Day 2 Mon, February 20, 2023最新文献

{"title":"An Engineer's Systematic Approach to Achieving Superior Safety Performances on Drilling Rigs","authors":"Basma El-Shamouty, S. Osisanya, Md. Motiur Rahman, B. Ghosh, Mark De Athe, Bekheet Al Jasmi","doi":"10.2118/213263-ms","DOIUrl":"https://doi.org/10.2118/213263-ms","url":null,"abstract":"\u0000 Safety on the rig floor must be addressed habitually to avoid tragic fatalities and environmental crises. The objectives of this study were: (1) creating an engineer's system approach named \"\" to achieve a superior drilling rig safety performance by changing the Health Safety and Environment (HSE) culture and worksite behavior, (2) ensuring proper engagement and commitment of the workforce from the top to the bottom of the hierarchy and (3) to provide a tool that can be utilized on any rig floor. This tool assists in evaluating the risk from three different perspectives: People, Equipment, and Process (PEP). The research covered surveys of offshore oil companies in the Middle East. A total of 16 sites, which included four jack-ups, eight island rigs, and four service areas (mud and cementing units). The feedbacks from the surveys were used to create a risk model and a risk assessment tool, which evaluates the risk factor of hazards resulting from the interaction between people and equipment. Based on the risk factor value and each survey feedback, an episode is created to deliver a very attractive and methodical safety message for the rig-floor workforce. The crew's safety performance has been monitored on a monthly basis to test the impact on the company's’ HSE performance. The results show that had a significant positive impact. A total of 335 days of an injury-free environment was achieved in 2018 while delivering several wells with a lateral length of 25,000 feet in a total of 66 days.\u0000 Additionally, the number of incidents was reduced by 85% by the end of 2018. The survey data also show insightful analysis: 50% of the incidents are due to lack of situational awareness; the rig floor equipment that exhibits the highest risk are top drive, iron roughneck, manual tongs, air wench, and lifting gears. The humane factors that indicate the highest risk on the rig floor are people's attitude, awareness, communication, driller's influence, and green hands. The identified opportunity areas of major concern are the Red zone, functional Iron-Roughneck, and regular equipment maintenance. The six by four weeks’ work-leave rotation cycle results in more incidents compared to the four-by-four weeks’ rotation cycle.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123421016","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":"Salvaging Restricted Entry Unconventional Lateral Sections through the Utilization of Multi Stage Diversion Frac","authors":"Maram Zakary, Abdulrahman Alowaid, S. Baki, A. Alowaid","doi":"10.2118/213247-ms","DOIUrl":"https://doi.org/10.2118/213247-ms","url":null,"abstract":"\u0000 The objective of the paper is to introduce a design procedure aimed at targeting the stimulation of unconventional lateral sections that are inaccessible using the conventional plug-and-perf (PnP) method. This salvaging process utilizes the diversion frac technique allowing for the stimulation of challenging lateral sections with minimum well intervention. Consequently, improve stimulation efficiency and minimize intervention costs. When a certain section of the lateral cannot be accessed while running in hole performing PnP operations, an immediate investigation procedure is carried out to determine whether that was due to an equipment failure or a deformed section of the wellbore. If the passage of PnP BHA cannot be rectified, the diversion frac technique presents an ideal solution to stimulate the challenging section salvaging valuable lateral footage. The design for a successful diversion frac is based on multiple variables including the length of the attended lateral section, number of perforating clusters, cluster efficiency, diverter selection and frac design. The restricted section is entirely perforated to minimize the number of well intervention post frac stages. During the stimulation phase, fluid diverters are then pumped to divert fluid flow from clusters taking fluid to the next. Hence, an upward trend in frac treating pressure is noticed with more diverters pumped indicating fluid diversion from existing perforations to new ones. The implementation of the diversion frac technique resulted in salvaging in excess of 1,300 ft of lateral footage per restricted well. Additionally, it is now serving as a salvaging option if restricted sections were encountered in future wells. This process was performed successfully on multiple unconventional wells in Saudi Arabia. Evaluation of this approach was conducted simultaneously with field implementation and hence, modified to reach the optimum design accounting for cluster efficiency, frac design and diverters selection.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"118 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125120413","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":"Successful Deployment of Metal Expandable Annular Sealing Systems in High Extended Reach Wells","authors":"Syed Muhammad Ali, Emmanuel Onyema Nwosu, Nasser Farsi, Kevin Wood","doi":"10.2118/213756-ms","DOIUrl":"https://doi.org/10.2118/213756-ms","url":null,"abstract":"\u0000 The successful deployment of metal expandable annular sealing systems in extreme reach design wells completion. The design and engineering of this technology resulted in the development of a fit for purpose, state of the art equipment that overcame several challenges such as having the liner with full rotational capability to overcome the drag during the deployment while maintaining the full liner torque capabilities.