bluuebunny/crossref_metadata_2025_split huggingface dataset:
Maximizing Efficiency: Coiled Tubing Success in Cutting Needles for Fishbones Completion
Authors: Sissembayev N. , Al-Braiki A. M. , Bakri H. , Turniyazov N. , Soliman I. , Malak M. , Rashid S. 
Published: November 2024

Abstract
This paper delves into a groundbreaking approach aimed at enhancing Weil stimulation in tight reservoirs through the utilization of Fishbones technology. The specific objectives of this study include the deployment of Fishbones completion, activation of needles using high-volume acid, and the cutting of needles without the need for a rig, achieved through the innovative use of Coiled Tubing.
The methodology employed in this study involved the installation of Fishbones completion following the drilling process. Subsequently, the needles were activated using high-volume acid pumping, and the cutting process was executed using Coiled Tubing without relying on a rig. This entire process was meticulously planned and executed with a keen focus on ensuring safety, operational efficiency, and minimizing environmental impact.
The results obtained from this project serve as a testament to the feasibility and effectiveness of utilizing Coiled Tubing for the purpose of cutting Fishbones needles. The findings from this study underscore the potential of Coiled Tubing as a viable alternative for needle cutting in Fishbones completion, offering substantial advantages over conventional rig-based methods. There are certain risks when cutting the needles with Coiled Tubing related to Coiled Tubing lockup. However, this could be greatly optimized using higher size Coiled Tubing and aviso taking precautionary steps when deciding to cut more than two subs per run. Cutting all needles was not implemented completely, however it didn't stop this approach resulting in the achievement of the main objective of avoiding the post stimulation brine loss.
Furthermore, this paper presents a novel contribution to the petroleum industry by presenting a successful case study that demonstrates the efficacy of cutting Fishbones needles without the need for a rig, using Coiled Tubing. This innovative approach not only enriches the existing body of literature but also offers a cost-effective and efficient solution for enhancing well stimulation practices. By disseminating these findings, this paper aims to contribute significantly to the industry's collective knowledge and inform best practices in well stimulation operations.
New Hybrid Completion Technology for Tight Carbonate Reservoir Productivity and Injectivity Enhancement
Authors: Rachapudi R. , Alshehhi S. , Mogensen K. , Chaudhry M. , Barragan E. , Utama I. , Abdussalam F. , Karbi H. Al , C Wissam , Fishbones Malak. M , J Sami , L Javier Antonio , B Noureddine , S Alexander , R El Sayed , S Saleh Ali , S Shamma. Al 
Published: November 2024

Abstract
Tight carbonate reservoir productivity & injectivity enhancement along with sustainability has been a challenge in the oil and gas industry for an extended period. Limited entry Liner and Fishbone technique are two technologies that can stimulate the entire horizontal section. In this work, we devise a hybrid method to combine both techniques together to deliver deep worm holing.
New liner completion technology, consisting of partly liner subs to introduce special needles that can penetrate deeper into the formation up to 40 ft i.e., and remaining liner subs with special holes that can jet the acid is under piloting. This innovative technology has the capability to connect sublayers & natural fractures that improves the poor vertical communication (low Kv/Kh) within the target zone and simultaneously can stimulate the horizontal section to bypass the near well bore damage. In addition, this technology provides a flexible option for deep stimulation of the reservoir during installation, followed by near well bore stimulation using liner holes as a second step after a certain production duration. This flexibility provides a backup option for regaining sustainability after a production period. The liner holes offer the possibility to improve the overall stimulation efficiency by generating worm holing in-between adjacent needles.
This innovative technology pilot is under implementation at field A. The reservoir is a tight carbonate reservoir with a permeability range of 1-2 md. The present strategy is to install Limited entry liner completions as part of the field development. However, with this successful Implementation of new pilot with special liner completion increased the production rate up to two times will provide a chance to revise field development plan with special liner technology in the upcoming new well drilling campaign. This paper will provide the details of the technology, well selection, completion design, implementation steps, pilot results along with lesson learned for inclusion as part of next Implementations. Further discuss about well monitoring plan, data collection and performance evaluation of the pilot. In summary this technology will provide a backup option to conduct stimulation in case sustainability of well productivity needs to be reestablished and overcome the current limitation of advanced completion stimulation techniques
This technology is an invention that combines deep acid stimulation technique and near well bore jetting with an option to execute them either together or separately.
Development of Fast Predictive Models for CO2 Enhanced Oil Recovery and Storage in Mature Oil Fields
Authors: Peralta Yessica , Ganesh Ajay , Zambrano Gonzalo , Chalaturnyk Rick , Shokri Alireza Rangriz 
Published: November 2024

