bluuebunny/crossref_metadata_2025_split huggingface dataset:
Enhancing Asset Integrity by Gamma Online Scanning
Authors: Hussain Sikkandar , AlBahrani Mohamed , AlBreiki Mohammad , Razack Abdul Fathah 
Published: November 2024

Abstract
Performance of industrial static equipment depends upon its mechanical design and chemical process optimization. Any degradation of the static equipment due to corrosion issues and process abnormalities, can cause material degradation and huge production loss which eventually result in high revenue losses.
To avoid such scenarios and in line with ADNOC unwavering commitment towards 100% HSE and asset integrity, ADNOC GAS, Habshan-5 plant recently deployed Gamma scanning known as Accu-Scanning that works on the principle low curie radiography for scanning the entire static equipment surface. The purpose of this paper is to present the successful deployment and highlight the key benefits and value created from having such technology.
Using the conventional, such as Ultrasonic and Radiography methods for inspecting static equipment found to be challenging one and has its own limitations. To inspect such assets, the usual requirement of having complete isolation, manual entry and examine the condition of internals using conventional Ultrasonic and Radiography technique found to be time consuming activity and by which complete 100% inspection also not found to be feasible, due to large are coverage requirement and inaccessibility of the locations. Hence, it gives some uncertainty in evaluating the Asset Integrity of such static equipment. But, with this Gamma Scan technology that operates based on simple Radiography based technique, the complete thickness profile of the shell surface along with equipment internal insight being captured.
This Diagnostic scan in-addition to identification of thickness reduction along the periphery, it provides the condition of the internals, mechanical damages and hydra-dynamic abnormalities such as flooding that normally occur in the static equipment such as towers and columns. Moreover, this technology can be deployed during on-line condition, without the need of equipment shutdown and isolation requirements and the output produces massive digital and accurate measurements that can be later fully utilized to perform fitness for service and remanent life assessment in line with API.
Post-deployment and to validate the technology, the data obtained from the Gamma Scan has been validated with conventional Ultrasonic and Radiography, the results revealed more confidence on the technique that confirms the accuracy and reliability.
Looking ahead, having this massive digital accurate and reliable inspection date will be utilized in Machine Learning platform for future prediction to further optimize inspection intervals of Static equipment.
An Insight into Fracture Pattern and Characterization in Salt Dome Area
Authors: Zhang Sihai , Fu Xin , Cao Peng , Xu Ning , Liu Huifeng 
Published: November 2024

Salt halokinesis and salt domes are prominent geological phenomena in the southwest of the Arabian Gulf and influence the formation and evolution of the overlying fractures (Richard et al., 2017). These small-scale faults and fractures subjecting to multi-phase stress regimes show diverse and characteristic fracture patterns. The fractures play a crucial role in the production performance of the tight carbonate reservoir in the 4-way dip closure above the salt dome (Fig. 1). However, mapping the extremely complex and diverse fracture system in this region under multi-phase stress regimes presents a significant challenge. The objective of this study is to investigate fracture development under multi-phase deformation and characterize the complex fracture system of the Upper Jurassic in this salt dome-dominated area.
Understanding the fracture system is critical for optimizing drilling strategies and improving the accuracy of reservoir simulations from these tight carbonate reservoirs. Detailed geological and geophysical analyses are conducted to understand the formation and evolution of fractures influenced by tectonic activities. Multiple seismic attribute analysis, along with core examinations and dynamic data analysis, will be employed to gain insights into the orientation and distribution of fractures. This study aims to (1) provide insights into the insights into the dynamics of fracture systems in salt dome environments and (2) enhance our ability to predict fracture behavior under varying stress conditions and inform better reservoir management practices.
Sustainable Practices for ERD Cementing: Success Story from Arabic Gulf
Authors: Herrera Juan Isaias Sarmiento , Nino Adriana Contreras , Sasso Alejandro De La Cruz , Zuleta Rodny Masoud 
Published: November 2024

