bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reducing CO2 Emissions During Wellbore Cleanout Operations by Employing Coiled Tubing Fluid Oscillation Tool – A Case Study
Authors: Elmoneim H. , Yousuf A. , Shahzad K. , Anwar R. , Khokhar S. Y. , Saeed M. S. , Inam S. , Sana-ul-hussnain M. , Shafee I. , Haider M. 
Published: February 2024

Abstract
During 2022, oil and gas operations resulted in emission of 5.1 billion tons of CO2equivalent. These emissions must be reduced on the journey towards net zero emission. Wellbore cleanout operations with coiled tubing are one of the most frequent operations performed during the life of a wellbore. The coiled tubing and associated equipment used for wellbore cleanout operations is powered by diesel engines which result in high CO2 emission during operation. However, these emissions can be reduced by using a fluid oscillation tool.
A fluid oscillation tool converts kinetic energy of the pumped fluid into potential energy resulting in the creation of pulsating waves. These pulsating waves induce cyclic stress in the scale. Continuous cyclic stress induces fatigue failure in the scale which ultimately leads to disintegration of the scale present in the wellbore or critical matrix. Fluid oscillation tools can remove scales in less time and provide better fluid velocities in the wellbore even in nitrified treatments. This ultimately reduces the time of operation considerably. Furthermore, reduction in operational time corresponds to low consumption of diesel by the CT and associated equipment, leading to lesser emission of CO2.
A fluid oscillation tool was employed at multiple wells in the region of this case study to perform wellbore cleanout jobs. This paper thoroughly performs data analysis of four different wells and demonstrates the impact of fluid oscillation tool on different performance factors. Using a fluid oscillation tool led to a decrease in CO2 emission between 35-62%, reduced CAPEX between20-47% and increased production between 170-310%.
Nearly 57% of the well intervention operations performed in the region of this case study are wellbore cleanout operations. Replacing the conventional jetting tool with a fluid oscillation tool led to a decrease in CO2 emission from 1843 Tons to 924 Tons. This reduction corresponds to approximately 50% of CO2 emission during wellbore cleanout operations. The scale of this reduction would be more appreciable when adopted universally.
15K Multi-Entry Cemented Multi-Stage Fracturing System-Alternative Completion Method for Deep Tight Gas Wells
Authors: Rodoplu Rasim Serdar , Alenezi Awad , Dahlan Mohammed , Tait William T. 
Published: February 2024

Abstract
Multi Stage Fracturing (MSF) completion technology with a true 15,000 psi pressure rating, Multi-Entry (ME), cementable system was developed for utilization in deep tight gas wells. The new completion system brings operational and design improvements to the MSF methods utilized for these types of wells. This paper discusses the details on the development of the novel system considering harsh well conditions, its multi-entry design for creating multiple fractures across each stage, and improvements compared to the traditional open hole MSF solutions. A detailed review of the requirements for the completion installation, activation, fracturing execution and expected performance metrics will also be covered.
The new cemented MSF completion system consists of a cementable hydraulic toe sleeve and cementable fracturing ports. The toe initiator placed in the first stage is opened by applying pressure whereas multiple cementable fracturing ports in the remaining stages are opened by dropping a single size ball in each stage. Zonal isolation relies on cement behind the completion rather than mechanical, swellable or metal expandable packer as in regular Open Hole (OH) MSF systems.
To verify the completion system suitability for the target application, a thorough design of the system components and qualification testing were needed. Collaborative approach, clear project scope definition and detailed review of the solution were key factors to ensure final product met expectations.
Several wells completed and stimulated successfully with the new ME MSF system will be discussed. It is observed that the slim design, rotatable feature was mitigating the challenges, reducing the overall risk of deployment. In addition, stimulating of stages using a single ball per stage activating multiple sleeves in each stage, except for the first stage which was with cementable hydraulic sleeves, resulted with more efficient fracturing operations by reducing time, resources, and emissions.
The 15K cemented ME MSF completion system provided a third MSF option to complete deep tight gas wells in addition to the current two methods of cemented liner and open hole MSF completions. It bridges the gap between the current systems by relying on the cement for zonal isolation and allowing multiple sleeves in each stage, imitating clusters used in Plug&Perf (P&P) operations. The system eliminates isolation packers compared to open hole completions and perforation, plug setting, plug milling when compared to P&P cemented liners technique in which wireline and coiled tubing interventions are required.
Optimization of Drilling With High-Frequency In-Bit Sensing
Authors: Stolboushkin E. , Kueck A. , Pauli A. 
Published: February 2024

