bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Innovative Characterization Method for Recovery Factor Quantification of Horizontal Shale Gas Well in Sichuan Basin, Southwest China
Authors: Yu Wei , Wu Jianfa , Huang Haoyong , Liu Chuxi , Sepehrnoori Kamy 
Published: November 2024

Abstract
This study presents a comprehensive methodology for evaluating the performance and economic viability of two shale gas wells in the Sichuan Basin, Southwest China. A hydraulic fracture simulator was utilized to model fracture propagation, incorporating a 3D geomechanics model and natural fractures. The fracture model was calibrated using real pumping pressure data, and the calibrated fracture geometry was integrated into a reservoir model using the Embedded Discrete Fracture Model (EDFM) method for history matching with field production data. The study introduces a new method to calculate the drainage recovery factor, providing a more accurate estimation of hydrocarbon recovery. Long-term production potential was assessed through a 20-year Estimated Ultimate Recovery (EUR) analysis, and the Drained Reservoir Volume (DRV) was calculated to understand reservoir depletion over time. The results indicated significant differences between traditional recovery factor estimates and those obtained using the new method, underscoring the importance of advanced modeling techniques in capturing the complexities of reservoir behavior. Additionally, an economic analysis was conducted, revealing that one well was significantly more profitable than the other, highlighting the value of integrating technical and economic evaluations in shale gas development projects.
Enhancing Upstream Operations: Hybrid Approach for ESP Failure Prediction in ADNOC’s Assets for Operational Excellence and Digital Progress
Authors: Hernandez C. , Asif U. , Caicedo S. , Al Nuaimi D. , Bakhti S. A. , Guzman R. , Aguilar H. , Alsaeedi K. , Al Radhi M. , Alhashmi Z. , Alhammadi A. , Abdelkerim A. , Chelligue T. , Almadhoun W. , Palomino C. , Ayoubi R. , Hammo A. , Arnaout A. , Penubarthi S. 
Published: November 2024

Abstract
This paper proposes a transformative approach in Electric Submersible Pump (ESP) management, aiming to predict failures and prevent ESP downtimes ahead of their occurrence. The goal is to build a reliable tool that assists in the decision-making process for preventive ESP replacements. This initiative not only enhances planning through accurate rig allocation and inventory optimization but also minimizes deferred production by establishing a zero-failure intervention strategy.
The predictive model operates on an assembly that considers a Real-Time data acquisition system, core predictive model algorithms, and automated engineering workflows. This ensemble is designed to process both real-time and historical data, complemented with surface parameters to accurately forecast ESP failures while providing probabilities of occurrence. By integrating machine learning techniques with traditional physics and statistical analysis, the model provides critical insights into ESP health, thus enabling proactive maintenance and operational planning. Applied across diverse ESP setups, this proactive strategy not only sustains production but also enhances operational flexibility.
The ESP predictive model provides the information that enables the establishment of a cohesive predictive maintenance solution that effectively unifies the principles of data science with operational technology. The implementation has notably improved the reliability of ESP operations by providing petroleum engineers with the tools to maintain continuous production. The evidence gathered during the pilot phase reveals the system’s proficiency in anticipating ESP failures, leading to a significant reduction in unplanned shutdowns and maintenance costs. The success of this project emphasizes the strategic value of predictive maintenance in realizing operational efficiency, enhancing profitability, and fostering a digitally empowered corporate culture within ADNOC’s upstream sector.
This paper introduces a groundbreaking approach to predictive maintenance in the oilfield, enhancing established methodologies with a comprehensive, data-driven strategy that bonds machine learning, physics, statistics, and real-time operational data. This novel method not only advances ESP management but also sets a new standard in failure prevention and operational optimization while improving decision-making by providing probabilities of occurrence.
Application of Agro-Waste Polysaccharide-Carbonate Blended Bridging Agent: A Dual Solution for Carbon Footprint Reduction and Wellbore Stability Improvement in Offshore Assets of India
Authors: Pandey Ashutosh , Singh Kulwinder , Dhakate D. M. , Kumar Neeraj , Gautam Amitosh , Verma J. S. , Singh Ratan 
Published: November 2024

