bluuebunny/crossref_metadata_2025_split huggingface dataset:
Chemical Admixture for Right-Angle Set Wellbore Cements
Authors: Contreras Elizabeth Q. 
Published: March 2023

Abstract
Polyaramid-based chemical admixtures for enhanced gas-tight oil well cements are of interest in the oil and gas industry. Here, a polymer platform is used as the base material for a line of new chemical admixtures in cementing in applications such as small molecule release and particle delivery. Polyaramid-based admixtures provide high-performance for high temperature and high pressure applications in ordinary Portland cement. Experimental results show that a basic cement slurry design responds to the release of admixture by the measure of changes in viscosity and thickening times. Applications in cement design is demonstrated from measurements obtained using oilfield equipment, like the consistometer. Immense efforts towards cement sheath integrity are important for production and safety. Challenges arises during the construction of wells when cement transitions from a slurry into a solid sheath. This transition can span over a significant length of time allowing gases to travel to the surface, causing casing-in-casing (CCA) events and pressure buildup. The ideal scenario is to eliminate the transition time of the slurry by designing cements to set instantaneously into an impermeable sheath. Right-angle set cements are characterized by a 90° set time as measured by a consistometer. The consistency of cement after addition of this new admixture remains at 20 Bc. In all cases, the admixture thereafter remains embedded within set cement and contributes significantly to its mechanical property. Dual performance stems from unique characteristics, such as chemical composition and mechanical integrity of new polymer admixtures. Using these admixtures, gas-tight cement sheaths show enhanced mechanical properties, such as resistance to breakage and fracture propagation, as well.
Innovative Coiled Tubing Hybrid Fiber Optics Technology Increases Operational Efficiency
Authors: Ahmed Danish , Kaki Mohammed Ahmed , Mehmood Sajid , Aljuaydi Haitham S Saeed 
Published: March 2023

Abstract
Production logging is very essential to understand the flow profile of the formation that is being produced from. It helps to identify the contribution of the oil, water, and gas to the total fluid. To add, it is done on a usual basis to monitor the reservoir performance. Organic deposit adherence to production logging tool (PLT) spinners can hinder logging operations and result in inconclusive data acquisition. To avoid this problem, standard practices have been developed to clean out organic deposits using a standard coiled tubing (CT) reel followed by production logging using a CT reel equipped with wireline cable. Further optimization of those practices can help minimize operational cost, footprint on location, and overall job time.
New CT hybrid fiber optic technology (HFOT) was deployed to meet the optimization objectives and eliminate the need for a second CT reel. The technology combines optical fibers and conductor cable with insulation to withstand corrosive fluid environments and deliver power to downhole tools, thereby overcoming prior CT system dependency on downhole batteries to run tools. The system was used in a two-run cleanout-and-logging process: first, organic deposit dissolver was pumped for wellbore conditioning purposes, before production logging was conducted with a multi-spinner production logging tool and pulse neutron tool in the second CT run.
The new CT HFOT was deployed for the first time in a Middle East reservoir. Organic deposit−dissolving treatments and production logging operations were completed in four oil wells equipped with electrical submersible pumps (ESPs). After stabilizing the pressures and rates, the logging runs were conducted by recording multiple up-down passes and stationary measurements.
Introduction of the new CT HFOT helped to reduce operational time by an average of 40 hours per job resulting from rig-up time optimization between CT runs, which also helped in delivering a substantial cost saving to the operator. Using one CT reel also helped in minimizing safety risks associated with personnel exposure to heavy lifting equipment during rig-up and risks associated with battery handling and management.
This study illustrates job design, pretreatment preparation, operational details, and post-job result analysis. It particularly focuses on the HFOT along with a comparison with operations using a conventional CT and CT equipped with wireline cable. Readers will broaden their knowledge by learning about CT cleanout operations, logging operations, and ways in which new technology can optimize overall intervention costs while minimizing location footprint.
Streamlining Overshot BHA's: A Guideline to Optimize Fishing in Horizontal Wells
Authors: Almansour Sulaiman , Crawford Elspeth , Alzahrani Bader , Hamidon Zahaezuani Rafiq 
Published: March 2023

Abstract
While the industry has many recommendations on fishing operations and setups, a process of the selection for overshots, and a streamline when similar fish or wellbore conditions has not been discussed before. This paper will review a challenging case history well, with multiple fishes of the same type, and the lessons learned on selections with varying wellbore conditions. Taking into measure was the learnings from the post well review, and the creation of a flowchart to better optimize the selection of fishing Bottom Hole Assembly's (BHA). This incorporated the coordination of charts’ creation with the service provider, ensured a robust process with multiple choices and supportive reasoning for selection. The well primarily discussed in this paper, was a horizontal well in a tight gas field. The knowledge gained from the multiple fishes in the case study horizontal well, streamlined future choices in BHA selections for similar fishes. As an operator, having the flowchart encourages more discussion with the service company, and supports the engineers in planning operations.
New Well Design and Drilling Practices Changes Ensured Well Integrity Across Highly Fractured Carbonate Formations in Total Losses Area
Authors: AlMahroos Mohamed , Franco Nata , Levario Jesus , Corona Mauricio 
Published: March 2023

