bluuebunny/crossref_metadata_2025_split huggingface dataset:
Leveraging LWD Ultrasonic Imaging for Enhanced Fracture Identification in Water-Injection Wells
Authors: Al Saidi Hamdan , Al Harth Al Maha , Das Anindya , Al Shuali Salim , Al Salmi Issa , Al Sawafi Samya , Al Muharabi Mubarak , Taher Ahmed 
Published: November 2024

Carbonate formations are known to be highly fractured. Water injection plays an important role in enhancing oil recovery, and accurate identification and characterization of fractures in the reservoir are crucial for optimizing injection strategies and ensuring efficient fluid displacement. This study investigates the application of logging-while-drilling (LWD) ultrasonic imaging technology as a tool for fracture detection and characterization in water-injection wells.
Carbonate reservoirs are usually characterized by the presence of natural fractures. High-resolution ultrasonic imaging sensors acquire amplitude and travel-time images for identifying open fractures and measuring hole size. The integration of formation evaluation data and high-resolution images provides important information for reservoir characterization.
The data in this study was acquired across a reservoir section for optimizing well injectivity. The study presents results from field trials where LWD ultrasonic imaging was employed for fracture identification in water-injection wells for the first time in the Upper Shuaiba formation, with no other water-injection wells nearby. The analysis focuses on the tool's ability to detect fractures, including their orientation, size, and distribution.
Lost-circulation intervals associated with open fractures were resolved by the high-resolution image. The upper section of the drilled interval appeared to be highly fractured with some cemented fractures. Five faults were identified, most of them associated with multiple fractures and loss of circulation. The shallow resistivity log across the highly fractured zone showed clear variations due to the presence of fractures. The general fracture direction was NW-SE with some less frequent fractures with different fracture orientations aligned in the NE-SW direction. Bed dips picked from the borehole image showed a consistent SE dip direction with average dip of 7 degrees.
The deployment of the ultrasonic imaging sensor in an injector provided important information for understanding fractures connectivity and its influence on injectivity. This knowledge can be used to improve reservoir performance.
Identifying and Unlocking Hydrocarbon Potential in Cretaceous Sandstones With High-Density Calcareous Concretions in Rondon-Terecay Area, Arauca, Colombia
Authors: Solano A. A. , Layton R. M. , Ataya C. D. , Chavarro N. A. , Hernandez A. 
Published: November 2024

Abstract
This paper endeavors to present the potential and development strategy for the K2C reservoir, characterized by low-resistivity sandstones interbedded with high-resistivity calcareous concretions. These features represent a reservoir characterization challenge due to the lack of logs response and the difficulty to quantify the oil volume storage by the sandstones in the calcareous zones. The study employed a comprehensive sedimentological analysis to delineate the geometry and architecture of the K2C reservoir in the Rondon area, integrating various data sources such as cores, logs, cuttings, and petrography. The selection of wells for workovers, based on integrated data, yielded favorable results, affirming the reservoir concept and prompting expansion in Rondon- Terecay and other Llano’s areas. The 2023/2024 workover campaign in Rondon yielded an average production of 1100 barrels of oil per day (BOPD) with an 80% water cut, validating the natural productivity of the reservoir without chemical or mechanical treatments. This success unveiled substantial reserves increase of 56%, for future development, with projected production peaks of 2000 BOPD by the end of 2024 and 2400 BOPD in 2026. The study also underscores untapped opportunities in northern fields, notably in Cravo Norte, indicating significant additional hydrocarbon potential. By validating the reservoir concept in calcareous sandstones with high-density calcareous concretions in Rondon- Terecay, this paper offers a novel perspective, providing valuable insights for practicing geologist and engineers to identify and develop analogous reservoirs, thereby enhancing their management and understanding of hydrocarbon assets.
Navigating the Talent Shift and Building the Digital Workforce of Tomorrow – PDO Case Study
Authors: Al Abri. H. 
Published: November 2024

