bluuebunny/crossref_metadata_2025_split huggingface dataset:
Optimasi Holding Time Untuk Mendapatkan Kekerasan Baja S 45 C
Authors: Widodo Edi , Huda Miftahul 
Published: April 2017

Baja S 45 C merupakan bahan yang banyak dipakai menjadi berbagai bagian komponen mesin. Dengan luasnya penggunaan bahan, diperlukan karakter sesuai untuk mendapatkan fungsi maksimal dalam berbagai aplikasi perkakas. Perlakuan heat treatment yang tepat merupakan langkah dalam mendapatkan sifat mekanik yang diinginkan. Langkah penelitian, bahan specimen S 45 C diuji dan dipanaskan dengan temperature 850 0. Selanjutnya pendinginan cepat dengan media Oli SAE 90 pada wadah terbuka. Parameter waktu pendidinginan dilakukan untuk mendapatkan hasil yang berbeda dari nilai kekerasan yang diperoleh. Kekerasan bahan dicatat dengan alat uji kekerasan Brinell test. Dari hasil penelitian, grafik rata-rata hasil uji menunjukkan bahwa nilai kekerasan mulai berkurang dari holding time 10 menit, kemudian holding time 20 menit, dan kekerasan tertinggi diperoleh pada holding time 30 menit. Hal ini disebabkan pada waktu holding yang pendek pembentukan martensit terjadi belum sempurna. Disebabkan penurunan suhu terpotong pada menit ke sepuluh. Pada holding yang paling lama yaitu 30 menit memberikan waktu yang cukup dalam pembentukan struktur Kristal yang seragam dan lebih teratur.
Utilizando el análisis de ciclo de vida para el manejo sostenible de los residuos sólidos en Bogotá
Authors: Gómez Daniel 
Published: April 2017

ONTARE. REVISTA DE INVESTIGACIÓN DE LA FACULTAD DE INGENIERÍA
Este artículo abarca dos estrategias diferentes para que una ciudad como Bogotá, logre el manejo sostenible integral de residuos sólidos. No es un estado fácil de lograr, debido a que requiere tener en consideración condiciones ambientales, sociales y económicas. El Análisis del Ciclo de Vida (ACV) funciona como una herramienta para guiar a las personas que toman decisiones hacia una solución sostenible. El ACV se utilizó para analizar el manejo de los residuos sólidos en Bogotá y se presentan dos escenarios específicos: la destrucción térmica del biogás del relleno sanitario y la introducción de un nuevo esquema de reciclaje basado en la separación desde la fuente. Los resultados del análisis realizado por Gómez (2004), muestran que aunque el potencial de calentamiento global se debe al impacto del biogás emitido, la toxicidad persistente es ocasionada en mayor grado, por la perspectiva de la sostenibilidad. Para el caso del esquema de reciclaje, los resultados muestran que los recuperadores o recicladores, necesitan participar activamente en el nuevo esquema, con el fin de reducir los posibles impactos y mejorar la aceptación social del proyecto.
Leveraging ESP Energy Efficiency with Permanent Magnet Motors
Authors: Harris Dennis , English Jack , Leemasawatdigul Jackris 
Published: April 2017

Abstract
The induction motor has dominated the global ESP market for decades; however permanent magnet motors (PMM) are gaining acceptance for use in artificial lift. Some PMM vendors have made claims of 20% - 30% reduction in electric operating costs, improved efficiency, and wider applications for today's challenging wells. This paper describes a testing program conducted to understand the characteristics of PMM's, to verify vendor claims and evaluate how to leverage this downhole motor technology to reduce operating expenses.
Two International Oil Companies (IOC's) partnered to sponsor a Motor Evaluation Test (MET) program from 2014 - 2015. A motor test protocol was drafted, and ESP motor sizes of 100 HP 450 series were targeted for evaluation. Six ESP vendors agreed to participate, contributing their motor and variable frequency drives (VFD). Four induction motors and four permanent magnet motors, each partnered with the vendor supplied VFD, were evaluated. The objective of the testing was not to differentiate the vendor's products, but to understand the differences in the motor technologies. An independent third-party witness was selected from industry experts to supervise the testing, ensuring to follow the test protocols, manage data security, and test validation. The results were analyzed, documented and reported to vendors by the sponsor companies.
The PMM was found to be a cost competitive alternative to the IM for equivalent ESP installations with a VFD. In existing fields, a phased-in approach to replace failed IM with PMM may be economic. For new field developments the PMM offers the benefits of power savings and use in challenging well bore configurations. Alternatively deployed (AD) ESP with PMM may offer reduced well intervention cost as well an improved ability to pass through build angles that would challenge the longer IM system.
Brazil Field Experience of ESP Performance with Viscous Emulsions and High Gas Using Multi-Vane Pump MVP and High Power ESPs
Authors: Barrios Lissett , Rojas Marisela , Monteiro Guilherme , Sleight Neil 
Published: April 2017

