Day 1 Mon, November 12, 2018最新文献

{"title":"Managing Drilling Risk Using an Integrated Approach to Real-Time Pore Pressure Prediction","authors":"N. Patel, S. Penkar, M. Blyth","doi":"10.2118/192692-MS","DOIUrl":"https://doi.org/10.2118/192692-MS","url":null,"abstract":"\u0000 Pore pressure and wellbore stability estimation in real-time has become a mandatory service in any situation where drilling hazards are expected and particularly in the cases of deep water, exploration, geologically complex and extended reach settings. The basic workflow assumes that under-compaction is the primary cause of abnormal pore pressure generation (Eaton 1975), where an increase in formation pressure is associated with a response in sonic, density and resistivity logs, and models are defined based on this assumption. However, structural deformities, dipping beds or alternate pressure mechanisms could result in a wrong prediction of pore pressure based on what is observed in the shales above, or what is predicted from the standard models. Besides increasing the Eaton exponent or creating different normal compaction trend lines (Malinverno et al., 2004; Sayers et al., 2006) or using an unloading parameter (Bowers 1995), there is the need to define an integrated approach using multiple data sources to construct and constrict the model.\u0000 Advanced mud gas interpretation and cavings (pieces of rock not drilled by bit or reamers) analysis have become important tools in real time pore pressure and wellbore stability monitoring and are used to determine the approach to a structural deformity (faults/fractures) or the presence of elevated pressures at the crest of a permeable formation, either due to lateral transfer or gas buoyancy. Analysis of cavings shape, structure and mode of generation helps to determine the current borehole condition and whether the mud weight (MW) needs to be raised to control the problem, or just modifying the drilling parameters would suffice. The presence of connection gas peaks aids the pore pressure analyst to estimate the pore pressure across a permeable formation by associating its magnitude and its relationship to dynamic (equivalent circulating density - ECD) and static (equivalent static density - ESD) environments. The use of Managed Pressure Drilling (MPD) to maintain a constant backpressure across the annulus, negates this fluctuating static to dynamic environment and hence affects the use of mud gas behavior to determine if the prevailing MW column is sufficient to provide static overbalance, but workflows to address this issue have been defined over the years. Although, the industry is currently beginning to use these secondary indicators into their workflows, there is no standard that incorporates these sources into a single, cohesive workflow.\u0000 This paper presents an integrated approach to pore pressure prediction and managing drilling risk by incorporating multiple sources of information beyond classical log-based techniques. It demonstrates the value of advanced mud gas interpretation, drilling mechanics interpretation, cavings and drilling parameter analysis to optimize the pore pressure model in real-time and enhance the traditional techniques.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"13 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82362372","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Optimized Isochronal Flow Tests","authors":"F. Franco, A. Rincón, M. Useche","doi":"10.2118/193252-MS","DOIUrl":"https://doi.org/10.2118/193252-MS","url":null,"abstract":"\u0000 An Optimized Isochronal Test (OIT) is presented to evaluate the deliverability of a reservoir eliminating the need of shut-in periods during a multirate well test, which represents an operational constraint for classical isochronal tests and in some instances for modified isochronal tests.\u0000 The proposed technique is based on the effect of several consecutive and different production rates over the well-reservoir model during both transient flow and pseudo-steady state flow; thus, it is possible to estimate the reservoir pressure at different radius of investigation, and the ratio between production volume and pressure drop. This method does not require stabilization of static reservoir pressure after a flowing period since it is calculated using a mathematical procedure based on the transient pressure equation.\u0000 A reservoir simulation model with known petrophysical parameters, fluid properties, pressure and temperature, is used as a reference to evaluate the accuracy of the proposed methodology. Two types of fluids are tested, a low compressible black oil and a high compressible gas condensate, with the objective to demonstrate the optimized isochronal test applicability with pressure, pressure squared P^2, and pseudo-pressure Ψ(P) equations. The production deliverability is evaluated applying four different analysis: flow after flow test, isochronal flow test, modified isochronal flow test and the proposed optimized isochronal flow test; the results are compared and analyzed using the percentage of error found for every method.\u0000 The optimized isochronal analysis provides the option to avoid shut-in periods during a multipoint well test and provide reliable production deliverability curves. OIT has a direct impact in reduction of costs and deferred production for companies involved in oil and gas operations.