bluuebunny/crossref_metadata_2025_split huggingface dataset:
First Multi-Zone Drill-Stem Test in the UAE Improves Operational Efficiency and Enhances Value of Information
Authors: Hassan Ahmed , Nuriakhmetov Ruslan , Al Hajri Saeed Salem , Sayed Sohdy , Belova Natela , Abdelmawgod Ahmed , Alloghani Jasim Ali , Sarac Sukru , Mugundan Mahidara , Radwan M. Sherif 
Published: November 2024

Abstract
Well testing is a critical stage of reservoir characterization. If not optimized, drill-stem tests (DST) can be time consuming when testing multiple formations in a well. This paper presents a case study for the first dual-zone DST performed in the UAE, to test 2 different zones individually in one single DST run. Significant operational efficiency gains, DST string design with multiple pressure gauges, multiple packers and wirelessly activated downhole tools will be explained.
In standard DSTs, non-value-added time such as running in hole, pulling out of hole, pressure testing the DST string and others can take 50% of the total test duration and cost. Operator companies may also test wells with simple completion strings to save time, but such tests come with limitations such as difficult downhole sampling operation (if possible) and challenging well kill operations. A dual-zone DST with wirelessly controlled downhole tools enabled to test 2 different zones individually. Multiple pressure gauges with real-time data transmission were used to monitor operations. Wireless downhole valves have controlled flow from different zones individually and enabled commingled flow.
Significant efficiency gains were achieved, and multiple operations were enabled with this first dual-zone DST performed in the UAE. Two zones were tested successfully in one DST run using the dual-zone DST string. A combination of 2 different packers were set in the well to isolate two zones from each other. Each zone was opened to flow through the DST string individually by two wirelessly controlled downhole valves. Pressure and temperature responses from each zone were recorded by multiple pressure gauges for pressure transient analysis. Downhole fluid samples were also collected with the built-in samplers on the DST string. Compared to two separate standard DSTs, 21 rig days and associated cost were saved with the use of the dual-zone DST string. In addition, compared to well testing with a completion string, downhole shut-in for accurate reservoir characterization was enabled. Despite high wellhead pressures that sometimes prevent wireline entry in the wellbore, wireline runs were performed without having to kill the well, enabled by the DST tools. Well kill operations were carried out smoothly by placing the kill fluid in the tubing with the use of downhole circulation valve.
The first dual-zone DST performed in the UAE has changed the well test philosophy from testing wells with a completion string to testing with DST. Efficiency gains and new practices are explained in this paper and can be applied to all well tests with multiple zones to test and enable new well test methods to enhance the value of information from well tests.
Utilization of Innovative CO2 Swelling Elastomeric Cement Integrity Sleeve as a Novel Well Integrity Enhancement Solution for Underground CO2 Storage Wells
Authors: Osorio A. , Vliegenthart A. , Vos A. 
Published: November 2024

Abstract
As the world aims to mitigate the climate-changing effects of global warming, intergovernmental regulatory bodies increasingly focus on greenhouse-gas emission reduction by implementing environmental policies to phase down fossil-fuel utilization and develop sustainable energy sources as part of global energy transition efforts. While various greenhouse gasses are emitted from a wide range of natural and artificial sources, human-produced carbon dioxide (CO2) is the primary driver of climate change as it accounts for approximately 70% of global greenhouse gas emissions (Olivier et al, 2020).
Efforts to reduce greenhouse gas pollution from the atmosphere have led to significant advancements in Carbon Capture and Storage (CCS) technologies, which aim to inject CO2 in underground storage wells with non-permeable formations capable of safe and permanent downhole containment. Furthermore, CCS is widely regarded as one of the most effective ways to mitigate climate change as recent studies estimate it could reduce CO2 emissions by 20% before the year 2050 (Elkatatny, 2021).
The planning and execution of a comprehensive CCS well integrity strategy is considerably more complex than conventional well integrity practices commonly found in the oil and gas industry. The hydration of supercritical CO2 leads to multiple carbonation reactions producing elevated concentrations of carbonic acid (H2CO3), which can severely degrade a cement barrier in radial direction and cause longitudinal cement defects. Concurrently, cyclic pressure and temperature fluctuations during long-term CO2 injection can compromise casing-to-cement bond, causing a potential leak path through micro annuli. These factors may lead to gas migration and subsequent Sustained Annular Pressure (SAP) buildup on surface, increasing the risk of direct CO2 leakage into the atmosphere.
An innovative CO2 Elastomeric Cement Integrity Sleeve (C-ECIS) has been developed specifically for the purpose of SAP prevention and well integrity optimization in CO2 storage wells. Distinctly different to a swellable packer, the C-ECIS was designed as a slip-on seal for external installation onto downhole tubulars. It is comprised of a novel swellable elastomer which utilizes CO2 as the primary swelling fluid medium for its volumetric expansion. It permanently swells and seals a casing-to-cement microannular flow path immediately upon direct exposure to gas migration within the casing-to-cement microannulus.
The C-ECIS is a unique technological innovation with the potential to transform the industry's current approach to CCS well integrity planning due to its simplicity and reliability. This publication provides an in-depth overview of the technology, its qualification process, and current field implementation status.
Combatting Mercury Threat in Sustaining Asset Integrity for Offshore Production Facilities
Authors: Nazori Q. Muhamad , Hamdan M. , Zulfa Z. Ahmad , Hashim W. Wan , Jaafar R. , Ali Z. 
Published: November 2024

