bluuebunny/crossref_metadata_2025_split huggingface dataset:
Capillary String Deployment Methodology for Tight HPHT Gas Wells Deliquification
Authors: Kalwar Ghulam Murtaza , Yami Ali M , Alomran Ali A , Kaleem Abdullah 
Published: February 2024

Abstract
De-liquification method utilization has been investigated as a possible solution in sweet and sour gas wells, which suffer from liquid loading issues. There are limited options available to deploy de-liquification technologies in deep, unconsolidated, high temperatures, and in for specific completion designs. This paper discusses the screening of a range of methods and selection of a robust option to deploy downhole injection treatment facilities for the continuous foam.
The technical feasibility of a range of downhole foam injection installation methods, while maintaining minimum barriers, has been assessed. The continuous deployment of downhole foam injection is much more efficient and cost effective compared to batch-treating the well with liquid foam. This application maintains the well integrity and avoids well deliverability reduction. The injection system may also be used to continuously inject multi-blend chemicals downhole to treat various other issues such as scale, corrosion, and condensate banking as well as address downstream problems and reduce the need for surface inhibition. Designing the system with the appropriate chemicals and tubing material is the key to success. The selection of material and chemicals should take into account the CO2, H2S, high temperature, and pH concentration in the candidate wells.
The chemical injection string can be installed into a live well using a capillary unit, without the need to shut in or choke back production. This can be a rigless installation and will be similar to a coiled-tubing operation, but on a much smaller scale. The capillary unit is small and compact, and is mounted onto a truck/trailer. The unit can quickly and easily be mobilized and de-mobilized for operation, saving time and cost. Routine maintenance to the injection system is crucial for a long-term, successful application. The qualification of the chemicals should be stringent and needs to allow for friction loss through small inner diameters (IDs) that can withstand the pressures, temperatures, fluids and extreme downhole conditions. Using the continuous downhole injection system will positively impact well integrity, improve completion lifetime, assure production continuity, reduce downtime and treatment operating costs, and avoid coiled-tubing descaling operational costs.
Installing a downhole treatment system can also be used for other purposes if needed, such as H2S management, scale inhibition, controlling paraffin/asphaltene and treating downhole pumps.
Advanced Downhole Torsional Oscillation Control Tool Improved Dynamics and Field Average ROP
Authors: Al Rubaya Ahmed Meshaal , Alexeyenko Alexey , Khateeb Ashraf 
Published: February 2024

Abstract
The introduction of a novel torsional oscillation control technology, characterized by its high amplitude, extended attenuation length, and mode-coupled axial excitation, has been instrumental in enhancing drilling dynamics and augmenting the on-bottom drilling rate of penetration (ROP).
To effectively integrate this technology, a strategic approach was employed, which involved the use of a multi-point elastic contact force software for tool placement modeling. This software is adept at pinpointing string elastic breakover points and discerning localized contact side forces within the drill string under specific drilling conditions. To realize the desired outcomes, the deployment of two torsional oscillation control tools was deemed necessary.
A comprehensive evaluation was undertaken to gauge the efficacy of these tools. This involved juxtaposing the outcomes derived from the tools with the real-time operational results of downhole systems in the same field, spanning a 1000-foot interval. Key metrics, including downhole stick-slip and measurement while drilling (MWD) revolutions per minute (RPM), were meticulously assessed, considering their responsiveness to surface parameters and loads.
The findings were promising. There was a marked improvement in the field ROP average, witnessing an increase of 8%. Furthermore, there was a notable decline in the peak-to-peak RPMs (stick-slip) relayed in real-time through the MWD tool. Another significant observation was the substantial reduction in the effective downhole reactive torque when juxtaposed with the offset data. The drilling dynamics data underscored an optimal downhole RPM coupled with an enhanced weight transfer. This was in alignment with the energy efficiencies projected by the model, which factored in the influence of the torsional oscillation technology and provided insights into optimal tool placement. An ancillary discovery was the improved downhole directional control. A more overarching insight was the diminished energy consumption during drilling relative to the offset. Moreover, this pioneering technology played a pivotal role in lowering the downhole MWD temperature.
What sets this Torsional Oscillation Control technology apart is its innovative approach to mitigating the inherent elastic inertia moments within the drill string. These moments, which are typically stored and subsequently dissipated, are effectively addressed by this technology. A salient feature of this technology is its capability to curtail the energy loads, paving the way for heightened drilling efficiencies.
A Statistical Approach Analytics and Considerations for Extending ESPs Run Life
Authors: Albori Mostafa M. , Al-Khalaf Ahmed A. , Alsadah Hashim A. , Flippin Cleavant J. 
Published: February 2024

