bluuebunny/crossref_metadata_2025_split huggingface dataset:
Axial Resonance Troubleshooting and Resolution of an Induced Draft Fan
Authors: Ashour Mohammed , Shalabi Mustafa , Ganesh Sankar , Piton Nicolas 
Published: November 2024

Abstract
This case study is focused on accurately identifying the root cause of the observed resonance on the induced draft fan bearing in the axial direction, by analyzing the vibration data during steady state, and transient modes recorded during frequent balancing jobs. Also, the interpretation of Modal Analysis testing for the fan rotor in the fixed and free-free conditions to identify the influence of the structure support stiffness on the system natural frequency (bearing dependent modes).
During normal operation of the fan, it was observed that vibration response in the axial direction is increasing gradually and exceeding the trip limit, however the vibration levels reduced well below alarm limit after fan cleaning and balancing. Each fan required balancing almost 3 times yearly which affected the plant availability. Closer look on the vibration levels before balancing showed that axial vibration level is more than 5 times the horizontal vibration levels. 1X vibration polar plots in the axial direction during startup and shutdown showed phase lag around 70 degrees between full speed 1X vibration vector and low speed 1X vibration vector, to be understood that the fan is approaching a natural frequency close to running speed.
Modal Analysis study carried out on the fan rotor components (blade, impeller fixed mode, and impeller free-free mode), which revealed that the amplification of the 1X vibration observed in the axial direction is due to resonance, as the fan most likely found to be running at speed close to a lightly damped rotor natural frequency (first rigid mode).
It was concluded that, a change in the structure support stiffness is the root cause for this resonance condition, and it was recommended to inspect the fan rotor housing and supports to find out a resolution for the resonance condition in the axial direction and to shift the natural frequency with enough separation margin away from any forcing frequencies (i.e., 1X … etc.).
After site inspection and multiple investigations, the root cause of the change in the structure support stiffness was identified to be because of improper tightening torque during fan installation, which was changed as per OEM recommendations. Same solution was applied on all induced draft fans onsite (10 fans in total). Later, fans showed stable vibration levels for longer operation periods without the need for frequent balancing activities.
Revolutionize Alarm Management: Streamlining Processes with RoRPAic Process Automation (RPA) for Dynamic Attribute Tables
Authors: Al Kalbani F. , Al Abri A. 
Published: November 2024

Abstract
Alarm management is a critical component in various industries, essential for the timely detection and response to system anomalies and failures. The cornerstone of effective alarm management is the comprehensive preparation and maintenance of variable tables that accurately map alarms to their associated attributes. Traditionally, this task relies heavily on manual data entry, which is not only time-consuming but also prone to human error and resource-intensive. To address these challenges, we are introducing an innovative approach that leverages Robotics Process Automation (RPA) to automate the preparation of these variable tables. The integration of RPA into this process offers several significant advantages: enhanced efficiency by drastically reducing the time required for preparation and maintenance, improved accuracy by minimizing human involvement and thereby reducing errors, and optimized resource utilization by freeing up personnel to focus on more strategic and value-added activities. Additionally, RPA provides a scalable solution capable of handling large volumes of data without compromising performance or accuracy. This novel approach not only streamlines the process of alarm management but also sets a new benchmark for how industries can harness advanced technologies to enhance operational efficiency and reliability. By adopting RPA, organizations can achieve higher levels of accuracy, optimize resource utilization, and scale their operations more effectively, ultimately leading to improved overall system performance and resilience. Furthermore, we are planning to replicate the success of RPA in the Control and Automation (C&A) discipline and extend its application to the preparation of other critical deliverables, such as the instrument index, load list, and line list. Our efforts also include making this innovative solution available in the cloud, enabling other engineering design consultants to fully benefit from the efficiencies and improvements RPA offers, facilitating broader access, collaboration, and scalability for enhanced project execution and seamless workflow integration.
A Flexible Digital Approach to Monitor Offshore Chemical Applications on Floating Production Storage & Offloading Units Chemical Application Monitoring
Authors: King J. G. , Shetty S. S. , Smith D. W. 
Published: November 2024