Abstract
Reservoir modelling tools have played a significant role in designing the subsurface fluid injection, such as CO2 enhanced oil recovery (EOR). However, these models are computationally expensive; they require extensive geological and engineering data that often are not available in the early phase of carbon utilization and storage projects. This work presents the development of fast predictive models and optimization methodologies to quickly evaluate the CO2 EOR and storage operations in mature oil fields.
Considerable experience with CO2 EOR and storage has been gained by the petroleum industry. In particular, the Weyburn-Midale project (Canada) is a comprehensive case to show how an oil reservoir could securely store CO2. Employing the Weyburn-Midale project, we developed, trained and tested several types of proxy models in multiple scenarios to assess the performance of the miscible CO2 flood in recovering residual oil, increasing the ultimate oil recovery factor while maximizing the permanent CO2 storage.
The history matching of the Weyburn-Midale CO2 EOR model involved 216 well histories (producers and injectors) from 1964 to 2006 using a compositional reservoir simulator. The predominant exploitation scheme was based on an inverted nine-spot pattern waterflooding, water alternating CO2, and consequently CO2 injection. Two simulation data sets were employed at different periods of 1956 through 2006, and 2007 through 2025. Among several proxy models, an artificial neural network (ANN) model proved to accurately estimate features of interest, namely fluid production (oil, water, gas), fluid injection (water, CO2) and the amount of CO2 stored in the reservoir. Additionally, an autoregressive exogenous input (ARX) model was implemented to predict the future outputs in response to a future input. Inspection of the relative estimation error and the model fitness score showed that the proxy model was capable of rapidly reproducing the trend in the validation set satisfactorily. Lastly, we evaluated the transfer of learning from a proxy model, trained to the Weyburn-Midale field (Canada), to assess the performance of CO2 EOR in another mature oil reservoir in Europe (Romania).
The application of proxy models under geological and operation uncertainties offers huge reduction in computational time and engineering data requirements. The results from the Weyburn-Midale case study deliver critical insights into the analysis of many process factors and modeling techniques intended to assess the economic limits and long-term performance of CO2 EOR and storage in mature oil fields.
Case Study: Edge Computing Solutions for Well Performance Monitoring and Asphaltene Detection in Deep Carbonate Reservoir, Greater Burgan Oilfield
Authors: Al-Shammari A. , Al-Azmi N. , Sinha S. , Agarwal S. , Al-Mutairi H. , Shamsaldeen M. , Al-Shamali A. , Harami K. , Abdulrahim K. , Robert H. , Parker A. , Biya A. , Hernandez M. 
Published: November 2024

Abstract
A huge amount of sensors data is daily being generated from a single well site, posing challenges for data transmission, storage and analysis. Marrat reservoir is adeep carbonate reservoirs in Greater Burgan Oilfield and is prone to asphaltene deposition. The present study leverages Edge computing technology which may revolutionize data processing, analysis, and algorithm-based decision making to enhance well performance in a cost-effective manner.
This case study illustrates a pilot project of an on-prem edge computing infrastructure. The project particularly focuses on monitoring well performance and tackling asphaltene problems. The utilization of edge computing in this context introduces two outstanding solutions: the virtual flow meter (VFM) and asphaltene problem detection module. The VFM solution is based on a combination of data-driven and physics workflows. While the Asphaltene module quantifies the asphaltene risk by utilizing fluid data and asphaltene precipitation envelope for well operating conditions. Numerous physical well tests and fluid sampling have been carried out to validate both the solutions.
The data-driven Virtual flow meter (VFM) has demonstrated a very high model accuracy over the test period, which signifies the reliability and potential of edge computing in the field. This solution seeks to estimate flow rates without the need for conventional flow meters, resulting in optimizing the frequency of wells production measurements and operating expenses. Through the estimation of real-time flow rates and asphaltene risk, a proactive wellbore clean-out job could be run to prevent any production losses due to asphaltene blockages. This study shows an opportunity of field scale implementation, which potentially will help in managing and optimizing reservoir performance.
The edge computing technology provides an innovative approach which enables real-time access to all the pertinent well information. The developed modules can be reliably used to identify potential well issues for early resolution and avoid significant production deferral. Asphaltene detection module will not only reduce the downtime but also deliver insights for production assurance, reservoir management and field development planning.
Ranking Geological Models Using Dynamic Lorenz Coefficient: Application for CO2 Sequestration in Saline Aquifers
Authors: Aldaif H. , Hoteit H. 
Published: November 2024