Abstract
The oil and gas industry is undergoing a significant transformation, driven by the need for greater efficiency, sustainability, and technological advancements. This transition requires a fundamental shift in the workforce, with a growing demand for digital skills and a new generation of talent. In this paper, we present a case study of Petroleum Development Oman's (PDO) initiative to navigate this talent shift and build the digital workforce of tomorrow.
The paper begins by examining the key drivers behind the industry's digital transformation, including the evolving energy landscape, the rise of automation and data-driven decision-making, and the changing expectations of the workforce. It then delves into PDO's strategic approach to address these challenges, highlighting the company's focused efforts to upskill its existing workforce, attract and retain top digital talent, and foster a culture of innovation and continuous learning.
The core of the manuscript details PDO's multifaceted talent development program, which comprises comprehensive training, targeted recruitment, and strategic partnerships. The program encompasses initiatives such as digital academies, online learning platforms, and collaboration with academia and technology providers to ensure that the workforce is equipped with the necessary skills to thrive in the digital era.
The paper also discusses the tangible results and impact of PDO's talent development initiatives, showcasing improved operational efficiency, enhanced decision-making capabilities, and the successful integration of emerging technologies across the organization. Finally, it explores the lessons learned and the key considerations for other oil and gas companies seeking to navigate the talent shift and build a future-ready digital workforce.
An Innovative Approach to the Selection of Critical Design Parameters Influencing Sand Control Efficacy in Standalone Sand Screens Deployed in Oil and Gas Wells
Authors: Razak R. , Alosail M. S. , Musa K. I. , Gago P. A. , Chen Z. , Tyson S. , Rahman S. S. 
Published: November 2024

Abstract
The objective of screen testing and selection is to minimise sand production while maintaining acceptable filter permeability, however, screen failures during operation are common and difficult or expensive to fix. Our research improves current selection tests and considers the expected time to failure for the screen. Experimental tests for screen selection compare retained permeability and produced solids for different screen apertures and weave types. Our study suggests that performance is only minimally dependent on aperture and weave, but more strongly dependent on the structure of the filter-bed that builds up on the screen. We also show that screen failures are directly linked to the structure of the deposited filter-bed. The aim of our work is to develop a relationship between filter bed packing, filter bed thickness, and screen stresses, to introduce preliminary quantification of the required strength of a screen and extend its operating life.
Our methodology uses a CFD-DEM model to simulate four common screen types. The numerical model is calibrated using an innovative laboratory experimental result and the corresponding micro-CT image of the deposited filter-bed at, using sand samples from wells offshore Brunei. The metric used for calibration is the single-phase permeability parameter.
The retained permeability and the rate of sand production is only weakly dependent on the weave and aperture of screen coupons in both experimental tests and numerical simulations. The behaviour of the screen is better correlated with the structure and composition of the filter-bed. Numerical simulations of behaviour of the screen and the filter-bed allowed us to analyse the stress on the screen, which is not normally measured in experimental screen retention tests. As the filter-bed is a granular media, the forces transmitted through the filter-bed are spatially highly variable with some locations on the screen receiving extremely high point forces which are above the manufacturers specified collapse pressure. Our advanced numerical method that involves stress analyses on sand screens allows us to develop a more comprehensive set of criteria for screen selection which should reduce the occurrence of screen failure or extended the expected time to failure.
The novelty of this research is the development of new techniques to investigate the screens’ ability to resist collapse due to non-uniform forces on the screen. During this research, it also became apparent that screens with different weaves and apertures perform broadly the same in terms of produced sand and retained permeability. As a result of these observations, we suggest a more rigorous comparative test that considers the expected life of the screen and its susceptibility to failure.
Unconventional Scale Inhibition and Acid Stimulation Strategies for Enhanced Oil Recovery in Sandstone Formations: A Case Study from Southern Oman
Authors: Shukaili Ghosin Al , Ruqaishi Moza Al , Kalbani Muhannad Al , Riyami Yaqoob Al , Amri Ibrahim Al , Habsi Al Moatasem Al , Lawati Ahmed Al , Jabri Dawood Al , Hatmi Safiya Al , Shabibi Ali Al 
Published: November 2024