\u0000 The metal expandable annular sealing system was designed to provide high expansion in potentially washed-out wellbores and across formations where effective isolation may not be achieved by primary cementation due to low formation gradient or cement design challenges in horizontal wells. The design included a long multi element sealing system with built in redundancy. The multi sealing element system chosen for this application due to it being a full bore, rugged, all welded, metallic construction with a constant, high ∆p over full expansion range. The system is fully rotatable during deployment, it also allows for high-rate circulation because of its slim OD.\u0000 The metal expandable annular sealing system was run in total or partial losses multiple times, and it was observed that circulation was gained after setting the metal expandable system. Furthermore, it was also confirmed that the system effectively provides zonal isolation by injecting into compartment and ensure that zone is completely isolated.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127439837","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":"Synergistic Hydrate Inhibition by Iota-Carrageenan with Kinetic Hydrate Inhibitors","authors":"Ajay Suri, Ashutosh Kumar Singh","doi":"10.2118/213610-ms","DOIUrl":"https://doi.org/10.2118/213610-ms","url":null,"abstract":"\u0000 The hydrate-inhibiting performance of a natural plant-based polysaccharide iota-carrageenan is evaluated as a standalone inhibitor and as a synergist with two well-known kinetic hydrate inhibitors (KHIs), polyvinyl caprolactam (PVCap) and polyvinylpyrrolidone (PVP), in order to achieve a higher hydrate inhibition performance. The hydrate inhibiting performance is assessed experimentally by measuring the induction time (IT) required for measurable hydrate formation and by the average hydrate growth rate (HGR) after measurable hydrate formation using a standard constant cooling rate of 1°C/h. Three inhibitor dosages at 0.5 wt% and 1 wt% are tested for the methane hydrate formation at 7.6 MPa and hydrate equilibrium temperature of 10.45°C. Synergy evaluation between the common KHIs and iota-carrageenan is done by making 50:50 ratio blends of iota-carrageenan with PVP and PVCap respectively (half iota-carrageenan and half KHI by wt%) and their performance is compared with the performance of individual PVP and PVCap performance at the same total inhibitor concentration for fair comparison. The individual inhibitor experimental results at 0.5-1 wt% showed that iota-carrageenan has a lower IT (around 4.5-5 h) than PVP (around 5.5-6.3 h) and PVCap (around 6.5-7.1 h), but has a lower average hydrate growth rate (HGR) between 0.07-0.08 m/h compared to PVCap (0.11-0.12 m/h) and PVP (0.13-0.18 m/h). The experimental results for the 50:50 blends of i-crgn with PVP and PVCap at a total concentration of 0.5-1 wt%, showed significant boost in the ITs (8.1-10.2 h for PVP and i-crgn blend) and (8.7-11.2 h for PVCap and i-crgn blend). These values were up 33-57% at the same total concentration of the individual inhibitor and the blend. The blends also have a much lower HGR with values 0.04-0.12 m/h at a total concentration of 0.5-1 wt% which is 16 - 64% lower than the individual HGRs of PVP and PVCap. Hence, iota-carrageenan, a natural, non-toxic, sustainable chemical can be used as hydrate inhibiting synergist additive to PVP and PVCap and other commercial hydrate inhibitors for enhanced hydrate inhibition performance and biodegradability.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122068435","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":"Improved Reservoir Management with Multi Positioning Interval Control Valves in Multilateral Wells","authors":"N. Shahreyar, B. Butler, Muzzammil Shakeel","doi":"10.2118/213769-ms","DOIUrl":"https://doi.org/10.2118/213769-ms","url":null,"abstract":"\u0000 Multilateral technology continues to gain interest within the oil and gas industry. While multilateral wells are recognized as an advanced well construction and completion technique to optimize production performance and improve field recovery, further opportunities exist to increase production performance throughout the life of these wells through the use of variable inflow control for the main bore and/or the laterals. The inflow control on these wells is achieved by interval control valves (ICV). An ICV is generally classified as either on-off (i.e., full-open or closed) or multi-position (i.e. discrete choking type). This paper discusses a reservoir simulation case study with varying degrees of inflow control to demonstrate value added by ICVs to multilateral completions to improve oil recovery of a field.\u0000 A 3D black-oil reservoir model was utilized to simulate production and cumulative recovery evaluation with horizontal and multilateral intelligent completion oil producers supported by vertical non-intelligent water injectors. The modeling was carried out with varying degrees of control in the ICVs employed in the oil producers. Multiple scenarios were modeled as follows: 2-position ICV (open-closed)4-position ICV (choking)9-position ICV (choking)\u0000 This modeling will quantify the value provided by a customized multi-position ICV in a multilateral intelligent completion with regards to improved reservoir performance. Since the customized ICV solution requires a more detailed well completion design and evaluation, it is necessary to be able to quantify the value that this option can deliver when employed in multilaterals. This paper shall demonstrate the added value that can be achieved in multilateral wells by utilizing multi-position choking ICVs versus binary open-close ICVs to manage reservoir uncertainty and improve reservoir performance. This paper will also highlight the importance of flow discharge characteristics with respect to each choking position and the benefits of flow trim customization during well life.