Abstract
Electrical submersible pump (ESP) system has been one of the major hydrocarbon artificial lifting mechanisms globally that is used to produce and sustain required rates. To avoid production interruption caused by ESPs undesirable events, a statistical approach had been conducted to look into ESPs up-time variation to find potential remarks to extend it.
Statistical analysis approach, such as probabilities distribution functions, had been conducted to analyze potential factors in electrical submersible pumps that exhibited extended running life. Multiple factors were evaluated and divided based on influences of run time, including: ESP downhole manufacturers, equipment conditions during installation, electrical motor sizes, soaking time, ESP settling environment, and ESP operation performance. This analysis helped to identify technologies, practices, and other factors that could have potential impact in ESP run life and the practicality in applying them to extend ESP run life.
Statistical approach of multiple factors and their effects were analyzed and evaluated to determine their impacts on ESPs’ up-time. Based on analyses, the findings were divided and characterized into their effectiveness range on the ESPs’ life time. The factors were divided into: little to no influence on the run life variations, some criteria had some influence on run life. While other criteria are suspected to have more effective role in determining and impacting ESP life. The studied factors and resultant recommendations are listed with implementation criteria to be considered to enhance future ESP installations and replacements to exceed the threshold ESPs’ target run life.
ESP running time is one of the major points to consider when it comes to fields dependent on ESP artificial lift method as the main production lifting mechanism. Therefore, extending ESP uptime can be of huge benefits in both operations and economics.
Enhanced Reservoir Understanding and Geomechanics With LWD High-Resolution Ultrasonic Imaging in an Unconventional Horizontal Well
Authors: Al-Naqeeb Mohamed Nizar , Ghneej Ali Faleh Abu , Al-Khabbaz Mohammed , Al-Ostath Mohammad , Ali Aisha Al-Bin , El Din Ali Hossam , Awadh Ahmad , Elshennawi Mohamed , Abdulkarim Anar 
Published: February 2024

Abstract
The Najmah carbonate-shale formation, an unconventional Jurassic kerogen layer in the North Kuwait region, has undergone testing, revealing its significant potential as a gas, condensate, and light oil reservoir in various well locations and as a prolific source rock. Given its exceptionally low porosity, the flow-control mechanism is heavily reliant on the presence of a natural fracture network.
This layer, previously referred to as Najmah shale, serves as the source reservoir, characterized by its abundant organic-rich clay with both argillaceous and calcareous components. This is evident in the notably high total gamma ray values, which are accompanied by elevated uranium levels on spectral gamma ray logs. Matrix porosity averages between 2% and 6%, permeability is low, ranging from 0.01 to 1.5 mD, and the total organic content (TOC) falls within the range of 2% to 30%. The precise identification and interpretation of fractures, bed boundaries, and borehole breakout through high-resolution imagery play a vital role in the optimization of completion design. In the context of horizontal wells, utilizing wireline technology has been challenging, making the preference for logging-while-drilling (LWD) acquisition evident.
The case in point pertains to a horizontal exploration well drilled in the Najmah formation of northern Kuwait, which employed a rotary steerable system combined with gamma ray and resistivity sensors. The drilling operation aimed to facilitate a multi-stage fracking completion. The comprehensive logging program also included measurements for density, neutron porosity, sonic, and high-resolution ultrasonic borehole imaging. To mitigate the risk of stuck events, the decision was made to utilize LWD acquisition. Traditionally, wells in the area were drilled in the minimum stress direction (SHmin) to intersect natural fractures perpendicularly for optimal fracking. Surprisingly, most of the natural fractures were found to be nearly parallel to SHmin. The data collected achieved a high level of quality, surpassing the expectations of the end data users. Within a measured-depth interval of 1,610 feet, a total of 96 natural fractures, 16 bed boundaries, and a few breakout intervals were interpreted.
The newfound insights into fracture orientation will be considered in future well design planning. These results have also proven invaluable in enhancing the prospects for future field development and completion design optimization. Further analysis and studies in the field are on the horizon to validate the interpreted findings.
Integrating Reservoir Mapping and High-Resolution Imaging Technologies Leads to Deliver the Fastest Well with Enhanced Production in an Unconventional Limestone
Authors: Al Ajmi Saad , Al-Azmi Mejbel , Al Otaibi Fahad , Joshi Girija , Pattnaik Chinmaya , Issa Dania , Danash Tarek , Tikhonova Izabella , Vican Kresimir , Abdulkarim Anar 
Published: February 2024