Abstract
Wellbore integrity is particularly complex during extended reach drilling (ERD) operations, and the curve section is one of the most complicated intervals. In the Arabic Gulf, reliable cement barriers in long horizontal sections are frequently compromised by weak formations, pipe standoff limitations, inadequate equivalent circulating density (ECD) management, and mud displacement issues. The application of advanced engineering practices and state-of-the-art cementing techniques under these conditions are highlighted and supported by discussion of successful case studies.
Robust engineering best practices and superior field execution were essential to meet operator requirements. Custom fluid designs were meticulously tailored and monitored to ensure optimal slurry and spacer performance. This included cement fluid-loss management, compressive strength development, enabling the spacer-to-bridge thief zones, exceptional bonding between the cement and wellbore, ECD control, and precise slurry placement within designated depths. The selection of casing hardware was also vital; the combination of centralizers improved standoff values, optimized torque-and-drag forces, and helped ensure the planned casing point was achieved. A specialized shoe-track arrangement was introduced to mitigate undesired cement consistency during drill out.
A campaign of seven wells were executed and deemed successful by the operator. Comprehensive evaluation through positive and negative pressure tests and cement bond logs (CBLs) demonstrated excellent cement coverage and bonding. Preapplication verification testing of all slurries with mixing fluid samples and location blends confirmed their readiness for flawless execution, with slurry behavior consistent with initial tests. Early development of set cement compressive strength and low slurry fluid loss were fundamental to minimize shoe-track contamination and achieve the necessary top of cement (TOC). Spacer and slurry designs and volume met fluid dynamics and mud removal requirements, which allowed ECD control and effective cement placement. Pressure values during pumping closely aligned with simulation results, which facilitated well-controlled execution and predictable job success. The appropriate selection of casing hardware enabled the crew to reach the casing point in each well and ensure sufficient standoff for optimal cement coverage. The operator's confidence in the design led to its use even when the previous casing was set beforehand, which allowed successful cementing of challenging zones traditionally left as pay zones.
The tailored solutions implemented in these ERD wells can help enhance best practices to achieve outstanding cement bonding and shoe integrity while cementing long horizontal pipe in weak formations with narrow ECDs.
Leveraging Machine Learning and Open Source Tools for Rock Image Characterization at the Pore-Scale
Authors: Al Ibrahim M. A. 
Published: November 2024

Executive Summary
A software for pore-scale rock image analysis and interpretation has been developed based on open source tools and libraries. The software focuses on specialized workflows and processes for rock characterization rather than image processing workflows and tools. Example workflows implemented include grain morphology estimation, rock component identification, carbonate rock classification, and palynomorph darkness index calculation. Overall, the developed workflows provide quantitative results, improves the accuracy and lowers the bias in the interpretation.
Navigating the Future of Maritime Operations: The AI Compass for Ship Management
Authors: Joshva J. , Diaz S. , Kumar S. , Suboyin A. , AlHammadi N. , Baobaid O. , Villasuso F. , Konig M. , Binamro A. , Saputelli L. 
Published: November 2024

Abstract
The maritime industry stands on the brink of a technological revolution, with artificial intelligence (AI) at the helm. This paper explores AI's transformative potential in ship management, where it is poised to redefine roles and responsibilities within the maritime workforce. With the potential to automate up to 300 million full-time jobs globally, AI's impact on route optimization, predictive maintenance, and decision support systems is significant. The research underscores AI's role in enhancing fuel efficiency and operational effectiveness, setting the stage for a new era in maritime operations.
Through a comprehensive methodological approach that includes a literature review, benchmark, case studies, and discussions with key stakeholders—ship-owners, classification societies, and technology providers—the paper analyzes the technical and financial impact of AI-powered initiatives. It proposes a novel AI-based decision support system tailored to the unique challenges of ship management. The paper outlines a detailed governance structure for AI adoption, reflecting the industry's shift towards smart, eco-friendly ships. This shift is projected to increase the number of technical employees in the industry from 35,549 in 2018 to 49,000 by 2028, highlighting the growing demand for skilled professionals in this evolving landscape.
The findings reveal that AI significantly enhances operational efficiency and decision-making capabilities through predictive analytics and real-time optimization. The integration of AI initiatives, such as digital twins, is identified as a key future enhancement, potentially offering substantial efficiency gains and risk mitigation. The study also notes that 6.5% of ships in operation and 51% on order are capable of operating on alternative fuels, reflecting a growing uptake of methanol, LPG, and the first hydrogen-fuelled newbuilds. This trend underscores the industry's commitment to sustainable shipping practices and the pivotal role of AI in achieving these goals.
The study introduces a pioneering AI framework for ship management, emphasizing the need for a custom AI evaluation framework to assess and prioritize AI technology applications across the maritime industry. It suggests that sustainable value creation can be realized through AI adoption models, enhancing collaboration and regulatory compliance. The research highlights AI's potential to revolutionize the efficiency, safety, and sustainability of maritime operations, presenting transformative insights for the industry's advancement.
Real Time Efficiency Based Energy Optimization
Authors: Sengupta Subhendu , Goveas Vincent , Al Seyabi Mathla 
Published: November 2024

Abstract
This paper is based on successful implementation of dynamic efficiency-based optimisation in Habshan-5 Utility Boilers
Objective was to Minimize Loss Opportunities in optimal Fuel Gas Consumption in Boilers while maintaining steam balance across Habshan-5 Utility Steam network.
Thus, scope was
To Implement efficiency-based optimizer that allocate load among boilers based on their dynamic efficiency instead of equal allocation
To Minimize letdown between STS and STL to minimum allowable while ensuring stability of both STS & STL headers
Maintaining header balance across steam system accounting all consumers and producers

Original Method
Original Operation was Equal allocation based on STS header pressure. Hi Selector based PID controls the letdown.

