bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Holistic Approach in Establishing a Structured Framework to Maximize Production Availability Through an Integrated ESP Key Performance Indicators
Authors: Khalaf Ahmed , Alquwizani Saud , AlSadah Hashim , Flippin Cleavant 
Published: November 2018

Abstract
Managing large-scale Electrical Submersible Pump (ESP) operations and assessing their performance can be a challenging task. Diverse operational environments, widely-spread geographical areas, large ESP populations, and different service providers are some of the complications facing operators. Nonetheless, it is vital to the success of any artificial lift project to establish a performance evaluation structure that can effectively capture deficiencies and highlight improvements.
While many operators focus on run life statistics as the central key performance indicator (KPI) for ESPs, these type of statistics may not be sufficient in providing meaningful information to decision makers. Other important ESP performance parameters include ESP shutdowns (both planned and unplanned), restart time of tripped ESPs, commissioning time, failure rate, and the number of premature ESP failures. Thus, a comprehensive study was jointly initiated between an oil operator and ESP vendors to establish KPIs that drive improvements in all aspects. The selected KPIs were developed in a structure that ultimately focuses on maximizing production availability and revenue generation.
By constructing the ESP KPIs framework, subpar performance areas were clearly visible by both the operator and the service provider. Decision makers were able to identify and act on fields that lag in performance while exerting efforts to improve underperforming service providers. Furthermore, regular meetings were conducted to review the established KPIs and recommend some action items, which might focus on either technical or operational solutions. Finally, KPI targets were set based on the review of historical trends and were assigned to be challenging yet relevant and attainable. The followed practice can prove to be successful in forming a common ground where service providers can quantify losses by the operator as a result of ESP performance deficiencies.
Comprehensive data collection and keeping of ESP trips, failures, and replacements are critical to the success of this work. Regular review of field reports and well performance are imperative to accurately compute the various KPI formulas. In fact, many of the KPI calculations can be automated to capitalize on the available communication networks installed in the field to improve ESP monitoring and accurately assess their performance.
Ultra-High-Speed ESP Solution for High Sand Production – A Real Case Study
Authors: Shakirov Anton , Koropetsky Vitaly , Alexeev Yaroslav , Agnaev Zelim 
Published: November 2018

Abstract
Sand production becomes more critical as the reservoir pressure depletes typically associated by water cut, scaling and sand production intensity. Erosion rate of Electric Submersible Pump (ESP) components tends to be ruled by pump rotating speed. Even so, strong focus on modern technological advances towards improving pump design has made ultra-high-speed ESP compatible with sandy wells.
This paper will review several case histories demonstrating the evolution of the ultra-high-speed ESP PMM (Permanent Magnet Motor) technology for over a decade. With a speed control ranging between 1,000 and 12,000 rpm, pump design and metallurgy were crucial aspects to focus on to ensure reliable operation in sandy wells. Continuous equipment analysis made during trials provided guidance to improve the design, while high-precision manufacturing techniques have made it possible to implement new solutions.
Case histories have showed high tolerance of the modern ultra-high-speed ESPs to solids in the produced fluid. Abrasion resistance is achieved with hard alloys being applied to the pump along with innovative modular pump design. As a result, ramp-up time has been reduced, with failure rate being minimized. Implemented design features enabled to declare maximum solid content for ultra-high-speed ESP at higher levels (up to 2 g/l) if compared to conventional equipment despite significantly higher nameplate speed (10,000 rpm) of the former. Successful results of the ultra-high-speed ESPs in sandy wells demonstrate a good example of integrating new technology developments into operation in harsh environment. These findings may help expand an application range of the systems traditionally considered as having relatively poor durability when exposed to sand production.
The systems studied in this paper represent a new generation of ESPs combining all the features of operation at high speed along with abrasion resistance being normally considered as incompatible with high RPM (rotation per minute). The conclusions of this paper are intended to provide advice when selecting and designing an artificial lift method.
Research and Application of Overall Energy Consumption Optimization Technology Under Low Oil Price
Authors: Zhang Xishun , Shi Junfeng , Zhao Ruidong , Deng Feng , Li Qiming , Zhang Jianjun , Sun Chengyan , Miao Guojing , Song Shenggang 
Published: November 2018

