bluuebunny/crossref_metadata_2025_split huggingface dataset:
Graduate Employability: Key Challenges and Possible Solutions
Authors: Afolayan Tunbosun 
Published: September 2016

Abstract
This paper seeks to identify key challenges in student employability, propose possible and sustainable solutions, introduce and reinforce the importance of ‘knowing self’ and developing ‘transferable skills’ that can help with sustaining their various phases of life
Formal and Informal education are designed to prepare students for life skills, or so we think? Life skills are those skills that are inherent in ensuring that we become responsible, successful and happy individuals. In becoming successful, desirable employability skills are imperative either as a potential employee or entrepreneur, as they help individuals to accomplish their ambitions and live to their full potential.
This paper utilizes a range of information from over 500 respondents in surveys comprising undergraduates, graduates and employed individuals, addressing specific aspects of education and employability, importance of vision and aspiration and others. Experts' opinions are included on survey results and guidance towards proposing suitable solutions and go forward plan while exploring applicable industry recruiting policies.
Incoming results already challenge the concept of employability versus education. It suggests effective integration and highlights dependencies on a range of attributes and developed abilities. Also student awareness of this concept needs to be developed. Hence, it is crucial to bring to the formal education curriculum a strategy that influences these skills development.
This is a culmination of my volunteer experiences as pioneer AAPG AR Young Professional Lead and currently Student Chapter coordinator, and as I step into a role with NAPE as the University Assistance Program chairperson.
It is evident that employability supersedes academic excellence. This project provides valuable information regarding this life skill and attempts to change the mindset and preparedness level of current and future employees/employers while creating more values for industrialization.
Improving the Foamer Selection Procedure for Gas Well Deliquification Application
Authors: Omrani P. Shoeibi , Shukla R. K. , Vercauteren F. , Nennie E. 
Published: September 2016

Abstract
Liquid loading is a common problem in mature gas wells which due to low pressures in the reservoir, liquid phase cannot be lifted to the well head. In gas wells, foamer injection is one of the method to mitigate liquid loading and increase the stable gas production. In this study a modified version of the Bikerman gas sparging setup was designed to evaluate the foamers performance at conditions which are more representative to the ones in fields, such as higher pressures and temperatures. The effect of different parameters on foam performance is studied. The study covers the effect of pressure, temperature, hydrocarbon fraction and foamer agitation velocity on the foam performance. Three tests were performed to quantify the foamer performance; foam buildup, collapse and liquid carryover tests. It is shown that performing evaluation tests at temperatures and hydrocarbon fractions close to the field conditions is inevitable. These results could be used as a basis to improve the current foamer testing methods. The same procedure could be used for surfactants evaluation for Enhanced-oil recovery (EOR) application.
Accelerating the Learning Curve of Next Generation Exploration and Production Workforce through Smart Data and Knowledge Environment
Authors: David Richard Mohan 
Published: September 2016

Abstract
Exploration and Production operating envelop is increasingly getting complex due to sub-surface and production challenges. This requires companies to work in a new operating environment that requires better understanding of the fields, apply new techniques, more agility in business decision, workforce development while improving operations excellence. This requires efficient transformation of the existing practices and workforces into the new operating environment while developing young nationals efficiently and integrating them into the main stream to enable them to lead future operations.
Knowledge Management (KM) is a key component that facilitates this transformation. Though knowledge management is practiced at varied levels in different organizations, the real value can be achieved when knowledge management is seamlessly integrated as part of the routine operations than as a standalone practice.
In this paper, the author discusses the strategy, methodology and use cases in establishing a Collaborative Knowledge Management Foundation that comprise of integrated knowledgebase, KM workflows, Virtual Community of Practices (VCoP), data analytics, collaboration tools, practice to embed knowledge as part of routine operational workflows. VCoPs are the practitioners and expert's hub for key business lines such as Geology, Geophysics, Reservoir, Drilling, Production, Engineering, HSE etc. that facilitates asking questions, share best practices and ideas, support each other efficiently while taking operations decisions in a virtual environment.
Integrated knowledgebase comprises of technical information, decisions and lessons learnt, FAQs, best practices, root-cause, after action reviews across different disciplines are vital to carryout quality planning, design and operations. The KM workflow systematically harvests the knowledge generated, data analytics tool derives insights out of vast volume of data smartly, collaboration tools facilitates smart interactions amongst the business community, the integrated process disseminates knowledge in real time.
The smart knowledge Management Framework facilitates accelerate the learning curves of the emerging talents, transform existing employees to adapt to the changing E&P operating environment towards strategically manage human capital and business transformation. The CoP enables the employees to leverage the collective knowledge and experience of experts in addressing operational challenges and decisions.
Defining Sand Control in an Uncharted Frontier: A Case Study on the Zawtika Field Development in Myanmar
Authors: Grant Graham , Soon Lee Boo , Moses Nicholas , Syifaa'i Arfi , Wallace Cal , Ling Chin Pui , Kikuchi Masato 
Published: September 2016

