bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Bayesian Optimization Workflow for Integrated Asset Management Under Uncertainty
Authors: Taha T. , Abdallah M. , Shabani M. , Gringarten E. 
Published: February 2024

Abstract
To improve production under existing facility operating constraints, while minimizing emissions and energy consumption, operators today are looking for workflows that integrate surface and subsurface models as a foundational pillar of the digitalization of oilfield operations.
In this work, we investigate the investment and operational planning of a multi-field asset development under uncertainty. Our solution is an integrated workflow for scheduling, forecasting, and optimizing the multi-field asset across the entire value chain, from the subsurface reservoirs to delivery to market.
Our integrated operation and optimization workflow example consists of one gas condensate and two oil reservoirs models, coupled to a common production surface network model, itself connected to a processing facility model, together with an economic model. Consistent PVT properties have been used throughout the system. The thermo-hydraulic performance of the production network is modelled using a drift flux based mechanistic approach. Operational constraints are honoured on wells, surface network, and processing facility.
Our proposed solution is built in a commercial integrated asset management platform that connects the models and orchestrates their execution and optimization.
We have successfully integrated the subsurface, gathering systems, and surface facility models. This integration has allowed us to better understand the behaviour of the field and optimize its operation. By combining data and workflows across multiple disciplines, we can make informed decisions more efficiently and more reliably and mitigate risk with confidence.
Bayesian optimization offers an alternative solution to traditional ensemble methods by using probabilistic surrogate models that can capture and propagate uncertainties from multiple disciplines without the need for large ensembles.
The solution is equipped with unified analytical and diagnostics dashboards for the multidisciplinary technical asset team including management for decision making under uncertainty.
This is a truly part of a digital twin of the oilfield with improved asset management under uncertainty in the era of digital transformation.
Unveiling the Stability of Modified Graphene: Insights Through Visual Observation and Light Scattering Technique
Authors: Murtaza Mobeen , Rana Azeem , Kamal Muhammad Shahzad , Alarifi Sulaiman , Mahmoud Mohamed , Saleh Tawfik A. 
Published: February 2024

Abstract
Graphene is an extraordinary two-dimensional material that demonstrate the application in various field, including utilization in the drilling fluid for the friction reduction and fluid loss control. However, the drilling fluid applications of graphene are limit by its tendency to settle over the time, that tremendously reduced the efficiency of the drilling process. In order to overcome the settling effect, the modification of graphene could be employed. In the current study, the electrochemically exfoliated graphene modified by incorporating Gum Arabic to improve the aqueous suspension stability in water. The transmittance and backscattering measurements were assessed over time to analyze the stability of the graphene dispersion. The stability indices obtained from the transmittance and backscattering profiles provide quantitative comparison of settling rate of the modified graphene with that of unmodified counterpart. The experimental outcomes of light scattering technique (LST) and visual observations revealed the lowering of settling problem and the improvement in the dispersion features of the drilling fluid. The assessment of the stability index revealed a prominent reduction in sedimentation and increased dispersion stability of the modified graphene solution as compared to the unmodified graphene. Furthermore, the modified graphene displayed prolonged settling rate that was much lower than unmodified electrochemically exfoliated graphene. These outcomes indicate that the Gum Arabic prominently improved the dispersion of graphene in water. Consequently, the Gum Arabic modified graphene boost the fluid loss control and decrease the fluid friction that conspicuously improve the overall efficiency of drilling fluids. The addition of the modified graphene to drilling fluid improved the dispersion stability, fluid loss control, and fluid friction that make it suitable for the diverse drilling applications.
Well Collision Risk Management by Fully Automated Wellbore Surveying
Authors: ElGizawy M. , Zackman N. , Hernandez J. , Gomez F. , Row A. 
Published: February 2024

