bluuebunny/crossref_metadata_2025_split huggingface dataset:
Extreme-Performance Polymer-Locked Wireline Cable Conquers New Frontiers of Wireline Conveyance in Deep Extended-Reach Well in UAE
Authors: Varghese Mathew , Da Costa Junior Jose Augusto , Billingham Matthew , Varkey Joseph , Chang Sheng , Cevallos Antonio , Unal Burcu , Mangum Jared , Mansour Ramadan , Morrison Montie , Kim David , Sladecek Pat , Tran Tam , Wheatley Edward Jason , Correia Gladwin , Al Kiyoumi Ahmed Abdulaziz , Othman Alaa Abdelkarim , Almarzooqi Laila Sayed , Altamimi Ahmed Mohamed 
Published: November 2020

Abstract
An extreme-performance polymer-locked wireline cable overcomes the conveyance challenges in tortuous wellbores, enabling the acquisition of high-quality production logging data in extended-reach drilling (ERD) wells. The use of this technology enabled an operator in the UAE to successfully evaluate the downhole production and reservoir properties in four extended-reach wells drilled from an artificial island. Production logging data acquisition using conventional wireline cables is challenging in such wells because of extreme cable tensions.
This paper presents a case study about a novel approach of combining an extreme-performance polymer-locked cable and high force tractors to successfully convey production logging tools in an extended-reach well, where previous attempts with two conventional wireline cable types had failed. The new approach is based on analyzing the drag forces acting on the cable in the wellbore and modeling the tortuosity of the wells for determining optimal cable and tractor properties to minimize these effects. Based on this in-depth analysis, high-strength, torque-balanced, polymer-locked coaxial cable and high-force tractors with large wheels are selected for the job. With meticulous risk management and establishing a core team of key personnel, including field operations, the operator, and the product manufacturing center, this new technology is successfully deployed. Production logging tools are successfully conveyed to the maximum depth of 27,800 ft, and safely retrieved from the well. Excellent flowing and shut-in log data are recorded in a single descent, making it possible to accurately quantify zonal contributions from this horizontal lateral for the first time. Good tension profile with new cable shows the value of torque-balanced cables in high-tortuosity well profiles.
The success of the job created confidence in conducting safer, more efficient intervention in maximum reservoir contact development wells. It demonstrates the value gained by deploying advanced high-strength polymer-locked coaxial cables in combination with high-force tractors.
Asset Reliability in Practice: An Effective Combination of APM, AI and Simulation Solutions within a One Stop Environment
Authors: Eilers Joachim , Jacquin Steven , Burgos Basile Natalia 
Published: November 2020

Abstract
This paper describes a data-centric approach for increasing asset reliability and performance through the creation of single-source-of-truth environment (i.e., an Evergreen Digital Twin).
For many oil and gas facilities today, asset data is spread across a multitude of applications and databases, and most are not connected. This paper will show how data can be aggregated and contextualized, and combined with powerful simulation, analytics, and asset performance management (APM) tools to enhance performance, reliability, and maintenance.
For illustrative purposes, an oilfield use case will be presented involving the implementation of a an open and flexible operational intelligence platform (OIP) and an advanced simulation platform. In the proposed scenario, the OIP makes it possible to integrate and contextualize data from the simulator – making it accessible and useful for field operations personnel. The paper outlines the benefits and capabilities the combination of these tools can enable – including visualization and optimization of well production and the ability to simulate "what if" scenarios. It also discusses how artificial intelligence (AI) and/or APM tools could be integrated within the digital asset portal to provide early prediction of equipment failures and conduct failure mode analyses. The solution has been conceptually and technically proven; however, it has not yet been implemented by the field operator.
Overall, the use case highlights the value that can be realized by integrating data from disparate sources within a one-stop environment to make better operational decisions regarding complex oil and gas assets and facilities.
The Novel Approach to Pressure Transient Analysis in Highly Fractured Reservoirs: Case Study from Patardzeuli Field, Georgia
Authors: Ramatullayev Samat , Akbayev Beibit , Tsaplin Dmitri , Urazaliev Jenis , Goloborodko Andrey 
Published: November 2020

