Day 3 Wed, September 26, 2018最新文献

{"title":"Applicability Criteria for Subsea Developments: A Study on the HSE Aspects, Technical Limits, Commercial Constraints, and Other Non-Technical Factors to be Discussed while Framing and Sanctioning a Subsea Project","authors":"F. Beltrami","doi":"10.2118/191418-ms","DOIUrl":"https://doi.org/10.2118/191418-ms","url":null,"abstract":"\u0000 The persistence of the current downturn of the subsea industry offers the opportunity to rethink the reasons of the success of subsea and deepwater projects over the past two decades to (a) identify where and how subsea technologies can be effectively used to create value for an operator, and (b) which are the subsea applicability limits, either real or perceived, that may suggest opting for a different field development concept.\u0000 This paper discusses the definition and use of the applicability criteria for subsea developments. Further to a brief methodology note, these criteria are then used to map, in a qualitative way, different situations where a project may benefit from the adoption of subsea technologies.\u0000 HSE aspects, technical limits to the required technologies, commercial constraints, profitability during field life, effectiveness of hydrocarbons recovery and other non-technical factors (from human error to geopolitics) are illustrated and arranged into a logical, clear frame to map the proposed applicability ranges for subsea developments.\u0000 The applicability maps are then employed to briefly discuss some significant aspects of the booming success of the subsea industry from its first ‘golden age’ (1999-2014) and also a few issues and challenges that deserve some attention while preparing for the next subsea and deepwater ‘boom’.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"38 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116802335","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":"Strategic Growth in Oil and Gas: A Capabilities Perspective","authors":"M. Capello, Q. Dashti, W. Al-Khamees, Moussa Mohammed, Maria J. De Sousa","doi":"10.2118/191429-MS","DOIUrl":"https://doi.org/10.2118/191429-MS","url":null,"abstract":"\u0000 Kuwait Oil Company (KOC), one of the most important National Oil Companies (NOC) in the world, is growing in every sense, as the State of Kuwait is seeking to boost its oil production capacity by 2040, in line with the new approved strategy of Kuwait Petroleum Corporation. This growth into the future entails a shift from primary extraction to more complex settings, where new fields are produced simultaneously with others submitted to water flooding, EOR and Steam Injection, in what constitutes one of the biggest challenges ever faced by the company, due to the short timelines involved.\u0000 The company has a variety of technological partners that include International Oil Companies (IOC), to further support the 2040 strategy of the corporation. This strategic growth vision, not exempted of an increasing breath of challenges, is accompanied by a focused effort in building new technical capabilities in the personnel, and in gradually transforming the way the training plans shape the professional profiles and set the paths for ensuring the specialized skills and expertise that will be needed.\u0000 This paper describes how KOC is collaborating with an IOC, for uplifting and accelerating the training of its personnel, with the aim of enabling the availability of critical expertise needed to ensure production targets. Selected examples will detail how this cooperation NOC-IOC has been fruitful in enhancing competencies and training workflows. The teams involved from both sides of the spectrum experienced interesting challenges, and did not shy away from applying tactics of management of change to support the evolving talent development ecosystem.\u0000 An emphasis will be placed in describing why elements like cultural nuances, corporate legacy, communication, alignment and integration are considered key in the implementation of the training strategies. With a well-established KOC competency-based training scheme, and after several years of fruitful exchanges with the IOC, the uplifts achieved in talent development schemes have shaped a transformation journey, with specific results worth sharing.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124064672","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 Diffusion-Corrected Sigma Algorithm for a Four-Detector Pulsed-Neutron Logging Tool","authors":"G. Schmid, R. Pemper, D. Dolliver, N. Mekic, Jon Musselman","doi":"10.2118/191738-MS","DOIUrl":"https://doi.org/10.2118/191738-MS","url":null,"abstract":"\u0000 Sigma logging is a proven method for determining oil/water saturation behind casing. In this paper, we present a new, diffusion-corrected, sigma algorithm for a four-detector pulsed-neutron logging tool. Since the diffusion effect is inversely related to the distance between source and detector, there is an advantage in having multiple detectors at varying distances from the source. We will show how we use this advantage to design a diffusion-corrected sigma algorithm, and will verify the results using lab data, MCNP simulation, and field logs. Furthermore, we will discuss our use of a dual-exponential fit to cleanly separate the borehole decay from the formation decay. We will show that this approach works well, and can provide a certain advantage relative to the \"moments method\".","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"277 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130633764","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":"Mapping the Success Dimensions of Large Oil and Gas Projects","authors":"Yitbarek Redda, R. Turner","doi":"10.2118/191764-MS","DOIUrl":"https://doi.org/10.2118/191764-MS","url":null,"abstract":"\u0000 