Abstract
Well placement in an Unconventional Jurassic Formations of North Kuwait is challenged by poor seismic resolution and high uncertainty in the stratigraphy leading to lateral variability of petrophysical parameters and thickness of the pay zone. The 6-9 feet thick target zone is located at 14,000 feet depth with expected uncertainty in the bed dipping angle. Key technologies were deployed to increase gas production in the tight carbonate formation with depositional uncertainties.
A pre-well model was built from existing offset wells to assess the well-placement capabilities. A combination of ultra-deep azimuthal resistivity mapping (UDAR) and gamma ray imaging tools were deployed for accurate landing and steering of the lateral section. The objectives were to keep the well trajectory in the payzone, anticipate and identify any abnormalities in the formation while passing through sub-seismic faults and enable rapid response to sudden changes in formation dip due to structural changes. The ultra-sonic high-resolution imaging (UHRI) tool was utilized across the lateral section to evaluate fractures, faults, and hole shape for optimizing completion design and enhancing production.
The 9.25″ landing phase successfully reached the desired target with around 1 degree higher-than-expected formation dipping angle. The target was identified and confirmed by the UDAR and additional logging-while-drilling (LWD) data. The 6″ lateral section was maintained within the target zone, achieving the maximum reservoir exposure passing through several geological features including faults, which were reflected on the resistivity inversions. The combination of deep and short-range measurements enabled successful well placement in the target zone. A spectral gamma ray image helped to identify the clay layers close to the wellbore, whereas the resistivity inversion identified multiple layers on a bigger scale, away from the wellbore. The UHRI helped to facilitate the optimization of completion design and further the field development by identifying 129 features including 125 fractures, 2 faults and 2 bed boundaries. The combination of UDAR with UHRI helped to deliver the fastest well in unconventional Najmah Limestone and supported optimization of the completion design providing enhanced production from the well.
This methodology was further recommended to be utilized in upcoming similar well profiles to improve the field development in Unconventional Najmah Limestone reservoir of North Kuwait
Advancements in Next Generation Collar Compact Integrated Logging While Drilling Technology
Authors: Elsherif A. , Verma J. , Alamin M. 
Published: February 2024