Abstract
Offshore operators often deal with siloed or delayed data in their daily chemical program management. By integrating flexible data systems with an operator's preferred platforms, offshore teams can proactively manage chemical programs, significantly reducing the risks of non-productive time (NPT) or regulatory noncompliance. To begin this approach, stakeholders evaluated the reporting requirements to determine the necessary digital product modules.
Typically, a web-based SaaS chemical reporting application serves as the primary user interface. By collaborating with stakeholder teams, including FPSO integrators, operator subject matter experts, networking, and cybersecurity teams, to identify data sources, instrumentation, networks, and software in use or planned for the FPSO, including connectivity to onshore systems. After gathering and analyzing this information, a solution was proposed which included the required connectivity, telemetry, data movement, persistence, alerting, and reporting. This ensures the optimal management of chemical applications.
This approach was implemented on two FPSOs, establishing best practices for monitoring process temperatures, pressures, and flows using time-series historians. These systems proactively managed chemical inventories, application rates, and lab results, optimizing the utility of chemical programs and providing up-to-date operational data while leveraging the customer's existing infrastructure. The successful integration of offshore data from instrumentation and laboratory tests with onshore SaaS visualization and custom reporting was achieved despite the varied software, processes, and cybersecurity profiles of different operators. This required expertise in industry standards, open protocols, and close collaboration with multiple internal and external teams.
The flexible, modular approach on these projects to digital monitoring of offshore chemical applications on FPSOs has proven effective, regardless of variations in instrumentation, software, and cybersecurity across different organizations. This integrated digital solution marks a significant advancement in chemical program management on FPSO platforms, with the potential to enhance reliability, safety, and efficiency across the industry.
A Dynamic Workflow of Back Pressure Reduction Leading to Well Uptime Maximization
Authors: Al Silwadi B. , Kurokawa S. , Albishr M. , Al Marzooqi K. , Al-Hajeri A. 
Published: November 2024

Abstract

Objectives/Scope
Field XX is a brown field that has suffered from a high pressure sealine system for decades limiting the productivity of oil producers. A multi-disciplinary task force was established with the primary objective of innovating solutions to reduce the sealine pressure and benchmark these solutions versus potential production gain and economic feasibility.

Methods, Procedures, Process
The main challenge that was encountered to reduce the high sealine pressure includes the identification of the root causes As a result, a multi-disciplinary taskforce was developed in which five projects were identified to reduce the back pressure including acceleration of a 24″ between production complexes, offloading production from one complex to another, utilizing wellhead compression solutions, radial pressure reduction through inlet control valve design, and introduction of drag reducing agents. Each of these aspects was validated through nodal analysis, a coupling model, and the dynamic simulation model combined with the economic friendliness of each item.

Results, Observations, Conclusions
A multi-disciplinary task force used brainstorming and innovative workflows to verify five opportunities for reducing back pressure impact. The assessment to evaluate and verify the added value of each opportunity includes:

Novel/Additive Information
This paper is a clear demonstration of collaborative expertise demonstrating innovative mentalities and collectively identifying innovative solutions to a historic production bottleneck. The utilization of subsurface and surface combined solutions has proven to be extraordinarily successful in unlocking hidden barrels of oil with minimum investment requirements. The contents of this paper can be cascaded to multiple brown fields on a global scale to enhance production in an immediate time frame without jeopardizing reservoir health.
Petrophysical Challenges and Impact of Bitumen Quantification in Reservoir Rocks
Authors: Singhal Manu , Al-Abri Ahmed , Jarratt Thomas , Zhan Lang 
Published: November 2024

Abstract
Conventional reservoirs with bitumen pose a challenge to accurately quantify its presence and impact on reservoir producibility. Due to the presence of bitumen in the reservoir, which can be in the form of pore lining, pore fill and/or pore throat blocking, reservoir connected porosity and permeability is impaired. If volume of bitumen is not correctly quantified then hydrocarbon in place, completion decisions, reservoir producibility and ultimate recovery is impacted.
Basic logs often do not have sufficient contrast to differentiate bitumen from hydrocarbon in the reservoir, hence, advanced logs viz. NMR and spectroscopy logs are required to identify bitumen and its quantification. An in-house simultaneous multi-sensor inversion algorithm is developed to quantity lithology and fluid volumes which are then calibrated with available conventional core data.
This paper outlines a workflow to accurately quantity bitumen in the reservoir with the integration of logs and core. Detailed thin sections, core sedimentology, digital rock and petrography work has been integrated with logs to quantify bitumen and assessing its impact on reservoir properties. Moreover, impact of bitumen presence on reservoir producibility is assessed with production data and PLT acquired across the reservoirs of interest. Reservoir properties modelling workflow to build static model is also discussed to generate static model with bitumen variation and thereby assessing its impact on hydrocarbon in place and ultimate recovery.
Enhancing Reservoir Model Agility: Integrating New Drilling and Performance Data into Business Planning - A Case Study
Authors: Al Ali M. Y. , Ebeid M. , Alkhatib M. , Khattak I. 
Published: November 2024

Abstract

Objectives/Scope
This paper tackles the challenges of field development planning and optimization in a green onshore oil field where production data is limited. An agile workflow was employed to enhance the existing reservoir simulation model, preparing it for the selection of the optimal field development plan (FDP) while accounting for uncertainties. Subsequently, the paper reassesses the FDP considering the performance of wells drilled during the execution phase and the necessary updates derived from acquired data.

