bluuebunny/crossref_metadata_2025_split huggingface dataset:
Using advanced technology to develop complex Northern Kuwait Jurassic Gas (NKJG) reservoirs to unlock additional reservoirs potential.
Authors: Al Saleh A. , Sabti A. , Al-Anezi H. , AlJasmi S. , Abas F. , Emera M. , Taheri S. , Nishi K. , Khakmedov Azat , Ameer A. , Al Saffar A. , Al-Ajmi A. 
Published: November 2024

AbstractField Development Plan (FDP) of the North Kuwait Jurassic Gas (NKJG) asset in Kuwait served as the basis of the yearly asset action plan, future development wells, development options and production forecast. Due to nearly fourfold increase in gas offtake and the increased number of wells, new production challenges, ongoing appraisal results from the deeper contact area, it was decided to update FDP based on the new data/challenges and using the new technologies.In a modified version of Shell's standard Opportunity Realization Process (ORP), a phased approach for developing fields is applied. The NKJG asset approach to this standard ORP process is different in two ways: – The pace of development/activities is very high, driven by gas demand– Concurrent appraisal, development planning, execution activities, and operation of the fieldsThe FDP work was carried out by an integrated, multi-disciplinary team consisting of KOC, SLB and Shellstaff. A number of new technologies have been applied to solve current production issues.The results for this work comprise of: – Base case depletion drive development plans with the updated well count for each reservoir.– Production forecast for all potential, current and future development wells (different well types based on reservoir conditions/properties) was delivered.– Development decisions like compression, artificial lift (AL), velocity string and well types (multistage frac, multi-lateral) are also addressed in this FDP update.– Gas recovery factor has increased as the very low pressure (VLP) compression was introduced in this work.– Additional gains because of better drainage, longer production period and VLP.This work presents some of the new technologies which enhance oil and gas production and solve development challenges in complex tight carbonate, highly fractured HP/HT reservoirs, sour near critical fluids, in a congested surface area fields. Examples from these technologies are multilateral wells and different types of wells, CO2 energized and multistage frac stimulation, AL, and VLP. Integrated work has been done using dual permeability modelling system to test impact of different technologies on production profile.
From Obstacles to Opportunities: Unlocking the Power of Customized Multilateral Solutions
Authors: Almasri Abdulrakeeb , Alsadeh Adnan , Shukor Arra'uf , Abdulhalim Abdullah 
Published: November 2024

Abstract
The continuous advancement of multilateral completion technology has significantly transformed the oil and gas sector. It has enabled access to reservoirs, resulting in a substantial influence on production capacity. However, the challenges faced when drilling a multilateral well need to be understood and addressed. This paper will outline such challenges and provide insights into how these were overcome to achieve the desired goals.
The efficacy of the Multilateral selective lateral access window has been demonstrated over the past few decades. It has allowed successful identification of reservoir problems and implementation of necessary measures based on obtained data. However, drilling the multilateral and deploying the technology in a challenging formation required extensive planning. The technology required a TAML-4 junction in a formation that encountered heavy losses. This necessitated further planning, such as adjusting the length of the liner and performing off-bottom cementing. All whilst ensuring the lower completion, featuring inflow control devices (ICDs), could be run unhindered.
TAML level 4 junctions require precise planning, orientation, and access. The integrity of the formation is at risk if the liner is not set in the predetermined depth and pumping the cement is not performed precisely. Therefore, the formation where the window will be cut must be consolidated and free of losses. However, if the formation needs to be drilled in an unconsolidated formation with losses expected to be faced while drilling, some engineering solutions must be implemented to ensure the integrity of the formation is not compromised. Identifying the loss zones and the ability to cure or avoid them are key to the success of the operation. Furthermore, the design and procedures can be customized to ensure success. Ultimately, the features of the junction cannot be compromised, and the junction must be of high quality to facilitate further well operations over the life of the well.
This paper will focus on the recent developments in multilateral completion technology, with a special emphasis on the capability to customize the solutions to achieve the objectives of the well.
Successful Deployment of Multiple Inversion Workflows in Low Resistivity Contrast and High Noise Environment
Authors: Thar H. , Valerio R. , Bandyopadhyay I. , Batheyab F. , Mazrouei M. , Deng L. , Soliman A. 
Published: November 2024