Abstract
This paper provides field experience for the Caisson ESP Technology in subsea boosting system with emulsions and high Gas Volumen Fraction (GVF) using the high power Electric Submersible Pumps (ESPs) systems. Field experience and experimental performance are compared regarding the effects of high viscous emulsion using conventional high capacity ESP systems and the effect of two phase (liquid & gas) fluids on ESP with new technology for high GVF fields and high viscous applications.
The Electrical Submersible Pump (ESP) system is an important artificial lift method commonly used for subsea boosting systems. Multiphase flow and viscous fluids cause problems in pump applications. Free gas inside an ESP causes many operational problems such as loss of pump performance or gas lock condition. The objective of this paper is to understand MVP performance for high GVF and viscous emulsions.
This paper provides a summary on the performance comparison for a high power ESP system for viscous emulsions and Multi-Vane Pump (MVP) for high GVF wells for Shell major Projects BC-10. These novel projects continue the long tradition of Shell’s leadership in the challenging deepwater environment. Presented is the capability and effects of viscosity and two phase (liquid & gas) fluids using a 1025 series pumps with a charge MVP in series; as well as a 875 series standard ESP system mixed-type pump, which is a multistage centrifugal pumps for deep boreholes.
Extensive testing and qualification of the subsea boosting system was undertaken prior to field application. The subsea boosting system experience for offshore operations is reported with new technology, and the effects of viscosity and two phases in real conditions. MVP and high power pumps were proved to be a reliable technology to use in field application managing GVF higher than 50% and high viscous fluid as high as 1200cp as consequence of fluid emulsion. Correction factors needed to be applied to standard design curves to ensure proper field design at opearting conditions.
Full-Scale Investigation of Gas-Handling Capabilities of High-Flow Helicoaxial ESP Stages for Deepwater Application
Authors: Rojas Marisela , Barrios Lissett , Cheah Kean Wee , Harris Grant 
Published: April 2017

Abstract
Caisson-ESP systems provide a cost-effective means of seafloor boosting. These systems are being applied in applications that requires the ESP to handle unusually higher gas fractions. The objective of this work is to investigate the gas-handling effectiveness of helicoaxial ESP stages used in combination with standard mixed flow pump stages. The results show that helicoaxial stages greatly extend the gas-handling capabilities of an ESP system and eliminate gas-lock over a wide range of conditions.
It is well known that high gas fractions and viscous fluids degrade centrifugal pump performance. Additionally, gas locking occurs due to gas entrainment inside the pump causing operational problems. This study investigated the use of 4 helicoaxial pump stages at the entrance of a 48-stage ESP. Testing was performed at the Shell Gasmer Caisson-ESP Facility in Houston, Texas. This full-scale test loop can test ESP's over a wide range of conditions. The test matrix covered viscosities from 2 to 300 cp at different speeds, flow rates, intake pressures and gas volume fractions (GVF).
Multiphase flow and viscosities affect the performance of the ESP pump system, degrading pump performance. The test results demonstrate that the high-flow helicoaxial pump can handle up to 73% GVF without gas lock. Pump performance improves at higher intake pressures and pump speeds with less pump degradation. In two-phase flow conditions, as viscosity increases, the pump degradation decreases thus improving gas-handling operations. A homogeneous model has a fairly good agreement with pump performance up to 30% GVF with minimal pump degradation.
This work provides an important field-scale validation of the helicoaxial pump hydraulic performance at high GVF with high viscosity fluids. This has benefits to the deep-water industry, which is seeking more affordable seafloor boosting options.
Well Control Strategy for ESP Rigless Deployment with Power Cable
Authors: Xiao J. J. , Roth Brian , Lastra Rafael , Sarawaq Yahya 
Published: April 2017

Abstract
As the use of electric submersible pumps (ESPs) increases in critical production operations, i.e., offshore and high production wells, the need for more efficient systems to replace the traditional jointed pipe installation and retrieval process becomes more relevant. Methods such as coiled tubing (CT) and wireline deployment have been used in the past with varying degrees of success and deployment with power cable is making its way into mainstream ESP applications. All alternative ESP deployment methods face issues when it comes to wellbore control, especially in applications where ESPs are installed to boost production in naturally flowing wells. This paper examines well control challenges associated with cable deployed ESP (CDESP) installation and retrieval, and provides strategies to carry out these operations safely.
Careful review of current ESP change out operations with workover rigs leads to the development of an equivalent well control strategy for rigless CDESPs. Well permanent completion design, the required components on the blowout preventer's (BOP) stack, and deployment and retrieval procedures are established. This strategy eliminates the use of expensive and duplicative well control barriers with no operational safety being compromised.
Moving from workover rig-based ESP change out to through tubing rigless operation is a major undertaking with many challenges of which well control is a key element. This paper provides a comprehensive review of all relevant issues and presents a practical strategy to ensure safe and economical field operations.
Achieving A 10-Year ESP Run Life
Authors: Lastra Rafael 
Published: April 2017