Abstract
A survey program is designed for every well to meet the well objective of penetrating the target reservoir and avoid colliding with other offset wells. The selection of the wellbore survey tools within the survey program is limited in number and accuracy by the surveying technologies available in the industry currently. Quality Control QC measures are regularly in place to ensure the wellbore surveys’ accuracy is validated. However, wellbore surveys often delivered without conducting the full QC measures and sometime are delivered with failing QC measures. This increases the risk of missing the survey program's objective and more critical escalates the risk of the well collision with other wells.
Hence, quality control of survey correction is a key to the success of the overall objectives of the well construction. As automated survey-correction software is becoming commonplace among oil and gas operators it is important to consider its use in relation to the overall well risk management strategies. This paper is presenting the latest developed automation workflows to strictly guarantee the quality control and quality assurance of the wellbore survey while placing the well in real-time.
Automated Survey QC and correction platforms go a long way to reduce gross error or human related errors with algorithms and machine to machine data transfer protocols. Automated survey QC and correction platforms can be key components in robust risk management solutions for well construction. When implemented appropriately, they allow quick and automated quality check and corrections on wellbore trajectory position which is critical in Anti-Collision and tight target wells. Even though the correction platform is automated it still requires clarity and confidence in the algorithms. This can be achieved with features that are easily accessible, clear, and understandable to inexperienced users. In addition, there should be readily reachable domain experts who can confirm and further interpret the results quickly and clearly, especially when well objectives are in peril of not being met.
In this paper, automated survey QC and correction enablers are detailed. How quality control of survey correction are automated, strictly controlled and easily auditable. Additionally, case studies of well construction risk management are presented as well as the successful proof of eliminating human/gross error and non-compliance are demonstrated.
The wellbore position is calculated using wellbore surveys. The fact the surveys inherit errors due to tools and environment, the quality of surveys must be ensured and corrected in real-time. The presented technique automates the survey QC and correction process in real-time with a main objective to minimize the risk of colliding with another well or missing the production zone targets while being part of a robust risk management structure.
Seeing Beyond the Obscure Fluid: How an Enhanced Production Logging Approach Helped to Improve the Workover Design
Authors: Mirza W. H. , Khan M. T. , Saud R. , Espinoza I. B. , Farooq U. 
Published: February 2024

Abstract
Typically, well workovers are performed based on production logging results. However, efforts to shut down water-producing layers may result in the opposite effect, such as increased water cut and decreased oil production. Hydrocarbon inflow behind the stagnant water at the bottom of the well that cannot be measured by typical production logging tool (PLT) sensors and may cause interpretation errors. As no alternative tools are available on the market, an enhanced evaluation approach is required to interpret the hydrocarbon inflow behind standing water column.
Characterizing producing intervals in heterogeneous reservoirs with various saturation levels and low pay is difficult with only open-hole (OH) logs. A standard PLT approach based on spinners and density readings may not identify the oil and gas entry across stagnant water in vertical wells. Therefore, an enhanced procedure for PLT was developed. The flow behind the static or moving water column was first identified using a combination of pressure derivative (dP/dZ), temperature (dT/dZ), and density data. The zones with high dP/dZ fluctuations were used for potential hydrocarbon inflow. Secondly, the weighted average of the density trend was used to break down the potential hydrocarbon entry behind the water. The dT/dZ variation was input into the HC exact production. The OH results used for PLT correlation improved the final interpretation.
Two cases with multiple historical PLT were evaluated for this study. In Case 1 (Well x02), PLT was carried out three times over a four-year period, and the water cut increased following production based on the standard interpretation. Different workovers were attempted to shut off water inflows, both successful workover that led to a 27% increase in oil production and a 68% decrease in water production was possible after the improved interpretation of three-phase flow from the enhanced PLT approach. In Case-2 (Well x06), the new technique confirmed a masking behavior of water to the wellbore fluid flow, and the interval above was selected to guarantee the evaluation from the lower part. The study shows that the new approach to interpretation successfully quantified zonal contributions, helping to enhance the workover strategy and mitigate the increase in water cut level of up to 30%.
The improved PL interpretation workflow demonstrates that traditional PLT interpretation cannot be directly applied to reservoirs with three-phase flow and the objective of reducing water cut. The enhanced technique has good potential for successful interpretation and helped to reduce water production.
Comparison of Auto Y-Tool Versus Conventional Y-Tool for Improving Successful ESP Wellbore Access in H2S Oil Producer Wells
Authors: Dominguez F. E. , Flippin C. J. , Yateem K. S. , Banjar H. M. 
Published: February 2024