Drawback
Package Boilers though identical, differ in efficiency due to various reasons.
Similarly, WHRB also differ in steam generation efficiency from duct firing.
There is a significant efficiency difference between WHRB and Package boilers & respective fuel consumptions. Also, variation existed in let-down opening with scope for optimisation.
Advanced Energy Solution (AES)
To meet the improvement needs, M/s Honeywell Advanced Energy Solution coupled with Honeywell APC was used.
Economic Load Allocation of boilers based on cost curve generated from reconciled efficiency (calculated dynamically using ASME method) curve.
Non-linear economic load allocation of boilers considering all constraints & efficiency curves are reconciled at every execution.
Multivariable Predictive Controller APC minimise Letdown opening.

Project Outcome
First of its kind in ADNOC, this real time dynamic efficiency-based optimisation resulted in significant reduction in Fuel Gas consumption & equivalent amount of GHG 24.7K Tons. Apart from this, the implementation completed in record low time (6 months) with payback period less than 4 months
A Novel Approach to Reduce Energy in Crude Transfer Operations
Authors: Nachiappan M. , Baudry M. , Saleh Ahmed. , Al Ali H. Abdulazi , Venkatesan K. , Brahmbhatt H. H. , Alebri F. , Chandran J. , Al Qassab I , Eisa Z. M. , Kadyrov I. , Finkbeiner N. , Zecha L. 
Published: November 2024

Abstract
As part of its 2030 Sustainability strategy, ADNOC set an ambitious target of reducing operational Green House Gas (GHG) emission by 25%. Inspired by this strategy, ADNOC Onshore Task force teams partnered with Contractors to pursue new technologies and best practices.
Main Oil Pumping from field to terminals in ADNOC is one of the significant energy consumers. The quest for energy efficiency prompted ADNOC Onshore to identify energy losses in the main oil pumping facilities and explore means to reduce it as much as possible.
As an innovative approach, it was decided to conduct a trial for reducing frictional pressure losses in the pipeline by injecting a Drag Reducing Agent (DRA) and optimizing the number of running oil pumps.
By injecting DRA, it was observed during the trial that the frictional pressure loss in the pipeline can be reduced significantly. Depending on the concentration injected (tested concentrations ranged from 7 PPMv to 20 PPMv), these frictional pressure losses were reduced by 50% to 66%. This reduction in observed pipeline frictional pressure losses meant the station discharge pressure could be reduced while still maintaining the same pipeline crude flow rate. By reducing the required station discharge pressure, one of the running main oil pumps would no longer be needed and could be stopped. This resulted in power savings of around 33% in one system (2 pump utilization against normal 3 pump operation) fields and around 50% in another system (1 pump utilization against normal 2 pump operation).
This paper analyzes the outcome of the trial study carried out using LSPI's LP 111 Flow Improver (‘LP 111’).
Stake-Less Nodal Seismic Deployment Using Internal GNSS Receiver
Authors: Garden M. 
Published: November 2024

Abstract
Pre-surveying receiver point locations is extremely time consuming and unreasonably lengthen seismic acquisition projects if the planned receiver grid is very dense. An alternative is to approximately deploy receivers and then use receivers internal Global Navigation Satellite Systems (GNSS) device for their final position. After some cleaning, these positions have an acceptable accuracy to be used in the processing of the seismic data.
Receiver deployment does not need accuracy. In practice it was carried out using a hand-held GNSS device, but it could have been done using simpler techniques like line of sight or steps counting. On the contrary, final positions need accuracy so that processing tools work optimally. While one GNSS measurement is not precise enough, repeated measurements at the same position are refined and combined into a much more accurate final position. Accuracy obtained following this procedure is below three meters in most cases, thus acceptable for all seismic processing algorithms.
Tests performed on real seismic datasets show that perturbations of less than six meters for receiver positions does not adversely impact the seismic image quality. Based on these findings, it was decided to make use of GNSS-derived horizontal coordinates. The accuracy of these coordinates, taken individually, is low but by combining several days of GNSS readings, the accuracy can reach acceptable levels, to below three meters. Since geophone nodes are usually deployed to the same location for several days or even weeks, large numbers of GNSS readings are available to be processed into a single accurate position. Raw GNSS vertical coordinates are even less accurate than horizontal ones and cannot been improved adequately. Instead, a Light Detection and Ranging (LiDAR) survey over the entire seismic survey area, provided centimeter accuracy for nodal geophones' elevations. Such LiDAR survey does not need to be concomitant to the seismic survey and thus does not hamper the seismic survey schedule.
Modern land seismic nodal systems onboard GNSS receivers. While GNSS receivers are primarily used in nodes to define times for recorded seismic traces, they can also provide horizontal coordinates of an acceptable precision simplifying greatly node layout and removing the need for lengthy and costly surveying operations.
Wireless Control and Monitoring; The Next Generation Downhole Completions
Authors: Abbott J. , Forrest K. 
Published: November 2024