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"58 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114763420","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 Effect of Graphite on the Properties of Class G Oil Well Cement","authors":"Muhammad Andiva Pratama, A. Mahmoud, S. Elkatatny","doi":"10.2118/213672-ms","DOIUrl":"https://doi.org/10.2118/213672-ms","url":null,"abstract":"\u0000 Cementing process is one of the most crucial parts in drilling operation that could determine the durability and stability of the oil or gas well. Many additives had been introduced into the formula of the oil well cement to reach certain qualities to support the well. This study intends to analyze the effect of graphite on the properties of the hardened cement samples as a function of curing time, and compare the change in the properties with that for the samples prepared without graphite. The alteration in properties of the cement compressive strength, Poisson's ratio, Young's modulus, and permeability were studied with curing time. The results showed that the graphite successfully increased the compressive strength, and Poisson's ratio while Young's modulus was reduced which indicates an enhancement in cement strength and elasticity. The cement sheath permeability was also decreased indicating formation of more tight cement sheath with incorporation of graphite into the cement slurry.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"43 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121740543","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":"Maximizing Productivity Index by Minimizing Fluid, Proppant and Additive Volumes","authors":"J. Rueda, Abdullah Alzamil, Abdulrahman Alowaid, J. Valbuena, Rashed Alnaimi","doi":"10.2118/213271-ms","DOIUrl":"https://doi.org/10.2118/213271-ms","url":null,"abstract":"\u0000 As part of the stimulation plan to obtain the optimum slickwater frac design in the main source rock play in Saudi Arabia, a series of systematic trials were carried out testing different frac design parameters, such as the proppant volumes and types, and fluid & additives volumes (friction reducers, spearhead acid etc.). These trials were carefully designed in several 4-well pads across the field, comparing different designs in wells next to each other in the same pad, to allow consistency in reservoir and geology conditions allowing the trials to be conclusive. Wells were flowed back for a relatively short period of time and different production analysis techniques were used to compare the different designs against the standard.\u0000 In this paper, the Normalized Initial Productivity Index of the wells was compared using the Gas, Gas Equivalent, Total Fluid Downhole Flow Rates Productivity Index (PI), and the Effective Fracture Lengths from rate transient analysis were used to help on selecting the optimum frac designs. In these trials, other important completion parameters were kept constant: the number of clusters per stage, cluster spacing, type of perforation guns, frac fluid and proppant type. The flowrates are measured using the three phase separators and the corresponding bottom-hole flowing pressures are estimated using multi-phase flow parameters, and the matched wellbore hydraulic models. The reservoir pressure is estimated from the pressure decline analysis of the frac stages along the lateral.\u0000 The results show that there was almost no change in the productivity results by lowering the proppant volumes 25%. The results also show that better wells are obtained by lowering fluid volumes by 33% and decreasing the additive volumes by more than 75%. Overall, the improved PI obtained with lower proppant and fluid volumes and less additive concentrations, provided an optimized frac design that is being carried into the development phase wells.\u0000 This paper helps in understanding and maximizing the productivity of the wells and optimizing the design including chemicals, to capitalize the value generation from the individual wells on the multi-well pads.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"20 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125530635","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":"Identifying and Ranking Multiple Source Models for Transfer Learning in Unconventional Reservoirs.","authors":"J. Cornelio, Syamil Mohd Razak, Young Cho, Hui-Hai Liu, R. Vaidya, B. Jafarpour","doi":"10.2118/213349-ms","DOIUrl":"https://doi.org/10.2118/213349-ms","url":null,"abstract":"\u0000 When a limited number of wells are drilled at the early stages of developing unconventional fields, the available data is insufficient for developing data-driven models. To compensate for the lack of data in new fields, transfer learning may be adopted by using a previously learned model/knowledge from similar fields (source data) to build a predictive model for the new field. To be effective, transfer learning requires the source and target fields to have similarities and to ensure relevant information/knowledge is transferred. The transfer of irrelevant knowledge may impede the training process and lead to a negative knowledge transfer. When multiple source data are available, it is important to identify each source data's relevance and potential contribution to the target data. We introduce a framework to rank different source datasets and determine their capability for transfer learning. The methodology relies on using knowledge learned from datasets with similar features to the target dataset. This methodology helps circumvent the data needs for training while ascertaining that the right knowledge is transferred when developing new fields. Additionally, the framework allows for combining relevant features from multiple source models (with similar ranks). It allows for transferring the knowledge learned from mature fields to improve the performance of deep learning proxy models for new fields with similar features.