bluuebunny/crossref_metadata_2025_split huggingface dataset:
Improvement of PCP's Run Life in Highly Deviated and Tortuous Wells Using Novel Design in Rod Strings: A Case of Study
Authors: Castillo Ivan Camilo , Valderrama Jasmine , Godoy Fernando 
Published: November 2018

Abstract
In this paper, the experiences of the use of a novel rod string design to improve the Run Life of the PCP system in highly deviated and tortuous wells are shared. These wells presented premature and recurrent failures in the rod string. The results are contrasted with real cases in the same wells where the conventional and continuous rods failed in a brief period.
Through a detailed RCFA (Root Cause Failure Analysis), it was determined that the main failure mechanism was due to fatigue in high DogLeg areas. To solve this problem, design simulations were carried out, by locating hollow rods in these zones and applying the Von Misses method to determine the effective stress due to torque and axial load, comparing these values with previous designs.
The hollow rod geometry allows for a greater polar moment of inertia, which causes the effective stress to be lower in high DogLeg points, making the string more resistant to axial and torsional stresses. The comparison was made between two widely used types of rods in two wells of a Colombian Field, with angles up to 50 degrees and DLS of 7.8° / 100 ft. The major benefit of the implementation of this design is that it managed to raise average run life from 45 days to 180 days, without presenting failure in the rod string.
This study is important because operating companies must reduce operating expense (OPEX) by optimizing the components in artificial lift systems, like the rod string in PCP, minimizing the frequencies of well interventions.
The methodology and design presented in the article can be replicated for other wells that have similar geometries and operating conditions to those of the explained cases, with the application of hollow rods as an alternative to conventional designs.
Real-Time Remote Monitoring to Enhance Electrical Submersible Pump System Run Life and Maximize Production
Authors: El Mahbes Reda , Manfoumbi Wilfried , Kadio-Morokro Benedicte 
Published: November 2018

Abstract
The advent of US unconventional completion presents new challenges for electrical submersible pump (ESP) systems. Rapid production decline from fractured unconventional wells, solid production, and high amount of gas are considered the main challenges for ESP system performance and longevity. In addition to production decline and high free gas, unconventional wells introduce scale, gas slugs, and solids. Consequently, it is important to monitor ESP systems to optimize performance, to detect anomalies, and prevent potential failure. This paper discusses multiple case histories where real-time remote monitoring was deployed to overcome unconventional wells challenges.
Real-time ESP monitoring uses downhole and surface data such as pressure, temperature, vibration, production data, motor load, and many other parameters to monitor the system performance. The data are stored in several servers and interfaced in real time with production engineers or production analysts through a web browser for analysis, optimization, and diagnosis of any potential failures. Monitoring helps to identify opportunities for maximizing accumulated oil production and reducing ESP system downtime. Remote monitoring provides analysts with access to the well for remote ESP optimization that significantly reduces the number of ESP shutdowns and decreases HSE incidents related to field trips and interfacing with surface units.
This paper presents a comparison between ESP performance before and after remotely adjusting the operation parameters using the monitoring system. The result shows how real-time monitoring system improved ESP system run life and maximized oil production. In addition, we look into details how the monitoring system enhances overall ESP efficiency and reduces the number of trips to the wellsite to adjust the operation parameters. ESP monitoring provides the operator with a good indication of issues related to scale, paraffin, asphaltenes, or system plugging to start chemical treatment promptly. In addition, this paper discuss how remotely modifying the ESP variable-speed drive (VSD) operating mode reduced ESP repeated shutdowns due to possible gas interference.
Sucker Rod Pumping System Optimisation Based on a Novel Finite Elements Analysis
Authors: Clemens Langbauer 
Published: November 2018