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"17 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77076251","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":"Business Process Improvement in ADNOC Gas Processing through Lean Kaizen Approach","authors":"Amal Balbahaith","doi":"10.2118/193130-MS","DOIUrl":"https://doi.org/10.2118/193130-MS","url":null,"abstract":"\u0000 In the past decade, the expansion of global market has significantly changed and has showed remarkable growth. This has also led to more challenges and competition like never seen before. The competition became tougher as the range and quality of goods and services available broadened. Hence to thrive in such cut-throat competition companies now need to focus on providing quality service and products at competitive prices. This distinctive change in the market also resulted in change in the approach; from a solely profit based approach to quality based approach. The word \"kaizen\" in japenese refers to improvement. kaizen lean in business philosophy refers to removal unuseful contents. It means to change for the better. In order to improve continuously and persistently all that is waste must be eradicated. The concept of lean and kaizen go against the traditional belief of just making improvement, amendments or addition to the existing system instead of time and again focusing on removing the waste and what is no longer required.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"44 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75633986","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Concept of Right Modelling, Toward a More Effective Usage of the Static Modelling Tool","authors":"R. Lazar","doi":"10.2118/193073-MS","DOIUrl":"https://doi.org/10.2118/193073-MS","url":null,"abstract":"\u0000 The reservoir modelling task occupies most of the reservoir modeller daily routine. The key challenge faced by the reservoir modeller has shifted from the ability to build A reservoir model to building THE right reservoir model. The concept of right modelling responds to the challenge of building more predictive reservoir model by using a structured methodology to use the static modelling tool in a more efficient fashion. Complexities are introduced in the model only when required and supported by hard data. A set of guidelines, covering the overall workflow, are established for the principal reservoir modelling tasks. By following the guidelines, the reservoir modeller can handpick the best modelling strategy to ensure that the reservoir is modelled at the right level. Following the right modelling concept minimizes the risks of under modelling (not tackling the technical need in a robust way) or over modelling (losing the technical relevance by being too narrow) the reservoir.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75439716","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":"Tipping the Scale in LNG Plant Design: Considerations for Train Size, Driver Selection, and Adopting Digitalization","authors":"D. Guccione, M. Russell","doi":"10.2118/193321-MS","DOIUrl":"https://doi.org/10.2118/193321-MS","url":null,"abstract":"\u0000 In recent years, there has been a great deal of discussion surrounding the topic of mid-scale vs. large-scale liquefaction trains in LNG export facilities. While in some select cases, mid-scale trains (0.5 – 2 million tonnes per year (typ)) may offer commercial, executional, and financial advantages, the decision is not a simple matter of one-size-fits-all, as large trains (>3 million tpy) offer economies of scale, among other benefits. As this paper will explain, choosing a solution that delivers the most value over the life of a facility is contingent on the operator's specific objectives and circumstances. Ultimately, train size and liquefaction licensor selection have only a marginal impact on project capital costs as long as the total facility achieves a minimum of 8 million tpy (Russell, 2018).\u0000 The paper will offer objective cases for building both mid- and large-scale trains and outline key areas for project stakeholders to consider when making an informed decision regarding capacity and liquefaction licensor. It will also discuss important considerations for optimizing LNG plant design, such as mechanical driver selection, modularization, and the incorporation of digital technologies. The paper will conclude by discussing the importance of adopting a holistic strategy that integrates the entire gas value chain when attempting to drive out costs, minimize risk, and maximize overall project economics.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"13 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77271473","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":"Application of Point on Wave Controlled Switching on High Voltage Systems for Weak Offshore Grids","authors":"Sara Al Ammari, Murugendrappa N. Kotrappa, M. Manna, Mohamed Abou El Makarem","doi":"10.2118/192763-MS","DOIUrl":"https://doi.org/10.2118/192763-MS","url":null,"abstract":"\u0000 At offshore oil and gas islands, on site generators running independently are often utilized. These on site generators have their benefits but also pose their own drawbacks and may have their own problems. Due to the instability of those weak offshore grids, the grid disturbances may cause power outages, voltage fluctuations, changes in frequency, blackouts …etc. which are easily felt by the consumers and can also impact the performance and the service life of the electrical equipment.\u0000 A study has been performed to examine different methods to improve the reliability of the overall network. Circuit breakers are designed to react by opening or closing the circuit as soon as a command is received. While doing so, the circuit breakers go through tremendous high stresses which ultimately may cause it to produce an arc. This phenomenon can be mitigated and reduced using controlled switching. This technology involves pre-defined control strategy for opening and closing each circuit breaker pole independently. Controlled switching methodologies are used to minimize the stress on circuit breakers, prevent failure of electrical equipment and improve power quality without affecting the overall grid. This new cost effective technology helps in reducing disturbances while improving electrical reliability to the end consumer. High Voltage Shunt Reactors, Subsea Cables and Transformer Energization and De-energization cause high inrush current on the system. Power system study software has been utilized to identify which loads will provide the optimum benefit when implementing the Controlled Switching application.