bluuebunny/crossref_metadata_2025_split huggingface dataset:
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

Abstract
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

ABSTRACT
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

Abstract
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

AbstractAccurate 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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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.