Abstract
The increase in global oil consumption in combination with low to moderate oil prices pushes the demand for cost efficient production in mature oil fields, which often employ any artificial lift system. The reduction of lifting costs by increasing efficiency is essential for extending the mean time between failure (MTBF), the recovery factor of the reservoir and the increase of the economic limit.
These goals can be achieved by applying a novel Finite Elements Method (FEM) for modeling and analyzing the behavior of the sucker rod string and the installed completion. These results are the basis for an optimization of the whole pumping system. Not just the subsurface components are considered, but also the surface pump jack is incorporated as well. The evaluation of the performance of existing units is performed by applying a diagnostic analysis. Also, a predictive analysis to optimize the performance and to design new pumping systems, represent the main targets.
This paper presents the capabilities and the concept employed for analyzing the sucker rod pumping system, based on the results of the sucker rod string FEM – simulation, including surface pump jack features and downhole pump characteristics. The model and the simulation results are verified on the one hand by a comparison with downhole dynamometer measurements, obtained by several self-developed DDS (Downhole Dynamometer Sensor) during field tests and on the other hand by tests at the Pump Testing Facility (PTF) at the Montanuniversität Leoben. The accuracy of the used simulation routine surpasses all currently available commercial software products and also allows the highest flexibility in terms of sucker rod string composition, operation conditions, fluid conditions and the choice of installed equipment.
A comparison conducted on the efficiency and performance of a standard sucker rod pumping system design and an optimized sucker rod pumping system design resulted beside rod string load reductions in the increased energy efficiency of more than 30%.
The Application of Big Data Analysis in the Optimizing and Selecting Artificial Lift Methods
Authors: Shi Junfeng , Han Qiqing , Ren Xianghui , Zhang Xishun , Zhao Ruidong , Chen Shiwen , Li Qiming , Zheng Xiaoxiong 
Published: November 2018

Abstract
A reasonable method of artificial lift is the guarantee of efficient production of mechanical producing wells during the whole life cycle, however, there are many factors affecting the choice of artificial lift methods and most factors cannot be described with mathematical model. As a result, artificial lift method selecting mainly depends on expert experiences, and incorrect decision will lead to huge economic loss. In China, there are a large number of mechanical producing wells, and the large amount of data generated by artificial lift is of great value, which contains the adaptability of different types of oil wells to different artificial lift methods. This paper selects 11 parameters, such as well reservoir properties, maximum fluid production, well trajectory, pump depth, production gas oil ratio, pump inspection period, and production maintenance frequency as influence factors. The total data of 30,000 Wells of CNPC was initially selected as the big data analysis sample. An effect evaluation function is established taking pump efficiency, power consumption with lifting per ton liquid 100m, annual operating maintenance cost into account, then the oil well samples is selected further according the value of effect evaluation function, which will participate in machine learning. The paper present a neural network model based on deep reinforcement learning here, which can select the optimal artificial lift method by using influence factors and effect evaluation function. This model uses strategy gradient algorithm to train the samples. Experimental results show that the neural network model has fast convergence and high prediction accuracy. With the application of this model, artificial lift method selecting and effect analysis have been conducted for more than 4,000 oil wells of CNPC with different reservoir characteristics, different wellbore structures, and different fluid characteristics. The coincidence rate between calculation results of this model and actual production situation is 88.43%. Big data analysis provides a reliable, practical and intelligent method for optimizing and selecting artificial lift.
Towards a Fully Automated Well Management System for ESP Surveillance and Optimization in PDO
Authors: Kulkarni Rahul , Al-Bimani Atika , Marin Antonio Andrade , Awaid Abdullah , Balushi Issa , Al-Busaidy Salim , Al-Murad Mohammed , Kumar Nitish , Gala Rahul , Marin Eduardo 
Published: November 2018

Abstract

Objective/Scope
Achieve operational excellence in field of Electrical Submersible Pump (ESP) surveillance and optimization by benefitting Petroleum Development Oman (PDO) asset teams in identifying optimization opportunities, use of real time data for well test validation and improving overall asset KPIs (Key Performance Indicator) through a fully automated Well Management System (WMS).

