bluuebunny/crossref_metadata_2025 huggingface dataset:
Peran Operator Sekolah dalam Peningkatan Pelayanan Publik di Era Digital di SD Negeri 6 Watampone Kabupaten Bone
Authors: Muh. Fadli Mangenre Fadli , Erwin  , Syamsuddin
Published: October 2024

This research discusses the role of school operators in enhancing the effectiveness of public services in the digital era at SD Negeri 6 Watampone, Bone Regency. The research method used is qualitative. This study aims to understand the role of school operators in improving public services at SD Negeri 6 Watampone. The approach taken is a descriptive qualitative approach, with data collection techniques including interviews and observations. The results of the study show that the role of school operators in the effectiveness of public services in the digital era at SD Negeri 6 Watampone, Bone Regency, can be observed through their performance in carrying out their duties as school operators. School operators handle educational administrative activities at SD Negeri 6 Watampone, starting from student administration, curriculum administration, teacher and staff administration, to facility and infrastructure administration.
In terms of management, school operators meet the requirements through recruitment, followed by training and development processes. The development of the school operator’s performance focuses on their main duties in the area of educational administration at SD Negeri 6 Watampone. Additionally, school operators are granted data access rights related to SD Negeri 6 Watampone. Furthermore, the services provided by the school operators have been adequately fulfilled, as evidenced by their performance. Despite facing unexpected and undesired obstacles, the school operators were able to overcome these challenges and deliver good results.
Detection of Edge Water Movement and 3D Dynamic Model Calibration Using Pressure Transient Analysis, Onshore Nile Delta, Egypt
Authors: Kamal Sherif Ahmed
Published: October 2024

Water drive gas reservoirs pose a significant challenge in detecting gas water contact (GWC) movement and accurately predicting the timing of water breakthrough. The ability to anticipate water breakthrough is critical for production optimizing and ensuring the long life of the reservoir and help in mitigating the reserves. dynamic simulation models are powerful tools for predicting GWC movement, however these models require extensive production data for calibration, which may only become available after water breakthrough has already occurred. This delay in calibration can mislead development planning and result in less effective production strategies. This paper discusses the application of Pressure Transient Analysis (PTA) as a tool to monitor water movement and predict water breakthrough times in water drive gas reservoirs before they occur. PTA can be used to obtain key reservoir parameters, estimating skin factors, and detecting reservoir boundaries, all these parameters are important for understanding reservoir behavior. By performing successive analyses, PTA can also detect boundary movement, such as the relative position of GWC in gas wells over time. Reservoir pressure is one of the most valuable and useful sources of data in reservoir engineering, and PTA provides a reliable means of analyzing this data to predict water breakthrough times. Our objective is to demonstrate the effectiveness of PTA in monitoring water movement and predicting water breakthrough times in water drive gas reservoirs.

In summary, this paper offers a practical solution to the problem of detecting GWC movement and predicting water breakthrough times in water drive gas reservoirs. The proposed method of using PTA provides a reliable means of analyzing reservoir data and offers valuable insights into reservoir behavior and future production under various modes of operation.

This paper presents a case study from the Lower Abu Madi (LAM) reservoir in the Nile Delta, Egypt, where PTA was used to monitor GWC movement and predict water breakthrough. The results show the effectiveness of PTA in providing early warning signs of water encroachment, allowing for better-informed reservoir management decisions. The integration of PTA with dynamic simulation models offers a practical solution for overcoming the challenges associated with detecting GWC movement and predicting water breakthrough in water drive gas reservoirs.
Unveiling Mediterranean Heterogenous Gas Reservoirs Through Pressure Points Analysis and Reservoir Simulation Modelling
Authors: Labib Amr , Dabbour Mohamed , Negm Ahmed , Mohamed Bassem , Elsayed Mahmoud , Mansour Khaled , Soliman Ali
Published: October 2024

The West Nile Delta basin is a significant petroleum region in the Mediterranean, hosting numerous gas and condensate fields. These fields consist of a combination of structural and stratigraphic traps with sandstone reservoirs from the Miocene and Pliocene epochs, where turbidite hydrocarbon reservoirs with substantial hydrocarbon volumes are found. This article focuses on the Miocene gas reservoir of the Abu Madi formation in the Abu Qir and Yazzi offshore gas fields, located in the West Nile Delta basin north of Alexandria, Egypt.

The study integrates recorded formation pressure testing points and production history of 6 wells that intervened Abu Madi Formation to identify isolated compartments that do not contribute to field production. The analysis revealed three gas reservoirs. The first reservoir, in the North Abu Qir field, has experienced long-term production, leading to pressure depletion and aquifer sweep, reducing the depth of the gas-water contact. The second reservoir, in the Yazzi field, shows some pressure depletion affected by the first reservoir production, but its gas-water contact remains at its initial depth. The third reservoir, in the eastern compartment, exhibits partial pressure depletion. The conceptual model proposes two main concepts for the relationship between the three gas reservoirs. The first concept involves the local structural framework, where the Abu Madi formation trap consists of multiple anticlines, with spill points playing a crucial role in filling hydrocarbons in these anticlines with the same water contact. The second concept considers the impact of stratigraphic facies changes and heterogeneity on transmissibility and permeability, affecting volumetric recovery efficiency.