Abstract
Concerns regarding climate change and global warming have intensified over the past decade. One of the main strategies to mitigate the rise in global temperatures is CO2 sequestration in geological formations. Reservoir simulators are the tools to evaluate the behavior of CO2 while being sequestered in the aquifers. However, the reliability of the simulation runs relies on the accuracy of the geological model, which is often associated with various uncertainties. Developing multiple realizations of the geological model is a common practice in the industry, which is typically adopted to incorporate uncertainties. There is a practical limitation to conduct detailed simulation studies for all the geological models. Ranking geological models using certain indicators is key to perform detailed studies on selective cases that capture the range of subsurface uncertainties. Dykstra-Parsons coefficient of variation (VDP) and static Lorenz coefficient (Lc) are common static indicators that are used in the ranking process. The main advantage of using VDP and Lc is that they can be easily and quickly calculated. However, studies have shown that dynamic Lorenz coefficient (DLc) is a superior tool to rank geological models and quantify heterogeneity. Numerous studies have examined the impact of aquifer heterogeneity on CO2 trapping mechanisms. However, existing research typically employs static indicators to assess aquifer heterogeneity, such as the coarse grain to fine grain ratio, sand to shale ratio, Dykstra-Parsons coefficient, and coefficient of variation. These static measures inadequately capture the spatial connectivity between reservoir grids and layers. Additionally, other studies compare homogeneous models with a single heterogeneous model without adequately quantifying the level of heterogeneity. In this study, the Sequential Gaussian Simulation method was utilized to generate multiple simulation models with varying levels of heterogeneity. The heterogeneity of these models was quantified using dynamic data from rapid streamline simulation runs and assessed with the dynamic Lorenz coefficient. Alongside a homogeneous model, four models with increasing heterogeneity (DLc values of 0.2, 0.4, 0.6, and 0.8) were analyzed. Sensitivity analyses were conducted on factors such as water salinity, wettability, injection rate/volume, and completion interval. Depending on the completion interval, the increased heterogeneity can enhance both solubility and residual trapping while reducing the amount of mobile CO2. This study uses dynamic data obtained from fast streamline simulations to quantify heterogeneity through the dynamic Lorenz coefficient, providing a more accurate measure of spatial connectivity of the reservoirs/aquifer and utilize that information to assess the impact of heterogeneity on different trapping mechanisms of CO2 in saline aquifers.
A Comprehensive Methodology for Assigning Capillary Pressure and Relative Permeability Curves to Reservoir Rock Types with Limited Laboratory Data
Authors: Carvalho A. , Valsardieu B. , Balthazar A. 
Published: November 2024

Abstract
Accurate characterization of capillary pressure and relative permeability curves is crucial for reservoir modelling and production optimization. However, in many cases, laboratory measurements are only available for reservoir rocks of better quality, leaving those of lower quality lacking essential data. This paper proposes a methodology that combines log data and laboratory measurements to assign capillary pressure and relative permeability curves to different reservoir rock types, even when laboratory data is limited. The suggested methodology was successfully applied to sandstone reservoirs in a northern Africa field.
First, all cored sample depths are converted to the corresponding log depths, and each sample is assigned to the most probable reservoir rock type (RRT) identified in the petrophysical analysis. Subsequently, Pc values are transformed into height above the free water level (HAFWL) curves, and these undergo a thorough screening process to filter out less confident samples. Higher confidence HAFWL curves are then grouped according to their respective RRTs. The subsequent step involves defining a reference synthetic Sw vs. HAFWL curve for those RRTs with assigned laboratory data. For the RRTs lacking laboratory data synthetic curves are then obtained by using log-identified irreducible water saturation (Swi) values above the transition zone. Finally, this part of the process concludes with the validation of the reference curves by comparing them to Sw profiles obtained from log interpretation.
Next, attention shifts to kr data, beginning with curves pre-processing. This entails determining endpoints and Corey coefficients for all supplied curves to construct analytical kr curves. The subsequent step involves an innovative screening technique of kr curves based upon the use of cross-plots between petrophysical parameters and kr curve endpoints. This process serves two primary purposes: firstly, it allows filtering anomalous samples and categorise representative curves per RRT, and secondly, it identifies trends in the cross-plots. The latter will enable the creation of synthetic kr curves for RRTs lacking laboratory data.
In summary, the proposed methodology offers a systematic approach to assign Pc and kr curves to reservoir rock types, effectively leveraging available laboratory data while addressing data gaps for less characterized rocks. Emphasis is placed on innovative screening techniques for kr curves. By incorporating synthetic curves and validating against log data, this methodology enhances the accuracy and reliability of Pc and kr curves, thereby supporting improved reservoir characterization and simulation studies for optimized hydrocarbon recovery.
Structure Characteristics and Deep Shearing in M Field, South Iraq, First Evidence from 3D Seismic and Integrated Gravity Study
Authors: Dengyi Xiao , Jiawen Song , Yanlin Huang , Jianlin Li , Xin Chen , Qunli Qi , Min Zhao , Bo Wang , Pengpeng Ye , Ziping Lu , Pengfei Zhang 
Published: November 2024