Methods, Procedures and Process
The ESP well models are built and sustained in WMS by automated processes to update recent well model information from PDO corporate databases.
WMS provides real time well and pump information, along with well model based calculated outputs, pump operational status, workbenches to validate well tests, design inputs, modeling sensitivities for users to perform daily tasks using well-defined standard operating procedures.
Operating envelopes based Exception Based Surveillance (EBS) were improved by replacing them with pattern recognition based EBS to improve accuracy, avoid wastage of time and resources. Continuous hands on coaching were conducted to users to strengthen their skills.

Benefits, Results, Observations, Conclusions
Since implementation of WMS, it has maintained more than 1600 ESP well by building well models automatically for new or workover ESP wells successfully saving huge effort and time from engineers in gathering data and building model.
Production Engineers have created more than 100 ESP design input datasheet using the WMS resulting in improved ESP design by avoiding human errors.
WMS have already supported assets in identifying around 138 ESP wells with optimization opportunity resulting in increasing around 3 % net oil gain only in year 2017.
Real time pump operational status calculation from WMS and sensitivity (Tubing Head Pressure and Hz) based operating point analysis reduced upthrust / downthrust ESP wells by ~50% across PDO in few months.
Early detection through Pattern Recognition based EBS has resulted in minimizing ESP downtime by around 30% through quick realization of sub-optimum wells.
Validating well tests utilizing downhole gauge data has helped in identifying dubious well tests because of faulty well test equipments thus saving time and money for sequencing the well for re-test and improving allocation.
A proper tool and SOPs utilization tracking mechanism is already in place highlighting areas for continuous improvement.

Novel Ideas
The utilization of real time data and well model together has proven to be a unique and novel way in improving ESP surveillance and optimization for managing around 1600 wells.
The replication of same methodology is already undertaken for Progressive Cavity Pump (PCP) and Beam Pump (BP) surveillance and optimization utilizing WMS for PDO assets.
Design Tolerance of Artificial Lifting of High Productivity Wells; What Makes it Fail?
Authors: Qahtani Abdullah Al , Qahtani Bader Al 
Published: November 2018

AbstractUncertainties in design considerations are usually attributed to unknown data in new wells, or unknown conditions from using the wrong model of calculation. This issue is exacerbated in extended, undulated horizontal wells, drilled in high productivity formations, with multiphase flow and experiencing transient flow, where the drilled wellbore is assumed fully contributing to flow while it is not. In addition, well productivity along the producing section will change with the onset of water or gas production. Additionally, multiphase flow through artificial lift systems, like ESP's, have been a challenge.This paper presents analytical solutions for calculating the productivity index of extended reach wells lifted with electric submersible pumps. In addition, it presents examples of design tolerance calculations of artificial lifting in high productivity horizontal wells with lower productivity indices than expected. In furthermore, it manifests the compounded effect of inherent errors in classical pressure traverse calculations typically used to design artificial lifting. More importantly, it quantity the amount of performance degradation attributed to the wrong design attributes/calculations, and shows how much tolerance available before premature failures occur. Calculations show that inaccurate well productivity data for wells, that are assumed highly productive, could make pumps fail to design incompatibility and make pumps run beyond efficient envelope.
Gas Lifted and Naturally Flowing Wells Exception Process via GIS - A State of the Art Surveillance Process
Authors: Nooraldeen Yasser , Derbas Zainab , Zainal Yousif , Esbai Rami , AlQassab Khalil , Alkooheji Hamza , Almal Mohamed , Bandla Kranthi , AlNowakhda Ali , Samineni Sreeharshan 
Published: November 2018