Abstract
Mercury production from reservoir is exceedingly challenging to predict, especially at the development stage of the project with limited data. Therefore, it poses operational challenges during production and may possess integrity risk to the assets and downstream buyer. This paper offers a comprehensive evaluation of product quality, integrity, and economic assessment for an offshore facility in managing elemental and solid mercury, which could impact the downstream system.
A comprehensive approach was undertaken, encompassing the analysis of historical production data, including mercury data, sampling and analysis, mercury partitioning simulation, pipeline partitioning simulation, integrity assessment, particles analysis, solid computational fluid dynamic (CFD) modelling, impact on product quality, and mercury technology screening. Historical and sampling data, along with future forecasts, were analyzed to develop scenario for the production facilities. Based on this, the elemental mercury partitioning and drop out was simulated throughout the facilities and the pipeline, comparing with the actual production data. The result was used for elemental and solid mercury integrity assessment for the facilities.
Study indicates there are no clear correlation between the gas and mercury production. For elemental mercury, partitioning study indicated that elemental mercury would partition into the gas phase and some of the elemental mercury would be partitioned into the liquid when there are changes in operating pressure and temperature in the processing and transport system in the offshore facilities. During transport of fluid in the pipeline, most of the elemental mercury would partition into the gas phase. The mercury is still within the downstream mercury removal unit and sales agreement specification. The particulates mercury will mostly be at the liquid side where a solid mercury removal unit (MRU) had been installed. However, sampling result indicated smaller particles had been produced from the reservoir compared to the design stage. Computational Fluid Dynamic (CFD) study was conducted to evaluate the behavior of the particles. Based on study finding, there is no evidence to suggest that there is a threat to the integrity of offshore facilities or cross contamination possibility to gas phase. As a result, there are no requirement to remove the smaller particulates as it does not pose erosion risk. In addition, there is limited technology available in the industry for removal of sub-micron particles.
This paper provides a holistic and systematic approach on evaluating the impact of changes on mercury production to the existing gas production facilities. Understanding of the integrity and product quality threat would direct the operation's management in making the right decision on the technology investment.
Complete Workflow and Case Study for Thermal Dynamic Simulation of Carbon Dioxide Storage in Depleted Gas Reservoirs
Authors: Rahman Shah Abdur , Golaco C. , Stashevsky V. , Shaykhattarov M. , Rat C. , Chepik E. , Hasan H. , Shady M. , Robert M. J. , Guerra J. , Stojic S. , Povstyanova M. , Bentaher A. 
Published: November 2024

Abstract
Using a case study from the Sajaa Field, onshore Sharjah, United Arab Emirates (UAE), we devised several workflows to set up a fully thermal dynamic simulation case for carbon dioxide (CO2) storage in a depleted gas reservoir.
The construction of the thermal dynamic model started with the setup of dissolution tables for CO2. A published dataset to model CO2 dissolution was used. This was followed by the setup of enthalpy tables for each component of the equation of state (EoS). The thermal capacity of the reservoir and caprock formations was also computed while considering the mineral composition of the rocks. Additionally, the thermal conductivity of the formations was calculated and corrected for formation temperature, considering the mineral composition of the formation as well as the saturation of the rocks.
A thermal dynamic model enables the user to capture several important processes while injecting CO2 in a depleted gas reservoir. These processes include the wellbore changes of temperature due to expansion of injected fluid (Joule-Thomson cooling), the salting-out effect near the wellbore, and the impact of temperature and pressure changes on the rock mechanical properties for the reservoir and caprock. Dissolution is one of the most important trapping mechanisms for CO2. To capture the CO2 dissolution accurately, it is important to capture the dissolution changes with pressure, temperature, and brine salinity. The thermal properties of the reservoirs are crucial to capture the heat transfer between injected CO2 and the rocks.
Several novel workflows were established during this study, including setting up dissolution tables for CO2 and impurities being injected, tabulating the enthalpy of each component, and computing reservoir and caprock formations’ thermal capacity and thermal conductivity. This paper will provide a complete guideline for thermal modeling for carbon capture and storage (CCS) projects in a depleted gas field.
Mechanics and Kinematic Evolution of Structural Styles Associated with Fold-Thrust Belt- Evidence of Inversion, UAE
Authors: Noufal Abdelwahab 
Published: November 2024