\u0000 This paper addresses the benefits of using controlled switching on high voltage circuit breakers on weak offshore grids. This paper also studies the applications and advantages of controlled switching of 132kV long subsea cable and transformer feeders wherein high inrush current is expected while showing the outcomes of research results and actual scenarios that have been implemented","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"46 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74234649","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":"Reactive Flow in Unconsolidated Sandstone: Application to Carbon Geosequestration","authors":"Hongyan Yu, Yihuai Zhang, M. Lebedev, Zhenliang Wang, M. Verrall, S. Iglauer","doi":"10.2118/193141-MS","DOIUrl":"https://doi.org/10.2118/193141-MS","url":null,"abstract":"\u0000 Carbon dioxide (CO2) inject to the saline aquifers are general considered as the best candidates for large-scale storage and CO2 enhance oil recovery. The pore structure and permeability are changed by the fines release, migration in the initial stage of CO2 injection, which is of great importance for reservoir screening and injection design requires adequate understanding. We thus imaged an unconsolidated sandstone at reservoir condition before and after live brine injection in situ with micro-CT core flooding apparatus. We conclude that the pore structure of the unsolid high pores media rock can be significantly changed after live brine injection, although the porosity just have a small increased. Meanwhile, many fractures are generated in the quartz after live brine flush away. Specific surface area are quantified from micro CT scan image analysis to calculate the absolute permeability. The permeability is significantly improved due to the pore structure change which can improve CO2 infectivity, especially low-permeability reservoirs. The results of this study present a broad characterization of the mechanical properties in lacustrine shale and can therefore help optimize hydraulic fractured fundamental and enhanced gas recovery.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"16 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79385072","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":"Continuous Improvement of Hybrid-Solvent Solutions through a Smarter Formulation","authors":"Stefano Langé, Jing Zhao, R. Cadours, C. Weiss, M. Bernadet, Michel Caetano, Lise Layellon","doi":"10.2118/192677-MS","DOIUrl":"https://doi.org/10.2118/192677-MS","url":null,"abstract":"\u0000 This paper presents how the optimization of the solvent composition provides significant OPEX reduction and simplifies process management.\u0000 Removing mercaptans from natural gas is becoming a tough work for operating companies due to the tightening of commercial specifications for sulfur-containing molecules in the final products. Beside this, about 40% of the known gas reserves are sour; some of them contain H2S and mercaptans. To commercialize these gas fields in a profitable way, smart process solutions focused on energy efficiency are needed. Classical gas sweetening units are based on chemical absorption by means of aqueous alkanolamines to remove CO2 and H2S from natural gas. These solvents have limited mercaptans removal capacity, requiring supplementary removal processes. This has a negative impact on the overall gas processing costs.\u0000 To face this challenge, TOTAL has developed a new series of hybrid solvents able to remove, in a one- step operation, CO2, H2S and mercaptans. Process performances can be improved without plant modification. The first solvent formulation was based on DiEthanolAmine (DEA) and was implemented in the sweetening units of the Lacq plant (France), demonstrating the benefits of the new hybrid solvents at industrial scale.\u0000 DEA solvent is a widely used and easy-to operate/monitor solvent. However, DEA has the drawback to be sensitive to chemical and thermal degradation. Moreover, DEA regeneration is quite energy demanding.\u0000 To overcome these problems, the amine components have been changed. The choice of new components is driven by following characteristics: good solvent stability, low regeneration energy demand, high CO2 and H2S removal efficiency.\u0000 A mixture of MethylDiEthanolamine and Piperazine (MDEA+PZ) has been adopted as the solution to replace the DEA based solvent. The choice has been made thanks to the good chemical stability of MDEA and the high performance of PZ as an activator to boost the rate of the absorption process.\u0000 This paper presents the operational feedback with this new formulation. The first benefit of the hybrid solvent formulated with MDEA+PZ is that it was implemented in the existing unit without plant modification. Other advantage is the improved chemical and thermal stability. This solvent swap allows to decrease the reboiler duty of the solvent regeneration, to reduce the chemicals consumption, while keeping the final product quality unchanged.\u0000 The benefits of the solvent swap will be supported by operating data collected before and after the solvent swap.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83675770","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 Holistic Workflow for Field Development Planning in Green Field Environment: A Case Study","authors":"Mohamad Alkhatib, A. Ali, Muhammad Mukhtar, Sangseok Park, K. Ghorayeb, Amirhasan Nasiri, Abdur Rahman Shah, Aditya Ojha","doi":"10.2118/193140-MS","DOIUrl":"https://doi.org/10.2118/193140-MS","url":null,"abstract":"\u0000 A novel workflow was developed to select the optimal field development plan (FDP) accounting for the associated uncertainties in a green onshore oil field with a limited number of wells and no production data. The FDP was then revisited in view of the performance of wells drilled during the execution phase and updated as needed based on the acquired data .