Abstract
This paper is aimed to investigate effectiveness of smartly blended agro-waste polysaccharide-carbonate bridging materials which was used in improving wellbore stability and drilling efficiency in brownfield environments with complex well bore geometries. This effectiveness of bridging agent also contributes to carbon reduction.
Reservoirs in brown fields are depleted and the intricate well profile poses significant challenges for maintaining wellbore integrity during drilling operations. This challenge was addressed by incorporating a smart blend of agro-waste polysaccharide-carbonate based bridging materials, with varying particle sizes, into the drilling fluid. Study was conducted on 34 wells for effectiveness of network structure and the bridging efficiency.
Study shows that by pumping over and around 20-25 ppb of bridging material into the drilling fluid system there was decline in seepage losses by 51.89%. Bridging materials enhanced hole cleaning by increasing the gel strength and yield point of the drilling fluid which reduced both Equivalent Circulating Density and fluid loss thus leading to efficient drilling operations and reduction in non-productive time by 46%.
The bridging material’s ability to form a strong mud cake with good sealing properties enhances wellbore integrity throughout the drilling process, minimizing mud losses and potential environmental impact. Also, the compatibility of cellulose-carbonate bridging material is both in oil-based and water-based drilling fluid system.
Time-Preserving Tomography in Structure Mapping: A Case Study of a Deep Gas Reservoir, Offshore Abu Dhabi
Authors: Hong Y. , Cambois G. , Al Neyadi A. A. , Cowell J. , Aljaberi F. , Al Kaabi A. S. , Puri A. K. 
Published: November 2024

Abstract
A deep gas reservoir in an offshore field, Abu Dhabi presents a unique challenge in structure mapping due to significant misties encountered when utilizing both Pre-Stack Time Migration and Pre-Stack Depth Migration seismic data. Rapid variation of velocity in horizontal and vertical directions makes the mistie issue very challenging especially for the wells not included during the velocity model building for PSDM. To address the challenges, improve the structural interpretation and velocity model of the deep gas reservoir, a novel workflow of time-preserving tomography (TPT) has been applied.
TPT is a technique that preserves the travel times of seismic events while updating the depth domain horizons and interval velocities by ray tracing. It uses a modified version of the Dix formula that accounts for the vertical and lateral variations of the velocity field. The process may need to be iterated several times until the velocity model and horizons that meet your expectations are obtained. TPT was applied to a deep gas reservoir using seismic data from a 3D survey and initial horizons and velocity models derived from well logs and conventional tomography.
The updated horizons and velocity model by TPT showed better consistency with the well data and seismic reflectors than the initial models. The difference between the initial and updated velocity model reveals a polygon-shaped area with significant velocity anomalies, which corresponds to the fault system or a carbonate buildup in the reservoir. The structural mapping and velocity analysis by TPT has enhanced the understanding of the reservoir geology and heterogeneity.
This paper presents the first application of TPT to a deep gas reservoir, within the offshore Abu Dhabi oilfields, demonstrating its advantages over conventional structure mapping in updating velocity models and improving the depth domain interpretation. TPT is a robust and efficient workflow that can be applied to other complex reservoirs with similar challenges. The case study highlights the method's ability to reconcile discrepancies and provide a more reliable geological framework for exploration and development strategies.
Supply Chain Management with AI
Authors: Hamadi Khaled Al , Ekambaram Somasundaram 
Published: November 2024

Supply chain management (SCM) in the downstream gas sector involves intricate operations that are pivotal for the efficient flow of materials, from procurement to delivery. The accurate prediction of material reservations is crucial in this process, ensuring that the right materials are available at the right time. Historically, these predictions have been performed using traditional statistical methods and human judgment, often leading to inefficiencies such as overstocking or stockouts, both of which have significant cost implications.
With the rapid advancement of Artificial Intelligence (AI), there has been a paradigm shift towards using data-driven approaches to optimize SCM processes. AI and machine learning models can analyze vast amounts of historical data to uncover patterns and trends that are not immediately obvious, leading to more accurate forecasts and more efficient operations.
Successful Implementation of Azimuthal Accuracy in Completions with Fiber Optic Cable to Optimize Productivity and Injectivity
Authors: Chinchayan Gustavo A. , Breiki Ibrahim Al , Sabari Sulaiman Al , Taiwani Mohammed Al , Ahmadzadeh Peiman , Hinai Khalil Al , Bahri Bader Al , Nadhari Nasser Al , Kamali Mohammed 
Published: November 2024