AbstractIn-bit sensing technology measures the dynamic response at the bit during drilling operations. Recently such devices have been equipped with high sampling rate sensors, advanced sensor designs, and large data storage allowing entire bit runs to be recorded. This paper will present the technology, research, and testing that has allowed the development of a data driven decision loop for the optimization of drilling operations in the field.Data from the in-bit sensors allows the identification of drilling dysfunctions and provides actionable information from which to tailor drilling parameters to specific geologies. Additionally, drilling simulator testing, with in-bit sensors, in various geologies and with BHAs provides a database from which it is possible to create stability maps and bit performance benchmarks that can be directly used for optimization of drilling operations.Various drilling dysfunctions, such as High Frequency Torsional Oscillation (HFTO), are detrimental to both drilling efficiency and the reliability of downhole equipment. Drilling performance also varies by geologic features. Field case studies of the successful use of this technology in actual drilling operations will be presented to demonstrate the utility and impact of this technology.The data from these sensors is particularly useful due to their placement in the drill bit, where the fullest extent of downhole dynamic regimes can be observed. In bit sensors are showing utility in bit design, drilling optimization, and even well and field designs.
Delivering Successful Quadlateral Wells Campaign in the Middle East: Milestones & Lessons Learned
Authors: Maafri Mbarek , AlGaiar Mahmoud , Farhat Moustafa 
Published: February 2024

Abstract
This paper examines the successful execution of multilateral drilling and completion of complex oil wells in the Middle East, a region known for its abundant hydrocarbon resources and unique set of challenges, including wellbore stability, stuck pipe, trajectory control, drilling vibrations, downhole tool failure, and low penetration rates. The objective is to provide an in-depth analysis of the challenges faced, the best practices employed, the lessons learned, and the value added to the industry through these efforts.
The challenges of drilling and completing multilateral wells require innovative approaches and advanced technologies throughout the well construction process. The pre-planning phase includes the analysis of offset drilling events and wellbore design, wellbore trajectory design and collision avoidance, wellbore stability modeling and recommended mud weight windows, mud system design including hole cleaning efficiency analysis, drill bits design and drilling vibrations management. The paper examines each challenge and the strategies used to overcome them, including the use of advanced drilling tools, real-time data analysis, and collaboration with multidisciplinary drilling optimization teams.
The vigorous implementation of the roadmap developed by the multidisciplinary optimization teams helped achieve the pre-determined run objectives in terms of planned target depths, stuck pipe avoidance, drilling vibrations management, increased penetration rates and improved tripability. Real-time drilling parameters, torque and drag, formation evaluation, and equivalent circulating density monitoring played a critical role in the drilled sections delivery. These practices contributed to the overall efficiency and safety of the drilling process, reducing the risk of potential hazards, and minimizing the environmental impact. Lessons learned were also highlighted, including the importance of cross-discipline collaboration, the value of embracing new technologies, and the role of effective communication in managing complex projects.
This paper explores the value added by applying multilateral drilling and completion best practices and highlights the benefits of a multidisciplinary approach in such a challenging drilling environment. These include improved well performance, increased hydrocarbon recovery, reduced well construction costs, and the potential for economic growth and development in the region. By sharing these insights, this paper aims to contribute to the ongoing pursuit of excellence in the oil and gas industry and promote sustainable and responsible resource development.
Case Study: Saturation Assessment in Law Resistivity Pay (LRP) 1d & 3d Modeling (DH-Libya)
Authors: Ablil W. , Elsadawi A. , Altownisi M. , Aboelkhier M. 
Published: February 2024

Abstract
DH reservoir located in North Africa in the middle of Libyan dessert, Sirt Basin. This field is an immature carbonate reservoir with good Petrophysical properties, but with Low Resistivity Pay (LRP). The development of this field has encountered several obstacles to overcome the effect of micro-porosity (vugy porosity) measurements to estimate the water saturation. Standard electrical resistivity tools used widely on DH reservoir to compute the saturation with no clear vision of success. This issue effects directly the Water Saturation computation and ends up with High uncertainty of STOOIP calculation. The objectives of this study are to find a representative saturation profile and to better estimate the STOOIP for new development plans. The target of this paper is to show the wide range of the new fluid saturation assessment used to overcome the electrical bypass caused by the water bearing extents.
Capitalizing on Steady-State Multiphase Simulation to Improve Rate Measurement Process
Authors: Alhuraifi M. A. 
Published: February 2024