Abstract
Over the last few decades numerous improvements have been made on electrical submersible pump (ESP) components, however, ESP reliability has just marginally increased. Operators have tried different approaches to incentivize ESP vendors to improve ESP reliability, including: strategic alliances, rental agreements, performance based contracts, just to name just a few. None of these approaches seem to have worked and the high reliability goal remains elusive. ESP failures have important economic implications for oil and gas operators, including nonproductive time (NPT), production deferral, production losses and the high cost of ESP replacements, especially for offshore or remote wells. Saudi Aramco has set an aggressive target of operating ESPs an average of 10 years without failure. This paper explores the likelihood of developing such an ESP system, it discusses the fundamental issues that currently prevent achieving higher reliability levels and also evaluates from different angles the potential solutions for approaching the reliability improvement challenge. Finally, it discusses the technical, operational, economic and market implications of such alternatives for both oil and gas operators and ESP vendors.
Maximizing Production in High Gas Wells with Electrical Submersible Pumps Utilizing Variable Speed Drives with Intelligent Gas Control Software: Case History in Colombia
Authors: Chira J. , Diaz A. , Gonzalez C. , Rodriguez B. , Serrano H. , Prada J. 
Published: April 2017

Abstract
Maximizing production in high gas wells produced with Artificial Lift Systems is one of the greatest challenges operators face daily. The accumulation of gas inside an Electrical Submersible Pump (ESP) creates a condition called "Gas Locking" which prevents fluid production and leads to system shutdown. Multiple shutdowns and frequent Gas Locking negatively affect the runlife and profitability of ESP systems. However, the impact of gas accumulation in ESP applications can be mitigated by implementing intelligent frequency control software included in Variable Speed Drives (VSD's) specifically designed to control and protect ESP's.
Baker Hughes has designed an intelligent solution to solve the problems caused by gas locking in ESP systems: a variable speed drive with built-in gas control software that can mitigate and clear gas locking, manage draw down to minimize formation face damage, and avoid gas locking during extended gas slugs to improve production.
This paper will present the results of the variable speed drive's gas control software implementation in a high gas well in Colombia. The case history presents a mature well with water injection secondary recovery operated by Ecopetrol in partnership with OXY. The ESP system operation was monitored before and after the VSD's gas control software activation. The following significant benefits in ESP reliability and increased production were achieved: 14% daily production increase, stable operation, lower operating downhole temperatures with no high temperature events, lower pump intake pressure (decrease of 170 PSI) and zero system shutdowns due to gas locking.
Comparative Project Economics: Wireline Retrievable ESP WRESP vs. Conventional ESP Systems
Authors: Malone David , Olabinjo Lanre , Vierkandt Steven , Patterson John 
Published: April 2017

Abstract
Electric Submersible Pumps (ESPs) are complex, high power electromechanical systems that operate in extreme environments under very tight geometric constraints. Despite the efforts of suppliers and operators ESPs will eventually fail, requiring replacement. In addition, it is sometimes necessary to intervene in a well to optimize or remediate production – a process not possible, or limited, with an ESP restricting access to the reservoir or lower completion.
The process of installing or removing an ESP has changed little since their introduction almost 90 years ago. Removing (or installing) a conventional ESP requires pulling the tubing string, replacing the ESP and reinstalling the tubing string with the use of a rig or pulling unit (a "heavy workover" or HWO). This expensive, time consuming process creates significant logistical challenges and QHSE risks along with significant lost production.
Increasing use of ESPs, along with today's difficult economic environment has brought a renewed interest in the potential of alternatively deployed ("rigless") ESP systems to improve project economics by reducing the cost of interventions while simultaneously increasing the oil produced per well.
Evaluation of the economics associated with alternative deployed systems is not straightforward, with many nuances which are not obvious. This paper seeks to develop a framework which can be used to compare the economics of wireline retrievable ESP systems (WRESP) to conventional, tubing deployed ESP systems, taking into account the uncertainties surrounding the reliability of the various system components (both conventional ESP and WRESP) through the use of Monte Carlo simulation.
This framework will be used to compare the likely economic outcomes in six ‘typical’ operating environments: West Africa Offshore, Middle East Land (high rate and moderate rate), Asia Offshore, Alaska, and US Land (lower 48) using (to the greatest extent possible) actual reliability data and operating parameters in these environments. The production and economic outcomes of both conventional ESP and WRESP deployments will be compared and presented along with the sensitivity of these outcomes to typical uncertainties in each of these environments.
Subsea Boosting with ESP's in High-Gas Environments - Full-Scale Prototype Testing Demonstrates Full Capability of New, Low-Cost System
Authors: Portman L. N. , Stibbe H. C. , Homstvedt G. O. , Farias M. 
Published: April 2017