Abstract
The low success rate of curing complete loss of circulation across fractured carbonates in the field, where all kind of loss circulation material and unconventional plugs were tried without success, required better understating of the fractures and changes to the well design and drilling practices to ensure proper zonal isolation and well integrity. This paper describes the successful planning and implementation of these changes and how they improved overall well construction performance.
As most of the total losses occurred in the intermediate section, which combines pressurized water injection formation with depleted oil-bearing reservoir, curing process was very often never achieved. Understanding that some areas of the field are naturally highly fractured, but specially characterized by carbonate karst, dissolution, and mega fractures, was critical to map the high-risk area and modify the well design and practices.
The innovative risk-based well design was deployed to a series of wells across the field. The isolation between low- and high-pressured layers to prevent casing-to-casing annulus (CCA) sustained pressure[NMF1] throughout well life and, possibility of drilling ahead with no returns with one of layers already secured by previous casing were implemented. Suitable casing seat was selected in such way that critical high pressure and depleted zones were identified and isolated. Water-bearing layers in the upper section was efficiently balanced with enough mud weight and casing point set above risky zone with addition of double mechanical barrier with gas tight feature. Highly fractures formations in the lower section were drilled with significant lower mud weight at minimum overbalance, surge stresses and best possible fluid rheology. Casing running practices were adjusted to avoid inducing losses, cement slurries redesigned for optimum properties at minimum equivalent circulating density (ECD) and cementing jobs were conducted with full returns. The total loss events were significantly mitigated in the campaign, with overall 15% well performance improvement, ensuring zonal isolation, and reduction of future CCA occurrence, which can compromise the production casing integrity after fracking job, involves high remedial work costs, longer shutdown phase and possible production loss.
This solution balances performance and costs can serve a technical reference for future application in the basin or other regions with loss-prone environment across large and fractured formations, and well integrity is a concern for operators and service companies.
Environmentally Friendly Nanoshale Inhibitor Water-Based Drilling Fluids
Authors: Alqahtani Hassan Sakar , Arfaj Mohammed Khaled , Alhassni Mohammed Faisal , Alotaibi Mohammed Abdullah 
Published: March 2023

Abstract
Metal Oxide Nanoparticles (MONPs) comparison has been used for the first time as Nanoshale inhibitors in water-Based Drilling Fluids. These Nanoshale inhibitors used in this study eliminate the use of toxic high potassium chloride (KCl) concentration in shale drilling operations and environmentally friendly with reducing the cost of drilling fluid treatment and waste disposal.
The dispersion test of Nanoshale inhibitors based on MONPs with shale samples revealed to be an effective candidate with significant interaction reduction between the drilling fluids and the shale particles compared without these Nanoshale inhibitors samples. This new Nanoshale inhibitor maintains the integrity of the cuttings and minimize the interaction of fluids with shale sections during the rolling test. Zeta potential (ZP) has been conducted to determine the charge of shale and nanoparticles samples.
Although the application of nanoparticles to improve the performance of conventional water-based drilling fluid was studied by researchers, it is the novelty of this research to eliminate use of KCl and to develop the new generation of Nanoshale water-based drilling fluid with economical consideration and lower environmental impact.
Successful Deployment of Metal Expandable Annular Sealing Systems in High Extended Reach Wells
Authors: Ali Syed Muhammad , Nwosu Emmanuel Onyema , Farsi Nasser , Wood Kevin 
Published: March 2023

Abstract
The successful deployment of metal expandable annular sealing systems in extreme reach design wells completion. The design and engineering of this technology resulted in the development of a fit for purpose, state of the art equipment that overcame several challenges such as having the liner with full rotational capability to overcome the drag during the deployment while maintaining the full liner torque capabilities.
The metal expandable annular sealing system was designed to provide high expansion in potentially washed-out wellbores and across formations where effective isolation may not be achieved by primary cementation due to low formation gradient or cement design challenges in horizontal wells. The design included a long multi element sealing system with built in redundancy. The multi sealing element system chosen for this application due to it being a full bore, rugged, all welded, metallic construction with a constant, high ∆p over full expansion range. The system is fully rotatable during deployment, it also allows for high-rate circulation because of its slim OD.
The metal expandable annular sealing system was run in total or partial losses multiple times, and it was observed that circulation was gained after setting the metal expandable system. Furthermore, it was also confirmed that the system effectively provides zonal isolation by injecting into compartment and ensure that zone is completely isolated.
Technical Limit Pursuit - Unconventional Engineering Toward Maximizing Performance While Overcoming Drilling and Tripping Challenges
Authors: Almasmoom Salahaldeen S , Al-Qahtani Faris A , Rahmani Nadhir , Ghazzawi Ayman 
Published: March 2023

