Day 3 Wed, September 26, 2018最新文献

{"title":"Application of Artificial Intelligence for Mechanistic Modeling and Probabilistic Forecasting of Hybrid Low Salinity Chemical Flooding","authors":"C. Dang, L. Nghiem, E. Fedutenko, Emre Gorucu, Chaodong Yang, Arash Mirzabozorg","doi":"10.2118/191474-MS","DOIUrl":"https://doi.org/10.2118/191474-MS","url":null,"abstract":"\u0000 After nearly thirty years of research and development, it is now widely agreed that Low Salinity Waterflooding (LSW) provides better oil recovery than High Salinity Waterflooding (HSW). Past studies also showed that there are significant advantages in combining LSW with other conventional EOR methods such as chemical flooding (polymer flooding and surfactant flooding) or miscible gas flooding to benefit from their synergies and to achieve higher oil recovery factor and project profit. This paper presents a study of Hybrid Low Salinity Chemical Flooding as a novel EOR approach with: (1) development of hybrid EOR concept from past decades; (2) implementation of an efficient modeling approach utilizing artificial intelligent technology for mechanistic modeling of these complex EOR processes; (3) systematic validation with laboratory data; and (4) uncertainty evaluation of LSW process at field scale.\u0000 The phase behavior of an oil-water-microemulsion system was modeled without the need of modeling type III microemulsion explicitly. The approach has been successfully applied to model both conventional Alkaline-Surfactant-Polymer (ASP) flooding and emerging EOR processes (LSW, Alkaline-CoSolvent-Polymer, and Low-Tension-Gas Flooding). The new development allows the mechanistic modeling of the benefits of combining LSW and chemical EOR. One of the main challenges for mechanistic modeling of these hybrid recovery processes is that several factors, e.g. polymer, surfactant, and salinity, can change the relative permeability simultaneously. To overcome this problem, Multilayer Neural Network (ML-NN) technique was applied to perform N-dimensional interpolation of relative permeability. The model was validated with coreflooding data and the effectiveness of hybrid processes were compared with conventional recovery methods.\u0000 The proposed model showed good agreements with different coreflooding experiments including HSW, LSW, and Low Salinity Surfactant flooding (LSS). This model efficiently captures the complex geochemistry, wettability alteration, microemulsion phase behavior, and the synergies occurring in these hybrid processes. Results indicated that LSS is an economically attractive hybrid EOR process since it increases the ultimate recovery factor compared to the conventional approaches and reduces surfactant retention. Bayesian workflow using ML-NN algorithm is efficient to capture the uncertainties in history matching and production forecasting of LSW.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"275 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":"132939313","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":"Grid Cluster in the Office: High-Performance Computing for Reservoir Management","authors":"R. Yaubatyrov, V. Babin, Akmadieva Liya","doi":"10.2118/191519-MS","DOIUrl":"https://doi.org/10.2118/191519-MS","url":null,"abstract":"\u0000 Optimal reservoir management usually requires evaluation of a large number of various development scenarios. This applies to a choice of well placement and settings configuration, waterflooding strategy and history matching process. Reservoir models are commonly used to obtain field production forecast depending on the development plan. Generally, a specialized external high-performance computational environment is used to accomplish the aforementioned multivariate calculations, while personal workstations stay idle most of the time. We propose an alternative way of organizing HPC environment using available computational resources. The method is based on integration of several personal workstations into a so-called grid cluster using local network, which allows managing the whole system from any connected node. Each computational node is provided with a flexible timetable to ensure that distributed calculations do not interfere with daily work. The solution does not require additional capital investments and is easy to implement in the office. Although initially designed for hydrodynamic simulations, the system can be used for any time-consuming multivariate task.\u0000 Proposed method has been applied to several optimization cases of real fields. Grid cluster consisting of fifty nodes with estimated peak performance of 60 TFLOPs was used to find optimal development plan for a field in Western Siberia, allowing to reduce computational time from several months to one weekend. The system prooved linear speedup depending on the number of involved workstations along with stability under conditions when each node may connect or disconnect at any time.