The information was compiled into a 3D reservoir simulation model, concluding that the remaining hydrocarbons must be redistributed. This opens the possibility of hydrocarbon accumulation in partially isolated compartments that need development. Additionally, the interpretation of recorded formation pressure testing points gradients was essential in identifying hydrocarbon fluid types, revealing an oil rim in the gas reservoir in the eastern compartment of the Abu Qir gas field, which altered the well development strategy in that area.
A Microfluidic Investigation on the Effect of Bulk Nanobubbles and Fluorocarbon Surfactant on Water Blockage Removal
Authors: Zhang Chuanying , Li Junjian , Zhang Miao , Xu Fei
Published: October 2024

In the late-stage development of gas reservoirs, water encroachment poses a significant challenge to maintain stable gas production. Surfactants have limited capabilities in reducing gas-water interfacial tension and water lockage removal. This study explores the potential of using nanobubbles to enhance surfactant performance in removing water blockage and improving gas recovery. A 2.5D microfluidic model is employed to investigate the microscopic mechanisms of water blockage removal using surfactant and nano-bubbles.

A series of core flooding experiments are performed using a 2.5D microfluidic model. Gas displacement is first conducted to the model to arrive at irreducible water saturation, followed by water displacement. The gas enhanced recovery performance is evaluated for fluorocarbon surfactant (FSC) solution, nano-bubble solution (NB), and nanobubble-surfactant solution (FSC+NB) injection respectively. The real-time model images and injection pressure data during displacement are collected to analyze remaining gas distribution and recovery. Fluid injection capacity is assessed by comparing injection pressures.

Results show that the FSC flooding can improve gas recovery by 4.3% due to water blockage removal by wettability alteration, compared with water flooding. NB flooding leads to an improved gas recovery by 6.4% by redistributing residually trapped gas. FSC+NB flooding is shown to further mobilize the residual gas, and the recovery is increased by 12.2% compared with that of water flooding. The experimental results provide visual evidence of the synergistic effect of enhancing gas recovery and water blockage removal by the combination of FSC and NB. Comparisons between injection pressures reveal that both FSC and NB solution shown improved injectability than water. The injection pressure of FSC is the lowest and equal to 21.4% lower than that of water injection. The injection pressure for FSC+NB is 17.8% lower than that of water flooding. NB injection exhibits the highest injection pressure which is 10.9% lower than that of water flooding. During the injection process of NB and FSC, pressure fluctuations are more pronounced, indicating a stronger capability in redistributing the residual trapped gas, which leads to gas recovery improvement and water blockage removal.
Application of Asphaltene Dispersant for Asphaltene Deposition Prevention in Esp Oil Producing Wells Seeing Plugging Issues
Authors: Mohamed H. N. , Ismail M. S. , Azab A. M. , Mohamed M. B.
Published: October 2024

Some ESP oil producing wells located at BED-3 area had been suffered from deposits formation downstream the pump, which lead to repetitive failures due asphaltene deposition, increased downtime/workover need and loss of production due to the plugging accumulations in ESP stages and motor. This plugging was seen in low and high water cut wells despite the scale inhibitors were injecting efficiently at those wells. In this study, methods such as SARA method, and asphaltene screening are adopted for the study of ESP downhole organic plugging problem. In addition, field trials were conducted by injection the asphaltene dispersant chemical (X) through the control line downhole the sensor of the ESP to ensure the effectiveness of the selected asphaltene dispersant product based on the close monitoring of the relative electrical submersible pump parameters. Further monitoring extended to more than one year proved the best performance of the selected chemical.
Integrated Well Testing and Simulation Analysis for HP/HT Reservoirs
Authors: Vera-Rodriguez J. L. , Cinco-Ley H. , Jamiolahmady M.
Published: October 2024

Gas and condensate reservoirs exhibit complex behaviors that require extra considerations in their understanding to be effectively managed within conventional oil and gas workflows. As these reservoirs become more critical in the energy transition, especially when discovered under challenging high pressure and temperature conditions (HP/HT), it's essential to address their complexities. Well testing (WT) analysis, under the right assumptions, is a powerful tool for reservoir characterization, offering insights that build upon traditional diagnostics and cannot be answered solely by a build-up test. This paper integrates WT with PVT modeling and compositional simulation, aiming to improve recovery strategies in line with the evolving energy landscape.