Abstract
A major requirement to make drilling a cost-effective exercise is to maximize the performance to cut well delivery days (and therefore well associated cost) to the minimum. The area of interest experienced challenging startup. However, quick learning curve, and therefore a clear well–on–well improvement, is achieved while pursuing the technical limits of the downhole drilling equipment. A recent well having a record-breaking performance will be covered. The optimization efforts are reproduced on all wells aiming to surpase the newly established performance records.
Offset wells were thoroughly analyzed to identify all potential areas for improvement and a detailed performance improvement plan was then prepared for all sections. Starting from surface sections (16-in and 12-in sections), clear road maps are followed taking into considerations each formation characteristics and previous real-time data for optimum parameters.
Then moving to the 8-½-in combined vertical/curve/lateral sections, the most aggressive improvement plan is applied. This was achieved by adjusting the drilling strategies, revising the drilling systems used, and modifying the bottom-hole assemblies to reach reducing the number of runs required to clean-out previous casing and drilling the combined vertical/curve/lateral sections to one.
Engineered solutions and continuous pursuit of the technical limits of the performance/directional equipment/systems succeeded to speed up the learning curve of the drilling performance, and then resulted in a continuous improvement along the journey of the development of the area of interest. The 16-in and 12-in sections are having back-to-back performance records. The work is continued with the consistent spirt of "limit is still to come" to maintain the good results and ensure repeatability (if not improving) on a well-on-well basis. Moving to the 8-½-in section, the one-BHA (bottom-hole assembly) approach succeeded and proved to be a major contributor to reducing well delivery time; it is now the standard practice on almost all new wells drilled, combining cleanout out previous casing and drilling vertical/curve/lateral sections to well total depth.
Connection and surveying procedures were revised on all sections, and optimized to the minimum. This allowed cutting the average weight-to-weight connection time from 14 minutes to 7 minutes. As a result, the well delivery days’ duration was cut to 16 days on average from 24 days in the previous year until delivering a country record well with spud-to-total depth in 12.8 days, and spud-to-rig release in 16 days. This country record-breaking well will be discussed in details.
Intelligent Coiled Tubing Systems: Overview, Research Trends, and Challenges
Authors: Li Chengxi , Singh Harpreet , Cheng Peng , Wang Xunjie , Hao Ge , Liu Qing 
Published: March 2023

Abstract
In recent years, improving the efficiency of producing hydrocarbons from extended-reach horizontal wells has created a need to develop better well intervention, specifically coiled tubing (CT) solutions. However, because the conventional coiled tubing system only relies on surface data to monitor and predict downhole conditions, its application's effectiveness, accuracy, and efficiency still need to be improved. On the other hand, intelligent coiled tubing interventions use real-time downhole data to improve operational efficiency and performance. The objective of this paper is to present a detailed review of the fundamental principles and applications of intelligent coiled tubing systems and a discussion of the challenges and prospects of intelligent coiled tubing technology. Based on the different telemetry systems, the Intelligent Coiled Tubing technology can be categorized into three systems: Tube-Wire System, Fiber-Optic System, and Hybrid Electric-Optical Cable System. This paper will mainly focus on these three types of intelligent coiled tubing systems with a detailed review of the system functionalities, features, surface equipment, bottom hole assemblies, downhole sensors, and critical applications supported by case studies. A summary of the conventional coiled tubing equipment, tools, and applications is also included as technical background for the readers. The current technology status of the major operators is also summarized, representing the most advanced technology and service available on the market. In this study, we give a thorough overview of the Intelligent Coiled Tubing technology systems currently on the market and identify potential applications that intelligent coiled tubing can bring value to improve efficiency and performance. We also present several case studies of intelligent coiled tubing. Based on the case studies data, we summarize these critical applications and evaluate the values created using intelligent coil tubing systems. From the analysis, we find that the real-time monitoring, diagnosis, and decision-making functions of intelligent coiled tubing can efficiently solve operational problems in real-time, improve operational efficiency, increase tool life, and reduce downhole accidents while achieving increased production because of parameter optimization and correct decision-making. The paper introduces the working principle of intelligent coiled tubing technologies and case studies in various fields with different operational conditions. The proposed paper thus gives a clear and big picture of this topic from various aspects. We further extract and summarize the critical knowledge from the most recent case studies of intelligent coiled tubing technology. As a result, this paper will facilitate operators with less experience in intelligent coiled tubing technology to understand and apply this technique efficiently.
Identifying Fracture Sweet Spots Using Artificial Neural Network Approach: A Case Study in Najmah/Sargelu Reservoir, Kra Al-Maru Field, West Kuwait
Authors: Nguyen Kim Long , Jumah Meshael , Verma Naveen , Quttainah Riyad 
Published: March 2023