Abstract
In today's world of increased automation and large data, Geographical Information Systems ("GIS") technology has been proven to be a useful component in the oil industry. Through the integration of GIS with critical production engineering and oil wells operations, a prime example of such uses have been realised at Tatweer Petroleum ("Tatweer"). Real-time data streaming from the Bahrain Field ("Bahrain Field" or "Field") has been integrated with GIS to deliver an advanced insight into the production environment leading to profound improvements in control and operation.
The GIS, Information Technology, and the Production Engineering teams at Tatweer collaborated to develop a unique application to highlight operations awareness of critical operational events using real-time streaming data imposed on a spatial map.Surveillance and Control of Operation Production Environment ("SCOPE") is a pilot application covering specific traits related to Tatweer's producing wells which focuses on seven traits - (alarms for events such as High Flowline Pressure, Dead Wells, Shut-ins, Transmitters Errors, etc.)
SCOPE is an application that was developed by using available tools by focusing on integrating and complementing existing applications and data sources. SCOPE is developed using GIS and real-time data management software which replicates the Bahrain field information on SCOPE within one (1) minute, focusing at well level as Iconics stop at facilities (i.e. Tank Battery/ Well Manifold) and obtaining data from different sources to one dashboard screen. Anomalies can be detected as cluster events, analyzing data to indicate post-events and pre-event and provides a decision tool to acknowledge and take action for particular problematic wells, and measures their efficiency (Key Performance Indicators).
It's Raining Barrels: Cloud Computing in the O&G Industry
Authors: Kumar Arvind , Dutt Ankit , Nahar Siddhartha , Batshas Siddhanta , Majumdar Chandan , Saraiya Rasesh , Sarkar Subhadeep , Chatterjee Chandreyi 
Published: November 2018

Abstract
Cloud computing has become the buzz word in the last few years. All the service industries from different fields are using cloud computing based data analytics to optimize their operations in order to improve the customer user experiences and the overall efficiency. It is mainly due to the use of high volume computing backed by significant development in advanced hardware capabilities. This paper describes the ‘what’, ‘why’ and ‘how’ based questions on cloud computing. To start with, a brief introduction of cloud computing has been discussed along with the history of computation usage in oil industry. Followed by that a brief introduction highlighting the significance of Artificial intelligence and machine learning in the current computing environment has been explained. As the industry moves towards more and more usage of digital oilfield techniques, the dominance of high end computing and data analytics in the oil and gas industry is also showcased. Once cloud computing is established as a standard, the paper further discusses different modes of cloud delivery service models- Infrastructure as a service (IaaS), Platform as a service (PaaS) and Software as a Service (SaaS). The paper also identifies the challenges and concerns/issues that comes as a part of cloud computing methodology and then describes how these all challenges are being addresses. This paper elucidates the comprehensive view of the cloud computing landscape in oil and gas arena through a review of available noteworthy open source literature
Special Implementation of SRP in Failed Existing Artificial Lift System
Authors: Pandit Akchaylal , Najaf Abdulaziz , Al-Dahash Sulaiman , Al-Salem Fajer 
Published: November 2018

Abstract
The robust construction, ease of operation and maintenance of Sucker Rod Pump (SRP) is a stand-alone artificial lift method owning mostly to its simplicity. SRP are widely used positive displacement pump in land and offshore oilfield applications for lifting of heavy, medium or light oil with gas and water. In this paper, one such implementation of SRP is discussed which are simulated for rigless installation with insert anchor in existing failed artificial lift system.
The failure of existing artificial lift system such as PCP, ESP or even SRP itself. Causes loss of cumulative production of the asset and thus economic disadvantage. The scheduling of rig to carry replacement based on oil priority further effects this interval which are generally overlooked. In this paper, implementation of SRP in such existing failed artificial lift system is discussed, carried rigless using insert anchor pump. Thus continuation of maintenance of asset production even after failure of artificial lift system. Such rigless installation opens window preferably of installations carried in wells with lower than expected productivity index. Which may have caused the existing system failure due to operation not being in the pumping range. In this paper, firstly simulation is carried as per the well test of recent failed artificial lift system for maximum production rate with maximum plunger size of the existing tubing size for insert anchor and flowing bottom hole pressure (FBHP). Secondly, rigless installation with economic advantage in comparison to installation with rig is discussed. Thirdly, the successful completion of installing SRP in 3 ½" tubing rigless is discussed with various existing failed artificial lift system. The paper evaluates for design and installation of artificial lift method of SRP through rigless flush-by unit with schematics in failed existing artificial lift system.
Generally, with passage of time the formation productivity index drops due to various reasons. Thus the added advantage of resetting the pump at any depth along the production tubing, assists further in the location for minimum free gas percentage and hence extended run life, based on actual well test data and fluid level survey.
The comparative results between the existing and new installation remain as a database for advantage in scheduling of rigless installation for optimum production. The design results are extensively discussed with schematics for effective rod stress, torque, rod and surface unit loading for a range of production rate.
Performance indicators for urban storm water systems: a review
Authors: Santos Liliana Ferreira , Galvão Ana Fonseca , Cardoso Maria Adriana 
Published: November 2018