Abstract
This paper describes the full-scale testing conducted on a new, step-change subsea boosting system that pairs an in-well electrical submersible pump (ESP) with a mini-processing plant.
A typical subsea boosting application is demanding for several reasons, perhaps most importantly being higher free-gas fractions, and the potential for variable or slugging flow that is often associated with aging wells. The new system as tested, demonstrates how a near-standard ESP can be operated in such high-gas environments within a mechanical embodiment that is compact, easy to deploy and to redeploy should the original ESP no longer meet the boost requirements. This paper lists the tests conducted and the results obtained regarding the operational, electrical and control performance, the vibration response and finally the ease of assembly.
Eliminating Gas Lift by Directly Converting SAGD Wells with High-Temperature ESPs
Authors: Shang Song , Caridad Jose 
Published: April 2017

Abstract
Gas lift (GL) and electrical submersible pump (ESP) are the two main artificial lift (AL) methods in the steam-assisted gravity drainage (SAGD) process. GL has been used for high-pressure SAGD processes effectively while the ESP has been used in low-pressure processes. There is considerable interest to convert SAGD wells directly into ESP lift during the startup or ramp-up phases, eliminating the GL process traditionally used in the high-pressure SAGD period for injection pressure from 3500 to 4500 kPa and bottomhole operating temperature exceeding 220°C, and using one artificial lift method for the entire SAGD production cycle. In 2011, the 250°C rated high-temperature ESP was introduced, and more than 90 SAGD wells from Athabasca formation have been converted directly to ESP since then. In this paper well production and injection data were analyzed in order to evaluate the key performance indicators (KPIs) including well oil and water production, steam-to-oil ratio (SOR), ESP production performance, and ESP reliability between the 250°C ESP in direct-to-ESP (DTE) wells and 250°C ESP in all SAGD wells.
Advanced Electric Submersible Pumps – Added Value for Offshore Fields
Authors: Marra Francesco , Girard Cyril 
Published: April 2017

Abstract
The application of Electric Submersible Pumps to facilitate well production is a long established production technology; however, the onerous requirements of offshore environment makes the current ESP technology and the associated business model not fit to meet these challenges. An enabling technology for those deep water fields, where physical constraints of gas lift starts to be very challenging and for a drastic improvement of reliability in exisiting offshore fields, is what is needed. A Statoil development for a high speed ESP (AESP) is ongoing to primarily re-design the current machinery arrangements so that many of the key failure modes are eliminated and to tailor the design to high value wells, using an engineered approach.
The AESP development focuses on 6000 rpm high speed motor and pump technologies, introduces a seal-less coupling between pump and motor, to build a robust artificial lift system.
The goal is to develop an ESP system with 90% survival probability at 5 years.
Extending ESP Run Life in Gassy Wells Application
Authors: Kadio-Morokro Benedicte , Curay Franklin , Fernandez Juan , Salazar Victor 
Published: April 2017

Abstract
The Electrical Submersible Pump (ESP) technology has dramatically evolved not only to cover wider inflow ranges but also to deal with abrupt gas conditions observed into unconventional applications. Gas production increment through the life of the well can cause multiple intermittent shutdowns which will constrain the overall well's production and eventually shorten the run life of the ESP. Therefore in order to avoid costly interventions and deferred production, it is fundamental to have the proper gas handling system sized since the beginning of the well's life.
This material will encompass different cases which occurred in the Permian Basin area; (1) Tapered system with gas handling stages deployed in new drill wells with gas' increment observed through the life of the well (2) Tapered system with multi-vane pump installed in existing producing wells with high gas level, low production and low pump intake pressure (3) Encapsulated system in wells with high and repetitive gas slugs conditions.
The present study describes performance of different scenarios in gassy wells and technologies applied to stabilize the challenging conditions; the benefits are demonstrated through those case histories. The primary goals of those applied technologies are to reduce or even avoid gas interference with the pump. As a result of reducing or eliminating cycling conditions due to gas, non-productive time was able to get reduced, production rate maintained and the run life of the wells extended successfully. A daily monitoring system is also a further help to achieve those goals.
The use of ESPs have been increasing through the years, especially in the unconventional market. Therefore, it is crucial to provide new technologies as solution to tackle those challenging conditions.
Data uncertainty is a well-known and common challenge regarding an ESP systems'design, observed mainly in new wells, but specifically in unconventional reservoirs. Unconventional reservoirs can be defined in many different ways, but in this study we will limit that definition on horizontal wells that have a rapid production declination curve but also tremendous gas increment through the life of the wells. Running a cost-efficient equipment is a must. Most of the new drills' population have been traced in those reservoirs.