bluuebunny/crossref_metadata_2025_split huggingface dataset:
Revolutionizing Drilling Efficiency in Highly Interbedded Formations Using A Sustainable Approach Through A Cutting-Edge Pdc Bit Design
Authors: Alqunais Dawood , Teasdale Paul , Case Matt , Hababi Ali 
Published: November 2024

Abstract
Drilling large diameter boreholes through highly interbedded formations presents significant challenges such as torsional instability that potentially leads to a drill string twist-off or a premature Polycrystalline Diamond Compact (PDC) bit damage. This paper introduces a novel solution to overcome these challenges by utilizing an innovative PDC bit that uses active cutting elements across the bit cutting structure to control the Depth Of Cut (DOC) while improving the performance and reducing the risk of twist-off.
A conceptual development project was established with the objective to replace multiple bits with a single PDC bit. The design engineering team have identified the application challenges and have designed an advanced PDC bit with an alternative cutters configuration to drill through interbedded formations more effectively. The unique PDC bit has a strategic cutters arrangement distributed across the bit face with alternating aggressive and passive back rake angles that enables the bit to shear the formation from various points of contact, control the DOC and improve Rate of Penetration (ROP).
The field test demonstrates the result of deploying the new concept in drilling transitional formations that generate significant torsional vibrations. Historically, several PDC and roller cone bits designs approaches have been unsuccessful to overcome the challenge of drilling interbedded formations in 22-inch section. The bits have been pulled out of hole prematurely due to bit damage or twist-off incidents. The advanced PDC design was tested in an established field with more than 1000 wells, where the operator typically completes the section with at least two bits, either roller cone or conventional PDC bits. The new bit successfully drilled the entire section through interbedded formations and has achieved the best ROP in the field with 49.56 % improvement over the previous ROP record. Subsequent testing in another field shows unprecedented achievement, the bit has drilled the whole section in a single run with 70% ROP improvement. It has been proven that the new approach has reduced harmful torque fluctuations by 25 % while drilling through transitional zones. The innovative PDC bit resulted in a smoother torque response, an improved PDC bit dull condition, and a significant drilling cost savings by eliminating bit trips and new bits cost.
This paper addresses a typical torsional instability issue that many operators encounter in large diameter sections, and it presents a viable solution that can potentially improve performance in variety of transitional applications. The new PDC bit can create more opportunities to enhance drilling performance and reduce drilling costs. In addition, the results of the real-time downhole vibrations analysis can be used to improve future design iterations, optimize drilling parameters and thus improve drilling performance.
Wellhead Desander with Real Time Weight Monitoring System for Enhanced Process Safety and Efficiency
Authors: Piasseski D. , Elhanbouly S. , Al Shehhi H. 
Published: November 2024

The presence of solids throughout the lifecycle of oil and gas reservoirs is not a new challenge. Solids in the flow path can originate from multiple sources: they may occur naturally due to reservoir characteristics or as a consequence of the methods, operations, and materials used—such as in unconventional reservoirs, where frac operations often result in solids being produced to the surface. Specifically, in the initial phases—during milling of the frac plugs or the initial flowback period—drawdown must be controlled to prevent frac sands (proppant frac) from being expelled from the reservoir into the wellbore and, consequently, into the flow path. Excessive sand production at this early stage not only poses risks to surface equipment and personnel but also has long-term impacts on well performance. In some cases, excessive sand can severely impact fractures, leading to a weaker connection between the reservoir and the wellbore, resulting in reduced production.
Although sand production is almost unavoidable, the lack of reliable detection and quantification of sand returns in real time hinders continuous process improvement and forces operators to rely on time-based sand flushing. Each flushing operation requires multiple valve operations, exposing the valves to solids and eventually leading to premature failures, which can result in process safety incidents. This paper focuses on the results of a field trial of a new desander model, featuring a novel Real-Time Weight Monitoring System, and how this technology can help improve both process safety and operational efficiency.
Empowering Drilling and Optimization with Generative AI
Authors: Amour Myriam , Rachmat B. Kent , Rementeria Agustin Soriano , Guillot Valerian , Millan Ekaterina 
Published: November 2024