Abstract
Over the past two decades, performance assessment based on performance indicators (PI) has been one of the areas showing the greatest advancement in the water sector. This practice may be defined as any approach that aims to measure effectiveness and/or efficiency of an activity or process using PI, supporting the decision-making process and encouraging the continuous improvement of a water utility. Despite the potential benefits, few projects and initiatives of performance assessment based on PI have been undertaken regarding storm water systems. The present article aims to review studies that have been carried out in the area to provide a state of the art on the subject, understand the applicability of the existing methodologies and their limitations, and to point out future directions. The review revealed that most of the research works were of limited scope, focusing on single storm water systems or some specific aspects of their performance, and also gave an inappropriate definition and selection of PI, compromising their further application. The identified gaps emphasise the need for a new methodology to provide a reference framework in the field. Such methodology should be objective, standardised and well-adapted to different contexts, driven by objectives and criteria and based on PI and targets.
Characteristic MRI Findings of Epidermal Cysts Categorized by Size
Authors: Sakamoto Akio , Okamoto Takeshi , Matsuda Shuichi 
Published: November 2018

Background:

Epidermal cysts are lined with stratified squamous epithelium and filled with keratinous material.Magnetic resonance imaging (MRI) findings can be used for the diagnosis of epidermal cysts, but characteristic MRI findings related to cyst size in particular go unreported.

Objective:
To analyse characteristic MRI findings of epidermal cysts categorized by size.

Materials and Methods:

Unruptured epidermal cyst cases were analyzed according to 3 cyst size categories: large (≥4 cm), medium (≥2 to <4 cm), and small (<2 cm). MRI assessments focused on the keratinized material using low signal intensity on T2-weighted images because of intracystic diffuse foci (a sign of intracyst debris) and serpentine structures at the periphery (a sign of a peripheral lining) of cysts.

Results:
Thirty-three patients (26 males and 7 females; average age, 52.2 years; 33 cases) were grouped by cyst size: large (13 cases), medium (12 cases), and small (8 cases). MRIs revealed cyst walls via low signal intensity on T1- and T2-weighted images. On T1-weighted images, the signal intensity of cysts relative to that of muscle was hypointense (1 case, 3%), isointense (4 cases,12%), and slightly hyperintense (28 cases, 85%). On T2-weighted images, cysts were hyperintense in muscle relative to adipose tissue (20/33 cases, 61%) and isointense relative to adipose tissue (7/33, 21%) or hyperintense relative to adipose tissue (6/33, 18%). Overall, signal patterns were similar among groups. Signs of inner debris were observed in all large (13, 100%) and medium (2/12, 17%) cysts, but not in small cysts (0/8). Large, medium, and small cysts had signs of peripheral linings (12/13, 92%; 9/12, 75%; and 4/8, 50%, respectively).

Conclusion:
Slightly hyperintense signals on T1-weighted images were characteristic, even in small epidermal cysts. Signs of intracyst debris and a peripheral lining reflect the pathology and were considered useful for diagnosis. Larger cysts were more frequently positive for keratinous debris.