Abstract
Field X is an oil field characterized by sandstone formations, discovered in 1984 and put into production in 1987. Waterflooding has been integrated into field development plan since 2007 to enhance oil recovery. One of the main challenges in Field X is the underperformance of the water flood system, which led to a severe oil production decline, 30% below target by the end of 2022.
The water injector wells suffer from significant scale deposition over time caused by water incompatibilities and pressure/temperature changes. Even though measures such as applying downstream scale inhibitors and performing acid stimulation have been in practice since 2010 to tackle the problem, the severity of scale deposition remains severe.
A comprehensive review on previous scale formation prediction studies has been done, along with taking downhole samples to identify main scale elements in place. Four different lab analysis have been conducted including solubility tests, XRD, XRF, and bulk scale analysis (BSA). Lab analysis from the downhole scale samples showed up to 60% of samples are insoluble in HCL acid, in which two dominant scale types were identified CaCO3 and CaSO4.
Assessment of the current field inhibition strategy to survey and quality assure different aspects, such as the applied scale inhibitor type, dosage, and skid locations. Three different scale inhibitors were tested at both surface and downhole conditions to identify the optimum candidate. Testing has shown an increase in dosage from 15-20 ppm to 30 ppm.
Due to the presence of HCl insoluble mineral deposits, the old acid treatment recipe was found inadequate and only provided temporary solutions. Based on Laboratory results using mineralogy data from analogous wells, mud acid (9%Hydrochloric acid-1%Hydroflouric acid) was proposed for stimulating poorly performing injectors in field X. Trail camping was done using new acid treatment strategy.
As a result of these efforts, Field X’s injection has improved by 73% compared to 2022. This has led to an improvement in overall field production by 27%. Additionally, there has been a decrease in total suspended solids (TSS) when compared to previous years.
This paper investigates the effectiveness of non-traditional acid and solvent systems in sandstone formations in Southern Oman for healthier waterflood management.
Enhanced 9.625-Inches Cementing Practices Proved the Best Well Integrity Solutions and Eliminates the 7-InchesTieback Options in Onshore Oil Field in the United Arab Emirates
Authors: Valencerina Lou , Ahmad Mushtaq , Reyami Mazin Al , AlShehhi Mouza , Khan Faisal Gul , Felaza Fesarama , Ameh Ugbedeojo 
Published: November 2024

Abstract
Conventional drilling methods in UAE onshore oil fields have faced significant challenges, including wellbore instability and fluid losses across aquifers during the drilling of 12.25-inch intermediate hole sections. These challenges impacted drilling productivity and compromise well integrity, particularly during the cementing of 9.625-incheds casing strings. The conventional practice of using repeated cement/sodium silicate plugs to address these issues has proven insufficient, often necessitating the use of a 7-inch casing tieback to ensure well integrity throughout the well’s lifecycle. This paper presents enhanced 9 5/8-inch cementing practices designed to eliminate the need for a 7-inch tieback while preserving the option for future side tracking. The adoption of these enhanced practices has led to significant cost savings, reduced well durations, and improved well integrity. By detailing the methodology, results, and implications, this paper provides valuable insights into modern cementing practices and their impact on drilling efficiency and cost management.
Enhancing Electrical Submersible Pump Operations: Leveraging Data-Driven Models Using Advanced Machine Learning and IoT Technologies for Effective Event Management
Authors: Al Mansoori Yousof , Al Shamsi Mohamed K. , Lotfy M. , Cardozo J. , Alzurba R. , Rivadeneira I. , Bougherira Y. , Akrouti Issam , Tawakol M. , Fidler E. , Lenicky M. , Wahba S. 
Published: November 2024

