bluuebunny/crossref_metadata_2025_split huggingface dataset:
From Challenges to Solutions: An Innovative Approach to Rod Lift Installation in Difficult Well Conditions
Authors: Cepeda F. A. , Zahran A. M. , Alsayed M. , Setiadi B. W. , Taha S. M. 
Published: October 2024

Abstract
The deployment of artificial lift systems is fundamental in extending the productive lifespan of unconventional fields. Rod lift systems, among the most prevalent artificial lift mechanisms, typically follow standardized deployment procedures globally. However, unique challenges in certain wells necessitate deviations from conventional practices. This paper describes the design, planning, and execution strategies employed in the successful deployment of continuous rod lift systems under challenging well conditions, while also disseminating lessons learned to refine future procedures. Rod lift pumping, a basis of artificial lift methodologies, symbolizes the oil industry with its conventional surface units. Despite its widespread application, introducing this technology in certain environments presents novel challenges due to unique well conditions, rigorous safety regulations, and pre-established operational standards. Adverse conditions such as high concentrations of hydrogen sulfide and significant gas-liquid ratios, compounded by internal safety and operational mandates, pose substantial complications in the installation of rod lift systems, whether standard sucker rods or continuous rods. A novel deployment strategy, integrating custom-designed pressure control equipment stack, was developed to navigate these obstacles effectively, ensuring safe and efficient well completion. An extensive period of discussion on overcoming the multifaceted challenges of well conditions, followed by a meticulous equipment selection and procurement phase, culminated in the successful deployment of the Rod Lift system under full pressure containment. This breakthrough has laid the groundwork for subsequent installations, signifying a crucial advancement in the artificial lift program. The innovative aspect of this procedure is its adaptation to complex well conditions within a shale play, marking a significant departure from traditional artificial lift system implementations. The insights gleaned from this endeavor offer valuable guidance for future rod lift system deployments in the under same challenging conditions.
Improved Process for ESP Dismantle, Inspection and Failure Analysis (DIFA)
Authors: Pessoa R. F. , Alsaif A. , Al-khalifa M. , Elbarkatawy A. 
Published: October 2024

Abstract
Dismantle, Inspection and Failure Analysis (DIFA) of Electrical Submersible Pumps (ESP) has driven operating companies as one of their key improvement factors for ESP run life. In this paper, an improved process and lessons learned of DIFA over 25 years will be presented.
Establishing failure mode, as per API RP 11S1 guideline, ensures the ESP DIFA is conducted in a structured and methodical manner. Generally, during DIFA three key pieces of information are considered, i.e., the failed item(s), failure mechanism and finally the failure root cause or causes. In addition, the history of the equipment installed, the well data, the completion geometry and any surface or downhole constrains are also used as very important part of the data needed for the DIFA of each well.
The improved process is not only applicable for the primary failed component mode but extends to the expected second or third components and also considers their failure modes even if the equipment survived the current failure. A comparison of the ESP technologies, in terms of failure mode and run life has been conducted. Individual component failure with respect to other technology alternatives is compared to derive a relative advantage achievable in run life of the system. Such comparison is saved in a database for equipment selection criterion which can be used as a tool during the initial design phase of other ESP systems that will be implemented in various environments, either mild or harsh. A relative comparison is shown with the same component completion in different location with similar environment. A DIFA alert process with lessons learned and recommendations has been established in order to communicate with all different parties involved or affecting the ESP lifecycle.
This technical approach keeps all organizations focused on maximizing ESP reliability while promoting motivation and a competitive environment for ESP vendors to do its best. The result is a reduction in failure rate and improved ESP run life which directly benefit the economics of both ongoing and new artificial lift projects.
Variable Speed Drive In-Field Upgrade to Operate PMM
Authors: Zamesin Evgenii , Nesterov Sergei , Abualsaud Muhammad , Rakovskii Roman , Mechsheriakov Ivan , Nambiar Vijay 
Published: October 2024