Abstract
At present in China, the prevailing optimization method for an individual rod pumped well pursues the maximum system efficiency under the condition of given production, which is ineffective for some high water cut oil wells and contributes a little to the oil production of a block. As a result, the maximum overall profit cannot be achieved. With the continuance of low oil prices and the increase of artificial lift cost, the individual well optimization method can no longer meet the requirements for field energy conservation and cost reduction. The energy consumption and contribution to oil production of every well are analyzed. Based on an analysis of the inter-relations between individual well production, energy consumption and efficiency, the energy consumption of individual wells and their contributions to oil production by utilizing relevant analytical approach, an objective function with the minimum overall block energy consumption is established in this paper to realize the overall profit maximization of block by allocating individual well fluid production, optimizing production parameters and using non-decreasing oil production as constraint condition. In view of the established optimization model characterized by complicated influence factors, multiple optimization parameters, enormous calculations and several constraint conditions, a penalty function algorithm is applied to optimization to convert a constrained optimization problem into the solution of an unconstrained optimization problem. In this way, fast solution of the model is realized. 154 wells of one oil production plant in Daqing Oilfield were subjected to overall block optimization. Since site execution of an optimization program, there are 63 wells with an increased fluid production, there are 91 wells with a decreased fluid production, the total oil production has basically remained unchanged, the total fluid production has decreased by 10.2%, the total energy consumption has decreased by 16.3%, and the average system efficiency has been improved by 5.1%. It is shown by field application that this technology can further decrease the overall cost and increase the overall profit of a block by allocating per well liquid production and optimizing production parameters comparing with the previous individual well optimization. It may be beneficial to any teams who are looking to lift more oil with less energy consumption.
Design Basis and Results from Field Trials of an All New Rigless Cable Deployable ESP
Authors: Liley Norman , Maclean Iain 
Published: November 2018

Abstract
This paper describes the overall system architecture and key enablers for through-tubing live well deployable ESPs. Further, the results from a series of installation and recovery trials are presented showing low cost cable deployable ESP's are now a reality.
Central to the design is the application of permanent magnet technology. This technology enables products to be built that are powerful, compact, retrofittable, spoolable and by their slenderness can be installed in high DLS wells.
Live well deployment is achievable using low cost spooling equipment and conventional wireline type PCE without the need for initial well re-completion. The deployment cable combines the roles of structural conveyance and provides electrical power to the Bottom Hole Assembly
Using alternative installation methods to convention opens the door for fast change-out when failure occurs, reduced deferred production, and avoids the need to schedule expensive drilling rigs from their primary purpose.
Optimizing the Process of Real-Time ESP Surveillance in Kuwait
Authors: Al-Jazzaf Abdulla M. , Krstic Nebojsa , Rutkowski Lukas , Al-Maqsseed Nora , Camilleri Lawrence , Al-Khaled Abdullah , Abdal Abdulaziz , Vasilache Liliana , Hua Gong , Faraj Bashayer 
Published: November 2018

Abstract
Real-time electric submersible pump (ESP) surveillance is becoming a standard in the oil industry, and many successful cases of applying 24/7 monitoring have been recorded around the world. Kuwait has more than 1,300 ESP installations, with the majority containing both downhole and surface sensors along with SCADA connectivity. Real-time surveillance is a relatively new concept in Kuwait because previous attempts were unsuccessful due to complications in the implementation. For the current application, it was necessary to set up the process without incurring additional costs and additional workforce. These challenges limited the process and application of real-time surveillance in Kuwait. Because increasing the workload with the same manpower risks loss in quality of implementation, it was necessary to improve the productivity of surveillance activities to cover more wells with the same workforce. The method of applying alarms was modified to speed up access and updates. Displays were redesigned for uniformity, resulting in an easy-to-navigate and user-friendly tool for monitoring. Decentralizing the surveillance center into smaller field units was also found to improve communications with field engineers. Improving the response time of identifying, diagnosing, and taking preventive actions is crucial in avoiding downtime. Multiple tools were built to identify triggered alarms to notify the surveillance engineers. A live diagnostic tool is built to improve the accuracy of root cause analysis and to recognize threats faster. GPS vehicle trackers are used to identify the closest service provider to take preventive action on every well. Sharing access with other sectors of the company enables interested sectors to be a part of the surveillance process. This paper presents the approach taken in modifying real-time surveillance by using existing company data and software without additional capital costs. The authors discuss applied methods of improving the productivity of the surveillance process and improving the response time to identify threats, diagnose, and take preventive actions.
Using Advanced Technology to Increase Production on Mature Fields
Authors: Woodman Malcolm , Rodriguez Javier , Wade Kevin , Marriott James 
Published: November 2018