AbstractReservoir navigation objectives of any lateral is to geosteer in the desired target layer maximizing the productivity and/or injectivity. Target layers with low resistivity bounded by slightly higher resistivity shoulder beds create low resistivity contrast and high noise environment attenuating the boundary detection capability of Deep Azimuthal Resistivity (DAR) tools. This paper presents successful case studies where multiple DAR hybrid inversion workflows were implemented to counter this challenge and optimize production within a field.Carbonates target layers with inverse resistivity signature and heterogeneity from the offset wells were analyzed and incorporated into a detailed feasibility pre-drill reservoir navigation model which highlighted the challenges due to low resistivity contrast and high noise environments. Workflow parameters were optimized to ensure an effective depth of detection. While drilling, the DAR tool was deployed along with GR, Density, Density image and Neutron Porosity. Multiple hybrid inversion workflows with their optimized parameters reduced the impact of noise in low signal environment and increased the reliability of resistive boundary approach. This successful method was utilized for proactive geosteering in similar wells.The holistic approach of data incorporation to find targeted solutions in pre-drill phase highlighted the range of parameters to ensure reliable detection capability in the real time. During the drilling phase, optimization of the multiple inversion workflows enhanced resistive layer approach understanding which in turn helped in navigating along the optimum target layer. Heterogeneity in the target zone affected the resistive layer approach capability. The combined data from other sensors and the inversion results integrated into the geosteering workflow helped in taking informed well placement decisions in the complex heterogeneous environment heterogeneity. Upon successful utilization of the DAR technology along with proactive geosteering in the initial wells, this application was taken forward to all upcoming wells with similar target profiles. This Increased the net to gross of the wells compared to the previous wells which were navigated with a reactive geosteering approach.The limited boundary detection capability of DAR tool due to inverse signature, low resistivity contrast and high noise environment was successfully overcome through the application of optimized hybrid inversion workflows.
Implementing a Solids-Free, Non-Damaging Loss Control Solution to Enable Overbalanced Workover Interventions: Case Studies and Applications from 80+ Wells in Iraq
Authors: Alarcon X. , Doghmi A. , Ahmed M. , Tellez J. , Alvarez J. , Chuc E. , Masoodi A. 
Published: November 2024

Abstract
Controlling lost circulation can be costly and complicated. When well conditions include low reservoir pore pressure and high reservoir permeability, traditional techniques to minimize fluid loss, such as solids or viscous pills, can damage the formation due to interaction with sandstone formation characteristics, such as kaolinite, smectite, incrustations, polymer residues, pH changes, clay swelling, and others. This often means that minimizing near-wellbore damage is key for the future productivity of the well.
This paper presents a laboratory validation and field application of a novel solids-free fluid-loss (SFFL) system based on a relative permeability modifier (RPM) used during well-kill and overbalanced workover operations. This study will focus on the detailed information needed for selection, treatment application, and operational procedures used in sandstone formations in Iraq.
This system relies on an ionic polymer that decreases matrix permeability to aqueous fluids, limiting leak-off into treated zones. This RPM, with low molecular weight, high salinity tolerance, very low viscosity (less than 3 cp), and acid resistance, immediately adheres to the rock's surface, eliminating the need to shut the well in. In addition, this system does not require breakers, which eliminates the negative impact on post-stimulation well productivity. Laboratory test data shows the capability of the material to control fluid leak-off and achieve high levels of regained permeability to hydrocarbons. Fluid is placed in front of the target zone and can be pumped, squeezed (or gravity injected) into the formation. As the majority ofmost of the cases have been applied in old wells, the treatment injection pressure limit must be related to the casing integrity with no more than 1,000 psi measured at surface.
To date, about 80+ jobs have been performed with this novel SFFL system in Iraq. This system has been proposed for solving partial and total losses, to full circulation in overbalanced operations such as: Lost-circulation events during well killing operationsWellhead maintenanceWell integrityReplacement of electrical submersible pumps (ESPs)Overbalanced tubing-conveyed perforating (TCP), among others
Laboratory tests, procedures, case histories, and continuous improvement actions are presented in this study.
A Novel Workflow of 3D Static Modeling Uncertainty in Karstic Reservoirs of the Central Luconia Province, Sarawak
Authors: Trianto A. , Jalil M. A. , Tewari R. D. , Sedaralit M. F. , Hendraningrat L. , Sagar S. F. , Latiff A. H. , G. J. Soto 
Published: November 2024