Abstract
This paper describes effective use of a multi-phase simulator software to meter the production virtually and accurately from a group of wells that are produced through a production system and have their individual rate tests measured at different conditions. In an oil production system with no metering devices installed on individual wells, multi-phase flow is measured separately for each well in the production system. To optimize well rate testing in such complicated system, steady-state multi-phase flow simulators are used to model the actual production system. A well-calibrated model can be practically utilized to get the most of the discrete measurement data. Hydraulic surface network simulation was utilized to mimic two operation modes, namely, production mode which simulates normal production conditions and rate test mode which simulates each well flowing individually to rate testing equipment for measuring its flow rate. This approach mandates the use of available rate testing and flowing pressure data to improve the fidelity of the hydraulic simulation model. The high certainty steady-state multi-phase simulation can be used to enhance rate metering accuracy and to optimize production from the modelled wells. Multi-phase hydraulic simulation is a powerful tool to thoroughly understand fluid flow from the reservoir to surface production facilities. Such an inexpensive approach is considered efficient as it could yield a continuous representation of the production system with available field data. It relies on NODAL Analysis which is an integrated analytical approach to examine the performance of the entire production system at each individual component.
Complex Well Intervention Activities to Restore the Integrity of Single Barrier High Risk Gas Well
Authors: Al Amri Y. B. , Al Bulushi Z. A. 
Published: February 2024

Abstract
This paper will present one of the challenging deep gas well integrity restoration within Petroleum Development of Oman (PDO). The well showed indications of parted 4 ½" tubing post frac operations. The failure resulted in compromising the well integrity and pressure communication was found on the Annulus behind the tubing (Annulus A). Moreover, access to the bottom part of the well was lost due to tubing miss alignment which made the intervention more complicated.
Downhole information were gathered using Lead Impression Block (LIB) and special Camera Runs. After Concept Design Selection utilizing engineering simulation software, an external casing patch (ECP) was found the best fit to restore the integrity of the 4 ½" cemented tubing. A specific design of the external patch including connections qualification and material selection was prepared based on gas production envelop.
Unit selection was done based on intervention simulations to select a fit per purpose unit, increase the chance of success and optimize unit technical cost (UTC)
The integrity of the wells is assured by PDO barrier policy which dictate 2 barriers at all times of the well cycle life for any flow path from the reservoir. Risk assessment to identify the integrity code of the well resulted in a code 9 (out of 10) classification which means that the well needed to be restored or abandoned as soon as possible.
Radial Cutting Tool (RCT) was used to cut the upper part which was fished out with 2 fishing assembles. Moreover, access to the wellbore was essential to isolate the reservoir. It was successfully gained by running a 4 ½" Overshot. The isolation plugs were run via slick line at different stages of the intervention for well control reasons
To verify the casing patch installation, a customized load design calculations for current reservoir conditions were performed. The integrity of the well was successfully restored and the well was put back to production after running the ECP.
The ECP design was done for the first time within similar scope of work which unlocked potential for future opportunities. As well, the intervention was done for the first time using light workover unit which minimized the cost impact.
Unique integrity repair plan with integrated risk assessment for high risk well interventions was done successfully to restore integrity of single barrier gas well.
The idea of selecting a light workover unit underwent a thorough risk assessment and detailed engineering design to prove the concept.
Protecting Boiler Feed Water Pump Against Cavitation Through Applied Mathematical Approach
Authors: Leal J. , Alkad K. 
Published: February 2024

Abstract
Boiler Feed Water Pumps play a crucial role in the Power Generation Blocks (PGBs) Unit at Jazan Refinery Complex (JZRC).
Frequent pump trips due to cavitation have resulted in significant financial losses and operational disruptions.
This manuscript introduces an innovative exponential solution which is mainly an equation to enhance pump protection against cavitation. This equation utilizes Factory Acceptance Tests performance curves values to precisely describe the pump's behavior, directly addressing the cavitation phenomenon.
The combination of this logic protection and the derived equation has been filed for a U.S. patent. Furthermore, this innovative approach has already been successfully implemented on 16 out of 20 Boiler Feed Water pumps at JZRC during PGB-1/2/3/4 Commissioning and Startup (CSU), with ongoing implementation on the remaining four pumps at PGB-5.
The intention of developing a better approach to protect the Boiler Feed Water (BFW) pumps against cavitation was an initiative to consider a dynamic model instead of fixed value for Net Positive Suction Head Available - NPSHA (14.7 m) based on 1 m separation margin respect to Net Positive Suction Head Required - NPSHR (13.7 m) @ rated flow provided by Pump Manufacturer, which was found very conservative protection at flowrates less than rated flow where NPSHR is less than 10 m and pump not well protected at flowrates exceeding the rated flow where NPSHR is expected to be above 20 m.
The dynamic model of protection, implemented by NPSH margin equation, has been applied successfully at Power Block Power Generation Units to avoid unnecessary trips at flowrates below rated flow and protect the pumps effectively when running at flowrates above rated flow.
NPSH margin ESD trip @ 1 m (decreasing) replaced the NPSHA trip set on 14.7 m (decreasing) to enhance the pumps reliability and availability, if the sister pump was unable to kick-in, leading to trip the Gas Turbine and loss of 220 MW of power generation.
Each power block has 02 gas turbines with 02 HRSG's and 01 steam turbine. Each HRSG has associated 02 BFW pumps, one running while the other is on hot standby. [Figure 1]
Reliability Study: Use of Chrome Plating on Special Purpose Steam Turbines
Authors: Baaqeel N. M. 
Published: February 2024