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"219 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":"132145539","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":"Implementing Blockchain Technology in Oil and Gas Industry: A Review","authors":"Vikrant Lakhanpal, Robello Samuel","doi":"10.2118/191750-MS","DOIUrl":"https://doi.org/10.2118/191750-MS","url":null,"abstract":"\u0000 The oil and Gas industry has recently transformed itself into a data-intensive industry – artificial intelligence, machine learning and internet of things. With such growth and expansion, distributed ledger technology, commonly known as blockchain, can carry the industry's transformation forward. This technology can help the industry to overcome various challenges such as price volatility, supply chain, accounting, data management and security. It can also help in streamlining various engineering and technical decisions.\u0000 Technologically, the oil and gas industry has been very innovative – 3-D seismic, hydraulic fracturing, geosteering, imaging beneath salt, etc. However, the administrative and managerial functions are still done in a somewhat traditional way. The Blockchain technology can help the industry become more efficient by streamlining these traditional methodologies.\u0000 This paper presents the four major areas where the blockchain technology can help the industry overcome various day to day challenges – (1) Supply Chain and Trading, (2) Regulatory, (3) Database Management and (4) Cyber Security.\u0000 Like any new technology, the blockchain technology might not get a full embrace at the beginning, but the idea is to present a qualitative study about its benefits. The industry currently has little or no knowledge about this technology, which is expected to bring transparency, security and convenience in one place. The objective of this paper is to help the industry peers understand the idea behind this technology and how it can transform the way the industry currently operates. It provides a frame of reference for the industry to realize the potential of this technology and assess its benefits.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"31 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":"125091652","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":"Geochemical Productivity Index, Igp: An Innovative Way to Identify Potential Zones with Moveable Oil in Shale Reservoirs","authors":"J. Piedrahita, R. Aguilera","doi":"10.2118/191644-MS","DOIUrl":"https://doi.org/10.2118/191644-MS","url":null,"abstract":"\u0000 A method is presented to identify intervals in shale oil reservoirs that contain moveable hydrocarbons with a novel geochemical productivity index, Igp. This index merges 3 important rock properties that always have to be considered for sound shale oil reservoir characterization: vitrinite reflectance (%R°), oil saturation index (OSI), and free water porosity (ϕFW). Integration of this index with other petrophysical properties and geomechanical parameters leads to define intervals with moveable oil.\u0000 Shale oil is both source and reservoir rock. Hence, it is critical to know both its organic matter maturity and oil/water flow capacity. The introduced Igp considers these features simultaneously; maturity is evaluated by discretizing %Ro from 0 to 1 depending whether the rock is immature or not; free oil flow capacity is modeled normalizing OSI between 0 and 1 based on results from Rock-Eval pyrolysis (REP) obtained in the laboratory or electric logs; and water flow capacity is estimated from ϕFW, obtained with the use of NMR log, which is transformed to an index between 0 and 1.\u0000 Use of the Igp is explained with real data from a vertical well that penetrates several stacked shale oil reservoirs. However, the same approach can be used in any other kind of wellbore architecture (deviated, horizontal, geosteered). Initially, a correlation between vertical depth and %R° is developed. This results in a continuous organic matter maturity curve along the well section. Next, OSI is simulated with the use of a bin porosity from NMR log, where T2 is between 33 and 80 ms and is correlated with OSI data from REP. As a result, a good match between simulated and real OSI data is achieved. Similar to OSI, ϕFW is also calculated from the NMR log but using a bin porosity when T2 is greater than 80 ms. All these 3 parameters are transformed to partial indexes, which are combined into a unique index, Igp. When the index is greater than 0.66 there is a good chance that the 3 conditions mentioned above will be met. For the example well considered in this study, it was found that almost 30% of total vertical section has good moveable oil potential. This corresponds to 10 intervals in the well.\u0000 The key novelty of the paper is that it develops a continuous curve of an index that is easy-to-use and is powerful for identifying intervals with moveable hydrocarbon potential. This is true even in those intervals without laboratory data due to the continuity of the Igp curve. In addition, the Igp integrates criteria that are usually applied independently.