AbstractKarst networks are characterized by their complex and heterogeneous dissolution cavities related to the shape, dimension, distribution, and fill, presenting significant subsurface challenges in reservoir characterization and management. In this work, it is proposed to deploy a new methodology to capture geological uncertainties in karstic reservoir while mapping field-wide karst geobody in JTN Field (Luconia). Previous studies assumed that karst geobody remains open as conduits, acknowledging the substantial influence of karst features on reservoir behavior and the flow of fluids. This further becomes an oversimplification of handling karstic carbonate reservoir modeling that may influence the result of hydrocarbon volume in place and reserve estimation, well location optimization, and field's management plan. In this research, we are examining specific seismic characters, i.e., chaotic reflection inside the collapsing cave geobody to identify potential particles filling within the systems. By integrating the chaotic seismic reflection inside collapsed network combined with the architecture of the conceptual model, the individual geobodies checking technique will be applied to identify possible karst fills within the karstic drainage components. This will allow the workflow to further assign possible karst fills and properties within the region with calibration of production performance. The proposed research will adopt a multidisciplinary approach, combining geological, geophysical, drilling information, and reservoir engineering data, along with advanced karstic reservoir modeling techniques to address key uncertainties and challenge karstic characterization, especially the uncertainty related to storage volume and containment. Finally, this would help us to improve karstic carbonate reservoir characterization & modeling for C02 storage and hydrocarbon production assessment.
Microfluidics – A New Tool to Differentiate Chemistry for Fracs – Functional Frac Performance Vs Reservoir Performance
Authors: Price B. , Li Y. , Liu S. , Abedini A. 
Published: November 2024

AbstractUnconventional reservoirs play an important role in the global energy supply nowadays due to recent advancements in hydraulic fracturing. It has been reported that the selection of completion chemicals have a significant impact on oil and gas production due to fluid incompatibility and polymer-induced formation damage. To optimize oil and gas production, flowback efficiency, and fracturing fluid-induced permeability damage, different completion fluid packages were evaluated using microfluidics.Two microfluidics chips were designed to evaluate regain conductivity and flowback efficiency in this work. The regain conductivity chips, representing proppant-packed fractured zones, were designed with two different fracture depths. The flowback chips consist of a high permeability zone and nanoscale channels to simulate fluid characteristics and transport in fractures, matrix, and their interface. Time-lapse microscopic images and videos of the chips were recorded during testing and the oil production was quantified using an automated images analysis platform. Microfluidic experiments were conducted using filtered produced water and oil samples collected from the field.In microfluidics experiments, friction reducers with similar flow loop performance, or functional frac performance were chosen and compared on the regain conductivity and flowback tests. The results of the regain conductivity tests showed that the regain conductivity of the best performing group was 25% higher than the worst performing group. The flowback tests demonstrated significantly higher oil production rates and total oil flowback volume, about 50%, in the best performing group compared to the worst one.This study introduces novel selection criteria for the design of completion fluid packages, aiming to optimize oil production in unconventional reservoirs. The pore-scale optical access of microfluidics enables a better understanding of formation damage and oil recovery mechanisms. Additionally, this microfluidic approach offers significant reductions in testing cost and time while providing improved reproducibility compared to traditional testing methods.
Enhancing Real-Time Stuck Pipe Prediction Using Trigger Coefficients: A New Approach for Realtime Well Engineering
Authors: Samuel Robello , Zhang Yuan , Agrawal Abhishek , Nakhle Amol 
Published: November 2024