\u0000 Comprehensive uncertainty analysis was performed resulting in multiple subsurface realizations. A broad set of development scenarios and options were screened under uncertainty. The viable scenarios were then economically evaluated, resulting in an optimal FDP that is robust to uncertainty and the least risk prone from an economical point of view.\u0000 The used workflow was specifically suitable to test many development concepts and explore various options including horizontal well orientation, well pattern concept, pattern acreage and spacing, length of the horizontal sections, and landing of the horizontal sections.\u0000 Following an extensive techno-economic analysis of all possible combinations (900 in total), the most robust development concept was selected and analyzed considering the viable development strategies pertaining to plateau rate, drilling schedule, phasing, water injection timing and artificial lift timings.\u0000 A phased development approach was adopted enabling acquiring necessary data to mitigate the remaining uncertainty and avoid costly consequences of significant over- or under-capacity. Data acquired in one development phase were assessed and used to update the following planned phases, if necessary.\u0000 The study demonstrated that the field development could accommodate a delay in either water injection or artificial lift implementation. Although it was not recommended at this stage to delay either of them, it is noteworthy that the long lead time that may be incurred in the implementation of artificial lift or the risk of lower injectivity would not impact the field performance or ultimate recovery if contained to a few years during initial production. These results further reinforced the robustness of the proposed development plan.\u0000 Large subsurface uncertainty combined with an extensive set of possible development scenarios and options required cutting-edge uncertainty analysis and screening workflows to select the optimal FDP. These unique workflows can be readily used in similar green fields to help arrive at the final FDP.","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73177616","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":"Integrity Assurance in Major Projects Warrantee Period","authors":"Al Busaeedi Ahmed Musallam, Al Marzooqi Mahdi Mohamed, A RahmanAl-SayedTalal, H KhadeSanjay, Al Awadi Farooq Jaber, Haikal Nabil","doi":"10.2118/193061-MS","DOIUrl":"https://doi.org/10.2118/193061-MS","url":null,"abstract":"\u0000 Through this paper, the author intends to share the valuable experience and benefits of introducing the key element of Integrity Assurance - the initial inspection during the EPC warrantee period in a structured manner and ensure the risks are minimized into the commissioning and Operating stages for major critical project.\u0000 ADNOC OFFSHORE is recognized for its pioneering and innovative approach. As one of the major Oil & Gas producers worldwide, the Company philosophy is to build a culture where critical Integrity Deliverables are embedded through customsied locally designed Code of Practice, known as \"Integrity Assurance in Projects\" that is monitored through a Value Assurance Process (VAP) stages. This enables robust control of Integrity Measures upfront and early identification of Integrity risks, with proactive mitigations based on experience from previous Projects. To further ensure the Integrity deliverables are strictly followed during the EPC; a well laid-out plan is rolled to the Project commissioning team by identifying and defining the non-intrusive NDT of piping system hot-spots as well as thorough internal inspection of typical medium risk high pressure equipment within the first 12 months of operations which fall under the EPC warrantee period. Being in the Project EPC phase, none of the items are classified under \"High Risk\" and are already eliminated through robust engineering. The inspection is scheduled considering minimal production impact.\u0000 Following this initiative enables a structure that is directed towards the prevention of operating critical facilities and minimizes the liklihood of unknown HSE and business risks impacting the delivery of the project to the production phase. The equipment warrentee will be in force after the successful commissioning as per EPC contract agreement.\u0000 One of the key Integrity deliverables is the implementation of Baseline Inspection. The baseline RBI Passport system has been broadly adopted across the Company operational sites and supports the safe continuous employment of assets to meet production targets. The high-risk items are already eliminated and mitigated during the EPC Engineering phase. Through baseline RBI study, the medium risk hotspots are identified for random cross-check during the EPC warrantee period with the obvious intention of ensuring the risk levels are well mitigated. If any deterioration or anomalies detected during the first inspection the same can be rectified through EPC warrantee; thereby saving the Company resources and cost. This innovative approach has been successfully implemented in all of the current on-going Full Field Development projects and has proven to be of great value by ensuring a high quality result whilst attracting significant cost savings. Some of the key successes realized through the roll out of the warrantee period inspection initiative include: Early interventions through selective assessment particularly the medium risk hot-spots. This is","PeriodicalId":11014,"journal":{"name":"Day 1 Mon, November 12, 2018","volume":"221 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75179043","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}