Electrical Submersible Pumps (ESPs) are widely used in the petroleum industry as an effective artificial lift method. ESP pumps are particularly effective in scenarios with reservoirs having low bottomhole pressure, low gas/oil ratio, high water cut, and low API gravity fluids. However, ESPs are very susceptible to issues depending on the well and reservoir conditions, requiring continuous monitoring and analysis of performance and failures of the ESP system. Despite their widespread application, operating ESP wells presents several challenges that can impact efficiency, reliability, and overall operational costs. Common issues include sand and solids production, gas interference, corrosion and scale formation, power supply inconsistencies, high reservoir temperatures, handling of viscous fluids, complications in deep and deviated wells, and mechanical failures due to vibration and stress. Addressing these challenges is crucial for optimizing ESP performance and ensuring economic viability.
Under this context, Abu Dhabi Offshore Fields, as part of its field development plan, has adopted ESP as its artificial lift system. In consideration of this ambitious project, Abu Dhabi Offshore Fields is proactively engaged in laying the groundwork to manage these wells with the highest operational efficiency. This involves strategic planning for the installation, maintenance, and monitoring of the ESP systems to ensure they deliver optimal performance and longevity. Therefore, continuous surveillance of the system is a must, especially considering that common ESP failures are categorized as follows: Electrical Failures, which are the most prevalent, making up about 60% of all ESP failures, including power failures, under-voltage, voltage imbalances, and motor underload. Motor Failures can result from overheating, insulation breakdown, or mechanical wear and tear. Gas Locking occurs when gas accumulates in the pump, hindering its operation. Mechanical Failures include issues like impeller wear, shaft breakage, and seal failures. Operational Failures arise from improper installation, poor maintenance, and operational errors.
Recent advancements in Artificial Intelligence (AI) offer promising solutions to mitigate these operational challenges. AI technologies, including machine learning and predictive analytics, can provide significant improvements in the management and optimization of ESP systems. For instance, predictive maintenance algorithms can analyze historical and real-time data to forecast equipment failures, allowing for proactive interventions that reduce downtime and extend the lifespan of ESP components. Similarly, AI models can predict sand production trends and recommend optimal operational parameters, minimizing sand ingress and associated issues.
Novel Approach of Reservoir Management to Ensure Reservoir Healthiness and Gas Availability to the Network
Authors: Al Yaqoubi Nouf , Sudarev Maxim , Latypov Eduard , Al Bairaq Ahmed , Alawadhi Fatima , Nachiappan Ramanathan , Al Hammadi Shamma , Al Shamsi Alia , Fathalla Magdy Farouk 
Published: November 2024

Abstract
The study accentuates the need for enhancing productivity and sustainability by curtailing the new wells drilling requirement and building associated infrastructure. The system implements a recycling process in the reservoir to enhance condensate collection and maintain pressure by dividing the reservoir into sectors. This method is especially beneficial in situations where there is a lack of make-up gas or the need to generate gas that is suitable for the market. This approach involves careful allocation of injection gas to maintain pressure and prevent early gas breakthrough. The goal is to divide the reservoir based on geological information and improve operation tactics for each well, including reallocating injections and detailed development plans. The first use of data such as rock layers along with tracking and production/injection figures helps verify the division strategy. This has led to improved condensate yield without extra costs. A plan has been created, specifying allowed injection rates for each injector, resulting in better condensate extraction and a prolonged gas output level.
By converting underperforming vertical wells into horizontal ones, we've increased the contact with the reservoir and enhanced output. Focusing on condensate-rich areas through strategic drilling at the periphery is a key part of our approach. Sectorization, along with horizontal and peripheral drilling, has significantly boosted ultimate recovery and production efficiency, with sectorization adding about 0.5% to recovery rates, horizontal drilling contributing an extra 1.5%, and peripheral efforts increasing it by about 4%, leading to an overall improvement in condensate recovery by roughly 5-6%.
The main goal is to secure a sustainable and profitable supply of gas, both presently and looking ahead, by enhancing the recovery process from a vast Gas-Condensate Reservoir in the UAE. The approach includes setting objectives, ordering priorities, and designating resources for actions and assessment methods to reach these objectives. This study presents a novel method to improve the exploitation of a substantial gas-condensate reservoir, with a focus on optimizing condensate retrieval while preserving reservoir pressure, and prioritizing decarbonization and emission reduction.
Hydrogen Storage Opportunities in UAE: Potential Innovations and Advances
Authors: Lyakhovskaya V. R. , Magomadov I. A. , Balhasan S. A. , Lamboi J. , Mahmoud S. Nagy Fathy Mohamed 
Published: November 2024