PVT analysis is crucial for understanding the phase behavior of gas-condensate systems, while compositional reservoir simulation allows for dynamic modeling of various scenarios, optimizing production strategies. The paper advocates a holistic approach, offering recommendations for the condensate reservoir management within the changing energy paradigm. By integrating WT data with a comprehensive PVT analysis and compositional simulation, this approach enhances the understanding of gas-condensate dynamics and informs the development of optimal production strategies for similar fields (Vera-Rodriguez, 2023).
Implications and Benefits of Deep Learning (CNN) in Borehole Image Interpretation: Cost Savings and Improved Accuracy
Authors: Abdel-Baset A. A.
Published: October 2024

saving cost and increasing accuracy of the data interpretation are considered a serious challenge within the oil and gas industry. These challenges come to the surface when there are a critical discission on the drilling of new wells inside the geological units created with the normal procedures of the sedimentological studies inside any area. the focus of this study is the application of the Convolution neural networks (CNN) techniques which outstanding performance in pattern recognition and classification to predict the borehole image facies in an efficient and accurate way inside the Qawasim Formation which was deposited during late Messinian time. The focus of this study is the application of the Convolution neural networks (CNN) techniques which outstanding performance in pattern recognition and classification to predict the borehole image facies in an efficient and accurate way inside the Qawasim Formation which was deposited during late Messinian time. This study presents the application of CNN workflow into five major steps including data collection, preprocessing, CNN model learning testing and evaluation. And For performance analysis. The dataset used to train and evaluate the model consists of 1350 images from three types of labeled facies (cross laminated, laminated and massive facies). The trained labeled mages will pass inside a tunnel of convolution and max pooling feature extraction filters and finally a fully connected layers neural network applied as a final stage of the classification results from the model. The produced model demonstrates high efficiency and scalability for automatic facies classification with a reasonable accuracy reached to 82%. This model particularly useful in when quick facies prediction is necessary to support real-time decision making and for cost reduction scenarios during performing a numerous number of borehole images. The produced model is easily implementable and expandable to other clastic reservoirs to create a quick and accurate geological model and be implemented for the future field development plane and production enhancement from a specific zone. the application of deep learning, as demonstrated in this study, will kill two birds with one stone, it increases the efficiency and accuracy Borehole image interpretations, decreasing the cost impact of the geological studies and minimize the risk by increase the accuracy of geological model for any reservoir.
Deep Learning Approach Based on Generative Adversarial Network for Automatic Diagnosis of Sucker-Rod Pump Operational Conditions
Authors: Moussa Ahmed , Darweesh Mohamed , Zamel Amr A. , Ahmed Abd El Hadi Nabih
Published: October 2024

Early and accurate detection of operational anomalies in sucker-rod pumping wells is crucial. Maximizing production while minimizing downtime is essential. Traditionally, dynamometer (dyno) card classification has been labor-intensive and inefficient, especially with increasing high-frequency sensor data.

To address this, a Semi-supervised Generative Adversarial Network (SSGAN) is proposed. It classifies sucker-rod pump conditions. The model uses both labeled and unlabeled dyno card data. It learns the underlying data distribution. Synthetic data is generated to improve the training set. This significantly enhances classification accuracy compared to traditional supervised Convolutional Neural Networks (CNNs), especially with limited data.

SSGAN achieves an accuracy of 86% with limited labeled data and surpasses 92% accuracy with increased labeled data, outperforming the CNN model in both cases. By reducing the reliance on extensive manual labeling, this method offers a promising solution for improving the efficiency and effectiveness of sucker-rod pump monitoring and maintenance.
Stratigraphic and Diagenetic Controls on Asl Reservoir in Downthrown Side, October Field, Gulf of Suez: Implications for Reservoir Quality
Authors: Bakr Abdelhalim Kareem
Published: October 2024

The Miocene ASL Member in the Gulf of Suez is an important hydrocarbon reservoir. This investigation focused on the sedimentological, diagenetic, and petrophysical properties to elucidate variations in reservoir quality. Data was gathered from well logs of four wells, including two that provided whole-core samples amounting to 150 feet. Around 65 rock samples were chosen for thin section preparation, which were examined under a polarizing microscope to determine their mineralogical composition and diagenetic alterations. The study incorporated X-ray diffraction (XRD), scanning electron microscopy (SEM), and core plug tests for porosity and permeability to analyze the mineralogy, pore throat structures, and pore system features of the reservoir. Findings indicated that the ASL Member originated from turbidites and gravity flows within a submarine fan system. Two adjacent siliciclastic sources, Wadi Baba and Wadi Feiran, were recognized as potential sources of coarser material transported through submarine canyons and relay ramps associated with extensional faults. Petrophysical analysis revealed considerable heterogeneity within the reservoir, with porosity ranging from 2% to 10% and permeability from 0.4 to 60 millidarcies (mD). The reservoir's quality is influenced by sedimentation and diagenesis, which can either enhance or diminish its characteristics. By combining sedimentological and petrophysical data, this study aims to identify high-quality reservoir zones. The results provide valuable insights into the factors affecting submarine fan systems in the Gulf of Suez basin and similar geological settings.
Cementing Through PBL Bypass System with BHA in Place
Authors: Maia C. T. , Pernambuco A. C. , Freitas D. G. , Gómez B. B.
Published: October 2024

Encountering severe mud losses while drilling oil and gas, or even a geothermal well, presents a significant challenge that necessitates the use of specialized tools and techniques. Circulating subs, more specifically such as the PBL, a Multiple Activation Bypass System, are engineered to effectively address and potentially eliminate these mud losses by facilitating the bypass of loss circulation material (LCM) through such tools. Pumping LCM through a directional bottom hole assembly becomes impractical for concentrations exceeding 80–100 kg/m3, and the use of cement slurries is often not permissible with most circulating subs. However, this Multiple Activation Bypass System uniquely enables multiple injections of aggressive LCM pills without any limitation on the amount that can be pumped through the system. It also accommodates cement slurries during the same run, offering a consistent and viable solution to this issue of severe mud losses. The system is straightforward, with an activation/deactivation method that is both reliable and easily detectable at the surface. The PBL, a Multiple Activation Bypass System offers a system with a proven worldwide operational efficiency rating of over 99%.