Methods, Procedures, Process
Through a comprehensive uncertainty analysis, multiple subsurface realizations were generated. A wide range of development scenarios and options were screened considering the uncertainties. Viable scenarios were then economically evaluated, leading to an optimal Field Development Plan (FDP) that not only addresses uncertainty robustly but also minimizes economic risk. The workflow employed was particularly suited to integrate new geological, drilling, and petrophysical data for updating the reservoir geological model. The challenges this workflow addresses include:

Results, Observations, Conclusions
The most robust development concept was chosen and analyzed, taking into account various viable development strategies such as plateau rate, drilling schedule, phasing, water injection timing, and artificial lift timings. A phased development approach was adopted, allowing for the acquisition of necessary data to reduce remaining uncertainties and prevent costly consequences of significant over- or under-capacity. Data obtained in one development phase were assessed and used to potentially update subsequent planned phases. The study revealed that field development could tolerate a delay in either water injection or artificial lift implementation. While it wasn't recommended to delay either at this stage, it's important to note that a potential long lead time in artificial lift implementation or the risk of lower injectivity wouldn't significantly impact field performance or ultimate recovery if contained within a few initial years of production. These findings further underscored the robustness of the proposed development plan.

Novel/Additive Information
Addressing large subsurface uncertainty alongside an extensive array of potential development scenarios necessitated cutting-edge uncertainty analysis and screening workflows to identify the optimal Field Development Plan (FDP). These innovative workflows, tailored for such unique challenges, hold significant promise for application in similar green fields. Detailed descriptions of these workflows will be provided in the paper.

Category (Complete)
056: FIELD DEVELOPMENT: Innovative Oil Development Plans and Case Studies
Post-Frac CT Intervention: An Overview of the Evolution of Practices in Extended Laterals in Unconventional Resources
Authors: Al Mulhim F. A. , Aldubikhi A. S. , Baki S. A. 
Published: November 2024

Abstract
This paper investigates post-frac Coiled Tubing (CT) intervention in extended lateral wells to evaluate the job design and the procedures implemented and how they dictate the evolution of practices, with more experience gained through the execution of many intervention operations.
This paper will be conducting a systemic assessment on the latest improvements in CT intervention practices. In addition, a hindsight review of the evolution of practices will be presented. Following that, the steps undertook to tackle extended laterals for postfrac are revisited and assessed, further exploring the key enablers that allowed that milestone to be achieved repeatedly.
In addition, the paper covers an overview on the evolution of practices in extended laterals as experience in intervening these wells increase. This will include best practices, an overview of the current level of efficiency, enabling technologies, and the new challenges to overcome paving the way forward.
Upon looking at post-frac CT intervention, namely frac plug mill out, an improvement in practices is clearly noted with time. This improvement was enabled using tapered coil tubing string design which improved overall lateral reach, in addition to the use of specialized bottom hole assembly components such as hydraulic extended reach tools to aid in maximizing reach limits overcoming commonly faced issues like lockups and buckling. However, the changes identified new challenges and bottlenecks that require further studying and trialing to finetune the progress of CT operations moving forward.
Preliminary results from the analysis done indicated that in CT milling operations, BHA components like motors and hydraulic extended reach tools are likely to be the new bottlenecks that dictate the progress and the smoothness of operations. A key enabler to overcome the bottlenecks presented and to fully unlock the potential & reach of CT intervention in extended laterals is to effectively work and collaborate with vendors and service providers to ensure tools are designed with a fit-for-purpose objective in mind.
Such overview of the evolution of CT intervention in extended lateral wells will allow operators and service providers to maximize the lateral length of horizontal wells confidently, therefore, increasing the overall reservoir contact. This can all be done with mobile CT units, which will save valuable rig time in addition to being safer and more efficient.
Innovative Multitrip Method for All-Electric Intelligent Multilateral Completions in Extended-Reach Wells
Authors: Fedorchenko E. , Musayev R. , Abramov Y. , Revheim K. , Agu D. , Warden A. 
Published: November 2024

Abstract
The multitrip all-electric multilateral well completion system with applicability also for in-lateral monitoring and control is a groundbreaking approach to well completion that provides both reliable deployment and reservoir management. It incorporates a first-of-its-kind wireless deployment system, for which the experiences and lessons learned by a major service provider and operator throughout the project are reviewed. The application of this tool is not limited to this specific deployment but can be incorporated in multilateral completion designs and deepwater applications. Applicable for even the most challenging environments and well completion designs, this technology is another step forward to achieving electrification of oil and gas well completions.
How Midstream Companies are Enabling CCUS: A Case Study
Authors: Mohammadi A. , Al Balushi B. , Al-Mujaini N. 
Published: November 2024