Abstract
This paper summarizes the steps and shows the results of field testing of a new Logging While Drilling (LWD) tool in a carbonate reservoir in the Middle East.
The next generation LWD tool was designed to achieve several tasks. The first task was to keep important sensors like Gamma ray and Density as close as possible to the tool bottom. This task is very important for Geosteering horizontal wells to allow fast reaction to environmental changes.
The second task was to combine all basic measurements (Resistivity / GR / Density / Neutron) in one collar less than 30 feet long. This was achieved with a 29 feet collar that has all the required measurements for basic petrophysical evaluation including fully compensated resistivity measurement with three depths of investigation.
The third task was to also include spectral Gamma ray measurement (Thorium / Potassium / Uranium) in the same collar. The Spectral GR sensor was tested in the tool with good results. The value of the Spectral GR across the formation was shown in this paper.
The final task was to include several azimuthal images capabilities with high resolution. That task was achieved with Gamma ray / Density / Caliper azimuthal images with 32 bins of resolution.
The tool was field tested first in Catoosa facility in USA and the data was compared with Wireline data from the same well. The comparison showed very good agreement in different measurements
The second phase of the field testing was done in Oman in a carbonate reservoir. Three trials were done with the tool in tandem with the main vendor tool and RSS while drilling. The data was recorded in memory mode using downhole batteries. After pulling out of the hole, the memory data was dumped and tested against vendor data with great success.
The imaging capability of next generation LWD tool has been verified as a great tool for Geosteering close to a shale barrier above the well trajectory in one of the three wells.
The Influence of Various Parameters on Petroleum Oil Removal from Produced Water with Novel Nanobubbles/microbubbles Flotation
Authors: Colic M. 
Published: February 2024

Abstract
Produced water at offshore and onshore petroleum and natural gas extraction sites is very complex and contains many inorganic and organic contaminants. Such contaminants include free and emulsified petroleum oils and suspended solids. Gas flotation technologies are commonly used to remove finely dispersed oil droplets and suspended solids. New generation of flotation systems use nanobubbles-microbubbles generators that can produce very small bubbles ranging from 1 - 1,000 nanometers and 1-30 microns. However, influence of various parameters such as pH, salinity, temperature, pressure, type, and dosage of polymeric flocculants, mixing energy and hydraulic residence time have not been studied. In this manuscript we present detailed analysis and literature review of parameters that influence the performance of such flotation systems. High molecular weight and high charge density cationic flocculants significantly enhance the removal of dispersed oils and solids. Dual cationic-anionic flocculant approach is particularly efficient. Centrifugal hydrocylone based flotation systems where nucleation of bubbles and flocs occur at the same time are particularly effective. Higher temperature and pH enabled better emulsion flocculation and flotation. Salinity impairs flocculant activation and the performance of flotation system.
Nanobubbles enhance flotation and flocculation at high NaCl concentrations. We propose a "hungry black hole" model for nanobubbles effects in flocculation and flotation: nanobubbles occasionally collapse and like black holes release a strong jet of gas that can then penetrate oil droplets, flocculant chain networks and floc pores. Secondary nano and microbubbles nucleation in those pores then creates large light flocs that float in seconds to the top of flotation units.
Dissolvable Materials for Buoyancy Driven Downhole Robots
Authors: Seren H. , Zeglache M. , Powell C. , StMichel N. 
Published: February 2024

Abstract
Dissolvable materials made a positive impact in many downhole applications by reducing down-time, cost, and operation complexity, especially as frac plugs. For a new application for these materials, here we investigate their deployment as ballasts that can be attached to buoyancy driven untethered downhole robots, such as the Sensor Ball [1]-[2]. The Sensor Ball is an untethered downhole tool that takes a ballast to sink in the well fluids and releases it to become buoyant, hence it can return to the surface. Although the ballast is released on-demand via a magnetic actuator, using a dissolvable ballast is useful for two reasons: 1) The clutter left behind is minimized; 2) Provides a fail-safe mechanism such that the buoyancy is regained even when the weight releasing system fails. The Sensor Ball needs a ballast material that is as dense as possible to easily offset its effective density. Among the readily available materials, aluminum alloys are suitable, but pose problems such as highly exothermic reaction. These materials can cause extreme heating that can raise the local temperatures over 100 °C at downhole pressures. A secondary issue is the byproduct formation and aggregation. The aggregated solids inside water cause a mud-like viscosity that can entrap the Sensor Ball. Polymer spray coatings and separation of functions for clutter prevention and fail-safe mechanisms were effective in reducing the exothermic heating and mud formation. We also investigated 3D printed dissolvable polymer containers with metal powders. Although this method was useful in addressing the heat generation problem, the containers showed mechanical integrity problems.
Sand Channel Characterization and Fault Identification Utilizing Ultra-Deep Resistivity 3D Inversion in Complex Clastic Reservoirs
Authors: Elkhamry A. , Bikchandaev Eduard , Fouda M. , Taher A. 
Published: February 2024