Abstract
Artificial Neural Network (ANN), defined as intelligence exhibited by computer through emulating the functioning of cerebral neurons, has many applications in today's society. ANN application (Ouahed et al, 2005) has become widespread in petroleum geoscience and reservoir engineering as it is able to generate accurate prediction taking an integrated and un-bias view of multiple inputs using supervised or unsupervised machine learning approaches. Unlike simple clastic sandstone reservoirs, the distribution of fractures in carbonate reservoirs is complicated and heterogeneous due to multiple genetic factors involved that makes high-resolution 3D modeling and simulation challenging. In order to enhance the reservoir characterization and modeling work in fractured reservoirs, an innovative application of Artificial Neural Network is introduced to tackle the disadvantages & shortcomings of existing techniques used in the Oil & Gas industry.
This paper discusses the importance of ANN to delineate fracture sweet spots of Nahmah/Sargelu carbonate reservoirs in order to optimize drilling strategy in Kra Al-Maru (KM) field, West Kuwait. ANN works as a simulation of human brain, which comprises of highly interconnected neurons. These neurons process and integrate data from various domains to generate a desirable output. Nowadays, the application of ANN is prevalent in the field of fracture characterization and modelling technology because of its supremacy in data prediction and estimation. An integrated Continuous Fracture Modeling (CFM) workflow is established using ANN technology to understand the relationship between 3D seismic attributes and fracture intensity log derived from borehole image (BHI) data in both qualitative and quantitative evaluation (Pinous et al, 2007). ANN plays a critical role as it transforms the learning from seismic-image log relationship to 3D fracture intensity model. Consequently, the fracture sweet spots in the KM field is delineated to gain comprehensive understanding of fracture distribution in the field. The validity of the work is confirmed by blind test from the recent development well. If the result is not satisfactory, the ANN model is fine-tuned until the result matches in the blind test. The success of the study helps to refine the drilling strategy of the challenging KM Field, while reducing the risks and costs significantly.
Real-Time Facies Characterization Using LWD NMR Factor Analysis in High-Angle Wells
Authors: Hursan Gabor , Van Steene Marie 
Published: March 2023

Abstract
Nuclear magnetic resonance (NMR) logs in long, high-angle wells drilled across a single reservoir often consist of a few recurring features which are difficult to identify visually in the NMR T2 distribution logs. This paper presents a fast data clustering method called NMR factor analysis (NMRFA) that categorizes massive LWD NMR datasets into a few poro-fluid facies, which enables a quick, data-driven geological interpretation using single or multiple wells.
NMRFA is a data reduction technique that aims to describe and interpret variability in NMR spectral logs using a small number of unique components. These components are clustered statistically to distinct groups called poro-fluid facies, which reflect combinations of pore volume, pore size, and fluid NMR properties. While drilling the well, the NMRFA is applied to the real-time T2 distribution measurements to quickly associate new observations of rock quality or heavy oil with stratigraphic understanding to assist well placement decisions. Joint interpretation of the NMR-based para-fluid facies logs from multiple laterals underpins data-driven updates of reservoir-scale geological facies maps.
After testing the method on two data sets already calibrated to core and formation testing measurements, the NMRFA technique was used in three laterals drilled back-to-back in a thin carbonate where pore size variations and possible presence of heavy oil were expected. In the first lateral, the best NMR facies were mostly observed in the first part of the well, followed by poorer poro-fluid facies that indicated the presence of heavy oil. At the end of the well, the facies analysis indicated mostly tight rocks. In the second lateral, the NMR log suggested a more homogeneous facies distribution than in the first well, with medium T2 and medium porosity. Tar or heavy oil were not encountered in this well. With the facies trends in the first two wells, the third lateral targeted a likely occurrence of the high-quality facies seen in the top section of the first well. After crossing a tight zone, this well encountered an excellent NMR facies of high porosity and very long T2 with no indications of heavy oil. The well was successfully navigated within the favorable facies whose quality matched or exceeded the best rocks encountered by the first two laterals.
NMRFA analysis was used for poro-fluid facies evaluation of LWD NMR datasets in real-time settings for the first time to better categorize complex reservoir types in horizontal wells. The robust, data-driven analysis method and its intuitive log-based and structural visualizations helped well placement decisions and enhanced structural learnings in three extended reach laterals drilled in a complex carbonate reservoir.