Abstract
An 18,000 HP special purpose steam turbine is driving a propane compressor in a Gas Treatment facility in one of Saudi Aramco gas plants. This turbine is designed with two 10-inch steam inlets, and each inlet has an independent, hydraulically actuated Emergency Shutdown Valve (ESV). The core function of these valves is to rapidly isolate the high pressure (600 psi) steam supply to the steam turbine whenever an Emergency Shutdown Device (ESD) signal is activated in a reaction time less than 200 milliseconds.
An inspection was carried out for the turbine (ESV's) by inspecting the hydraulic section drain lines through port B when actuated to open positions. The inspection revealed that oil flow through the drain line is continues at a rate of 30 ml/s. While oil flow through port B should stop when the hydraulic section is at its ultimate open position.
Initial review for the hydraulic section internal components revealed that the section was designed in a way that does not require any soft sealing components to provide oil sealing between the cylinder and piston during oil pressurization when valves are opened. It was only when valves were dismantled that it was found that the oil sealing between cylinder and piston is achieved by a very tight clearance between the two sliding components. The required Original Equipment Manufacturer (OEM) clearance was 0.9 to 1.9 thou, and the max "as found" clearance was close to 4 thou in both actuators.
A plan was set to refurbish either the cylinder or the piston in an effort to reduce the internal clearance between the sliding components.
A "weld-buildup" which is one the most common and traditional repair methodology was proposed on the internal side of the cylinder. However, due to the sheer difficulties to produce uniform manual weld on the inside surface of the cylinder, in addition to the risk of cracks formation and propagation caused by welding on cast iron were two main reasons to discard such repair proposal.
Since the objective was to decrease the clearance between the cylinder and piston it was evaluated that using a chrome plating repair methodology on the outside diameter of the piston in attempt to increase its overall outside diameter while maintaining the inside diameter of the piston. It was concluded that the use of chrome plating will produce far superior outcomes than that of the use of traditional weld-build up repair alternative.
A Sustainable Approach to Drilling in Shale Formations with Fresh Water-Based Mud System
Authors: Geri Mohammed Ba , Kauffman Demond , Almubarak Tariq 
Published: February 2024

Abstract
Drilling through shale formations poses significant challenges due to clay reactivity. The issues can lead to several problems, including water influx, well control issues, abnormal pressures, differential sticking, and significant formation losses. This paper presents the development of a new water-based mud that addresses these challenges. Customized water-based muds (WBMs) can inhibit shale hydration and minimize these risks. This study evaluates a novel polymeric additive for improved WBM shale inhibition. The objective is to characterize the novel WBM and demonstrate its ability to reduce shale swelling and deliver stable drilling compared to traditional WBMs.
Novel water-based muds (NWBMs) have been developed to address the limitations of conventional water-based drilling fluids in reactive shale formations. This study systematically evaluated the performance of the NWBM system using freshwater through laboratory experiments and field trials. Rheological characterization showed that the NWBM exhibited enhanced viscosity and gel strength compared to traditional systems. The NWBM increased rheological properties and lowered shale swelling by 50% versus reference WBMs. X-ray diffraction (XRD) and cationic exchange capacity (CEC) tests were conducted to characterize the shale mineralogy. Scanning electron microscopy (SEM) provided visual evidence of the dense, low-porosity filter cakes achieved with the NWBM. Successful offshore examples validated the NWBM's ability to maintain wellbore stability and avoid stuck pipe events in problematic formations. Offshore field trials exhibited 50% fewer sticking events, 30-40% faster ROP, and no wellbore instability issues through problematic shales with the use of NWBM. The integrated results highlight the NWBM's technical advantages for improved drilling performance in complex reactive shales.
Automation-Assisted and Signal-Driven Relative Geological Time Model Toward Sequence Stratigraphy and Identification of Sand Fairways in a Turbidite System: Case Study, Neuquén Basin, Onshore Argentina
Authors: Daynac N. 
Published: February 2024

Summary
The Neuquén Basin is proven to be a hydrocarbon resource rich onshore region with several petroleum systems. Its depositional history was primarily influenced by changes in relative sea-level from the Triassic to the late Jurassic, leading to the occurrence of submarine and subaerial deposits (Brinkworth et al., 2018). In the study area, located in the Neuquén Embayment province, the authors performed a comprehensive seismic interpretation, focusing on the Cuyo Group (spanning from middle Lias to late Dogger Epochs). The work illustrates the benefits of using a signal driven Relative Geological Time (RGT) model (Pauget et al., 2009) to enhance the understanding of regional scale stratigraphic features, revealing a complex turbidite system. It ultimately offers the ability to draw new perspectives and insights in the evaluation of legacy data and further demonstrate the potential prospectivity of understudied deep stratigraphic traps.