Abstract
The use of Y-tool assemblies permits production logging and stimulation work in Electric Submersible Pump (ESP) oil well completions. Auto Y-tools use a valve design which preclude the need for a blanking plug used in conventional Y-tool completions and hence provides an alternative to the use of standard Y-tool assemblies in oil well completions. This paper; therefore, compares the use of an auto Y-tool as an enhanced alternative to conventional Y-tool completions for successful wellbore access below an ESP.
To properly relate the operational requirements of conventional Y-tool during logging or stimulation activities, an Auto Y-tool design was identified and assessed based on its ability to automatically seal and unset above the bypass tubing depending on when ESP is in operation. An assessment of the compatibility of the metallurgy of the auto Y-tool components in an environment of high H2S partial pressure for the expected completion life was performed. Furthermore, an auto Y-tool installation would provide experience on its performance of the valve's benefit and its ability to seal and open as a means of enhancing natural flow production rate when the ESP is off.
The auto Y-tool assessment proved better, easier and more efficient to use in ESP well completion to the conventional Y-Tool system. The auto-Y-tool provides faster access to the wellbore below the ESP string than the conventional system for a typical well intervention. There is no need for additional wireline or slickline activities following the initial rig installation. This, in turn, reduces the amount of man power required during well intervention for an ESP well completed with auto-Y-tool. It further reduces the amount of time used in such intervention, which has direct impact on the operational cost and production costs per barrel. The absence of blanking plug in the auto-Y-Tool assembly reduces pressure loss caused by friction due to flow through the ESP stages, thereby increasing the production rate for a natural flowing well when the ESP in not in operation. This paper includes example calculations for natural flow in different flow paths in ESP completions
This paper offers operators a review of potential operational benefits of an auto Y-tool option to conventional Y-tool systems in ESP completion wellbore intervention.
A Data Driven Novel Perspective for Day-To-Day Digital Integrated Asset Operation Model and Business Intelligence Tool Utilization
Authors: Albadi Mohamed , Alsaeedi Ayesha , Alzeyoudi Mohamed , Alharethi Fahed , Alhammadi Maryam , Elabrashy Manar , Konkati Sarath 
Published: February 2024

Abstract
With increasing number of wells added over time in the matured fields to production sustainability, asset monitoring has become an integral part of the daily asset operation. Monitoring large number of wells as creates massive challenge related to increased man-hours spend and reduced efficiency due to manual work-process. This paper explains the data driven approach to overcome challenges monitoring for the asset operation utilizing the Integrated Asset Operation Model (IAOM) and Business Intelligence (BI) tools.
Prior to the implementation of IAOM and BI tool, conventional manual work-process was performed to achieve the asset monitoring. The data driven approach of IAOM links different corporate data sources under a single centralized digital platform. This platform utilizes historical, real time and model-based data for further analysis, visualization, and monitoring purposes. IAOM utilizes a combination of data to run the complex engineering algorithm and presents analytical output to the users in the form of trends, grid, and statistical screen. The smart user defined BI dashboard and reports is integrated with the IAOM platform thus creating a single digital framework for asset monitoring.
The key drawbacks of the conventional manual steps are the increasing man-hours on data gathering and data validation. Thus, resulting in less time on analysis and delaying bottleneck detection. After the implementation of data driven approach as part of IAOM, the increase man-hours diverted on analysis instead of data gathering and validation. The utilization of complex engineering algorithms and automated workflows have significantly reduced time consumption on asset monitoring and debottlenecking. The linkage of different data sources has enabled creating a single source of record (Sor) across the entire asset. This has also improved the efficiency and accuracy of the analytical studies. The intuitive plotting and trends functionality of the data or combination of data helps in comparative analysis over time or related well parameters. Integration of advanced BI tool within the IAOM has enabled creation of smart and intuitive dashboards and reports which cater to the needs of different job roles within the asset. Thus, the end user gets a bird eye view on the information relevant for his day-to-day asset monitoring task.
As a part of IAOM, standard Thirteen workflows and work-process were implemented with an ability to consume large and varied data set from different sources for more accurate and efficient outcomes with respect to the conventional approach. This approach is an integration of data driven analysis, user expertise and advanced technology capitalization.
Hydrocarbon Value Enhancement: A Novel Total Systems Solutions Approach for Contaminants Removal
Authors: Pinappu S. R. , Murugesan S. , Jani J. K. 
Published: February 2024

Abstract
A unique solution has been developed to tackle the problems caused by contaminants that can adversely affect the quality of hydrocarbons. These contaminants can lead to issues such as corrosion, fouling, and concerns related to health, safety, and the environment. The approach involves using a combination of specialized chemical additives and mechanical equipment to improve the quality of the hydrocarbon stream and increase its market value. This holistic approach ensures a synergistic effect, resulting in a premium quality hydrocarbon product.
The marketplace typically regulates the quality standards of hydrocarbons through organizations such as ASTM and ISO. These standards are determined by measuring the levels of contaminants present using approved testing methods. There are several contaminants that are commonly tested for, including but not limited to mercury, arsenic, iron, aluminum, silica, and sulfur. These contaminants present significant challenges in processing and can also pose health, safety, and environmental risks. Although traditional chemical additive treatment can assist in bringing the hydrocarbon stream back to its desired specification, these methods are often time-consuming and not always effective in completely removing certain contaminants. This paper proposes a new system solution approach that includes ideation, pilot plant studies, and final long-term implementation. The approach involves the use of contaminant-selective chemical additives and appropriate mechanical separation equipment.
This paper demonstrates practical examples of eliminating contaminants from various hydrocarbons through a total systems approach. The contaminants in question, including mercury, arsenic, iron, aluminum and silica, were effectively removed using chemical additives like carbonamide/thiocarbamide, acid-catalyzed resins, and sodium tetra hydroborate. To achieve optimal results, we also utilized separation equipment such as centrifuges, decanters, and liquid-liquid contactors. This innovative system utilizes a selective chemistry approach combined with mechanical equipment to enhance the value of hydrocarbons through a synergistic effect. Furthermore, the study proposes the possibility of utilizing this approach in the realm of sustainable energy sources.
Utilization of Innovative Elastomeric Cement Integrity Sleeve as A Field Proven Cement Assurance Solution: A Sustained Annular Pressure Prevention Case Study
Authors: Osorio A. , Vliegenthart A. 
Published: February 2024