In order to satisfy the increase in world energy demand, the global oil and gas industry is expected to invest US$ 25 trillion from 2015 to 2040 in development projects (IEA, 2015). However oil and gas projects have had a long track record of sluggish performance. This study investigated the performance of Development (Pre-FID) Large Oil and Gas Projects and determinants of their success. Adopting a view that project success comprises success factors and criteria considered simultaneously, 11 success criteria and 57 success factors were first identified using a systematic and exhaustive literature review backed up by validation from experienced practitioners. A global online survey was then conducted to solicit the perceptions of project directors and managers from Owners and EPC Contractors regarding the identified success criteria and factors. A total of 96 and valid responses were received.\u0000 Exploratory factor analysis using SPSS software identified three success criteria groupings - (1) Project Management Success, (2) Business Success, and (3) Future Potential/Growth. For success factors the number of groupings is six. These are (1) Project Management, Leadership & Team Competence, (2) Front End Loading, (3) Project External Context and Compliance, (4) Project Impacts on External Environment, (5) Project Risk and Quality Management, and (6) Project Connectivity with Local Resources Capacity. The criteria and factors identified are directly applicable to projects and programs in other domains such as mining, large scale infrastructure development, ship building, and defense acquisition. The results of this study can be used as a starting point towards the development of a success measurement methodology for industrial megaprojects.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"465 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126834526","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Low Tension Foam Flooding for Chemical Enhanced Oil Recovery in Heterogeneous Systems","authors":"Ruth Hahn, K. Spilker, D. Alexis, Harold C. Linnemeyer, Taimur Malik, V. Dwarakanath","doi":"10.2118/191706-MS","DOIUrl":"https://doi.org/10.2118/191706-MS","url":null,"abstract":"\u0000 Current chemical EOR technologies, such as surfactant polymer flooding, have limitations, such as, high temperature, high salinity, and/or low permeability reservoirs. Low tension foam flooding, however, can be performed at high or low temperatures, salinities, and permeabilities. Low tension foam reduces residual oil saturation and increases sweep efficiency. The current literature shows the effect of foam in corefloods and limited 2-D micro-model experiments. We investigate the ability of low-tension foams to successfully divert flow into lower permeability zones in both communicating and non-communicating heterogeneous systems.\u0000 During this laboratory study, a surfactant that has shown success for foam applications in the field was evaluated and used as a baseline to compare and evaluate low tension foam formulations. We measured resistance factors under constant pressure and constant flow conditions. In addition, we established benchmarks for flow diversion. The low-tension formulations were modified to display foaming abilities and compared against the baseline surfactant benchmarks. Phase behavior experiments were conducted to determine the oil solubilization ratio of each surfactant formulation. Foam floods with surfactant formulations with favorable solubilization ratios were conducted in heterogeneous systems to determine sweep efficiency and oil recovery.\u0000 Surfactant formulations were developed that showed favorable apparent viscosities during in situ foam floods and improved sweep efficiency in a dual-permeability communicating system comparable to the baseline foam. During oil recovery experiments in a heterogeneous system, the baseline surfactant recovered approximately 40% of the remaining oil while the low-tension formulation recovered over 70% of the remaining oil. This study indicates that we can use low tension foams to successfully divert flow from high permeability zones to low permeability zones in heterogeneous sand packs and recover oil at the same time.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126502427","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":"Small Field Rejuvenation: Challenges, Lessons Learnt & Redevelopment Concept","authors":"Jing Zhi Kueh, Umar Islam M Dimyati, S. Mat, K. Michael, M. Fadhil, Khairul Arifin Dolah","doi":"10.2118/191744-MS","DOIUrl":"https://doi.org/10.2118/191744-MS","url":null,"abstract":"\u0000 Field D is located in offshore Sarawak, Malaysia. It was discovered in 1980s, and achieved first oil in 2012. Field D is categorized as small field, due to small reserves. In order to minimize development cost, Field D development utilized refurbished platform, tied back to Field A Complex, which act as central gathering facilities for nearby fields' production. Post drilling, Field D oil production was stabilized at around 1800 barrels of oil per day (bopd). Original field life was expected to be eight (8) years, as per original PSC expiry in 2021.\u0000 In 2014, Field D PSC was extended to 2034. With the new PSC, a team had been established to study Field D potential with the objective to extend Field D life to the new PSC expiry. In order to de-risk Field D redevelopment, the team reviewed existing wells drilled in Field D, and conducted production enhancement to increase Field D production before infill drilling commenced. The team had overcome various surface and subsurface constraints in redeveloping this small field: limited facilities, production capacity limit, compartmentalized reservoir, and fluid type & fluid contact.