Abstract
Majority Variable Speed Drives (VSD) currently deployed in various fields are designed specifically for running induction motors. Yet, with the growing application of permanent magnet motors, there arises a demand for VSDs built on a distinct operational framework. However, replacing existing drives with ones compatible with permanent magnet motors poses significant economic and logistical challenges. This paper explains the methodology involved in on-site retrofitting VSDs to turn them compatible with permanent magnet motors.
VSD retrofitting stategy is based on three major principles: leveraging existing drive capabilities for technical advantage, cost efficiency, and streamlining logistics and footprint.
On the technical front, upgrading conventional drives deployes integrating PMM-compatible components, faster IGBTs, modern HMI controllers, and output Sine Wave Filters. This unified approach enables on-site modification of VSDs regardless of brand, whether in onshore or offshore environments. Prior to implementation, a thorough prejob inspection customizes the procedure to suit each drive's unique dimensions, shape, and condition.
Economically, a lean approach maximizes original components and preserves OEM-specified technical features, ensuring optimal cost-effectiveness.
The primary result of VSD modification is achieving of compatibility with Permanent Magnet Motors while minimizing intervention and cost, keeping technical parameters either unchanged or improved. Post-upgrade, VSD becomes capable of operating at frequencies up to 300 Hz enabling application of ultra high-speed ESP for increased production. The incorporation of a modern HMI controller, featuring a user-friendly color display, extends standard protections and mitigates a risk to human error. Retaining the VSD's original rectifier ensures THD level stipulated by the VSD OEM. The addition of the system with a Sine Wave Filter further enhances power quality and contributes to the extended operational life of ESP.
The technical enhancements achieved through modification are balanced with the project's cost and resource allocations, thereby minimizing materials and streamlining operational processes.
From a logistical perspective, the elimination of heavy machinery dependencies, such as trucks, forklifts, cranes, and barge-cranes, results in a notable reduction in both financial expenditures and project timelines.
Consequently, this methodological procedure offers a pragmatic upgrade of field infrastructure with PMM compatible drives in the most eco-friendly way.
The retrofitting of conventional VSD presents a comprehensive transformation opportunity for Artificial Lift systems, yielding numerous financial benefits. A seamless transition from induction motors to PMM streamlines the cost per barrel, while leveraging existing inventory enables the immediate embrace of technical advancements without delay.
Leveraging Circular Economy Principles for Electrical Submersible Pump Equipment
Authors: Alhashem M. , Al-Aseef S. 
Published: October 2024

Abstract
This paper presents a comprehensive analysis of implementing circular economy principles in the electrical submersible pump (ESP) industry to enhance sustainability and reduce carbon footprint. Focusing on the Dismantle, Inspection, and Failure Analysis (DIFA) process, the study quantifies its impact on carbon emissions and evaluates key practices, such as component refurbishment and recycling. The research examines how collaboration between vendors and customers for failure analysis generates valuable insights, leading to enhanced product life and decreased manufacturing requirements. The findings demonstrate significant reductions in carbon dioxide (CO2) emissions associated with rig operations and component production. This research contributes novel insights into ESP afterlife and circular business models, filling a gap in petroleum industry literature and offering a framework for sustainable practices in artificial lift systems.
Workflow for Cost-Effective Reactivation of Low-Flow Wells in Deep and Mature Fields Using Compact Units for Sucker Rod Pumps
Authors: Guillca L. N. , Reyes C. , Enriquez L. , Batallas E. , Tagarot G. , Fraga R. , Charry A. M. , Landi R. , Caballero L. Salazar 
Published: October 2024