Therefore, the PBL simple, proven methods that effectively reduce complexity while offering high operational and economic efficiency.
Integrated Reservoir Modeling for Fractured and Dolomitized Abu Roash G Carbonates
Authors: El-Bagoury M. , Abdel Raoof W.
Published: October 2024

This paper introduces an integrated approach in reservoir modeling of mixed pore system carbonate rocks. The scope of this study is to characterize the matrix and non-matrix porosity of the Abu Roash "G" reservoir.

An integrated approach for reservoir characterization and modeling utilizing multi-disciplinary data sets as well logs, core data, borehole images (BHI), and seismic attributes to describe the Abu Roash "G" reservoir architecture in the inverted structures of North East Abu Gharadig (NEAG). The workflow starts with the 1D and 2D data analysis for structure, gross, NtG, porosity maps, fracture trends, and geometry (model on paper). 1D principal component analysis (PCA) is classifying and estimating pore systems to differentiate between matrix, pseudo-matrix, and non-matrix pores. The 3D geo-cellar model honors and validates the stochastic and geometrical trends in an integrated reservoir static model.

The different geologic attributes present markable harmony for the lithology and porosity identification. Production and pressure data simulation verify the output reservoir model. The well-based data analysis and variogram proved robust results at well and reservoir scale with consistent fluid flow model on matrix and non-matrix (fracture and dolomitized) naturally enhanced pores.

The applied workflow is pragmatic, runnable, auditable, and fit for reservoir modeling purposes for different reservoir pore-type gatherings that contribute to reducing the subsurface uncertainty of mixed carbonate systems.
Gas Wells Production Forecast Using Artificial and Recurrent Neural Networks Models and Comparison with Traditional Decline Curve Analysis Techniques
Authors: El-Ghobashy Ibrahim M. , Sayyouh Mohamed H. M. , El Ela M. Abu , El-Banbi Ahmed H.
Published: October 2024

Accurate production forecasting is crucial for effective reservoir management and field development planning. Traditional methods; such as numerical simulation, material balance equations coupled with well models, and advanced decline curve analysis (DCA) require extensive data and involve tradeoffs between accuracy and complexity. Recently, deep learning techniques, specifically artificial neural network (ANN) and recurrent neural network (RNN) models have demonstrated promising performance in this domain. This study applies ANN and RNN for production forecasting and compares their effectiveness with traditional DCA models.

An actual production dataset for a gas field containing 13 wells is used to compare ANN and RNN models to traditional decline curve analysis models. After thorough data cleaning and preparation, the dataset was divided into training (historical) and test data sets. The training data was used to build ANN and RNN models in addition to estimating the model parameters for traditional DCA models. Traditional DCA models that were investigated include Arps (exponential, hyperbolic, and harmonic), Duong, Power Law Exponential Decline (PLE), and Stretched Exponential Decline (SEPD). Finally, the prediction of different models was evaluated and compared using the testing dataset. The comparison also included long, medium, and short-term prediction.

Based on the comparison of daily gas production rate forecast, the ANN model demonstrated notable improvements over Arps models for the majority of wells, with a mean absolute percent error (MAPE) of 3.9% compared to 9.1%. However, across all wells, the average MAPE was slightly lower at 6.3% versus 8.1%. Conversely, the RNN model exhibited varied performance compared to Arps models. It showed poorer long-term performance (13% versus 4.5%), similar performance in the medium term (4.4% versus 4.2%), and superior performance in the short term (2.7% versus 4.2%). Furthermore, among DCA models specifically developed for unconventional wells, SEPD exhibited nearly identical performance to Arps (8.3% compared to 8.1%). In contrast, Duong model demonstrated the poorest performance with MAPE of 21.9%.

This study provides insights into model analysis and introduces guidelines in using artificial and recurrent neural networks for predicting production rates. The ANN and RNN models were developed through careful testing with different designs and techniques. All the models in this research were created using Python scripts and powerful open-source libraries like SciPy and TensorFlow.
Maximizing Drilling Efficiency and Bit Longevity Through Advanced Optimization Techniques Using an In-Bit Sensor
Authors: Loucif I. D. , Jones A. , Hallal A. , Bailey M. J. , Roberts S. L.
Published: October 2024

This paper explores the application of the in-Bit Data Recorder (BDR) targeted at improving drilling efficiency and prolonging bit lifespan within the challenging drilling landscapes of the Arabian Peninsula. The BDR is an innovative downhole vibration recording system integrated into the drill bit shank. It captures crucial parameters including axial, lateral, and torsional vibrations and revolutions per minute (RPM) at the bit and downhole temperature. Leveraging this data, the tool enables the identification of downhole vibration types, which allows for the optimization of drilling parameters and continuous drill bit design iterations, seeking ultimate drilling efficiency.