Abstract
Oman Mountains deformation is being continued by massive thrust fault systems in Eastern Abu Dhabi basins with dissipating stresses laterally to the subsurface. Thrust faults with a strike-slip component that include a fault damage zone of strong rock shearing, and complicated zones of deformation. The initial episode was caused by the compressional movement of the Masirah, which faulted and folded again during the Semail tectonic events. Large faults are typically modelled on seismic as a single, large slip plane, but the outcrop analogues demonstrate the case is far more intricate, according to understanding of fault zone complexity and fault rock attributes. To understand the strength characteristics and seismic behaviour of faults in the subsurface, more in-depth information of the growth and structural style of thrust systems on outcrop analogues is essential considering the future exploration in eastern Abu Dhabi. Architecture, geometry, and tectonic uplift resulting from accumulated slip on the faults are all expressed at the surface that can express the geometrical prediction in subsurface.
The paper describes the geological features and evidence of inversion structures, such as anticlines, reverse faults, and detachment surfaces, using seismic data, well logs, and surface outcrop analogues. It also explains the kinematic models, strain rates, and restoration methods used to understand the structural evolution and deformation history of the region. It highlights the positive and negative effects of inversion tectonics on hydrocarbon generation, migration, and trapping, and how they vary depending on the fault orientation, lithology, fluid pressure, and tectonic context. It suggests that the Abu Dhabi basin has experienced multiple phases of extension and compression, resulting from the interaction of the Arabian and Eurasian plates, and that the strike-slip faulting regime has played a significant role in shaping the basin geometry and hydrocarbon potential.
This study has provided new insights into the geometry, timing, and driving mechanisms of thrusting deformation, as well as the regional tectonic implications of the fold-thrust belt. The fold-thrust belt can be further divided into three sub-belts, including the Northern Emirates zone, the eastern Abu Dhabi and the Abu Dhabi basin including onshore fields and further west. The former is characterized by imbricate stepped-thrust sheets composed of developed thrusts and related folds, and the detachment-fold sub-belt, which is composed of box, chevron, and closed overturned-isoclinal folds. The second eastern Abu Dhabi zone is characterized by thrust-fold sub-belt observed on seismic. The last western zone is mainly showing strike slip regime with few thrusts zones, which may due the transpressional regime between the fault segments.
Reactivating Oil Producer and Water Injector Wells Using Single Phase Retarded Acid and Fiber Optic Equipped Coiled Tubing
Authors: Maheshwari Y. K. , Subaihi M. H. , Almuharrami A. O. , Shaqsi A. K. Al , Leguizamon J. A. , Ahmad B. , Bashir A. , Delgado E. Franco , Mahmoud W. , Belkadi W. , Seoudy S. , Elattar A. , Ryan A. 
Published: November 2024

Abstract
This technical article outlines the implementation of single-phase retarded acid (SPRA) and its advantages over double-phase retarded acid systems. It follows an established Matrix Stimulation Engineering (MSE) workflow, leading to improved hydrocarbon production in an oil producer well and enhanced water injection in an injector well within the operator's field.
Previous stimulation techniques, employing a constant volume/feet dosage of hydrochloric acid via conventional coiled tubing (CT) in 6-inch open-hole horizontal wells targeting tight-carbonate formations, yielded inconsistent results and rapid declines in hydrocarbon production rates or water injection rates. In response, an MSE workflow was introduced in 2019 (Abdelrehim et al, 2020), incorporating fiber-optic-equipped CT and high-pressure jetting guns. Now, with the adoption of SPRA, the process is further optimized, leveraging slow acid reaction to enhance worm holing.
The understanding of formation damage plays a crucial role in designing appropriate matrix stimulation fluids. Pre-flush fluid system was designed and pumped prior main treatment for wellbore conditioning. To address damage bypass in tight carbonate formations, a novel single-phase retarded acid technology with a slow reaction rate was employed for deeper penetration.
Utilizing fiber optic cable as a temperature surveying logging device during injectivity tests allowed for the assessment of fluid distribution along the horizontal openhole section. This data, juxtaposed with petrophysical data and post-treatment production logs, empowered the engineering team to fine-tune chemical pumping schedules.
Implementing SPRA through the established MSE workflow facilitated selective fluid placement in target producing zones, leading to deeper penetration and enhanced wormholes. Consequently, there was a notable improvement in hydrocarbon production from producer well and increased water injectivity in injector well.
This article highlights the utilization of SPRA within a MSE framework, incorporating distributed temperature surveying (DTS) for assessment. It demonstrates SPRA's efficacy in enhancing hydrocarbon production and water injection in the operator's field.
The use of the SPRA has a positive environmental impact by reducing carbon emissions as a result of less volume, consequently utilizing less logistic and well operation time compared to regular acid or double-phase retarder acid systems.
Intelligent ESPs Diagnostic Model Based on Big Data and Machine Learning
Authors: Jiang Lu , Jiang LiPing , Guo Songyi , Xue Heng , Yang Lingfeng , Tang Xialan 
Published: November 2024