Abstract
This document gives a brief technical description of the mechanical pumping system and important technical definitions, then it summarizes a workflow developed to achieve a cost-effective method for reactivating low potential wells (under 150 oil bbl./day) in a mature field.
The workflow includes the decision process to either reactivate the well rigless or with a workover rig. It also includes the ben-efits of using a compact, easy-to install and operate surface unit.
The challenges encountered in the field include depths exceeding 9,000 ft true vertical depth (TVD), over 9,500 ft measure depth, temperature surpassing 230°F, high tortuosity and oil API between 11° to 32° API.
With an implementation in eight units, we achieved 106,000 oil bbl. during the pilot test, and a cost reduction of between 40 and 55% and other benefits, such as interventions in neighboring wells and reduced installation times.
Finally, the results in terms of benefits, lessons learned and best practices for reactivation with these compact units are shown.
Data-Driven Monitoring and Optimization of an Intermittent Gas-Lift Operation
Authors: Shresth K. , Bhatt B. , Vadivel K. 
Published: October 2024

Abstract
Gas lift is an extensively used artificial lift technique in the oil and gas industry. However, operators often shift to intermittent gas lift for low productivity index, reservoir pressure or high-water cuts, or due to the limited availability of gas (IGL). These wells have unique dynamic behavior and are generally not high producers, often lacking monitoring and surveillance, which leads to suboptimal production. Using a simulation-based method can incur excessive computing expenses that sometimes might not be justified. This paper presents an approach that combines data-based models, numerical methods, and machine learning-based algorithms to monitor and optimize IGL operations.
This process uses readily available operational data to estimate the well rates using API RP 11 V10 recommended methodologies and allows for careful monitoring of injection and shut-in phases in IGL wells while coordinating injection schedules between neighboring wells. The solution primarily consists of the following: an empirical equation with adaptable parameters that are designed to forecast the daily production rate of IGL wells, a numerical algorithm that proposes the optimum shut-in and injection period to maximize the production rate of an IGL well, and a genetic algorithm that minimizes the disturbance to a compressor that supplies compressed gas to the adjacent wells by synchronizing their injection schedule. The advanced genetic algorithm can also conduct binary-based scheduling to achieve a more streamlined control process that minimizes the total number of simultaneous injections.
The implementation of this solution has led to significant time savings, delivering a considerable improvement in operational efficiency and a noticeable increase in production. Real-time monitoring of the parameters provides numerous insights for IGL surveillance. Previously, the operator's approach was more reactive, and field engineers had to depend on ad-hoc hit and trial methods upon encountering such issues. The tests that could provide diagnostic signatures about the well performance used to occur occasionally, sometimes only once a year. These tests involved two or three pen recorders, tagging the fluid level using wireline tools, carrying out long cycle studies, bottom hole gradient surveys, etc. Now, using the real-time data monitoring and outputs from the solution, operators can troubleshoot and optimize the IGL operations remotely, which has led to proactive operations management, limiting the number of field visits. These operations have reduced the operational cost, HSE risk exposures, and carbon footprints.
This solution combines various technologies and methods to address challenges in the surveillance and optimization of intermittent gas-lift wells. The solution enables users to monitor important parameters, estimate daily production rates, determine optimum gas injection cycles, and schedule gas injection cycles to minimize gas injection overlap between the wells.
Safety First: Best Practices in ESP Project Management for HSE Excellence
Authors: Alghamdi Albaraa , Villarreal Leigber Rivera , Leon Jaime Pena , Alomran Abdulaziz Y. 
Published: October 2024