Abstract
Conventional approaches to addressing stuck pipe scenarios in oil field operations have typically depended on established tools and procedures. While previous research has delved into the causes of drill pipe sticking and suggested adjustments in operational methodologies, current methods often fall short in predicting incidents comprehensively, particularly in light of diverse wellbore conditions. This paper presents a novel methodology that merges principles of physics, data science, and uncertainty modeling to offer more resilient and precise solutions for managing real-time pipe sticking occurrences. The methodology put forward embraces diverse modes of pipe sticking mechanisms, encompassing mechanical, geometrical, differential, keyseat, cuttings packoff, and geomechanical factors. Individual coefficients are assigned to monitor various parameters, with their weights dynamically tuned in real-time according to operational conditions and surface/downhole measurements. The independence of these parameters facilitates the prediction of mechanisms that contribute to pipe sticking occurrences. By integrating engineering and data science models through microservices, multiple calls during calculations are enabled, accommodating the expected nonlinear behavior of variables across various drilling conditions.
In real-time analysis, the findings indicate a fast convergence towards optimal prediction, ensuring predictability and favorable outcomes, particularly in test wells with inherent uncertainties. Interestingly, the study sheds light on the multifaceted factors contributing to pipe sticking conditions, even when initially perceived as differential sticking. Notably, in wells with minor doglegs, secondary geometric factors such as borehole torsion emerge as significant contributors to sticking. This leads to increased resistance against pipe movement in both axial and radial directions, elucidating the role of mechanical factors outlined by the well profile energy coefficient.
Moreover, trend analysis reveals a rising trend in pipe sticking conditions, attributed to uncertainties in input data. Furthermore, the integration of high-resolution lithology inputs enhances the accuracy of stuck pipe predictions. The prescriptive analytics approach comprises two modules: an inferencer and a recommender, providing operational parameters for intervention. The inference output offers practical recommendations to mitigate specific stuck pipe conditions. Additionally, in certain wells, the pack-off model and risk calculations incorporate insights from three primary models: cuttings bed buildup, caving volume concentration, and heightened friction on the drill string.
Advanced Embedded Discrete Fracture Network Modeling in a Complex Carbonate Reservoir: A Case Study from Abu Dhabi
Authors: Singh M. K. , Zhang L. , Rat C. , Al-Jenaibi F. , Al Kobaisi M. , Tahir S. , Kada Kloucha C. , Al-Kindi Z. S. , Mustapha H. 
Published: November 2024

AbstractFractured reservoirs present distinct challenges in the oil and gas industry due to their intricate origin and the dynamics of fluid flow within them. Successfully modeling these reservoirs entails surmounting multiple obstacles, such as delineating complex fracture networks, comprehending dual-porosity flow, and addressing scale dependencies. In this study we detail the application and assessment of innovative simulation algorithms tailored for fractured reservoirs within a complex, tight, and fractured carbonate reservoir located in Abu Dhabi, United Arab Emirates.The reservoir, with more than 15 years of production history and 17 wells, has production from both matrix and fractured zones. Leveraging image log and other fracture drivers, a discrete fracture network (DFN) model has been constructed, considering the tectonic history of the basin. The reservoir was simulated using the embedded discrete fracture modeling (EDFM) approach. In this method, fractures are represented as discrete entities, each modeled with specific geometry, orientation, and properties, embedded within a porous matrix characterized by distinct properties.By honoring the fracture geometry and fluid flow behaviors, EDFM modeling has become a versatile tool for simulating fractured reservoirs. It optimizes production strategies, identifies sweet spots, and improves hydraulic fracturing designs, ultimately enhancing recovery rates and economic viability.
Modelling of Propped Fracture Length for Variable Perforation Shot Designs in Unconventional Wells Undergoing Multi-Stage Hydraulic Fracturing
Authors: Alowaid Abdulrahman M. 
Published: November 2024

AbstractThe scope of this paper is to model the fracture geometry generated from different perforation shot designs in an unconventional well stimulated with multi-stage hydraulic fracturing. The objective of the paper was to assess the uniformity and symmetry of propped fracture half-lengths conducted through a sensitivity study on the number and distribution of perforating shot designs across a single hydraulic fracturing stage. A 3D transverse fracture simulation model was built using the petrophysical and geo-mechanical properties of an unconventional well, utilizing a commercial fracture simulation software. The objective was to identify the most optimum perforation design yielding the highest stimulation efficiency and fracture uniformity. Five different scenarios were tested: three scenarios with a uniform distribution of perforation holes per stage, and two scenarios with variable perforation distributions. The variable scenarios modeled higher distribution at the toe and heel sides of the stage for two scenarios, and consistent distribution with different number of perforations for three other scenarios. To guarantee a fair comparison between all scenarios, each was simulated with five clusters per stage. All five scenarios exhibited different distribution of fracture half lengths as expected. For the three scenarios with a uniform distribution of perforations per cluster, the lower the number of perforated holes per cluster, the more uniform the propped fracture half lengths were, indicating a clear correlation between fractures uniformity and the number of perforation holes. In contrast, for the two scenarios with variable perforation hole distributions, the one with higher perforation holes closer to the toe of the stage yielded a more uniform fracture geometry compared to the other scenario where perforation holes were concentrated more at the heel of the stage. The scenario with the lowest number of holes distributed uniformly yielded the most uniform distribution of fracture geometry out of the five scenarios. Consequently, the approach and outcomes of this paper are aimed towards the selection of optimum perforation designs, that yield similar fracture geometry symmetry, and ultimately have a positive impact on well deliverability.