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"1906 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128003523","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":"RTPD Safety Management System Toward Safety Excellence","authors":"Muatasem Abdulhadi Al Hakami, Majed Al Hamzah","doi":"10.2118/213283-ms","DOIUrl":"https://doi.org/10.2118/213283-ms","url":null,"abstract":"\u0000 Event: Middle East Oil, Gas and Geosciences Show\u0000 Title: RTPD Safety Management System Toward Safety Excellence\u0000 Objectives/Scope: The objective of this abstract is to explain how Ras Tanura Producing Department have achieved the President's Award for Safety Excellence for the most improved department among all Saudi Aramco departments.\u0000 Ras Tanura Producing Department had shown a high level of collaboration and engagement with Loss Prevention Department that led to improve the safety performance and culture among Ras Tanura Producing Department employees. As a result, Ras Tanura Producing Department has achieved an overall score of seventy six (76) percentage during the assessment of safety Compliance Review management system carried by Los Prevention Department in the year of 2021, which demonstrates a commendable improvement from the year of 2018 review score of fifty seven (57) percentage which is recognized as the highest in Saudi Aramco Company.\u0000 The Ras Tanura Producing Department safety program effectiveness was assessed utilizing a risk based approach which focuses on the most prevalent areas for improvement identified in an analysis of Saudi Aramco safety performance and a thorough review of Ras Tanura Producing Department's documentation. The review also assessed the implementation of the Eight Lifesaving Rules. Evidently, Ras Tanura Producing Department has an opulent and mature Safety Management System that reveals comprehensive and logically written processes. These processes have gone through several reviews and revisions. Also, Ras Tanura Producing Department piloted management monthly safety audits and the verification, closure system of major incidents recommendations, which have been recognized as best practice.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130903000","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":"Graph-Based Temporal Process Planning and Scheduling for Well Drilling Operations","authors":"Maksimilian Pavlov, N. Bukhanov, S. Safonov","doi":"10.2118/213623-ms","DOIUrl":"https://doi.org/10.2118/213623-ms","url":null,"abstract":"\u0000 Well construction is the most expensive stage of oil field development. Oil and gas companies carefully calculate all possible expenditures to assure that the project of well construction and exploitation will be profitable in time. The time for every operation of well construction is strictly regulated. However, in different oil and gas companies time allotted, for example, cementing surface casing or tripping operations can differ significantly. Therefore, some oil and gas companies are unable to calculate their well construction expenses accurately and lose a significant amount of money, which can be reduced. Also, engineering teams spend a substantial amount of time developing a drilling plan for the drilling crew, which may also be fully or partially developed by automated means. We present a data-driven approach for automatic planning and scheduling of drilling operations on wells with similar design and geological characteristics, suggesting also an improved operation classification based on the IADC dictionary of drilling operations.\u0000 The model for drilling operations planning is based on the directed graph traversal and process mining techniques. The algorithm takes as an input an undetailed plan, the section which is planned to be drilled, and the phase of well construction (drilling, cementing, logging). The algorithm selects the shortest path between two adjacent operations, gathers all paths together, and outputs a detailed plan with the corresponding time for each operation. For directed graph construction, we processed about 15 drilling reports from wells of a particular oil field which have similar well design and geology conditions by virtue of their geological proximity.\u0000 Algorithm performance was estimated by comparing graph time against similar plan time which was calculated based on the median time of every operation in a whole dataset. Median time (P50 percentile) was used because it demonstrates objective time in terms of well construction operations. We conjecture the above based on the fact that in some cases time for tripping can be faster or slower in some wells due to geological or other conditions, and the median provides an outlier-robust estimate of the average value. Also, graph time was compared between the engineering team's proposed plan and the actual time from drilling reports. Graph construction quality was estimated using three principal metrics: the Jaccard coefficient, structural distance, and fitness similarity.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"85 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130548780","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}