Abstract
Carbon capture, utilization, and storage (CCUS) is a crucial pillar in the global decarbonization journey. The deployment of CO2 transportation infrastructure is pivotal to enabling successful CCUS value chains. This paper explores how OQ Gas networks (OQGN), Oman's exclusive natural gas transmission network owner and operator, is overcoming various challenges, from technical to commercial to regulatory, to develop Oman's open access, multi-user CO2 pipeline transmission network, linking CO2 emission sources to sinks.
To conceptualize a national CO2 pipeline network, OQGN has followed a robust methodology in determining the CO2 market forecasts across the country, consisting of stakeholder engagements, the release of a CO2 market survey, while also examining significant emitters and respective sinks. A techno-economic analysis of the network was also conducted, as well as assessing viable commercial model options and the strategies and economic regulations needed to futureproof the network. Policies and regulations are crucial to accelerating CCUS uptake as they provide clarity and assurances to investors, lenders, and societies. In addition, OQGN is providing input to Oman's Policy Maker on CO2 transport regulations to define robust legal frameworks that ensure the health and safety of people and the environment while concurrently aiming to ease regulatory burdens.
Based on the CCUS market projections, OQGN anticipates three CCUS ecosystems to be established in Oman: a Northern Ecosystem, a Central Ecosystem and a Southern Ecosystem; the ecosystems connect major emitters mainly located in coastal industrial areas to utilization sites further inland. The price cap model is concluded to be the most optimum due to its flexibility and adaptability. Moreover, futureproofing the network can be ensured through oversizing as well as through specific economic regulations or government support.
This paper provides a case study of how a midstream company is growing its portfolio to transport a new commodity in a nascent sector, leveraging its expertise to address key challenges, and ultimately enabling a low carbon economy.
Advanced Reservoir Permeability Distribution Prediction: A Discrete Cosine Transform-Based History Matching Workflow
Authors: Hamady Abdelrafae El , Gharieb Amr , Diaz Alberto , Bogachev Kirill , Eydinov Dmitry 
Published: November 2024

Abstract
Reliable reservoir simulation is essential for effective reservoir management in the petroleum industry, as it enables engineers to make well-informed decisions on production strategies and resource allocation. However, accurately calibrating reservoir models to match observed field data remains a significant challenge. This difficulty primarily arises from the inherent uncertainties in key parameters such as permeability and porosity, which are crucial for predicting reservoir behavior and performance.
Traditional history matching methods, which involve adjusting reservoir parameters to align simulated models with observed production data, often require substantial computational resources and can produce multiple solutions that do not necessarily reflect the true reservoir conditions. These methods typically rely on extensive trial and error, leading to models lacking geological accuracy and realism. To overcome these limitations, there is increasing interest in applying advanced mathematical techniques and intelligent algorithms that offer more efficient, precise, and geologically consistent solutions.
This paper introduces a novel workflow for enhancing the accuracy and efficiency of history matching in reservoir simulations using real-field data. The approach addresses uncertainties in permeability and porosity relationships, particularly when modifying relative permeability (RP) might conflict with lab-measured data. A multi-objective Differential Evolution algorithm is employed to tackle these uncertainties, reduce randomness, and identify optimal solutions along the Pareto front. This process is followed by Principal Component Analysis (PCA), used for clustering all optimal solutions along the Pareto front, leading to several clusters of well-matched oil/water (O/W) models.
Finally, the Discrete Cosine Transform (DCT) is applied to capture key reservoir features and expedite optimization. By converting the permeability array into the frequency domain, the DCT achieves significant data compression while preserving essential geological characteristics, thereby reducing data complexity and enhancing the efficiency and accuracy of history matching. The methodology culminates in integrating the matched O/W models with bottom-hole pressure (BHP) data, resulting in comprehensive O/W/BHP matched models. This framework minimizes uncertainties and provides an efficient, systematic approach for improving history matching in complex reservoir simulations.
Enhancing Concentrated Solar Power (CSP) with Geothermal Energy: A Geothermal Battery Approach
Authors: Agson-Gani P. H. , Roshan H. , Regenauer-Lieb K. , Rahman S. 
Published: November 2024

Abstract
This study presents an innovative approach to integrating concentrated solar power (CSP) with ultra-high-temperature underground thermal energy storage (UTES) as a geothermal battery for power generation. UHT-UTES is a combination of a CSP plant and a Geothermal Battery. The system consists of two main wells, a Brayton cycle and an Organic Rankine Cycle (ORC), which are used to convert the heat from the CSP into electricity. The ORC is used to extract heat from the CSP and the ORC is used to extract heat. The analytical solution is based on a one-dimensional (1D) approach to calculate the heat injection cycle in the battery, employing a one-dimensional approach. The numerical results show that the system can maintain more than 94% of its initial output capacity after 30 years, demonstrating the potential of this hybrid approach to enhance the longevity and reliability of renewable energy systems. The study further shows that the effectiveness of the UHT-UTES system depends on site-specific parameters, such as Direct Normal Irradiance (DNI) and subsurface temperatures.