Abstract
Fractures are common features of many carbonate reservoirs. Given complex flow network that they create, characterization of dynamic behavior of these reservoirs is often complicated and becomes important, especially, if fractures provide primary pathways of fluid flow. In this paper a novel semianalytical simulator was used to understand the pressure behavior of naturally fractured reservoir containing a network of discrete and/or connected finite and infinite-conductivity fractures.
In this study an integrated interpretation methodology is applied to analyze well test data acquired in open hole section of exploration well drilled into highly fractured carbonate reservoir of Lower Eocene - Upper Cretaceous sediments on Patardzeuli field of Block XI-B, Republic of Georgia. The main steps consisted of explicitly modeling fractures - both wellbore-intersecting fractures and fractures located away from wellbore - using formation microimager data and calibrating the model to actual well test response using a unique novel mesh-free semi-analytical simulator designed for fractured reservoirs.
Study presents the results of well test of one zone performed in highly fractured carbonate reservoir drilled in Patardzeuli field. The pressure-transient response confirmed the complexity of reservoir and dominant contribution to flow regimes from fractures.
It is shown in this paper that there are many factors that dominate transient behavior of a well intersected by natural fractures, such as fracture conductivity, length, intensity and distribution, as well as whether fractures intersect the wellbore or not. Moreover, it was demonstrated that presence or absence of damage on wellbore-intersecting fractures in vicinity of wellbore will impact the pressure- transient behavior of reservoir and shape overall productivity of the well.
The novelty of the approach is the analysis of the dynamic behavior using a unique semi-analytical pressure transient simulator for fractured reservoirs. The simulator can be used to obtain a response for arbitrarily distributed infinite and/or finite conductivity natural fractures within the reservoir by modeling them explicitly. In this study, it allowed to maximize the value of well tests by assessing the effect of fractures on reservoir dynamic behavior and obtain matrix and fracture parameters where conventional well test interpretation tools would be deemed unviable.
Evaluating Percentage Cost Volume of Engineering, Procurement & Construction to Add Value in EPC Petrochemical Projects
Authors: Siddiqui Talha 
Published: November 2020

Abstract
This research analyzes a real-time data extracted from multiple Mega EPC projects (min 50 Million US Dollars) in petrochemical industry. The data pertains to the distribution of overall project cost in to three major segments in a typical petrochemical project which are engineering, procurement and construction. By knowing the percentage volume of cost in each of the three major segments in a petrochemical EPC lump sum project, improved efforts can be made to dedicate adequate resources & save significant cost in the relevant segment and in the overall EPC project.
Method used was that twelve (12) completed EPC lump sum petrochemical projects were selected for cost data analysis. Out of these twelve projects, cost for hundreds of line items segmented into engineering, procurement & construction was tabulated in the cost model spreadsheet. Against each line item, its corresponding cost estimated by Owner / End-user and all bidders (on average five bidders were taken) for each project was listed. Average cost of all 6 organizations (Owner and five bidders) was calculated and analyzed to a minute detail ignoring any outliers. The data was buildup from a single line item in a project to the complete level cost of engineering, procurement & construction for the particular EPC project.
Following criteria for the selection of data & projects was adopted for the purpose of this research: Petrochemical industry projects onlyProjects considered with individual overall cost of minimum 50 Million US Dollars (USD)Revamp and grass root projects
As the cost of engineering, procurement and construction was segmented for each project, it is concluded that average cost of engineering is approximately 9% of the overall EPC project cost (however engineering is driving procurement and construction which combine consumes approximately 91% of the overall project cost). Cost of procurement on average came out to be approximately 52% of overall EPC lump sum petrochemical project therefore it is most important that while preparing cost estimates of an EPC project, co-ordinated efforts by each of three disciplines that is engineering, procurement and construction are required to develop accurate cost estimates. As procurement corresponds to major percentage of an EPC lump sum project therefore investment in right resources in procurement & supply-chain can result in major cost savings for the organizations.
Cost Optimization in Onshore Pipeline Design and Construction
Authors: Al Braiki Ahmed , Kant Nath Nahum , Sulaiman Mohamed , Shivaji Gongade Ashish , Al Awadhi Ibrahim 
Published: November 2020