Abstract
Oriented perforating has been a challenge in the oil industry for different applications from vertical to horizontal wells. The introduction of fiber optic cable in completions allows better well data and reservoir monitoring. Assurance and reliability on technologies to maintain fiber optic integrity while perforating remains a concern in the industry. The application began covering from narrow azimuth to an expanded circumferential coverage in the borehole. The superior circumferential coverage was possible with the development of new technology. Increasing azimuthal exposure of the borehole requires confidence on accuracy of the instrumentation.
The methodology implemented together with technology available should provide positive results securing the asset investment and maintaining the integrity of the fiber optic cable.
In this article, different approaches are described for oriented perforating with fiber optic installed along the casing. The document outlines both a mechanical orientation with tubing conveyed perforating and oriented perforating with wireline.
The mechanical orientation with tubing conveyed perforating starts when casing and fiber optic is installed on the well. A special permanent casing device is designed together with a retrievable running tool conveyed with guns that will lock in the adequate azimuth away from the fiber optic cable. A standard correlation survey is required to verify the depth position of the special device in the casing.
The oriented perforating with instrumentation conveyed with wireline uses an azimuthal oriented tool or a gyro device. The gyro is used for wells with deviation less than five degrees. The azimuthal oriented tool is used with wells with a deviation larger than five degrees. The instrumentation locates the fiber optic cable angle position with respect of the high side of the hole or angle position with respect of magnetic north. In order to help the location of the fiber optic a special strip is installed together and below the fiber optic cable. Prior perforating, this angle position is verified. The verification assures reliability of the whole system avoiding damage on the fiber optic cable.
The azimuth coverage has risen from one hundredth and thirty five degrees to two hundredth and twenty five degrees. The estimation of azimuth coverage with instrumentation is about two hundredth and seventy degrees. Furthermore, the methodology with wireline conveyance could improve above mentioned values.
In summary, this article describes procedures, difficulties observed on actual services and successful implementation of techniques that leads to successful oriented perforating with larger circumferential coverage.
Supply Chain Network Optimization & Simulation Model Digital Twin
Authors: Almaazmi Jawaher , Alzaabi Mohamed , Naidu Kiran 
Published: November 2024

Executive Summary

About Borouge
Borouge is a leading petrochemical company that provides creative plastics solutions for a wide range of industries. Established in 1998, Borouge is a joint venture between the Abu Dhabi National Oil Company (ADNOC), one of the world’s leading oil and gas companies and Austria based Borealis. petrochemical and plastics manufacturing plant is in Al Ruwais at about 250 km west of Abu Dhabi. In addition to our production site in Abu Dhabi, Borouge also has a Compounding Manufacturing Plant (CMP) in Shanghai which compounds resins from the Ruwais plant specifically for the Asian automotive industry.

Supply Chain Design & Planning Model

Need
As a world leader in polymer solutions, we required an established digital twin for its supply chain planning (more specifically logistic network optimization & simulation) and configurable assets. The initial transformation process focused on UAE production site, global supply chain network and operations, with an emphasis on cost and service levers. The need was to develop a digital twin within the first 8 months of the project. The solution was to be used as a strategic tool to define the optimal network. This was to be done by selecting the optimal Inventory Holding Point ("IHP") to serve customers based on associated costs, capacities and lead times.

Key Objectives
The primary objective of the Supply Chain Network Optimization & Simulation model was to optimize the Inventory Holding Point ("IHP") selection between Al Ruwais and the destination port to minimize network cost leading to better

Development Brief
The model was developed using:

Outcome
A Network Optimization Model utilizing applications like Supply Chain Guru X & Data Guru was created that lead to following outcomes and certain capabilities for the end user:

Results
This information has been utilized by various departments for orders executions. It is helping the business to better analyze data to optimize operations, enhance customer experience, and reduce costs.
Second-Level Heading.
Drilling the World's First Fully Sequestered Co2 Injection Well: Challenges, Execution and Lesson Learned
Authors: Arbadov Gurbandurdy , El-Husseiny Mahmoud , Sumaida Ali , Anwar Mohamed , Al Huwait Nada 
Published: November 2024

According to the Intergovernmental Panel on Climate Change (IPCC) and the International Energy Agency (IEA), carbon capture and storage (CCS) is crucial for meeting climate change targets. CCS is a key part of the UAE's sustainability strategy and its commitment to achieving net-zero emissions. The field operator initiated a major CCS project focused on permanently storing CO2 in carbonate deep saline aquifers. Following a rigorous feasibility study, the first CO2 injection well was drilled. The aim was to gather the data essential for asset management, ensuring wellbore integrity in CO2-rich environments, and advancing real-time monitoring capabilities.
The project employed several innovative techniques and methodologies to achieve its objectives. For the first time in the UAE, a permanent fiber optic cable was deployed behind a 7" casing to enable enhanced real-time monitoring. The project utilized CO2-resistant non-Portland cement globally for the first time to ensure the long-term integrity of the wellbore. Six coring runs were completed across intended cap rocks and target water reservoirs, and water samples were collected from the interest zone under expected loss formations. A TCP gun was used to perforate 600 feet of 9 5/8" casing in one run with a 100% firing success rate. Additionally, 3 ½" CRA tubing with dual fiber optic cables was run, and a deep-set surface-controlled subsurface safety valve (SSSV) was installed in the tubing. Custom wellhead modifications were made to accommodate fiber optic cable exits, and fit-for-purpose operational procedures were developed for the permanent deployment of fiber optics behind the casing. Feasibility studies, risk assessments, and de-risking strategies were integral to the project's execution.
The project reached a significant milestone by achieving 100% data gathering, meeting the asset's requirements, and marking several groundbreaking achievements along the way. One notable accomplishment was the successful mini frac operation across hard cap rock RUS, a first-of-its-kind operation in the UAE. This operation validated the feasibility of this formation to act as a caprock, crucial for ensuring the safe injection and containment of CO2. Moreover, the project was executed with zero HSE (Health, Safety, and Environment) incidents.
Advancements in Oil-Based Mud Micro-Resistivity Imaging - How Enhanced Dynamic Range Improves Feature Detection in Low and High Resistivity Formations
Authors: Elshurafa Basil , El Khamry Ayman , Osman Adham , Fakhry Waleed 
Published: November 2024