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"9 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":"126123451","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 Flowline Tiebacks: Flow Assurance Considerations From Appraisal to Operations","authors":"J. I. Monge, Sampath K. Bukkaraju, N. Osorio","doi":"10.2118/191748-MS","DOIUrl":"https://doi.org/10.2118/191748-MS","url":null,"abstract":"\u0000 In addition to the recent downturn in oil price, as tiebacks get deeper, longer and originate from more remote areas, interest in making single flowline tiebacks (SFTs) viable development options continues to grow. SFTs provide a means for smaller operators with marginal projects and large international operators with stranded assets to move projects from concept to producing assets. The main challenges in making SFTs viable are: Development and implementation of mitigation and remediation strategies for addressing the typical flow assurance challenges encountered in deep-water.Development of operational strategies considering the processing and liquid handling capacities of the existing tieback host.\u0000 By more clearly understanding the operating conditions from subsurface to surface and systematically addressing each of the field's challenges with novel operating techniques, enhanced facilities and/or chemicals, SFTs have gone from once simply a conceptual idea, to a valid development alternative. The focus of this paper is to apply findings and lessons learned from various SFT projects, ranging from concept selection to decommissioning, to highlight various considerations. It is the hope and intent that by highlighting these considerations we, as an industry, can continue to mature SFTs. This maturation will then be able to provide an alternative development option to make certain projects economically viable, while not making them unfeasible, difficult and unsafe to operate.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"498 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":"116194300","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 Industrial IoT in Oil & Gas: Use Cases","authors":"P. Flichy, C. Baudoin","doi":"10.2118/191756-MS","DOIUrl":"https://doi.org/10.2118/191756-MS","url":null,"abstract":"\u0000 Since the Industrial Internet of Things (IIoT) became its own domain, in parallel with consumer-oriented IoT, various industries have been successfully deploying such systems – initially as pilot projects, and more recently at scale. Meanwhile, the O&G industry, hurt by the price of oil, postponed investments in new technologies. Nevertheless, there are now multiple successful case studies of IIoT in O&G. This paper contains a high-level review of several such IIoT projects in O&G and aims to help the reader gauge the results achieved in this area. By examining these cases and looking at the similarities and differences with applications in other industrial sectors (transportation, water management, utilities…), the O&G industry can derive guidance in its adoption of IIoT, in particular by identifying the \"lowest-hanging fruit\" to improve operations and reduce human and equipment costs. While there is still confusion in terms of standards, choice of technologies, and myriad actors of all sizes, this is neither new in our industry nor unexpected in an emerging field; these challenges should therefore not prevent others from moving forward.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"205 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":"116391245","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":"Optimization of Fortified Section Length in HIPPS System","authors":"K. Kapadia, Neil Rodrigues, Justin B. Hayes, Jade Juzswik, Yogesh Kapoor","doi":"10.2118/191616-MS","DOIUrl":"https://doi.org/10.2118/191616-MS","url":null,"abstract":"\u0000 In the recent era of low commodity prices, the offshore oil & gas industry has focused on economic tie-backs rather than standalone projects to exploit potentially stranded reserves in the Gulf of Mexico. High pressure tie-backs to existing infrastructure may be lucrative, but they are often challenging with respect to pressure & safety ratings.\u0000 A high integrity pressure protection system (HIPPS) can be used to safely contain pressures in a subsea flowline system when the shut-in tubing pressure (SITP) of a well exceeds the maximum allowable operating pressure (MAOP) of the tieback. As stated in API Standard 17O, a HIPPS system should be designed with highly responsive control systems, fast acting safety valves, and fortified sections of pipe known as \"burst free zones.\" The burst free zone is designed to have a higher MAOP than the rest of the flowline system. Optimizing the length of this zone can be achieved by accurately determining both the SITP and the time it takes for the system to reach the maximum SITP. These two key parameters are dictated by how the reservoir pressure responds during shut-in.