Abstract
"Optimization" or "Fit for Future" is the new norm for any industry in this competitive global environment. To encounter the challenges and to embed 100% HSE, efficiency, performance and profitability in operation, maintenance and new constructions, there is an urgent necessity to review and update existing design and construction specifications related to Pipeline. Hence, this paper summarizes the latest specification optimization efforts in pipelines material engineering without compromising the safety and integrity of the assets.
In ADNOC Gas Processing, specifications for various engineering disciplines namely, process, automation, control, electrical, static/ rotating equipment, piping/ pipeline, civil/ structural are followed in engineering, construction and maintenance activities. These were developed over years to steer the Company towards unparalleled reliability, operability and integrity. Now, the challenging market demands adaptability, agility and forward thinking with a need to "balance the performance with efficiency and profitability", without compromising HSE.
Hence, a "Lean" approach towards the specifications is emphasized by focusing on cost-saving and value addition in terms of optimized schedules and enhanced efficiency. A set of pipelines DGSs were reviewed internally based on International standards/specifications, best engineering practices, lessons learnt from involvement with Operation and Projects and consultants optimized specifications. Through this paper, major changes in pipeline specifications are elaborated highlighting potential areas of optimization and realized cost savings.
ADNOC Gas Processing (AGP) plays a strategic role in ADNOC and the UAE hydrocarbon value chain by contributing significantly for the development of the Emirates. ADNOC Gas Processing (AGP) operates and manages an integrated Pipeline Network of approximately 3500km length of Pipelines with the mission of uninterrupted supply to its Customers and any impact on the upstream plants. Various fluids are transported via pipelines such as Sales gas, Crude oil, NGL, Condensate, Water, Nitrogen and associated gases wherein majority of network contains Sales Gas. AGP is involved in executing many Major Pipeline Projects.
This paper presents "Fit for Future" initiative that has changed the organizational culture and reflects effectively in all activities across the Company. As all the technical activities are based on DGSs, update plan and potential cost realization are the main drivers for enhancing the performance without compromising HSE. This approach of re-visiting the technical specifications in the light of "high efficiency with low cost" can be adopted across other OPCOs and move towards common specifications for ADNOC.
Automated Well Portfolio Optimization for a Mature Hydrocarbon Field in the Middle East
Authors: Reddicharla Nagaraju , Alshehhi Shamma Saeed , Rachapudi Subba Ramarao , Utama Indra , Gönczi David , Stundner Michael , Schweiger Georg 
Published: November 2020

Abstract
Production optimization for mature hydrocarbon fields face several challenging tasks, including the long process of decision making when inactive and low performing wells are being evaluated. The lack of necessary data integration and evaluation of valuable strings, wells, reservoirs can vary between departments making it challenging to bring a prompt and standardized solution.
Therefore, an automated decision-making system has been developed with an open source software with capturing the logics and innovations of subject matter experts and managers. The current assessment is focusing on the automated re-evaluation of inactive strings, low performance wells as well as interventions candidates.
Automation process initially starts with proper data analysis and integration. The advisory system consists of unique, fully automated workflows consuming several data sources. Essential part of data integration is to find the most relevant input parameters, which can be used by the optimization system, and provide recommendations to the end user. A hierarchical control system is added in parallel to data import, providing a long-term and easily sustainable data set for evaluation of wells, reservoirs and fields. This approach leads to a long-term and easily sustainable solution platform, which can be updated and extended whenever new resources are available.
A scoring system is provided encountering the historcal and current performance of the existing entities like equipment, wells and reservoir including problems faced during operations. Individual well performance (including down-time, losses, status) is assessed by identifying contributing factors of production decline and failures using data-driven machine learning and fundamental analytic models.
Exploitation of Waste Energy Within the o&G Facilities: How Orc Technology and Gas-Expanders Can Drive the Decarbonisation Path of the O&G Companies
Authors: Rizzi Davide , Rossetti Nicola 
Published: November 2020

Abstract
Following the trend of energy efficiency, the Oil&Gas sector is looking continuously to sustainable solutions aimed to reduce carbon footprint while maintaining competitiveness. The market shows that a clever way for O&G field is the implementation of Organic Rankine Cycle technology, which turns waste-heat into useful power, with minimum impact on the existing facilities. An ORC unit can exploit waste heat from several sources. Different ORC applications within the O&G field were studied.
The study conducted evolved in two phases. The first one aimed to identify the most suitable waste heat sources unexploited in the O&G facilities. The second one explored the technical and economic analysis of different configurations, in order to understand the best ORC solution for this industrial sector (in terms of process parameters, equipment and layout).
A proved ORC application was in the Gas-compressor-stations along the pipelines where multiple gas-turbines operating in open-cycle are used as prime-movers for compressors. Although reliable and flexible, they waste a significant amount of energy that can be converted into useful power by means of an ORC system, a clear opportunity to boost the overall efficiency of the plant.
Other applications regarded the exploitation of hot streams in associated petroleum gas (APG) process carried-out within refineries. Due to its poor chemical composition, APG are typically burned via torches, thus wasted. ORC can exploit that energy to produce electricity by means of a flare-gas-boiler which heats up a vector fluid to feed the turbogenerator.
Beside those waste-heat streams, another potential form of energy was available in gas pressure-letdown stations, where lamination valves dissipate the potential energy contained in the pressurized gas. In this scenario, the Gas-expander technology (similar to ORC) can be a valuable alternative and a more efficient solution. It consists in a turbine through which the NG at high pressure, rather than being laminated, expands to produce work, thereafter converted into electricity by a generator.
This paper will present the above-mentioned solutions, employed both individually or combined.
Considering a large-scale application, the paper will show how the implementation of the ORC recovery systems represents other than a way to meet sustainability targets also a remarkable and profitable business for O&G companies. Furthermore, the Gas Expander technology represents a solution to improve the energy efficiency of NG transmission and distribution networks, as well as upstream and downstream facilities.
Employee Motivation in the Workplace
Authors: Emmanuel J. I. 
Published: November 2020