Abstract
This paper covers the design, execution, and evaluation of the development of the Zawtika field operated by PTTEPI in Myanmar. This includes the study of the reservoir, the selection of completion methodology, the operational challenges, and the performance of the wells.
The Zawtika field development focused on the laminated Plio-Pleistocene reservoirs. The formation comprises a thick sequence of mixed deltaic and shallow marine clastic sediments. A conservative geomechanics study indicated that any reservoirs shallower than 1,700 m true vertical depth (TVD) have high sanding risks and would require an active sand control method.
A batch completion campaign was planned and deployed as a mix of single-zone and stacked dual-zone cased-hole gravel packs (CHGP). A pre-gravel pack acid treatment was tailored for formations with high chlorite content and fines stabilization. A fracture- and gravel-pack service was the primary gravel pack option followed by high-rate water pack (HRWP) depending on water zone proximity or a lack of stress barrier. The sanction that was placed on the country at the startup of this campaign and the limited infrastructure in place led to various challenges during different stages of the campaign.
Over 15 months, 17 wells were completed on three platforms with eight single-zone wells and nine stacked dual-zone wells. This totaled 26 zones where 10 zones were completed with the fracture- and gravel-pack service and 16 zones with HRWP. These jobs were executed on a tender assist for the first platform and on a hydraulic workover unit for the following two platforms. These were among the notable points for the campaign: First CHGP completion in MyanmarAchieved production objective with zero sand productionIntroduced the technique of pumping HRWP in sweep stages for longer intervals in MyanmarIntroduced several fluid systems in Myanmar, including a polymer-free carrier fluid, acid system with diverting agent, fluid loss pill, and clay stabilizerCompleted all wells without downtime related to delivery of products despite the remote location and logistics between multiple countriesCompleted the campaign without any HSE incident and with high operating efficiency
Enhancing the Understanding of Hydraulically Fractured Well Performance in Gas Fields Using Production-History Matching-Case Studies
Authors: Waheed Arshad , Brohi Imad , Rahim Zillur , Omair Ahmed , Pacheco Eduardo 
Published: September 2016

Abstract
In most cases several folds of increase in production after a fracturing treatment is sufficient testimony to the success of the technology and its application in the particular well or field. A cursory look at a post-frac, pressure transient analysis (PTA) will show a stimulated well condition and validate the achievement. For a proper assessment of well potential this approach may be inadequate. The fracture geometry, conductivity, phase flow through the reservoir, reservoir quality, completion practices and pressure behavior under the boundary conditions all contribute to a well's performance. With all these factors considered, the post frac production results may be significantly different from expectations. To encompass this, the preferred methodology would be to benchmark the production from different fractured wells to have a valid comparison and then optimize the methods.
Production-history matching through reservoir simulation is a very effective tool in meeting this challenge. Many subtle features of the reservoir get highlighted in relation to hydraulic fracturing with the dominant component being the fracture itself. This paper examines several successful wells, which unexpectedly fell below the benchmark. The study investigates whether the hydraulic fracture underperformed or the post-frac activities contributed to low well deliverability. Conventional hydraulic fracturing and the newer technique of channel fracturing were part of this analysis.
The post-frac flowback procedures had a significant impact on the productivity of the wells. The presence of condensate brought its own set of challenges. In the long term, it was also interesting to note how the wells recovered after these damages. This paper will provide an insight into this investigation.
Efficient Calculation of Proppant Transport in a Wellbore-Fracture System
Authors: Filippov Andrey , Lu Jianxin , Popa Florentina 
Published: September 2016

Abstract
Analysis of particle-laden fluid flow near an individual perforation (and assuming the fracture is only being fed by this one perforation) showed that the efficiency of particle transport to the fracture (ratio of particle concentration in the fracture and in the wellbore) depends on two dimensionless parameters—the particle stokes number St and parameter Λ, which is the ratio of flow velocity in the wellbore and to the fracture. In a simplified geometry approach, the entrance to the fracture is modelled as a short segment of a circular pipe. Using a detailed 3D CFD model of fluid-particle flow to the fracture (built in a commercial software), the efficiency of particle transport to the fracture was calculated for various combinations of parameters, St and Λ, and tabulated. Using the obtained tables, the proppant delivery efficiency can be very efficiently and accurately calculated by linear interpolation of tabulated data. The calculations presented in the paper have been carried out using water as the fracturing fluid with low proppant concentrations.
Applying Data-Driven Method to Production Decline Analysis and Forecasting
Authors: Jia Xinli , Zhang Feifei 
Published: September 2016