Abstract
The paper aims to explore hydrogen storage opportunities in the UAE, focusing on the potential of salt domes in the region. It evaluates the technical, environmental, and sensitivity aspects of utilizing salt domes for large-scale hydrogen storage, aligning with the UAE's strategic goals for energy transition and decarbonization. This study employs a comprehensive approach that includes geological analysis, cavern design, and sensitivity assessment.
The methodology involves identifying and characterizing suitable salt domes, designing storage caverns, and calculating their capacity. It also incorporates sensitivity analysis using Monte Carlo simulations to evaluate uncertainties and risks, alongside suggests advanced monitoring systems to ensure structural integrity and safety of proposed salt caverns.
The analysis identifies several salt domes, such as Jebel Dhanna, Delma, and Sir Bu N'Air, as highly suitable for hydrogen storage. The designed caverns show significant storage capacity, with a median of 1144 caverns capable of storing approximately 503 million pounds of hydrogen. Sensitivity analysis highlights dome diameter and edge length as critical factors influencing storage capacity. Advanced monitoring systems and safety measures are proposed to mitigate risks associated with structural integrity and gas leakage. The findings support the UAE's strategic commitment to advancing hydrogen storage, contributing to energy security and the transition to a low-carbon future.
This paper presents novel insights into the feasibility of using UAE salt domes for hydrogen storage, combining detailed geological analysis with advanced design and risk assessment techniques. It offers practical guidance for implementing large-scale hydrogen storage projects, contributing to the existing body of knowledge and supporting the UAE's leadership in the hydrogen economy.
Optimizing Data Driven Recruitment Strategies in a Disruptive Era Through Digital Workload Analysis
Authors: Handayani S. , Kusumaningtyas R. , Wicaksono D. , Putri N. Sasmita , Triasnita C. 
Published: November 2024

Summary
To emerge as a leading global energy company, an agile structure that facilitates business acceleration and operational excellence is necessary. However, following a recent subholding restructuring, the organization faces a 23% vacancy rate. This situation is compounded by the dynamic business landscape, which makes additional challenges to recruiting efforts. To address these issues and ensure an effective recruitment strategy to maintain productivity while adapting to the changes, a comprehensive organizational evaluation and processes is essential. A digitalized Workload Analysis (WLA) application was implemented to comprehensively assess staffing needs of 6,200 positions across the organization, including structural and contracted positions. This approach addressed limitations of conventional WLA methods such as data validity and extended timeline. Pre-filled questionnaires based on standardized job descriptions ensured data accuracy, and sharing sessions for high-level management, Subject Matter Experts (SMEs), and all respondents, further enhanced completion quality. Additionally, technical guidance and support were offered in various forms, including online/offline assistance, instructional videos, and interactive communication channels. This streamlined WLA process was completed within two months. The analysis resulted in some critical insights: among the 23% vacancy rate, 15% were identified as high-priority roles within core operational teams. Another 3% could be eliminated, while recruitment for another 5% could be deferred based on anticipated business developments. These findings informed targeted recruitment strategies, timelines, and resource allocation, ensuring efficient workforce management. Emphasizing a data-driven approach, it optimizes the recruitment process and identifies opportunities to enhance efficiency by eliminating redundant positions, supporting the company to swiftly adapt to evolving talent demands and ensuring readiness in the dynamic business landscape.