Abstract
Over the last 10 years, no industry has faced more pressure and scrutiny to gain efficiency than the oil and gas (O&G) industry. Drilling engineers are tasked with leveraging data to optimize design and operations. O&G companies have collected and stored large amounts of high-frequency sensor data and reporting data. Efficient data access is fundamental for upstream projects, and data operations skills are critical for drilling engineers. However, data operations have not become a core competency for most of the drilling engineering community.
A novel solution to this problem is proposed—a framework that, to the best of our knowledge, represents the first application of Text-to-SQL using LLMs within the Oil & Gas (O&G) domain, specifically designed to handle complex database structures. This paper presents a novel solution that bridges the gap between drilling engineers’ need for efficient data access and their lack of specialized data skills. Our Natural Language (NL) to SQL GenAI workflow transforms complex data transformation operations into a seamless process requiring no special expertise and delivering results within seconds. By converting natural language queries into SQL queries, this framework dynamically enriches users’ questions with relevant contextual information before processing them through a Large Language Model (LLM). This ensures that drilling engineers can quickly analyze multi-well data, address critical issues, and capture knowledge for future wells, all while overcoming the challenges of accessing and interpreting large SQL databases.
Hydrogen Gas Accumulation in Subsea Umbilical Cable Splitter Boxes: Evaluating HSE Risk, Overcoming Challenges & Deploying Mitigation Measures
Authors: Khatua Anup Kumar , Alhashmi Abubaker Alaidarous 
Published: November 2024

Abstract
This paper presents a comprehensive analysis of potential sources of hydrogen (H2) gas, its propagation, and accumulation within subsea umbilical cable splitter boxes, leading to deformation of the splitter box. With a focus on addressing challenges and proposing effective mitigation strategies, this paper provides actionable insights for practicing engineers. The meticulous exploration of health, safety, and environmental (HSE) risks enhances the understanding of subsea cables & umbilical, making this paper a valuable resource for managing risks and safety protocols in the upstream oil and gas industry.
An integrated approach has been developed through discussions with key stakeholders, including the original equipment manufacturers (OEMs) of the umbilical cable, topside umbilical termination unit (TUTU) & splitter box teams, and consultants. This collaborative effort led to root cause analyses and the identification of the most efficient and cost-effective methods for mitigating hydrogen accumulation in splitter boxes.
The insights gained from this study can be applied to similar installations, helping to enhance the safety and reliability of subsea electrical systems in the oil and gas industry. Future work will focus on monitoring the effectiveness of the implemented measures and exploring additional strategies for further risk reduction.
Enhancing Asset Reliability Through Comprehensive Implementation of Systematic Approach for Conducting Pre-Commissioning Material Adequacy Assessments in offshore Fields
Authors: Aoudi H. K. , Al Mukhmari H. K. , Alhammadi M. S. , Almarzooqi S. M. 
Published: November 2024

Abstract
This paper addresses the comprehensive integration of material adequacy assessments aimed at enhancing asset reliability and service life within offshore fields. In offshore oil and gas projects, ensuring the reliability and longevity of assets is very critical. The primary focus is on the seamless integration of new packages and modifications into existing facilities while safeguarding asset integrity through detailed corrosion monitoring. By assessing the reliability of existing equipment and piping mechanisms, the paper aims to mitigate risks associated with changes in process conditions and fluid compositions. The proposed methodology combines existing manuals and expert knowledge to enhance processes, harmonize best practices, and update information, ensuring effective corrosion control measures amid evolving project requirements. The study emphasizes downstream tie-in points for existing facilities, considering the dynamic nature of process conditions and fluid compositions. The results suggest that standardizing corrosion control practices and aligning with industry standards improve operational reliability, reduce costs, and enhance risk management. Proactive corrosion management, updated material selection, and rigorous evaluation processes are highlighted as key to ensuring long-term sustainability and asset integrity.
De-Risking the Steam Injection Project with Comprehensive Geomechanical & Geochemical Assessment, Sultanate of Oman
Authors: Maranu R. , Al Amri B. A. H. , Mirza M. , Sudono H. , Ezzat G. , Shinde A. L. , Singh H. , Harper C. , Rao D. Govind , Kidambi T. , Perumalla S. 
Published: November 2024