Abstract
Based on historical production data, decline curve analysis (DCA) can be used to monitor production, identify potential problems, and predict well performance, life, and economics. Optimized production history matching is crucial to economic analysis on future operations and decision making. The widely used decline models such as Arps rate-time relations and their variations are based on fitting predefined equations and often times do not work for shale gas and oil wells since most of the production data from these wells exhibit fracture-dominated flow regimes and rarely reach late-time-flow regimes. This approach can mislead the trend of the decline curves and produce poor matches and unreliable production forecasts. A suitable data-driven model combining physical or operating parameters can be greatly beneficial and serve as the basis for decline analysis and prediction.
This paper discusses a method for automatic history matching and decline analysis for shale production data based on machine learning, which can be effectively applied to production surveillance and process automation. This approach is based on time series (TS) analysis and neural networks (NNs), which was then extended to applications with operational parameters available, such as bottom-hole pressure (BHP). The proposed TS and NN models were applied to production data from a Barnett gas well. The historical production data was divided into two parts. The first part of the data is used to train the NN model, and the second part of the data is used to verify the accuracy of the prediction results from each input parameter. The results were analyzed and compared with classic Arps decline models.
An NMR Experimental Study and Model Validation on Capillary Condensation of Hydrocarbons Confined in Shale Gas Condensate Reservoirs
Authors: Wang Haijing , Seltzer Scott J. , Sun Boqin , Wigand Marcus , Horch Carsten , Stallmach Frank , Li Baoyan , Thern Holger , Mezzatesta Alberto , Arro Roberto , Zhang Hao 
Published: September 2016

Abstract
Unlike conventional gas reservoirs, shale gas reservoirs contain organic mesopores that have pore sizes ranging from 2 to 50 nm. These organic pores may cause capillary condensation of confined hydrocarbons due to the non-negligible capillary pressure. A novel phase equilibrium model has been developed to quantify effects of pore size distribution on the phase behavior of confined hydrocarbons, including the occurrence of capillary condensation. However, it remains a challenge to assess the phase behavior of confined hydrocarbons by laboratory experiments. This is because the conventional pressure-volume-temperature (PVT) method measures the phase behavior of a bulk fluid. Here, we employ low- and high-field nuclear magnetic resonance (NMR) techniques to experimentally probe the capillary effect on phase behavior using retrograde condensates in synthetic porous media and shale rock samples.
In low-field NMR experiments, water-wet porous glass and oil-wet polymer-based spherical activated carbon (PBSAC) beads are used as porous media. NMR relaxation times are used to observe the occurrence of capillary condensation for pure and mixed hydrocarbons at room temperature under controlled pressure. High-field NMR is employed to gain further sensitivity and resolution for the phase behavior of a confined methane-butane mixture. NMR spectroscopic signatures of the dew point were identified, enabling the comparison of dew-point pressures of the bulk hydrocarbons and hydrocarbons confined in grinded shale rock. NMR-measured dew point of confined hydrocarbons is ~115 psi higher than that of bulk phase. This pressure shift agrees well with simulation results.
In summary, we present NMR experimental studies and model validation on the capillary condensation effect, showing a shift of dew-point pressures of confined hydrocarbons mixtures in porous media. The agreement between NMR and simulation results validates the novel phase equilibrium model implemented in the newly developed PVT simulation software. The lab measurements and model validation results show that a) oil-wet is one key condition for the occurrence of capillary condensation of confined hydrocarbons; b) the shift of an upper dew-point pressure of hydrocarbons confined in shale rock can be tens of psi to slightly over 100 psi for the retrograde condensate system being used; c) the phase equilibrium model is valid for modeling phase behavior of multi-component hydrocarbons confined in mesopores.
Quantifying and Mitigating the Impact of Asymmetric Induced Hydraulic Fracturing from Horizontal Development Wellbores
Authors: Walser Doug , Siddiqui Shameem 
Published: September 2016

Abstract
Sufficient production and fracture mapping evidence across North America is now available to clearly demonstrate that pairs of delineation and development wells often underperform when there is substantial production time (months or years) between the completions of the two wells. The relative degree of impact on hydrocarbon extraction per acre varies from one play or formation to another, but the phenomena is generally attributed to asymmetric induced fracturing from the development (child) well into the previously partially drained and lower static pressure delineation (parent) well reservoir volume. This paper briefly discusses two solutions that have been employed to minimize the negative fiscal ramifications and improve recovery.
Rigorous 3D unstructured grid reservoir modeling can assist in the quantification of the phenomena; however, options for mitigating the problem for cases where the impact is extreme are typically limited. Synthetic history matching and forward modeling were performed with a grid-based numerical simulator that mimicked a series of asymmetric oblique fractures interacting with a drained reservoir volume, comparing acceleration of reserve recovery and total recovered reserves with a similar case involving symmetric fracturing. Two scenarios for preventing extreme asymmetric fracturing are discussed. These included dramatic shortening of the time between completions, and performing pressure sink mitigation (PSM) via refracturing of the delineation wellbore.
It is shown that the asymmetric fracturing into drained volumes can materially impact reserves and rate of recovery if the acreage position of a given project is substantial. It is demonstrated that the overall stimulated reservoir system permeability, the degree of permeability contrast between reservoir layers, and the degree of asymmetry are all factors that have an impact on the degree to which the long-term time between completions affects recovery of hydrocarbons over and above simple volumetric depletion.
Integration of rigorous 3D reservoir modeling and far-field fracture mapping have established that the negative ramifications of extreme induced fracture asymmetry can be overcome with careful application of drilling and completion (D&C) timing and offset drainage pressure management process.
Providing Accurate ESP Flow Rate Measurement in the Absence of a Test Separator
Authors: Camilleri L. , El Gindy M. , Rusakov A. 
Published: September 2016