Drawing from four case studies conducted with a key regional operator, this paper demonstrates the efficacy of the BDR across diverse drilling scenarios. In the first case study, conducted in a 16-in. unconventional drilling setting, the BDR facilitated the precise optimization of the bit dull. The second case study, involving a 12-in. unconventional drilling operation, used the BDR to evaluate a downhole tool's effectiveness in mitigating axial vibrations and boosting the rate of penetration (ROP) and footage performance. In the third case study, the BDR supported the inaugural runs of a novel drill bit platform, validating its exceptional stability against vibrations in a challenging environment. Lastly, in a 12-in. geothermal drilling application, the BDR enabled the identification of the drill bit primary failure mechanism in conglomerate drilling, allowing for an efficient bit design to match the application requirement.

The findings from these case studies illustrate the BDR as a reliable optimization sensor for drill bit development, delivering substantial enhancements in drilling performance and drill bit longevity across demanding operational scenarios.

This paper explains how the BDR's data-driven insights empower customer operations to fine-tune parameters, optimize efficiency, and reduce operational costs associated with downtime and multiple-bit runs. Ultimately, the case studies presented demonstrate the pivotal role of advanced downhole monitoring and optimization technologies like BDR in attaining operational excellence.
Reservoir Characterization & Dynamic Modeling in Dahab Field, Sirte Basin - An Integrated Approach
Authors: Ghirfal T. A. , Alelwani R. R.
Published: October 2024

Reservoir characterization and modeling is an important step in developing and operating oil and gas fields. Proper reservoir characterization requires acquiring, analyzing, and integrating all the data and tools to build a comprehensive understanding of a reservoir and its properties. Advanced reservoir simulation models used for predicting future reservoir performance and efficiently exploiting the oil and gas reserves can only be relied on if the reservoir behavior is well understood.

In this paper, an integrated reservoir engineering analysis approach is presented. The analysis approach comprises using historical production and injection data, pressure behavior and historical trends, reservoir fluid analysis from different reservoir zones, well log data, and core analysis to properly characterize the reservoir behavior. Reservoir engineering-driven understanding coupled with information from Seismic and geological data was integrated and used for building a robust 3D Geological model. Well Test analysis, waterflooding schemes analysis, and Material balance calculations came in agreement with the inputs/outputs from the different other disciplines.

The Dahab field has two fluid regions in the reservoir which explains the change in the GOR behavior over time. Special Core Analysis data (SCAL) indicated that the reservoir permeability is in the same order of magnitude (between 10 and 70 md with an average of 20 md) and the analysis shows three distinct rock types and was represented by three Relative permeability sets and 3 J functions for model initialization. The waterflood analysis was inconclusive (immature waterflood). It has been concluded that water injection has a pressure impact and arrests the declining pressure. The dynamic model initialization shows OOIP is in line with Material balance calculation and the first reservoir dynamic simulation runs showed that the reservoir characterization is properly captured, and models are reliable.

Therefore, the main goal in reservoir characterization and modeling is to construct reliable reservoir models that can assist decision-makers in improving field development strategies. The more consistent the model is with the available data, and the more accurate that data is, the more correct the model's predictions will be. This holistic approach helped to ensure the reservoir characterization and modeling were properly captured, making the models more reliable for informing critical field development decisions.
New Oil Discovery in Al Zahraa Brownfield Using New 3D Seismic Data, North Western Desert, Egypt
Authors: Eid Ehab , Hassan Ahmed , Belal Fathy , Ibrahim Mona , Sharaf Mai
Published: October 2024

Al Zahraa oil field is located in the East Ras Qattara concession, northwest of the Kattaniya inversion, and to the south of the East Tiba basin, within the northeastern part of the Western Desert, Egypt. The new discovery is likely located within one of the existing Jurassic-Early Cretaceous basins. This paper aims to highlight this discovery in Al Zahraa brownfield that was characterized by previously developed areas and currently undergoing re-evaluation using newly acquired seismic data.

Al Zahraa field is a highly structure-deformed area encompassing normal, reverse, and thrust faults due to the Kattaniya Inversion. The main producing reservoir is the Late Albian-Early Cenomanian Bahariya Formation. The field is divided into multi-compartments, with a stratigraphic element of lateral reservoir facies change, adding some risk to the trap and the reservoir presence. The production performance of the field suggests more oil in place than initially calculated. Accordingly, new high-resolution 3D seismic data was acquired using the blending seismic acquisition technique with denser source and receiver line increment compared with the legacy survey, and processed using the de-blending technique with highly dense parameters to delineate the structure and obtain high-resolution field outlines.