Abstract
This paper aims to present a detailed and practical safety management procedure for surface and subsurface Electrical Submersible Pump (ESP) systems. The safety procedure covers all aspects of the ESP project, from equipment procurement to commissioning, while ensuring the highest Health, Safety, and Environment (HSE) standards are met at the lowest cost.
The procedures were developed following the highest HSE standards. Behind any successful ESP deployment project, several activities must be performed safely to guarantee successful project delivery. Comprehensive safety and inspection measures were developed and implemented in each activity starting from the ESP supplier facilities to field installation and commissioning. Most importantly, all safety measures are documented, certified, and revisited frequently by all stakeholders to ensure the highest levels of safety at all times.
The comprehensive safety management procedure resulted in a track record of successful ESP project deliveries without incidents. The procedure includes details on (1) Revising equipment specifications and equipment test certificates to confirm compliance with operating company and international standards, (2) Attending Factory Acceptance Tests (FAT) of manufactured equipment, (3) Inspection before and after equipment delivery, (4) Performing multi-level pre-energization checks, (5) Issuing energization certificate, (6) Conducting final walkthrough by all concerned stakeholders, (7) Performing final pre-commissioning to validate safety and ESP functionality before commissioning. The paper presents a detailed account of the entire process and can be used as a reference for oil and gas operators to achieve HSE excellence.
This paper presents a comprehensive list of safety and technical checks for complete ESP equipment delivery, adding to the existing body of literature on ESP project management. The procedures presented in the paper go beyond standard practices, ensuring the highest HSE standards are met at the lowest cost. It offers valuable insights and recommendations to the oil and gas industry, helping operators achieve their HSE goals while delivering successful projects.
Shale Gas Field Production Optimisation Decision Making and Intelligent Dewater Production Technology
Authors: He Zuqing. , Liu Wei. , Zhou Zhongya. , Liu Huanle. , Zhou Chao. , Zhou Penghui. 
Published: October 2024

Abstract
With the deepening of shale gas field development in Nanfang gas field, there are more and more low-pressure and low-production gas wells, and the current drainage and gas extraction process is not well adapted to the exploitation of the gas field, for this reason, the drainage and gas extraction completion technology of Fuling shale gas wells will be systematically tackled, so as to effectively support the long-term stable production of this shale gas field.Scope:shale gas field and other unconventional gas reservoir.
Enhancing Reliability in Sucker Rod Pumping System: Understanding Premature Failures and Implementing Sustainable Solutions
Authors: Al Abri Ahmed T. , Al Badi Said S. , Al Hinai Nasser , Al Abri Ahmed N. , AL Busaidi Khalfan , Khemnar Atul 
Published: October 2024

Abstract
Daleel Petroleum is operating an oil field in the northern region of Oman. Sucker rod pumps drive most of its production. While, most of wells have smooth commissioning time, considerable number of them experience premature failures in less than 90 days. This paper offers Daleel Petroleum experience and methodology in failure's root cause analysis and the integrated solutions that enhanced the run life and reduced the failure rate.
A comprehensive analysis was conducted to understand the failure root causes and the best recommended practical solutions that integrate the surface unit and downhole pump completion. The analysis focused on three main areas which are prior the pump installation level, which include the well cleanout program, sucker rod installation level and post failure analysis area. Thus, the pump mineralogy, installation and running in hole procedures optimized along with aligning the compatibility of the used materials with the well's downhole conditions. Accordingly, the pump's material and grade tested to ensure it is compatible with the different reservoir fluids and the surface unit installation checked to get the right alignment with minimum vibration. The pump design, running hole and installation procedures optimized to have the best efficiency with lowest cost. On the other side, the failed pumps dismantled and the pump's running data analysed to identify the failure leading causes and enhance the pumps overall performance.
The collaborative enhancements across various levels have significantly extended pump run life and markedly reduced failure rates. Key modifications included upgrading downhole pump materials to endure challenging well conditions, such as high water cut, solids production, and corrosive environments. Additionally, the optimization of installation and RIH procedures was aligned with the manufacturer's guidelines and API standards. The wellbore cleanout program was also enhanced to ensure a clean bottom hole before pump installation. These integrated modifications have resulted in a more than 30% reduction in failure rates and a 20% increase in average well run life over a three-year period. Furthermore, deferment and workover costs have been reduced by minimizing intervention times.
This paper offers comprehensive root cause analysis of premature failures at Daleel petroleum at different levels (pre- pump installation, during and post installation stage). The paper presents integrated and effective solutions implemented in North Oman to enhance the run life, reduce the failures and the deferment and optimize the workover cost.
Ultra-High-Speed Applications: Stepping Beyond Traditional Approach
Authors: Shakirov Anton , Alexeev Yaroslav , Al-Salahi Zaid 
Published: October 2024