Abstract
The subject field has a cretaceous clastic sandstone reservoir which has been producing heavy oil (16-17° API). The reservoir is overlain by thick shale cap rock with an unconformity. The study area is bounded by two faults on the eastern and western sides of the field. Enhanced oil recovery methods are deployed to improve the productivity, including cyclic steam stimulation (CSS). A steam flood pilot was performed on a few wells with the aim to implement the full-field steam injection in the near future. As part of this full-field deployment, comprehensive Geomechanical & Geochemical risk assessment was carried out with multi-disciplinary reservoir data integration. This paper discusses the relevant workflow for risk assessment in detail.
Understanding and evaluating the state of in-situ stress is essential before and during steam injection operations. This requires building calibrated Geomechanical models for key wells based on the best available data. A normal stress setting prevails in the reservoir at initial pressure and temperature conditions. In order to simulate the complex geological structure of the reservoir, 3D finite element (FE) modeling is deployed with the aim to compute stress and strain changes in the reservoir and cap rock due to changes in reservoir pressure and temperature. A watertight structural framework for the 3D Geomechanical model is built covering overburden, reservoir and underburden formations along with faults capturing the complexity. The full field 3D Geomechanical model is populated with rock mechanical properties with guidance from a static geological model. Then, the 3D Geomechanical model is coupled with a reservoir dynamic model that has forecasted pressure and temperature at different time intervals as per the planned steam injection. This model computes the stress/strain changes in and around the reservoir with forecasted changes of pressure and temperature with time. Furthermore, geochemical assessment was conducted considering the reservoir mineralogy and estimated the fines production risk as well as the risk to the integrity of the formations as a result of the introduction of steam into the formations.
Results of the finite-element modeling are evaluated to quantify the geomechanical-related risks, which includes compaction/heave in the reservoir, cap rock integrity, and fault reactivation. Additionally, an estimated safe operating envelope for injection was defined to avoid risking reservoir integrity. A customized multi-technology monitoring strategy is developed for further field development planning. This integrated study has systematically de-risked the development plan with safe operating envelopes and further recommendations to develop the reservoir.
Case Study: Practical Solutions for Managing Small-Volume Flares in Community Areas: the Installation of an Incinerator
Authors: Matsuo R. , Takada Y. , Jeanes T. 
Published: November 2024

Abstract
Flaring, the combustion of excess gas from oil and gas operations, remains a contentious practice, particularly when it comes to routine flaring, which contributes substantially to both energy loss and greenhouse gas (GHG) emissions. In 2023, satellite data estimate that annual flaring amount will reach 148 billion cubic meters (BCM) globally, with small-scale operations flaring less than 5 million standard cubic meters per day (MMSCFD) responsible for 59 BCM [1]. Notably, upstream flaring accounts for over 90% of total flaring [2]. The World Bank's Zero Routine Flaring by 2030 initiative underscores the critical need for enhanced gas management practices.
Elevated flare stacks have long been the standard method for managing excess gas; however, incomplete combustion remains a frequently cited issue. While combustion efficiency is generally assumed to range between 97% and 98%, lower rates have been observed in certain cases [3,4], raising concerns that publicly reported figures may underestimate actual GHG emissions. These discrepancies stem from various uncertainties, including inconsistencies in measurement techniques [5]. Additionally, decreased efficiency has been confirmed under specific conditions, such as strong crosswinds [6,7] and suboptimal flare gas properties (e.g., lower heat value, reduced flow) [8]. Incomplete combustion also produces black carbon [9] and unburned methane, both of which have a higher global warming potential than fully combusted CO2. Furthermore, these emissions can potentially degrade local air quality, posing significant risks to public health [10]. Volatile organic compounds (VOCs), polycyclic aromatic hydrocarbons (PAHs) [11], and particulate matter (PM) [12] are significant sources of pollution associated with flaring activities.
Moving from Composite to Dissolvable Plugs, A Journey Towards the Elimination of Post Frac Intervention
Authors: Alfaify Alhaitham , Baki Sohrat , Alabdrabalameer Musab , Alzamil Abdullah 
Published: November 2024