Intensive and detailed horizons and faults interpretation and mapping were successfully employed for detecting and delineating the subtle traps of Al Zahraa oil field and hence building a new geological model that is defining more potential exploration compartments to be drilled in the future.

After the high-resolution 3D seismic acquisition in this field, the old geological model has changed dramatically and showed an interesting potential in the southern part to drill an exploratory well that led to a new discovery in the area. The Al Zahraa case history demonstrated clearly how effectively new dense 3D seismic survey can be successfully exploited to detect hydrocarbons in geologically complex scenarios.

The initial geological model for the brownfields derived from the legacy seismic data has limited capability to match the field production performance, suggesting to acquire an up-to-date high-resolution seismic acquisition with advanced processing techniques to unlock additional exploration potential and guidance for future development plans.
Contribution of Outcrop and Seismic Data for Better Understanding of Hydrocarbon Potential in the Egyptian Red Sea Basin
Authors: Mostafa Ahmad
Published: October 2024

The main objective of this paper is to provide new insights on the structural architecture and hydrocarbon potential of the Egyptian Red Sea basin. Interpretation of the long-offset (12-km offset, 14-s record length) broadband 2D regional seismic survey acquired over the Egyptian Red Sea in 2018 has improved our understanding of the structural elements affecting this Late Oligocene-Early Miocene rift basin.

The Subsurface evaluation is complemented with surface geology, Landsat images, geochemistry data, and compilation of vertical stratigraphic sections from field excursion to the Gebel Duwi and Safaga-Quseir districts along the Egyptian Red Sea coast. The surface analogues of these areas offer distinctive model for the syn- and pre-rift structural and stratigraphic pattern, which has significant control on equivalent successions extending in the offshore. Integration of surface and subsurface geology provided coherent pattern of the fault complex and the structural relations of fault linkage and transfer zones affecting the Precambrian basement rocks.

Seismic cross sections and subsurface mapping of top basement show large rotated fault blocks bounded by NW-SE master faults (Clysmic trend) and dissected by NE-SW fault system parallel to the Aqaba fault trend. The syn-rift sedimentary successions attain an average thickness of ~4,500 m in offshore penetrations. The pre-Miocene potential source rocks are proven from the tunnels, mines, and cores along Red Sea onshore area in Egypt's Eastern Desert. These source rock intervals are sporadically cropping out in the Gebel Duwi area. Equivalent successions extending in the offshore are anticipated to be preserved in the depocentres and minibasins. This is supported by seismic reflection data and offshore penetrations.

The thick Middle Miocene reefal and shelf carbonates exposed in Ras Benas area, or their offshore marine equivalents, may act as additional source and reservoir rocks. The Middle Miocene reservoirs exhibit oil and gas shows and reservoir quality with porosity ranges between10-15%. The South Gharib massive salt intervals provide the high capacity top and lateral sealing in addition to the fault seal juxtaposition of shale intervals. However, further understanding of the subtle stratigraphic traps and reservoir distribution in the pre-salt successions can be improved by evaluating the newly acquired 3D seismic data (during 2022 and 2023), which cover ~12,000 km2 in the northwestern Red Sea. These data improved the subsalt seismic imaging. Therefore, Comprehensive 3D seismic interpretation and drilling of exploratory wells are essential in the next step toward successful exploration of the Egyptian Red Sea basin.
Mature Fields Production Optimization Using Conformance Enhancement Gels.
Authors: Sabaa Ahmed , Mukhtar Mohamed , Mohamed Haytham
Published: October 2024

Rigless operations for production optimization, well integrity, and reservoir management are the only practical options when firms are looking for ways to save costs. Conformance enhancement gel technologies are particularly useful for treating near-wellbore problems where a complete blockage is required. For water or gas control purposes, these cases include near-wellbore channeling, high-permeability layers without crossflow, and zone abandonment. Cross flow is a common problem in wells producing from many zones in commingle. This phenomenon results in a reduction in hydrocarbon recovery. Precise placement is required in the appropriate zone to achieve long-term selective zonal isolation in a multilayer well.

Gels for improving oilfield conformance exist in a variety of forms and chemical compositions. Polymer gels and inorganic gels are the two primary forms used in the petroleum industry to increase conformity. Gels created from synthetic polymers like polyacrylamide are known as polymer gels. Silica and other inorganic particles suspended in a liquid are used to create inorganic gels. Mechanical solutions were not an option in any of the cases since it would have required renting a workover rig. Selective, high-strength, and permanent zonal isolation using conformance enhancement gel was the optimum solution to isolate targeted zones.

The paper discusses several treatment methods, procedures, and results from two successful conformance enhancement cases applied to wells in the Western Desert of Egypt. These applications managed to successfully isolate unwanted water or gas and to eliminate cross flow. Cross flow is a common problem in wells producing from many zones in commingle. This phenomenon results in a reduction in hydrocarbon recovery. Mechanical solutions were not an option in any of the cases since it would have required renting a workover rig.

