a high H2S environment. Moreover, they can be engineered to fulfill the intended application due to their high design flexibility and durability. In the downhole applications, there is a number of NM products that have been implemented in sour environments, including sealants as well as downhole accessories and tools, where the list of NM technologies is considerably growing.\u0000 This paper highlights the concept of using NM products such as coiled tubulars, pressure control equipment and elastomers as well as the challenges on the development and deployment of these key components in high sour fields.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"19 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127099073","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}