\u0000 With the availability of fast-transient multiphase flow simulation, it is possible to simulate the SITP and optimize the fortified section length. However, currently-available thermodynamic multiphase flow simulators do not provide an option to simulate near-wellbore reservoir phenomena. These software packages only simulate the shut-in of the well as an instantaneous pressure buildup, which is often very conservative for HIPPS and predicts fortified sections lengths that are longer than necessary.\u0000 To simulate appropriate pressure buildup from the reservoir, a multiphase transient package is coupled with a reservoir simulation software that accounts for reservoir response and near-wellbore behavior. This model more accurately simulates the time required to reach the SITP, thus optimizing the selection of fortified section lengths. Additionally, reservoir and production factors that influence the fortified section length were also studied. One of the main influencing factors identified was fluid GOR. This is because a higher GOR fluid is more compressible; therefore, the time it takes to reach the maximum SITP increases, ultimately decreasing the required fortified section length. This paper will discuss how to apply known reservoir pressure responses to a coupled reservoir and multiphase transient simulator tieback scheme to optimize fortified section lengths when a HIPPS system is applied. It will also analyze the influence that production and reservoir characteristics have on the fortified section length and discuss how to optimize that length.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"143 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":"114456920","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":"Ensemble-Based History Matching and Uncertainty Quantification for Reservoirs Exhibiting Complex Non-Gaussian Characteristics","authors":"Devesh Kumar, S. Srinivasan","doi":"10.2118/191648-MS","DOIUrl":"https://doi.org/10.2118/191648-MS","url":null,"abstract":"\u0000 History matching is an integral part of field development planning for oil and gas reservoirs. It can be viewed as an inverse modeling technique which utilizes information contained in the observed flow response variables like flow rate, well bottom hole pressure etc. to better quantify the spatial distribution of reservoir model parameters like permeability or porosity. As the reservoir parameters and flow response variables are often related by non-linear relationships, the solution to the inverse problem of history matching is often non-unique. This makes it a problem that can be better handled by stochastic approaches than deterministic approaches. The proposed approach called ‘Indicator-based Data Assimilation’ (InDA) is suitable for such problems. To initiate the process, multiple realizations of the reservoir model parameters are generated based on the available information related to the reservoir description. The ensemble of realizations serves as a measure of initial uncertainty in the spatial distribution of model parameters. Next, flow simulations are run on the ensemble of models and the difference between the observed and simulated flow response variables are used to update the reservoir parameters using InDA. With successive updates, the uncertainty in the model parameters is reduced and the spatial distribution approaches the \"true\" distribution. Considering the residual uncertainty of the final updated models, reliable field development planning decisions can be made. The proposed method is validated using a realistic reservoir with complex channel-like features emulating a reservoir formed in a fluvial depositional environment. Liquid rate data from existing wells are used for updating reservoir parameters for several time steps using InDA. A comparison of the spatial distribution of final model parameters with the reference model used for validation shows a good match. After the history matching period, existing and new infill wells are run in a forecast mode where the observed and simulated flow responses show a good match. As majority of oil reservoirs comprise of high permeability oil-bearing zones in form of channels passing across low permeability zones, the statistical permeability distribution is bimodal making it non-Gaussian. It is shown that ‘Indicator Transformation’ of variables used in InDA preserves the non-Gaussian structure of the permeability field in comparison to methods like ‘Ensemble Kalman Filter’ (EnKF) that are sub-optimal in such cases.