\u0000 Field D infill drilling campaign in 2017 yielded positive results, and field production post drilling had been sustaining at 6000 bopd since. This paper chronicles Field D journey, from initial development to field redevelopment. It will benefit operators who are looking to redevelop their small field and maximize field recovery.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127683745","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 Drilling by Simulation and Automation with Big Data","authors":"Mark Hutchinson, B. Thornton, P. Theys, H. Bolt","doi":"10.2118/191427-MS","DOIUrl":"https://doi.org/10.2118/191427-MS","url":null,"abstract":"\u0000 For many years the aerospace and automotive industries have realized significant improvements in efficiency, performance and cost savings by simulating multiple prototype vehicle designs and control systems under various operating conditions. These same simulation techniques have now been introduced to the oilfield drilling industry and are delivering insights for more effective drilling tool designs, bottom hole assembly optimization, drilling severity minimization, dysfunction recognition and for drilling performance improvement with fewer downhole failures. Drilling is a non-linear, coupled and dynamic hydro-geomechanical process, the physics for all aspects of which must be captured to enable a robust automated drilling control process.\u0000 Drill string, drilling tool and drill bit failures are frequently incorrectly blamed upon the invisible geology through which they drill. Field engineers frequently report more severe downhole vibrations at rotation speeds other than those predicted by linear frequency-based finite element critical speeds analyses. The same multi-body dynamics simulation techniques used by the automotive and aerospace industries, however, are now being applied to capture the non-linear aspects of the drilling process and provide more realistic predictions of drilling performance.\u0000 Simulation validation is achieved by comparing virtual data to physical data with an implicit understanding of the uncertainties of each. Recommendations are presented for improving the usefulness and the quality of physical drilling data which simulation can then also help assure.\u0000 The ultimate objective is to deliver better quality boreholes which are less costly with fewer drilling tool failures. These novel simulation techniques are enabling manufacturers to benefit from lower development costs and shorter times to market with more reliable proprietary drilling tool designs. Drilling contractors are using simulations to optimize top-drive controls and drill more effectively. Product developers are able to configure higher performing and more optimal bottom hole assemblies. Operators are able to reduce overall drilling costs with the potential benefits of higher performing drilling automation systems and greater production from better quality boreholes.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"354 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132488866","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":"Statistical Analysis of Effect of Proppant Design on Production Decline Profile of Shale Wells","authors":"A. Yang, B. Stewart, T. Jacob, A. Abramov, Alexandre Ramos-Peon","doi":"10.2118/191423-MS","DOIUrl":"https://doi.org/10.2118/191423-MS","url":null,"abstract":"\u0000 In recent years, operators have been pumping more and more proppant per stimulated foot while simultaneously increasing lateral lengths. In order to mitigate the resultant costs and logistical difficulties, operators and service companies have switched to lower cost brown sands sourced from the Hickory Formation. We believe enough time has passed to test the hypothesis that the new design profile of wells-massive amounts of lower crush strength sand-will result in steeper production decline. We have gathered data from fracfocus.org on frac treatment design, supplemented it with data from state databases when available, and rigorously validated and cross-referenced all sources of data. We also gathered monthly production data from said state agencies. We regressed proppant type and intensity against production for every play, including in Texas where raw well level production data is unavailable, and instead allocated production to wells on a lease. We used geographical components and operator fixed effects to control for acreage and operator practices, respectively. In addition to statistical analysis, we also looked at well pads where wells used different types of sand.\u0000 While we succeeded in building predictive models for production decline, we did not find that sand color was a significant feature in these models","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"306 5","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131851904","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":"Results from a Phased Piloting Approach in First Eocene Reservoir of Wafra: Reducing Uncertainties in Carbonate Steamflood Development","authors":"D. Barge, Joel Brown, Raushan Kumar, C. Lolley, Ruurd Bartlema, Saleh Al-Ghamdi","doi":"10.2118/191695-MS","DOIUrl":"https://doi.org/10.2118/191695-MS","url":null,"abstract":"\u0000 The First Eocene is a multi-billion-barrel heavy oil carbonate reservoir in the Wafra field, located in the Partitioned Zone (PZ) between Kingdom of Saudi Arabia and Kuwait. After more than 60 years of primary production, the expected recovery is low and provides a good target for enhanced oil recovery (EOR) processes. A phased piloting approach has been used to reduce the uncertainties (subsurface and surface) related to application of thermal EOR processes in this field. This paper outlines the motivation for and benefits of the phased approach leading to steamflood development in the First Eocene reservoir. The key learnings from each phase, with focus on the progress made in identifying and mitigating key uncertainties for carbonate steamflooding, are discussed in detail.