Abstract
Modifying the well position to maximize production requires both detailed reservoir characterization and mapping of sub-seismic features to identify and remain within the optimal zone. Sand channel characterization, including mapping their orientation, thickness and geometry is important to enable optimization of the well path in this complex environment to maximize the net to gross. Combining high Resolution Imaging tools used traditionally for sand channel characterization and fault identification with ultra-deep 3D electromagnetic inversion improves understanding and provides clear visualization of sand channel behavior.
Advanced azimuthal ultra-deep resistivity tools with improved signal to noise ratio and processing techniques have enabled better reservoir visualization. Resistivity and geo-signal curves, images, raw components and associated inversions are provided which can be widely used for landing, geo-steering, geo-mapping and lithology identification (Anisotropy) or even petrophysical analysis (Far Field Saturation) at distance. Recent advances provide 3D Inversions, which can be used for sand channel characterization (mapping out the orientation, thickness, and geometry) and fault identification (dip, strike and amplitude) with confidence. In the candidate wells, 3D EM Inversion revealed sand channels distribution in the area for the target reservoir.
An innovative workflow for Sand channel characterization and fault identification with ultra-deep resistivity 3D inversion in complex clastics reservoirs has been developed based on the acquired 3D Inversion data and combining multiple sources of data from near wellbore as well as offset logs. In the first field case two sand channels were identified, in the second field case a break with displacement (fault) dislocating the reservoir has been identified and characterized with dip, strike and amplitude values from the 3D Inversion. The 3D Inversion and proposed workflow could be used for optimizing current and future well placement by adjusting well azimuth while drilling, planning sidetracks and field studies incorporating the 3D data into seismic models.
This paper demonstrates field cases utilizing ultra-deep resistivity 3D inversion for mapping out the orientation, thickness and geometry of the sand channels and fault identification in complex clastic reservoir to provide increased reservoir understanding.
Data-Driven Drilling Performance Improvement: The Synergy of Digitalization and Offset Well Data Utilization
Authors: Elghoneimy Mahmoud , Hiep Nguyen , Fakhrylgayanov Ayrat , Gari Abdulrahman , Nsanov Nurbol , Osman Ahmed , Chen Wei , Gonzalez Luis F , Shatrovskiy Anton 
Published: February 2024

Abstract
Data-driven optimization for drilling operations is becoming increasingly important in the oil and gas industry. Digitalization and utilization of historical offset well data can provide critical insights into improving drilling performance and aid in making informed decisions for the best selection of drilling parameters. This paper aims to present an integrated approach between a research center and the field that leverages offset well data and drilling engineering domain knowledge with data science and machine-learning models to improve drilling performance through more stable drilling dynamics. This novel drilling optimization method utilizes a digitalized process that combines drilling dynamics data from offset wells and drilling engineering domain knowledge with advanced data science algorithms (statistical analysis, optimal searching, and machine learning) to generate optimum drilling parameters automatically. This hybrid optimization approach, integrating science and domain knowledge, aims to systematically minimize the energy dissipated in drilling shocks and vibration (S&V), which would then lead to maximizing drilling efficiency in a continuous improvement cycle. The effectiveness of this approach is proven through case studies from various oil and gas fields in which we discuss the associated key challenges for current and future developments. The authors showcase through these examples the significant gains in drilling engineering efficiency when automated data analytics’ workflows are used to make the utmost value of offset well data utilization in improving drilling parameters. The results include a significant reduction of S&V, which leads to better directional drilling accuracy and reduced downhole tool failure risks. The approach has also increased drilling performance, resulting in faster and more efficient drilling operations. Furthermore, the use of this approach has led to a reduction in overall drilling time, resulting in substantial cost savings for drilling major oil and gas fields.