Abstract
Subsurface imaging is essential in exploration and field development, primarily for resolving and integrating geological complexities to the reservoir structures & depositional environments. Acquiring high resolution image data in non-conductive drilling muds has been one of the key challenges which led to the development of a new measurement technique in recent generation Oil Based Mud (OBM) imaging tools. Further challenges arise while acquiring high resolution OBM image in maintaining the quality across a broader formation resistivity range and with coverage in large borehole sizes. Among all, resolving features in both the high and low end of formation resistivity ranges was one of the most difficult to achieve.
Qualification of the new generation 8-pad / multi-frequency micro-resistivity imager tool was the primary objective which was deployed throughout the field-test runs. The tool was deployed in a number of selective wells covering a wide range of trajectories, hole sizes, lithologies and formation resistivities, stand-alone or combined with other existing OBM imaging technologies that utilizes similar or different measurement techniques. The result of the field-test runs outline the added value of each measurement independently and when compared and/or combined with others.
This paper delineates the principal characteristics of the new generation high resolution OBM imaging tool and presents key findings from the acquired image logs in variety of formation types, resistivity ranges and trajectories. Illustrative examples underscore the enhancement in image quality, dynamic range, coverage as well as the ability to resolve features for successful geological interpretation, decision-making, and risk management.
The results from this field testing marks an outstanding milestone on the range of apparent formation resistivities that can be covered using a higher number of frequencies with a broader range, show the value of combining different OBM imaging technologies for achieving optimum results.
Advanced Fault Diagnosis and Prognostic Maintenance Strategies for Continuous Operation of Permanent Downhole Gauge Systems
Authors: Mohammed Ali Dheyaa , Anuar W M Anas W Khairul , Kamat Dahlila , Amat Hadi , Choon Tan Boon 
Published: November 2024

Abstract
"Over the past thirty years, Permanent Downhole Gauge (PDG) systems have become essential in reservoir and production engineering. However, maintaining their ongoing functioning requires reliable fault diagnosis and proactive maintenance procedures. This study explores fault diagnosis methodologies and prognostic maintenance approaches specifically designed for PDG systems. The objective is to improve the reliability and longevity of these systems while minimizing non-productive time (NPT). By doing so, this research aims to enhance production efficiency and reduce costs in oil and gas development and production processes.
We perform a comprehensive evaluation of the current PDG behaviour, examine data collected from the field, and employ diverse fault diagnostic techniques to compile a list of spare components for internal maintenance purposes. The Plant Information platform consolidates data for monitoring and surveillance, facilitating real-time remote monitoring of all PDGs from an office setting. A significant obstacle faced by oil and gas operators is the decline in production efficiency and the rise in costs associated with development and production procedures. This study examines various approaches for identifying defects and their underlying causes, as well as predictive maintenance techniques aimed at ensuring the reliability and durability of PDG systems.
We investigate prognostic maintenance strategies, including as condition monitoring and predictive analytics, to identify imminent failures and improve maintenance schedules. The integration of these several techniques aims to enhance the dependability and efficiency of permanent downhole gauge systems, enabling uninterrupted data collection and prompt repairs to prevent expensive periods of inactivity. We assess the efficiency and real-world use of the suggested methods by creating a defect diagnosis database, maintaining an inventory of spare parts on-site, and integrating them with the Plant Information (PI) platform. The utilization of fault detection methods, root cause databases, various troubleshooting techniques, and the accessibility of spare parts collectively enhance the maintenance of PDG systems, hence ensuring their consistent and reliable operation in oil and gas production environments. This exercise enhances the flow rate by approximately 5 kbopd, reduces downtime by 47%, and minimizes the cost of slickline intervention by 35%."