Abstract
The low oil price clearly provides the industry with some challenges and the need to optimise oil production or reduce operating costs is now more prevalent than ever. Software tools that can accurately model the field and then perform production optimisation, while minimizing operating costs by informing operations as to what control variables to change on the field, can play an important role.
It is extremely important that the advice provided by the technology to operations can be implemented easily and quickly. This is particularly important for mature fields where the field conditions may be changing continuously and therefore an even greater need for regular (weekly or daily) optimisation of production, to ensure that the field is operating optimally on a day-to-day basis.
The aim of all model-based optimisation technology is to change the available control variables (from their current settings) so that the objective function is either maximised or minimised. In most production systems the objective function would be to maximise oil production, with the control variables being items such as: gas-lift injection gas rate, choke settings, well and pipeline routing, etc. Alternatively the objective could be to minimise costs while keeping production at the target rate. In either case the optimal solution may require that a considerable number of control variables be changed.
For a practical implementation, the large number of required field changes will be a challenge to the production engineer and operations. What is required is a reduced set of control variable changes that yields an increase in production (not necessarily the optimum). However, prior to the optimisation, the production engineer will not know the most important control variables to change, thus the software tool has to undertake this task as part of the calculation.
To date the direct deployment of model-based optimisation to support operations has had some challenges. Some of these challenges involve technical issues that have not helped the wide-spread acceptance, specifically; lack of confidence (validation) of the underlying model's predictionsinefficient handling of continuous and discrete control variables by the optimisation algorithmfailure to integrate production and facilities in the same modeland, perhaps most critically, delivering a solution that cannot be implemented directly in the field due to recommending a large numbers of changes from the current operational point
In this paper, we focus on next generation equation-based optimisation technology (as implemented in the gPROMS Oilfield optimiser) that can address these deficiencies to deliver a solution that can be implemented directly onto the field that includes the simultaneous optimisation of both continuous and discrete control variables.
Hybrid Artificial Lift System- Alternate SRP/PCP in Cyclic Steam Injection for Heavy Oil Wells
Authors: Mesbah Hossam , Dange Aarti , Tanasescu Ion 
Published: November 2018

Abstract
The main objective for the implementation of this methodology was to achieve uninterrupted production and avoid failures. Heavy oil wells undergoing CSS in the field in Kuwait, pose challenges of high temperature and sand incursion. As soon as the well was brought on production at the end of soaking period, Metal PCP, which was earlier believed to be the best choice proved wrong when it underwent failures due to dry run because of steam (gas) and the lost interference fit between the stator and rotor owing to reduced viscosity and poor efficiency due to fluid slippage. The strategy was revisited and Sucker rod pumps were initially installed as soon as the well came on production. Being shallow wells on VSD control, they were safely ran at 3 SPM and that kept the sand from entering the well since the velocity of the fluid kept way above the critical velocity. The pump produced around 100 bbl./day. As the reservoir cooled, and the viscosity increased, the calculated rod stresses were seen to increase beyond 80%. Anticipating the rod failures and the subsequent production loss, strategic decision to install all metal PCP was made for the next period of production. The increased viscosity of the fluid provided excellent efficiency to the PCP operation and also eliminated the rod fall. The well produced around 245bbls/day consistently. Thus the methodology states alternating the Sucker rod pump (SRP)and All Metal PCP (AMPCP) through the production cycle using viscosity as the indicator.
The cost and benefits of this approach was evaluated. The work over cost to replace the AL type against the costs due to failures and production loss was studied. It was concluded that this system provided the tangible cost benefit of around 30%, along with the uninterrupted production and conserving the heat energy in the reservoir. This method utilized the best combination of the performance features of SRP and PCP in their optimum operational brackets.
Considering the energy loses to the reservoir for a short period, which will be caused due to the work over rigs that utilize the cold mud fluids to replace the AL system or to clean the deposited sand which would cover the perforation, some design changes were made such as drilling the hole 1000 ft more than originally designed to maximize the production.
Interlinking Industrial Revolution 4.0 with Intelligent Field Cyber Security Protection
Authors: Almadi Soloman , AL-Khabbaz Fouad , AL-Askandrani Faisal 
Published: November 2018

Abstract
Cybersecurity is a fundamental element in the Industrial Revolution 4.0 (IR 4.0) due intercoupling of the safety, and the integrity of the Intelligent Field Operation Technology (IFOT) systems infrastructure in both the plant/fields system layers and the enterprise system layer. The rapid evolution from proprietary to open standards-based solutions has introduced major challenges in the cybersecurity domain. Intelligent Filed (IF) special purpose hardware and software is now increasingly moving to a common platform and from isolation to interconnection with the Enterprise networks and systems; resulting in seamless IFOT data flow. This evolution has resulted in growing and previously unforeseen cybersecurity threats. Therefore, a closer look is required to ensure cybersecurity is embedded into existing systems and is an integral part of workflows, policies, and the skillsets of the workforce.
In this paper, the authors share a critical review for the IFOT cybersecurity risk, available solutions, and the systematic approach in weaving cyber-protection into the end-to-end system. The outcomes result in actual enhancements by considering cybersecurity as an integral part of the overall IFOT. Best practice and guidelines improvements are also highlighted.
Research on Pump Efficiency of Sliding Vane Pump for Oil Recovery
Authors: Wang Shuolong , Wu Xiaodong , Han Guoqing , Zhang XiShun , Ren Zebin , Zhu Zhiyong , Tang Jingfei , Zhong Ziyao 
Published: November 2018