Abstract
Where well rates are outside the range of the test separator, operators usually have no choice but to estimate well production using back allocation techniques, which rarely capture the variance in flow rate over time. This was the case of a well in the Thistle field in the UK sector of the North Sea, where high-frequency flow rate was accurately calculated using ESP real-time data, which was instrumental in measuring inflow properties.
The liquid flow-rate calculation was based on the principle that the power absorbed by the pump is equal to that generated by the motor, which provides a linear equation that can be resolved for rate. Water cut (WC) was calculated by measuring the production tubing differential pressure (DP), which provides the average fluid density, which is subsequently converted to a WC. Analytical equations are used throughout the process, ensuring that the physics are respected at all times. This yields greater repeatability and confidence than analogous methods, which are based on correlations and artificial intelligence.
The calculations provided continuous liquid flow-rate and WC trends over the 6-month life of the ESP with a frequency of one calculation per minute with excellent repeatability and resolution. This enabled us to calculate inflow properties such as productivity index (PI) and skin, as well as history matching a reservoir simulation of the drainage area. This was essential to explaining why production dropped from 1500 to 500 B/D over a period of 8 months, which was found to be a lack of pressure support. The fall in production also caused production instability because of severe slugging, which could be remediated by concurrently increasing the tubing head pressure and ESP frequency without changing the drawdown.
In addition to demonstrating the superiority of an analytical virtual flowmeter over correlations or artificial intelligence, the method also shows how the model can be calibrated accurately using an alternative pump reference curve, which is independent of flow rate, as opposed to traditional centrifugal pump curves. Flow-rate independence was indispensable because of the inability to physically measure rates with the existing test separator and was key to delivering accurate results.
New Hybrid Bit Technology Provides Improved Performance in Conventional Intervals
Authors: Wong Alex , denOuden Bruce , Herman J. J. , Isnor Sid , James Phil , Marley Ryan 
Published: September 2016

Abstract
The increasing emergence of hybrid drill bit technologies in recent years is pushing drilling performance to new levels that were previously unattainable by conventional designs. One example of a hybrid bit technology uses a combination of gouging inserts and shearing PDC cutters to increase the overall effectiveness of rock removal. In two and a half years of development, this hybrid gouging / shearing cutting structure has consistently demonstrated a superior average ROP over rollercone bits, as well as improved PDC cutter durability and lower reactive torque compared to traditional PDC bits.
Until recently, the majority of gouging / shearing hybrid bit applications were in surface intervals drilled by six-bladed, 16mm cutter designs. This configuration is adept in enhancing ROP and durability in challenging formations such as gravel and boulders, which normally cause severe impact damage to PDC cutters. However, to push the benefits of the hybrid technology into new territory, significant design changes were made to optimize its performance in the newly targeted applications.
In high ROP intervals, lowering the blade count of the bit has been shown to provide two key benefits: firstly, reduced cutter density increases the depth of cut and work rate for each PDC cutter, thereby increasing the aggressiveness and ROP potential of the design. Secondly, it enables more geometrical freedom for a hydraulic configuration that better suits high ROP and thermal demands. Unlike the six- bladed designs, the hydraulic layout of the reduced blade count designs incorporates separate nozzles dedicated to both the gouging inserts and PDC cutters on each blade. The ability to direct high velocity drilling fluid to both cutting structures promotes more effective cooling and removal of cuttings.
The first instance of the updated hybrid technology was realized with a four-bladed, 12.25 in. diameter design used in a series of runs in Western Canada, drilling competent formations consisting primarily of shale with interbedded sandstones. The hybrid runs in these areas have exceeded the ROP typically achieved by six-bladed PDC bits in offset wells, and in certain cases, recorded average ROPs of over 310 ft/hr while still maintaining superior torque management throughout the entire run. Additionally, the dull conditions of the bits have repeatedly demonstrated reduced PDC cutter impact damage and thermal wear compared to conventional PDC designs. More development is currently underway to further expand lighter-set hybrid designs into more diverse applications.