Abstract
Hydraulic fracturing is a fundamental technique used to extract hydrocarbons from reservoirs with low permeability. A pivotal aspect of the process of hydraulic fracturing often require the temporary isolation of specific wellbore sections to ensure effective zonal isolation. Traditionally, composite plugs have been used for their strength and durability, however, they do still require post-fracturing cleanup. Dissolvable plugs on the other hand, are now revolutionizing the industry by having the distinct advantage of disintegrating under downhole conditions. This paper evaluates the performance of both traditional composite and dissolvable frac plugs through a detailed assessment of various plug milling (plug removal) parameters. The study compares two composite plugs and four dissolvable plugs separately to ensure a fair evaluation, addressing key metrics such as milling time, debris weight, exposure period, and dissolution rate for dissolvable plugs. The goal is to streamline the process to reduce and potentially eliminate post-fracturing intervention required to for plug removal. The results show that while composite plug A offers consistent performance, dissolvable plug two stands out with the highest dissolution rate, cutting post-fracturing intervention time by half and generating the least debris. These findings provide insights into the evolving practices in the industry and highlight the advantages of adopting dissolvable plugs. Ongoing research and advancements may lead to plugs with a 100% dissolution rate, potentially eliminating post-fracturing intervention altogether.
Application of PLT and Tracer Testing Data on Deposition Study and Reservoir Geological Modeling-A Case From the Mishrif Formation in H Oil Field in Southeast Iraq
Authors: Han Rubing , Song Benbiao , Zhao Hang , Sun Liang , Xiong Lihui , Lou Yuankeli , Li Shunming , Mao Xianyu 
Published: November 2024

Abstract
For many oil fields, due to the limitation of economic benefits or short development history, there are many difficulties, such as fewer cores, larger spacing of cored wells and poor seismic data quality, etc. This paper takes a giant carbonate reservoir in H oilfield as an example, utilized common reservoir monitoring data, namely PLT and tracer detection data, to assist sedimentary facies research and get more convincing results in both deposition understanding and facies model. The new procedure of deposition study and facies modelling were introduced as follows: Firstly, with comprehensive geological data, the sedimentary facies study was conducted and the initial sedimentary facies maps were made; Secondly, the PLT data and tracer detection data were collected and analyzed; Thirdly, reservoir monitoring data were utilized to improve the initial sedimentary facies understanding. Finally, the sedimentary facies maps were redrawn and used to constrain facies modelling and a few realizations of facies models that complied with the geological knowledge were got. They are for the geologists and the reservoir engineers to choose the right realization together. Then the sedimentary facies maps were redrawn and used as trend to constrain facies modelling, which show better coincident rate between static and dynamic data. With the continuous reservoir development, the amount of reservoir monitoring data is gradually increasing, and the corresponding geological research is increasingly deepening. The new facies model was more in line with the actual underground conditions of the reservoir and laid a solid foundation for other workflows in the static and dynamic process of reservoir study. Without changing other parameters, the history match results improve significantly, which lays solid foundation for reservoir management.
An In-Situ Mobility-Controllable Nanofluid for Enhanced Oil Recovery in High Temperature and High Salinity Reservoirs: Experimental Study
Authors: Zhao X. , Wang H. , Liu R. , Li C. , Sun Z 
Published: November 2024