Abstract
Ultra-High-Speed (UHS) Electric Submersible Pumps (ESP) Systems have grown in popularity in recent years for providing synergy benefits of high-speed rotation and centrifugal pumping concept. This study intends to demonstrate how UHS operation can leverage its advantages beyond traditional approach to address issues in oil and gas wells through application of various pump types. Authors reviewed three revolutionary concepts for future UHS pumps including Vortex, Helico-axial and Boundary Layer design, to validate their application range at ultra-high speeds. In addition, to highlight the enhanced capabilities and performance of Centrifugal UHS ESPs under varying operational conditions. Authors conducted in-depth case studies in three fields, one each from Africa, Europe, and North America.
Features of UHS operation (10,000-15,000 rpm) can be found across different components of the downhole system. The research has brought more focus on pump and pumping method design for sand containing gas-liquid mixtures. Various designs of multiphase pumps and their combinations may deliver unique features that cannot be reached with standard-speed applications. Study results represent detailed application range matrix for high gas, high sand and traditional centrifugal pump designs under ultra-high-speed operating conditions.
Results of this study demonstrate the superiority of ultra-high-speed pumps over their standard counterparts resides in their capacity to meet the increasingly stringent demands of modern industrial applications. This advantage stems primarily from their enhanced efficiency and performance metrics, which manifest across multiple operational dimensions. Project findings have brought new insights and perspectives into pumping fluids for both oil and gas/gas-condensate wells, with some of them having been partially tested.
WITHDRAWN: New Breakthrough in Triple-Negative Breast Cancer Treatment: A Study on the Clinical Efficacy and Safety of the Combination of Carrilizumab and Apatinib in Dual-Targeted Neoadjuvant Therapy
Authors: YIN Yulai , ZHANG Xiaoyu 
Published: October 2024

Abstract

The full text of this preprint has been withdrawn by the authors as it was submitted and made public without the full consent of all the authors. Therefore, the authors do not wish this work to be cited as a reference. Questions should be directed to the corresponding author.
WITHDRAWN: A Meta-Heuristic Based Approach for Optimal Fake News Detection Using Supervised Learning
Authors: Jaiswal Arunima , Verma Himika , Sachdeva Nitin , Wary Alongbar , Indra Gaurav , Brahma Daniel Kr. 
Published: October 2024

Abstract

The full text of this preprint has been withdrawn by the authors while they make corrections to the work. Therefore, the authors do not wish this work to be cited as a reference. Questions should be directed to the corresponding author.
Spatial scale dependence of fault physical parameters and its implications for the analysis of earthquake dynamics from the lab to fault systems
Authors: Zaccagnino Davide , Bruno Oscar , Doglioni Carlo 
Published: October 2024

Abstract

An accurate assessment of seismic hazards requires a combination of earthquake physics and statistical analysis. Because of the limits in the investigation of the seismogenic source and of the short temporal intervals covered by earthquake catalogs, laboratory experiments have been playing a crucial role in improving our understanding of earthquake phenomena. However, differences are observed between acoustic emissions in the lab, events in small, regulated systems (e.g., mines) and natural seismicity. One of the most pressing issues concerns the role of mechanical parameters and how they affect seismic activity depending on boundary conditions and on the spatio-temporal scales. Here, we focus on fault friction. There is evidence inferred from geodesy that most large faults are weak and featured by very low static friction coefficients not compatible with those of smaller faults and laboratory experiments. We propose a possible explanation: static friction decreases with fault size also depending on a few physical properties (e.g., faulting fractal dimension), while dynamic coefficients are not affected by the spatial scale. Mathematical derivations are grounded on hypotheses validated using a simple model for earthquake occurrence based on fracture mechanics and able to reproduce the fundamental statistical properties of seismicity.