Abstract
Dynamic downhole well production management has been historically limited to cabled intelligent completion systems. This paper introduces a new technology that provides wireless communication, control, monitoring and autonomy while being retrofittable for existing downhole well completions. The technology has been field deployed in three variants to address different challenges: remediate failed safety valves, restore downhole monitoring and provide flow control at a given interval. The field application of this technology has proven the feasibility and long-term performance of this wireless command, control and monitoring system under downhole conditions. It has also demonstrated the cost and CO2 savings of retrofitting versus recompletion.
The tool is designed to be deployed or retrofitted in an existing completion and record downhole data, responding to wireless commands from surface or operating autonomously in response to a change in a well's flowing conditions. Most variants were deployed via slickline intervention with the option to retrieve later in the well life. The intelligent safety valve is a fully autonomous system, API14A qualified, device that enables the safe production of wells with failed downhole safety valves. This valve was installed in both oil and gas wells to restore production under a variety of challenging production conditions. The intelligent control valve was installed to provide commanded flow control of a long lateral with a late life risk of water. The wireless gauge was trialled for retrofit to replace a failed downhole gauge and allow continuous downhole measurements in wells without existing gauges. We will review the field applications of this wireless technology and discuss the challenges overcome through application.
The production of five wells was restored by retrofitting the wireless intelligent safety valve. The valve successfully operated under a variety of challenging conditions including cyclic loading, gas lift, velocity string and slug production. The intelligent control valve successfully actuated to provide zonal isolation on a subsea well without intervention. The wireless gauge provided pressure, temperature and gauge diagnostics on a daily basis while recording shut-in data at high rates to capture valuable transients during well shut in. This data was compared with existing downhole gauges as part of a trial to validate the technology. The retrofit ability of this technology significantly reduced environmental impact and overall project costs.
This is the first publication that describes widespread application of this technology to address industry challenges. This is one of the only wireless control and command technology that does not rely on repeaters. The two-way communication method utilizes pressure perturbations in the production fluids to transmit downhole data or tool commands. The communications protocol allows for communication with multiple devices in the well and independent of depth.
Innovative Approaches and Lessons Learned from Longest Slim Hole Smart Completion Wells with Hybrid Cable: Twin Fraternal Well Monobore Case Study
Authors: Antoro Robertus , Al Zaabi Alyazia , Baranek Bartlomiej , Jinqiang Xue , Qasem Khalifa , Malalla Mohamed , Mwansa Peter , Bahroom Abdulraman , Al Soliman Abdulkareem , Waka Turky , Tleulin Artur 
Published: November 2024

Abstract
This case study aims to break down the engineering and operational strategies, along with the challenges faced in deploying the longest slim hole smart completion wells, with hybrid cable in a monobore configuration. The slim hole monobore smart completion design with twin fraternal were required as part of the Reservoir Monitoring Plan (RMP) in the Simultaneous Injection of Miscible Gas and Polymer (SIMGAP) project. It is a pilot concept to perform Enhanced Oil Recovery (EOR) with the purpose of increasing recovery factor (RF).
The twin fraternal wells, equipped with water injector and oil producer, have been presented with challenges due to material availability for 7" liner, 3.5" tubular, and completion accessories. These requires for a slim open hole size of 6" for a monobore, a completion made of carbon steel (L-80) and chrome resistance alloy (CRA P-110), additional line and completion accessories for the oil producer, and a targeted total depth (TD) of 13,000 feet measure depth (MD) in water-based mud.
Slim hole monobore deployment and smart completion in one trip are challenging due to the risk of longer stationary time in the open hole that can lead to differential sticking. Additionally, the risk of buckling with the small size of the tubing, and well tortuosity itself. It opted for a hybrid cable to improve the completion process and reduce the number of installed lines. Critical steps included open-hole preparation, operational strategy, and detailed execution, all defined by a comprehensive approach.
The first well completion installation as a successful case for the water injector, using carbon steel (L-80) material without a centralizer in the open hole, Limited Entry Liner (LEL) configuration in the lower part, successfully reached over 12,000 feet. The second installation was unsuccessful for the oil producer, which used CRA (Alloy SM2535) with a feed-through centralizer, additional lines for chemical injection, gas lift mandrels, and a tubing hanger groove. Despite the unsuccessful landing and completion to the planned TD, the second well reached over 12,700 feet MD.
This application represents the longest monobore slim hole smart completion as a journey in the UAE onshore field, The fraternal wells reveal successes and lessons learned from the other case, emphasizing adaptability and continual learning for similar applications in the future and successful deployment.