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"59 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":"114643329","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":"Ultra-Light Weight Proppants for Better Placement","authors":"N. Bestaoui-Spurr, Chunlou Li","doi":"10.2118/191585-MS","DOIUrl":"https://doi.org/10.2118/191585-MS","url":null,"abstract":"\u0000 As well construction technology enables ever-longer horizontal reach, the challenge increases for proppant placement in hydraulic fracturing operations. Effectively placing conventional proppants (sand and ceramic) in extended-reach wells requires either high pump rates or high-viscosity fluids and are subject in both cases to early proppant settling and banking. Even when heavily gelled fluids are used, proppant suspensions are subject to particle settling in the presence of vibration, and/or due to fracturing fluids breaking before the fracture closes. Furthermore, the fractures are typically vertical; and in this case the proppant has a tendency to settle in the lower portion of the fractures while the upper portions close in the absence of proppant. This can lead to impairment in the geometry of the fracture and well productivity. Using proppant with much lower densities than that of conventional proppant will provide better transport. Another benefit from these ultra-lightweight proppants (ULWP) is the elimination of polymer damage with the use of low-polymer or slick water fluid systems, enabled by their extremely slow settling rates.\u0000 Since the mid-2000s, ULWP has been used in over 3000 wells to overcome placement and settling challenges. Taking advantage of low-viscosity fluids, ULWP have been used as nearly neutral buoyant proppant; thus, minimizing settling within the created fracture and leading to a better placement. In this study, the hydraulic treatment and production data of those wells treated with ULWP and offset wells were carefully reviewed. Main production metrics are calculated to evaluate the production performance.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"32 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":"125466439","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":"Enabling Collaborative Decision Making Through Immersive Visualisation","authors":"P. Helm, J. Pickering","doi":"10.2118/191525-MS","DOIUrl":"https://doi.org/10.2118/191525-MS","url":null,"abstract":"\u0000 \u0000 \u0000 Virtual Reality (VR) and Augmented Reality (AR) are becoming increasingly popular in many industrial sectors but the uptake in oil and gas has, in comparison, been very modest. There is little doubt that these technologies will have a growing influence in our recreational lives over the next few years, as the hardware capability increases, costs decrease, and applications become more widely available. The real strength of these technologies is their capability to disseminate information to the user in a truly immersive experience. One area where this could be very valuable in our industry is in the support of drilling and production operations. Real-time Operations Centres (RTOCs) are now in widespread use but these suffer from high capital and operating costs, they are difficult and expensive to reconfigure and are often difficult to engage with from a remote location. Conversely, a Virtual Real-time Operations Centre (vROC) is low cost, can be configured quickly and decommissioned readily when no longer required. With modern networking configurations it is easy to connect from anywhere. This paper describes the first developments of a vROC.\u0000 \u0000 \u0000 \u0000 A common understanding or shared situational awareness is essential for making the best operational decisions in the shortest possible time. This has been the main driver for the development of collaborative working and has resulted in the development of a wide range of work spaces ranging from smaller Collaborative Work Environments (CWEs) through to large scale RTOCs and interactive visualisation centres. The vROC replaces the need for the user to relocate to these physical areas. By deploying a 3D headset, they can enter the 3D virtual workspace and work with colleagues in true collaboration. This project has enabled data to be visualised within the workspace in the same way that it would be seen in a physical room with conventional display panels.\u0000 \u0000 \u0000 \u0000 This project is in the early stages of development, but it has shown already how quickly a vROC may be configured and populated with live and historical data from different sources. Using 3D CAD models, photogrammetric representations and other spatial data, process plants, reservoirs and wells can be brought into the vROC, annotated with real time data and experienced by all users. We have developed live trends and have animated models to highlight alarm situations.\u0000 \u0000 \u0000 \u0000 At a time when operators need to minimise their operating costs whilst maintaining top performance the use of virtual work environments is likely to become a major contributor to cost savings.\u0000","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"27 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":"122078150","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}