Abstract
Pump efficiency is an important indicator to reflect the utilization ratio and management level of pumping outfit. A reasonable theoretical model of pump efficiency is of great significance to improve lifting efficiency and optimize structure parameters of sliding vane pump. On the basis of the mechanical structure and working principle of SVP, the analytic model of volumetric efficiency is established from the perspective of leakage and degree of fullness respectively. The analytic model of mechanical efficiency for SVP is established considering viscous friction and contact friction. Based on the theoretical model, the influence of structural parameters (inlet/outlet opening angle,rotor-groove radius, vane number) of SVP on pump efficiency was analyzed. The research shows that the pump efficiency increases with the increase of opening angle, and with the increase of displacement, the difference of pump efficiency decreases.Meanwhile, the pump efficiency will increase with the rotor-groove radius and vane number decrease, so on the premise of meeting the requirements of pump weight and sand control, the rotor-groove radius and vane number should be as smaller as possible.
A 24/7 Surveillance Service Improves ESP Uptime in US Unconventional Reservoirs: A Case Study
Authors: Kutluev Denis , Quinzo Bravo Ma. Elena , Jasim Ahmed 
Published: November 2018

Abstract
Development of unconventional resources in the primary US basins helped the US increase oil production to where it is now one of the top two worldwide oil producing countries. The unconventional well production cycle is characterized by a comparably short natural flow period, and unconventional wells require artificial lift to continue production. Electric submersible pump (ESP) systems are used as first artificial lift system in the well life cycle in 36% of the US unconventional wells. Such use challenges ESP performance with gas, solids, and abrasives and other issues that negatively affect ESP run life and uptime.
A reliable solution to face those challenges is surveillance using real-time technologies with remote control capabilities. Artificial lift surveillance centers (ALSCs) provide 24/7 surveillance of all wells with ESPs as the artificial lift system to prevent or resolve ESP critical events. Reducing critical events in ESP operations helps reduce stress on ESP components and increases ESP reliability, but this requires timely intervention. Real-time interventions via remote control can eliminate the high-temperature, high-vibration, high-pressure, and high-electrical-load events that would otherwise lead to immediate equipment damage or premature failure.
This paper summarizes how an ALSC 24/7 service helped to increase uptime for an operator by using workflows for remote ESP analysis and control to spot critical events, which constituted 46% of 1026 events registered in the system for this operator. Remote intervention techniques, including a gas lock recovery feature, combined with global ESP well event classification and reporting workflows helped to identify every event and avoid ESP shutdowns, thus reducing deferred production and improving ESP performance.
Active collaboration of 24/7 ALSC personnel with the operator and field personnel reduced trips to the field, which directly reduced driving risk, one of the significant hazards in the oil industry.
IIoT Edge Analytics: Deploying Machine Learning at the Wellhead to Identify Rod Pump Failure
Authors: Boguslawski Bartosz , Boujonnier Matthieu , Bissuel-Beauvais Loryne , Saghir Fahd , Sharma Rajesh D. 
Published: November 2018

Abstract
Oil and Gas operators now have the possibility to collect and leverage significant amounts of data directly at the extremities of their production networks. Data combined with Industrial Internet of Things (IIoT) architecture is an opportunity to improve maintenance of assets, increase their up-time, reduce safety risks and optimize operational costs. However, to turn data into meaningful insights, Oil and Gas industry needs to fully take benefit of Machine Learning (ML) models which are able to consume real-time data and provide insights in isolated locations with scarce connectivity. These ML models need to be precise, robust and compatible with Edge computing capabilities.
This paper presents an analytics solution for rod pumps, capable of automated Dynagraph Card recognition at the wellhead leveraging an ensemble of ML models deployed at the Edge. The proposed solution does not require Internet connectivity to generate alarms and addresses confidentiality requirements of Oil and Gas industry. An overview of the employed ML models as well as the computing and communication infrastructure is given. We believe the given outline is insightful for the petroleum industry on its road to digitization and optimization of Artificial Lift systems.