Abstract
The South Iraq is one of the most prolific hydrocarbon-producing regions in the world. Most of fields in this area are elongated in N-S, NW-SE and characterized as four-way dip closure. The kinetic and dynamic mechanisms of these structures are reported as deep salt diapir or regional shear but lack clear evidence in field scale. To robust understanding of structure origination and growth, a dedicated study with the integration of seismic and gravity illustration was carried out.
This study was conducted based on high-quality 3D seismic as well as field-scale gravity investigation in M field. Tectonically, this field locates in transition zone of N-S trending and NW-SW trending. The basement depth and tectonic lineament were delineated through gravity-based inversion with different scenarios to figure out the influence of Hormuz salt. Under the recognition of gravity, faults in Jurassic and Cretaceous were interpreted according to dedicated seismic interpretation through geometric attributes and AI techniques. Geometric, kinetic as well as dynamic mechanisms of structure were organically analysed. The anticline growth history is also quantitatively demonstrated through 2D seismic horizon flattening and 3D paleo-structure reconstruction. These understandings of fault features, anticline evolution history as well as basement condition give a clear delineation on the generation and growth procedure of M field.
Generally, two sets of faults develop in M field and are separated by Gotnia anhydrite. The fault systems are generated in same stress regime and show different patterns. The Jurassic faults perform as sinistral trans-compression with two N-S trending major faults and eighteen NW-SE subordinate faults. The Cretaceous faults distribute as right-stepping en echelon series. The Gotnia formation adjusts the deformation differentiation through ductile flow and results in the lateral thickness variation. The coincidence of Cretaceous anticline crest and Jurassic fault-constraint area indicated the contribution of fault activity to growth of the anticline. Paleo-structure through 2D horizon flattening and 3D methods indicated the continuous growth of since the early Cretaceous.
Conclusively, this is the first time to explicitly display the fault configuration in South Mesopotamian basin and prove the dextral shearing of Jurassic formation in 3D seismic and gravity. The study provides insight into the relationship between tectonic movement and field growth. The achievement of this study would enhance the understanding of hydrocarbon accumulation in South Mesopotamian basin and give inspiring information on hydrocarbon accumulation.
Green Acid Transformative Technology for Sustainable Oil Production, Reservoir Management and Operational Efficiency in UAE Hydrocarbon Recovery
Authors: Ghahgarokhi R. Barati , Alhajeri Mubarak M. , Tsau Jyun-Syung , Rowley S. 
Published: November 2024

AbstractThis paper introduces the groundbreaking application of a novel, low-corrosion, deep-penetrating, environmentally green acid designed for high-temperature Gulf reservoirs. The green acid exhibits various beneficial properties, including low corrosion rates with stainless steels and wireline materials, improved interfacial tension, and deeper penetration into carbonate rocks under reservoir conditions. The acid's performance was evaluated through interfacial tension measurements, corrosion testing, reaction rates with different materials, and matrix acidizing experiments. The results demonstrated lower corrosion rates, improved permeability, and potential for deeper penetration compared to similar HCl-based products with results pass the minimum requirement presented by the industry. The matrix acidizing experiment results revealed a permeability increase of 2,671 times for a limestone core with an initial permeability of 1.74 mD, which indicate that the green acid achieves approximately 2.5x greater permeability enhancement compared to 15% HCl. The green acid is non-corrosive, non-fuming, non-toxic, and biodegradable, making it a cost-effective and environmentally friendly alternative for reservoir applications.
Surviving the Flame: Ensuring Facilities Safety with Fire Survivability Study
Authors: Ali Z. , Ngah W. Wan 
Published: November 2024

Abstract
Traditionally facilities blowdown is normally designed for emergency depressurization to 100 psig or half of design pressure, whichever is lower, within 15 minutes as per recommended by API RP 521 (referred to as legacy method in this paper). API RP 521 criterion was developed based on pool fire and applies to carbon steel vessel with wall thickness of 25.4mm and more. This paper addresses the adequacy of legacy API 521 guidance for application to cases which differs from the criterion to reduce the risk of catastrophic equipment failure especially for jet fire impingement scenarios. The process systems are studied in detail to bridge the gaps and resolve the safeguarding limitations for facilities in operations which were designed based on legacy method, if any. Furthermore, this paper also provides further insight on the design aspects to meet the blowdown requirement. The findings from the study will be elaborated and recommendations proposed to solve any problems will be discussed.