Abstract
A plunge in oil prices and slow economic growth has led to a reduction in the top line and bottom line of both local and international oil and gas companies worldwide. Whilst some companies have gone extinct due to the harsh operating regime, others have merged to share the risk, boast profit, and lower overall operating costs associated with the oil and gas business. Others have engaged in cost reduction initiatives like lowering of physical asset cost, cutting of staffing overhead, reduction of vehicle expenses, descoping of maintenance activities, deferment of non-critical inspections of assets, reduction in supply, advertisement, and insurance cost.
However, most of the organisations have not effectively harnessed their immense human resources pool to improve productivity and gain competitive advantage by developing core competence. While other cost reduction schemes have been applied to increase the bottom line, there is a need for more emphasis to be placed on employee motivation schemes as employees are the most important asset of any organisation and integral to company business continuity and sustainability (ISO 22301, 2012). How to engage and motivate employees is one of the most challenging tasks facing most organisations.
In spite of the direct effect of motivation on the bottom line and overall organisation productivity based on a plethora of research, immense gap exists in knowledge on how best to apply motivation theories and strategies to enhance employee productivity in the Oil and Gas Industry.
In addition, only limited research exists that has evaluated the factors influencing employee motivation in the oil and gas industry with consideration to the diverse nature of the oil and gas operations ranging from exploration to production, transportation, refining, and product marketing. The need to investigate the influence of employee motivation in the workplace constitutes the focus of this study, and the findings of this research work will be useful to all stakeholders in the oil and gas industry.
Therefore, this research work would evaluate employee motivation in the workplace as a case study of the worldwide oil and gas Industry. If employees can be adequately motivated, the chances are higher they would be engaged to expend more energy towards the achievement of their organisations corporate objectives. In addition, motivation is geared towards developing employees as the human capital of the organisation (Steers & Porter, 1991).
This paper presents the findings on this research work with the objective of equipping organisations and managers with the tool they need to engage, motivate, and get the best out of their staff. This study will be underpinned by relevant literature and views of some practitioners in the Industry.
Gas Breakthrough Identification in ERD Wells using Gas Tracers with Quantum Dots
Authors: Ovchinnikov Kirill , Malyavko Evgeny , Husein Nadir , Gorbokonenko Oksana 
Published: November 2020

Abstract
In the context of high hydrocarbon price volatility on the global market and worsening resource structure an increasingly greater attention is paid to the search of effective and economically sound tools for production and exploitation process management and control, including in horizontal and directional wells.
Conventional PLT methods applied in extended reach drilled (ERD) wells have a number of limitations related to data relevance and well bore accessibility. The alternative method is deployment of tracer-based material while well completion process. This enables a stream of downhole data on demand without needs of well intervention using Coiled Tubing or Tractor services.
This paper describes an approach of deploying the dynamic tracer-based production logging monitoring systems as a part of well completion equipment. Special cassettes attached to slotted liners or ICV/ICDs carry out advanced polymeric composition for 3-phase monitoring for oil, water and gas, including off-shore project with extended reach wells (ERD).
Protecting Transformers Against Static and Dynamic Pressure
Authors: Younis Dana , Bagarwan Ali , Salah Maha , Gandham Mallikarjuna Rao 
Published: November 2020

Abstract
Oil filled transformers are extensively used in oil and gas electrical networks. The o il in power transformers cause a major hazard to the electrical installations especially in case of fault, which may lead to explosion hazards that would have destructive effects to the people, asset and environment. Therefore, transformer manufacturers and design engineers shall consider suitable devices and mitigation measures in the design of oil-filled transformer to avoid harsh effects in case of failure. Moreover, they need to prevent the event of fire spread and damage to other assets that surround the transformer area.
The following sections in this paper highlight various possible solutions and safety measures to consider when designing your oil-filled transformer for the required installation. Some of these include adequate power rating, selection of insulating oil, suitable tank size, study of temperature rise, proper selection of protection devices, selection of monitoring devices etc.
Additionally, this paper explains different methods and features available in the industry to protect the transformer and assets in case of any fault. These measures include internal in built protections, external protections and additional mitigation measures to avoid explosions. These measure will ensure safeguarding to our people, asset and environment in compliance to ADNOC 100% HSE.