Abstract
Well integrity maintenance is one of the most prominent concerns encountered throughout the life cycle of an oil & gas well. Operating companies and governmental regulatory bodies increasingly place significant emphasis on well-construction optimization, safety risk mitigation, and environmental sustainability as an effort to prevent well integrity issues while simultaneously maximizing operational longevity and commercial profitability. While many factors have a direct impact on well integrity, significant importance is placed on cement assurance and relevant optimization techniques given the intrinsic nature of cement as the main physical barrier preventing upwards annular gas migration and subsequent sustained casing pressure build up on surface. Moreover, the oil & gas industry places considerable emphasis on optimizing cement assurance by preventing typical cement failure mechanisms such as chemical shrinkage and casing-to-cement bond failure which commonly occurs as a direct result of cyclic pressurization and tubular ballooning occurrences during mechanical integrity testing and hydraulic fracturing operations.
An innovative and unique elastomeric cement integrity annular sleeve has been developed with the objective of cement assurance optimization and annular gas migration prevention. Distinctly different in comparison to a conventional swellable packer, the elastomeric cement integrity sleeve is a thin elastic swelling seal designed for onsite slip-on installation externally onto oilfield tubulars; it is a high-value solution capable of swelling and establishing an effective casing-to-cement seal in the event of micro-annular flow path emergence throughout cemented casing and tubing sections.
The elastomeric cement integrity sleeve can be installed onto all oilfield tubular sizes ranging from 2-7/8" tubing to 30" conductor casing and does not require additional downhole components, moving parts, or operational actuation for its activation. It is designed to swell and seal a micro-annular flow path immediately upon direct exposure to wellbore fluids after cement displacement. By preventing gas migration in critical barriers, the technology provides increased value given significant CAPEX & OPEX savings as a result of elimination of remedial cementing requirements and operational simplification during plug and abandonment decommissioning activities.
This publication presents a detailed explanation of the technology, it showcases the simplicity of its onsite installation sequence and provides an overview of global installations to date. Furthermore, it provides an overview of a recent case study carried out in conjunction with a major global oil & gas operating company in which utilization of the elastomeric cement integrity sleeve resulted in an 80% reduction of sustained annular gas pressure in a multi-well drilling campaign in the Far East.
High Bandwidth Distributed Acoustic Sensing for Microcrack Detection
Authors: Turolla A. , Zampato M. , Correra S. , Schenato L. , Palmieri L. 
Published: February 2024

Abstract
This paper presents a new system for distributed acoustic sensing (DAS, Hartog 2018 [3]). This system can continuously monitor structures along paths with a total length of several kilometers. It can detect fast impulsive events, such as those generated by microcracks, that can have a duration of around 1 μs. This is particularly useful for monitoring structures susceptible to microcrack phenomena, where traditional DAS systems may not be able to detect such short vibration events. This new system has many potential applications in predictive maintenance, including monitoring long structures like pipelines, tubulars for oil and gas wells, and wind turbine blades.
The system relies on a novel Continuous Wave probing of the sensing fiber based on Orthogonal Frequency Division Multiplexing (OFDM, Schulze, Lueders 2005[3]), which is commonly used in digital television, DSL internet access, wireless and mobile communications. OFDM is used to continuously probe the sensing fiber and overcome the limitations imposed by the round-trip propagation time of the probe pulse in traditional DAS systems. With this method, the acoustic sampling rate can be increased beyond the traditional limit. This results in higher sensor bandwidth and greater efficiency in the system.
Here, a theoretical model of the system is developed to define the hardware of the interrogator, formulate the algorithm for extracting the vibration signal from the optical signal, and evaluate the theoretical system performances. Subsequently, a lab-scale system prototype is designed and built to validate the soundness of the technique.