Wearable sensors have traditionally been used to measure and monitor vital human signs for well-being and healthcare applications. However, there is a growing interest in using and deploying these technologies to facilitate teaching and learning, particularly in a higher education environment. The aim of this paper is therefore to systematically review the range of wearable devices that have been used for enhancing the teaching and delivery of engineering curricula in higher education. Moreover, we compare the advantages and disadvantages of these devices according to the location in which they are worn on the human body. According to our survey, wearable devices for enhanced learning have mainly been worn on the head (e.g., eyeglasses), wrist (e.g., watches) and chest (e.g., electrocardiogram patch). In fact, among those locations, head-worn devices enable better student engagement with the learning materials, improved student attention as well as higher spatial and visual awareness. We identify the research questions and discuss the research inclusion and exclusion criteria to present the challenges faced by researchers in implementing learning technologies for enhanced engineering education. Furthermore, we provide recommendations on using wearable devices to improve the teaching and learning of engineering courses in higher education.
Hydraulic fracturing in tight gas sandstone reservoirs increases the connectivity of the well to more reservoir layers and farther areal regions, thus boosting the production as well as the net-present-value of the project. When comparing different well performances, wells that far outperform other wells are usually connected to high permeability streaks or natural fractures. This paper demonstrates the analysis and performance evaluation of hydraulic fractures that are connected to high permeability streaks or natural fractures.In order for oil and gas operators to consider the development of tight gas sandstone reservoirs economically feasible, stimulation operations such as a large hydraulic fracture treatment of the wells are required. However, the induced fracture is not the main reason for the success of many of the field development in tight gas sandstone reservoirs. In the Southern North Sea, the more productive multiple hydraulically fractured horizontal wells (MHFHW) are usually connected to high permeability streaks or natural fractures. In this work, a reservoir with high permeability streaks and natural fractures was then modelled. This is then calibrated against several years of production and pressure history.The analysis of core data, borehole image logs, well tests and geomechanics data demonstrated the existence of high permeability streaks or natural fractures in the reservoir. The data derived from the analytical methods were then captured in the simulation model. The simulation model shows a very good match with the history data and when compared with a 3-week long shut-in, the build-up pressure response and its derivative displayed an excellent match. This study shows that, in addition to the role played by the hydraulically induced fractures, natural fractures and high permeability streaks also serve as dominant factors in success of tight gas sandstone reservoir development.This study demonstrates a practical integrated approach towards the modelling of high permeability streaks and natural fractures that are connected to hydraulic fractures. This can be used to better understand hydraulic fracturing and tight gas sandstone reservoirs in the Southern North Sea.
Producing oil and gas from increasingly more difficult reservoirs has become an unavoidable challenge for the petroleum industry as the conventional hydrocarbon resources are no longer able to maintain the production levels corresponding to the global energy demand. As the industrial investments in developing lower-permeability reservoirs increase and more advanced technologies such as horizontal drilling and hydraulic fracturing gain more attention and applicability, the need for more reliable means of production forecasting also become more noticeable. Production forecasting of hydraulically fractured wells is challenging particularly for heterogeneous reservoirs where the rock properties vary dramatically over short distances, significantly affecting the performance of the wells. Despite the recent improvements in well performance prediction, the issue of heterogeneity and its effects on well performance have not been thoroughly addressed by the researchers and many aspects of heterogeneity have yet remained unnoticed. In this paper, a novel empirical approach for production forecasting of multi-fractured horizontal wells is presented in attempt to effectively include the effect of heterogeneity. This approach is based on the integration of hyperbolic Decline Curve Analysis (DCA) and heterogeneity impact factor (HIF). This newly-defined ratio quantifies the heterogeneity impact on the hydraulically fractured well performance and is calculated based on net-pressure match interpretation and post-fracture well test analysis. The proposed approach of decline curve using heterogeneity impact factor (DCH) is validated against data from a Southern North Sea field. The results show a maximum of 15% difference between the outcome of the proposed method and the most detailed three-dimensional historymatched model, for a 15-year period of production forecasts. DCH is a novel, fast, and flexible method 2 for making reliable well performance predictions for hydraulically fractured wells and can be used in forecasting undrilled wells and the range of possible outcomes caused by the heterogeneity.
The high prices of energy encourage investments in oil and gas research and development leading to new or improved technologies to recover more hydrocarbons from resources and re-evaluate the reserves. As a result of such technological developments and experience of job practices, hydraulic fracturing techniques have improved significantly in terms of designing and execution and this, at the same time, has made the process much more complicated. This paper suggests a practical multi-disciplinary workflow for hydraulic fracturing modelling mainly in tight gas sandstone reservoirs.Hydraulic fracturing stimulations in costly environments such as the Southern North Sea require deeper insight into the chemistry and mechanics of the process, characteristics of the formation, and most importantly, the interactions during and after the stimulation job. Different sources of information and analysis such as seismic, reservoir static modelling, initial geomechanical modelling, initial hydraulic fracturing study, fracture initiation point analysis, 1-dimensional (vertical) stress modelling per frac, mini-frac, mainfrac, flowback analysis, well test analysis, and reservoir dynamic modelling are discussed in this paper. The key data cross checks are recognised and lessons learnt from industry are also incorporated to highlight the possible outcomes of different decisions.Having more information, particularly from different disciplines, can be more productive only if a comprehensive guideline explains the essential elements of the required studies and illustrates their interrelations. This workflow has been the reference of a validated study for a multi-fracced tight gas sandstone reservoir in the Southern North Sea. The workflow has been deployed to organise and recognise the key elements that control the performance of hydraulically fractured wells in a heterogeneous environment. From the workflow, a thorough examination and analysis of available data were performed and fed into the static and dynamic models. As a result of the integrated workflow, a better understanding of the reservoir was formed and potential upside opportunities became visible.This paper highlights the importance of integrated multi-disciplinary workflow required to detect, characterise and evaluate information from the field into a product that can be used to better understand hydraulic fracturing and tight gas sandstone reservoirs.
Hydraulic fracturing operation in tight reservoirs increases the connectivity of the well to more reservoir layers and further regions, thus boosting the production. Heterogeneity influences the hydraulic fracturing performance; this is observed when comparing the performance of different fracced wells. Those that far outperform other fracced wells are generally connected to more
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