In conclusion, conformance gels have proven to be an effective solution for production optimization. Their high stability and ability to control fluid flow within a reservoir make them a valuable tool for improving well performance and enhancing oil recovery. Effective conformance management is crucial for the efficient and sustainable exploitation of petroleum reservoirs, and conformance gels played an important role in achieving this goal. The cost of the rigless chemical treatment was approximately 25% of the cost of the mechanical solution.
Heterogeneous Carbonate Characterization using Integration of Petrophysical Analysis to Different Rock Type Approaches, A Case Study in the Carbonate of Upper Sabil and Harash Formations, Intisar-D Field, Concession 103 Sirte Basin, Libya
Authors: Gobia H. B. , Alazrag A. A.
Published: October 2024

The integrated subsurface study of the Intisar-D oil field in the Sirte Basin focused on Paleocene carbonate reservoirs, specifically the Harash and Upper-Sabil Formations. Petrophysical properties—shale volume, porosity, and water saturation—were derived from wireline logs and validated using standard core data via Techlog software. Despite the fair to good quality of the data, difficulties were caused by the lack of sonic logs in several wells, especially in areas where washout affected the density and neutron logs. Upper-Sabil emerged as the primary reservoir, characterized by a very clean carbonate reservoir with porosity ranging from 25% to 35%. In contrast, the Harash Formation displayed variable shale content, transitioning from clean in the upper part to increased shaleness in the lower part (Harash TST), with porosity between 15% and 30%. Original Oil Water Contact (OOWC) depths varied (9418 to 9442 TVDSS) due to permeability differences.

Reservoir quality was primarily influenced by the texture of reservoir facies, with diagenesis impacting the porosity-permeability relationship. Facies logs were contributory in modeling reservoir properties, and machine learning techniques provided valuable insights for permeability prediction. In offering a comprehensive understanding of subsurface conditions, this case study guides reservoir management and development strategies for the Intisar-D oil field. Despite data quality challenges, the integration of wireline logs, core data, and advanced software enhances the reliability of findings, contributing valuable insights for the field's future exploration and exploitation endeavors.
Novel Smart Multiparametric Sensor For Pipeline Inspection – Eni UK Success Story
Authors: Passucci C. , Wolicki R. D. , Morodei F. , Arca S. , D’Alessandro E. , Leoni A. , Barile G. , Stornelli V.
Published: October 2024

As of today, pipelines represent the safest and the most reliable transportation solution for hydrocarbons, guaranteeing stable and replicable conditions through its whole length. However, pipeline maintenance represents a relevant cost in flow assurance in order to avoid production losses, assets damages and environmental damage. To avoid it, the detection and the localization of anomalies along the pipelines is fundamental. The integrity assessment of pipelines is expensive, invasive and not always applicable due to the harsh environment typical of pipelines, causing an increasing interest in smart and inexpensive devices for such applications. In this work we describe the performance of a novel small (45×35×24 mm) multiparametric device for pipeline inspection, which can be deployed directly into the conduct, either alone or bonded to cleaning or inspection pigs. It is equipped with long lasting battery (up to 72 h) and capable of wireless recharging and data management. The user can manage the system and collect data through dedicated software and mobile app, performing specific analysis on the data collected. The operational conditions which are suitable for the application of such device are pressure ranging from 1 to 150 bar, temperature ranging from -20 to 80°C, 3 axial accelerators ranging from 1g to 16g, 3 axial rotations ranging from 1 to 2000 dps, a sampling frequency settable from 1 to 200 Hz. The device has been enclosed in a special epoxy resin oil-proof, gas-proof and water-proof shell, capable to withstanding any kind of environment which is typical of a pipeline. It can also be equipped with an optional floating shell and thus free to flow inside the oil stream. In the end, the main benefits can be summarized in three keywords: low cost, low risk and high returns, making it ideal for large scale applications. Such device has been successfully tested in various pipeline and we’re reporting case studies, covering a total of 3500 km of pipeline in various geographic locations. We are reporting here a detailed case history of the successful application of the DeepSense device, part of ENI Technology's e-Splora™ portfolio, in an ENI UK gas pipeline. The data collected allowed for a significant optimization of the pipeline cleaning program, resulting in remarkable cost savings in pipeline maintenance activities.
Reservoir Formation Damage, Myths, Facts, and Lessons Learned From the Damage of a Deep Well in the Western Desert of Egypt
Authors: Alqutt Marwa , Sabaa Ahmed , Salem Amira , Seleem Mostafa , Abdel-Aziz Islam , Bassem Ahmed , Hussein Ahmed
Published: October 2024

Formation damage causes a significant loss of both short and long-term profits in the Petroleum Industry. It is the probable cause for the loss of millions of barrels of recoverable oil and billions of cubic feet of gas. Drilling and completion fluids are the first non-indigenous fluids to contact the formation; thus, it is the first opportunity for causing permeability damage. Accordingly, this paper will deal mainly with formation damage that occurs at that earliest stages.

In the Western Desert of Egypt, one of the deep wells that was drilled to 13800 ft, was initially producing from formation at 13000 ft, and due to reservoir depletion and high water cut, it was decided to abandon this interval and to produce from another potential interval which was the 1st time to be produced in Agiba. The well was perforated underbalanced and tested using test string. In order to run with the well completion string, the well was killed using NaCl–KCl filtrated and inhibited completion fluid. After the release of the workover rig, the well production decreased by almost 45%, which indicates that the reservoir was severely damaged.