\u0000 The first step of the phased approach was an extensive EOR screening study in 1996 that identified steam flooding as a viable EOR process for this reservoir. In 1999, the Eocene Steam Stimulation Pilot, a multi-well cyclic steam stimulation (CSS) test, was conducted to provide information regarding the applicability of steam injection to Eocene reservoirs. The pilot evaluated reservoir, production and operational factors associated with injecting steam into the First Eocene reservoir. This was followed in 2005 by single 5-spot pattern pilot known as the Small-Scale Test (SST). The primary objectives of the SST were to address uncertainties regarding steam injectivity and the ability to generate steam from Eocene produced water. The SST successfully proved sustained injectivity in the dolomite reservoir using steam generated from produced water. The SST was followed in 2008 by a 16-pattern pilot referred to as the Large-Scale Pilot (LSP). The LSP was designed to evaluate the technical and operational feasibility of continuous steam flooding and further reduce 1) subsurface uncertainties such as recovery, vertical (potential barriers and baffles)/horizontal (high permeability layers or streaks) heterogeneity, steam-rock/steam-water interactions, and, 2) operational uncertainties associated with scaling and corrosion.\u0000 Key objectives of each pilot were defined and phase-appropriate subsurface/engineering design, reservoir surveillance and subsurface response plans (linked to the uncertainty management plan) were formulated to meet pilot objectives. Detailed data analysis (logs, cores, production, pressure, temperature, fluid properties, geochemical), reservoir characterization (stratigraphy, petrophysics, earth-modeling) and dynamic modeling (predictive and prognostic/validation) helped to understand production behavior, quantify impact of uncertainty parameters on reservoir response and estimate oil recovery. Finally, poststeam cores were acquired in the SST and the LSP pilots, adjacent to existing presteam cored observation wells, and detailed analysis (routine and SCAL) helped to quantify the residual-oil-to-steam and steam-rock interactions.\u0000 The learnings from the phase","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130915761","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Modeling Fault Reactivation Using Embedded Discrete Fracture Method","authors":"S. Tavassoli, Yifei Xu, K. Sepehrnoori","doi":"10.2118/191412-MS","DOIUrl":"https://doi.org/10.2118/191412-MS","url":null,"abstract":"\u0000 The integrity of a geological formation is a primary concern in any underground fluid injection project. Hydraulic pressurization due to injection may reduce fault strength, trigger fault slippage, and cause fault reactivation. The reactivated fault affects the fluid migration and loss from the injection zone, which might undermine the efficiency and safety of the project. Hence, a reliable modeling of fault reactivation is critical.\u0000 In this work, we propose a new approach to modeling fault reactivation. Faults are complex structures and generally consist of core and damage zones with macroscopic fracture networks. The embedded discrete fracture model (EDFM) is an effective method for simulating complex geometries such as fracture networks and nonplanar hydraulic fractures. We used the EDFM in conjunction with a compositional reservoir simulator to model fault reactivation under hydraulic pressurization. The phase behavior and fluid flow are accurately modeled using the equation of state (EOS) compositional simulation.\u0000 The activation of fault occurs at a threshold pressure, which depends on the chemo-mechanical properties of the formation rock. The threshold pressure can be estimated using analytical, numerical, or laboratory methods. In this study, we provided an analytical calculation of the threshold pressure. Moreover, we used a refined, multiphase, compositional, and geomechanical reservoir simulator to predict the threshold pressure. The coupled geomechanical reservoir simulation is computationally expensive; therefore, we suggest using this approach, in the absence of laboratory measurements, to simulate only a few regions of the formation with distinctive rock types. The estimated values of threshold pressures for different geomechanical rock types can be used in our simulations.\u0000 We performed large-scale reservoir simulations using the EDFM to investigate the storage capacity of carbon depositional formations representative of the Gulf of Mexico and monitor CO2 migration paths before and after fault reactivation. The results of this study are helpful to evaluate the capacity and integrity of carbon storage sites. Our methodology gives promising results for the prediction of fault reactivation and CO2 migration within a formation.\u0000 The proposed approach accurately models faults and their reactivation. It does not require refinement and geomechanical calculation for each gridblock in the domain, which reduces the computational time by at least five times. The significance of this approach becomes more pronounced in large formations with multiple rock types and faults. Although we used our approach for the study of carbon storage, the same methodology can be used for other types of fluid injection, such as water disposal.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"51 4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131094576","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}