Abstract
In order to improve the EOR efficiency of water flooding in reservoirs which are high temperature and high salinity (HT/HS), a polymer-free nanofluid based on the synthesized amphiphilic nanocarbon with In-situ mobility-controllability has been developed and evaluated. Thickening water-in-oil Pickering emulsion was produced from this amphiphilic nanocarbon. The viscosity of the emulsion was exponentially increased as the water content increased up to 90%.
The dispersibility, intrinsic wettability and oil/water interfacial tension (IFT) of the amphiphilic nanocarbon were investigated. The prepared amphiphilic nanocarbon was a nanoscale emulsifier, which had an excellent colloidal dispersibility in harsh brine for 90 days at 120 °C. Low IFTs facilitated the oil external phase emulsions within a wide range of water/oil proportions. The study of morphologies and droplet size distributions of the corresponding emulsion type within various water cut region was conducted. A distinctive Maltese cross pattern around the emulsion droplet edge indicated that a protective layer was produced in a spontaneous emulsification process.
Then the shear-dependency of viscosities for emulsions were tested. The apparent viscosity of the emulsions regularly increased higher than that of crude as increasing of water proportion when the water/oil proportion was below 80%. Based on the static experiments, the core displacement behaviors of the emulsifier were evaluated by flooding test to identify the in-situ intelligent mobility-controllability of this amphiphilic nanocarbon. Owing to the tunable viscosity of the in-situ emulsions together with low magnitude of IFT, and the wettability modification of rock surface produced by this unique amphiphilic nanocarbon, the oil recovery factor could be enhanced about 20% to 35% by injection of the nanoscale emulsifier when the WCT of earlier water flooding exceeded 90%.
Industrial-Scale Application of Amine-Based Tail Gas Oxidation-Absorption Technology Combined with Claus Process for Lowering Sulfur Dioxide Emission from Natural Gas Purification
Authors: Tang Quanwu , Li Jing , Fu Jingqiang , Fan Rui , Chen Shiming , Sun Feng , Wang Xingrui , Hu Chao , Lai Bing , Zhao Liang , Jiang Guobin 
Published: November 2024

Abstract
Natural gas emits less air pollutants and carbon emissions than other fossil fuels, thereby natural gas consumption is growing rapidly and natural gas purification becomes more important around the world. Claus process and extended Claus process (e.g., superClaus, cold bed adsorption and clinsulf-SDP) are industrialized sulfur recovery systems to convert hydrogen sulfide to sulfur and have been widely used in natural gas purification plants, but there would be a large number of sulfur dioxide emissions. To reduce sulfur dioxide emissions, an innovative tail gas oxidation-absorption technology combined with Claus process has been developed and applied in a natural gas purification plant of PetroChina. In this paper, the tail gas oxidation-absorption technology combined with Claus process was elucidated in detail, an amine-based sulfur dioxide absorbent was employed and evaluated, and key operation parameters such as oxygen volume fraction, burner temperatures, amine-based sulfur dioxide absorbent concentrations, pH of lean amine solution and molar rate of heat stable salts versus the amine-based sulfur dioxide absorbent were investigated and analyzed in an industrial-scale. The key operation parameters were determined as follow. Tail gases of the sulfur recovery system was burned at 810±5°C in a burner, and the oxygen volume fraction was maintained between 3.3v% and 3.7v%. The concentration of amine-based sulfur dioxide absorbents was controlled between 21w% and 25w%. The pH of lean amine solution was optimized among 5.0 to 5.7. In addition, the molar rate of heat stable salts versus the amine-based sulfur dioxide absorbent was controlled between 11:10 and 14:10. As a result, with above operation strategies, super low sulfur dioxide emissions can be gotten below 100mg/m3, which is better than the sulfur dioxide discharge standard of natural gas purification plants (GB39728-2020) in china. Wastewater produced from the amine-based tail gas oxidation-absorption technology was reused. This work would be helpful for exploiting high-sulfur natural gases and decreasing sulfur dioxide emissions from natural gas purification plants in the world.