Abstract
There are various types of available data, with different data structures, dimensions, and intervals. Conventional big data algorithms can lead to poor interpretability. In this study, novel methods are proposed based on big data analysis and machine learning. First, the data are categorized into 4 pairs to build parameter analysis model: pump static data, pump dynamic data, production static data, and production dynamic data. Combining static and dynamic data to establish parameter analysis modeling and different data pairs adopt different modeling methods: current and voltage data adopt picture recognition algorithm, vibration data adopt time domain analysis, and production data adopt random forest algorithm. Then, a deep neural network is developed to couple four models to diagnose ESPs production status. All the models have high accuracy through optimization. In the end, a management platform had been established for ESP wells including data visualization, production analysis, fault diagnose and warning. Visual production dynamic tracking management can improve the management efficiency of ESP wells and reduce the cost of future workover and relocation.
The Impact of Artificial Intelligence on Cybersecurity
Authors: Basu Amit 
Published: November 2024

The digital revolution over the last several decades has ushered in an era of unparalleled dependence on interconnected information systems. The smooth functioning of modern society, its critical infrastructure, from power grids and financial institutions to healthcare networks and communication channels depends on information technology. However, this reliance has also created a fertile ground for cyberattacks, posing significant risks to national security, economic stability, and public safety.
Cybersecurity involves protecting information systems and networks from unauthorized access, use, modification, or destruction. It is essential for ensuring the confidentiality, integrity, and availability of data and services, and for safeguarding the privacy, security, and trust of individuals, organizations, and societies. Cybersecurity is a dynamic and complex domain, characterized by the constant evolution and escalation of cyber threats, the rapid development and adoption of new technologies, and the diverse and conflicting interests and values of various stakeholders. It requires a multidisciplinary and holistic approach, involving technical, human, organizational, and societal factors, and addressing the technical, ethical, legal, and social implications of cyber activities.
Over the years, cybercriminals have evolved into highly organized and sophisticated entities, resembling traditional crime syndicates with clear hierarchies and specialized roles. They collaborate extensively and use advanced techniques such as zero-day exploits, sophisticated malware, and social engineering tactics like spear phishing. State-sponsored actors and cybercrime syndicates leverage the latest technologies to automate and enhance their attacks, exploiting vulnerabilities in target organizations. Financial motivations drive them to use cryptocurrencies for anonymous transactions, fueling the growth of ransomware and cyber fraud. Their global reach and ability to target critical infrastructure pose significant challenges, necessitating continuous advancements in cybersecurity measures and international collaboration to effectively counter these threats. Traditionally cybersecurity measures are often reactive and limited in their ability to cope with the rapidly evolving threat landscape.
Automatic Electrical Wiring Inspection with Advanced Computer Vision Models
Authors: Valvano G. , Rossi A. , Caridi G. , Vanzo G. , Politano A. , De Magistris G. , Salusti L. 
Published: November 2024

Abstract
Safety and reliability are paramount in energy industries. In this context, guaranteeing precise electrical wiring connections within terminal blocks is crucial for maintaining quality standards and enabling efficient remote support for on-site installations. Unfortunately, the current wiring quality checks are time-consuming and repetitive, and they are prone to human errors. This situation has led to an increasing interest in leveraging the capabilities of Artificial Intelligence (AI) to expedite the inspection process. AI assistants can either help in or completely automate the tedious checking operations, thereby enhancing operational efficiency. In this work, we introduce a novel approach that can be used to automatically verify the correctness of wiring connections to a terminal block. Our proposed methodology consists of a series of sequential operations, each contributing to the overall effectiveness of the system. First, we use an instance segmentation model to identify and isolate the connections between PINs and wires on a terminal block image. Then, we use text detection and recognition models to translate the pixels into an alphanumeric string. Lastly, we parse the obtained strings and compare results with the expected wiring connections in a reference database. Our proposed approach is not only simple and modular but also highly effective. It only requires a camera and a mobile device, and it swiftly generates a comprehensive report about the wire connections that are under inspection. This method is not only fast, but it also demonstrates promising performance levels (e.g. detecting connections with Precision and Recall &gt; 96%), thereby confirming the potential of AI-based systems in revolutionizing the inspection process. With our work, we underscore the potential of AI-based systems in advancing traditional processes and setting new standards for efficiency and accuracy in the energy sector.