Attempted to stimulate the well using several stimulation techniques to recover well production, but unfortunately, the problem worsened and well production drastically decreased. Finally, based on the results of the investigation of damage mechanism, the lower interval of the reservoir was hydraulically fractured in order to bypass the damage, as possible, to recover well production.

This paper will discuss the lessons learned from the case of deep well formation damage and will discuss the investigated damage mechanism by which the reservoir was plugged. Also, this paper will present the challenges encountered during the well recovery process, and the novel technique used to avoid introducing the damage again into the reservoir.
Operational Excellence and Multidisciplinary Integration Lead to A Cost Optimized and Timely Managed DST Operation in Newly Developed Oil Field in Gulf of Suez
Authors: Ayyad A. A. , Mohamed S. O. , Taha O. , Hashim S. , Mahmoud M. , Fawaz I. , Hasan H. , Abudooh M. , Adel A. , Elwan M. , Hamdy A. , Farag M.
Published: October 2024

This abstract presents a detailed case study illustrating the successful integration of multidisciplinary team members during the design, preparation and execution for a critical decision Drill Stem Test (DST) operation for a newly drilled sand body in a recently developed mega projects at Gulf of Suez Petroleum Company (GUPCO) allowing both the technical team and the management to properly select the suitable production methodology without affecting the strategic development plan for the field. The test aims to aid the decisions on whether (1) complete the well solely to the subject reservoir or not, and (2) deepen next planned wells to target the subject sand, adding around $2MM per well plus operational risk. Integration and proper tool selection were key to success, and have led to optimizing the operational rig days and thus the overall operation cost, saving the company more than $500M, without compromising on data acquisition requirements.

During the design phase, multiple-disciplinary meetings took place to communicate objectives and clarify operational procedures amongst all involved parties, including extended team from Almansoor Petroleum Services and other service companies. The team examined several options during selection of the best operational procedure and the right equipment for it. Comparison between alternative options and compatibility of different tools and equipment from different service companies was assured to generate an integrated solution without compromising the predefined job objectives. Strategic objectives and technical and operational objectives were clearly defined and assured during each stage of the journey starting from the design phase through the planning, the execution, and post job analysis and reporting.

In conclusion, this case study demonstrates that investing in efficient front-end loading, thru effective pre-planning, is good business and translates to clear value in both short- and long-terms. Also, it shows that introducing new technologies facilitate and simplify the operation saving the time and the cost. The use for robust and well integrated tools assure the results and lead to successful operation.

Using the decision trees with proper task assignment techniques and establishing a proper communication protocol among different disciplines allows a smooth operation and less miscommunications. In addition, this has set a prototype for similar jobs in Gupco in the future. Applying the DST showed the true value of information that led to saving much more money than the cost of the test itself. Pushing the technology to the limit is mandatory to gain knowledge and experience to improve the workflow for future similar operations. Establishing a methodology and developing a design philosophy sets the road for overall company development.
Statistical Analysis Plan for the “Empirical treatment against cytomegalovirus and tuberculosis in HIV-infected infants with severe pneumonia” clinical trial
Authors: Rodríguez Sara Domínguez , Lora David , Tagarro Alfredo , Moraleda Cinta , Ballesteros Álvaro , Madrid Lola , Manukyan Lilit , Marcy Olivier , Leroy Valerian , Nardone Alessandra , Burger David , Bassat Quique , Bates Matthew , Moh Raoul , Tam Pui-Ying Iroh , Mvalo Tisungane , Magallhaes Justina , Buck W.Chris , Sacarlal Jahit , Mussime Victor , Chabala Chishala , Mujuru Hilda Angela , Rojo Pablo
Published: October 2024

Background
The EMPIRICAL trial aims to assess safety and efficacy of an empirical treatment against cytomegalovirus (CMV) and tuberculosis (TB) compared to standard of care (SoC), on adverse events and 15-day and 1-year mortality among infants living with HIV hospitalized with severe pneumonia in Africa.
Methods and design
The EMPIRICAL trial (NCT03915366) is an international multicenter phase II-III, open-label randomized factorial clinical trial conducted in six African countries. The trial has four randomization arms in a 1:1:1:1 fashion with patients allocated to (i) TB-Treatment plus SoC, (ii) valganciclovir plus SoC, (iii) both TB-Treatment and valganciclovir plus SoC, and (iv) SoC only.
Discussion
This paper describes the statistical analysis plan (SAP) for the trial which, per the study publication plan, needs to be published prior to the database lock and final analysis results. The SAP includes details of the analyses to be undertaken and unpopulated tables that will be reported to address primary and secondary endpoints. The database will be locked on 31st January 2025.
Trial registration
ClinicalTrials.gov: NCT03915366, Universal Trial Number: U111-1231-4736, Pan African Clinical Trial Registry: PACTR201994797961340.