bluuebunny/crossref_metadata_2025_split huggingface dataset:
Optimal Practices for Gas Injection to Overcome Black Powder Formation Utilizing Expert Systems
Authors: Alhajri Naif , Nengkoda Ardian , Almedallah Mohammed 
Published: November 2024

Abstract
Gas injection systems are prone to black powder formation, hindering optimal reservoir injectivity and facility integrity. This paper presents best practices during the facilities design phase (FEL and FEED) to overcome these operational challenges by overseeing such systems, particularly in high gas injection systems. Expert systems workflow thoroughly analyzes potential black powder damages, including possible causes and recommendations to protect the injection facilities and reservoir formation to sustain long-term injection performance. A comprehensive expert system, including global field experiences and simulation studies, was developed to determine potential causes of forming black powder and recommend mitigating potential reservoir and facility damages. The analysis included the investigation of optimal dehydration for lean gas and the velocity to maintain inside the pipeline during reservoir injection. Moreover, optimal filtration systems and gas specifications were also investigated. The study indicates proper commissioning is the first step to ensuring that black powder is not formed in lean, rich gas pipeline sources. Other factors, such as long delays during construction and long pipeline exposure time, have increased the concentration of O2 and H2O (moisture) and the accumulation of corrosion solid contaminants inside the pipeline. The three primary root causes of black powder contamination are moisture (H2O), impurities (H2S, O2, CO2 or elemental sulfur), and operating condition (pressure or temperature variance). The paper lists several recommendations to overcome black powder formation, including adopting rigorous commissioning procedures, optimizing network design, regularly monitoring the injection gas quality (contaminant), and including corrosion management such as corrosion inhibitor injection and monitoring. In addition, scraping operation and corrosion monitoring can help mitigate the accumulation of Black powder.
Automated and Unmanned Shale Shaker Performance and Borehole Instability Monitoring Using Computer Vision and Artificial Intelligence
Authors: Ruggiero M. , Meledeth A. , De Smedt F. , Kucs R. , Ripperger G. , Comotti S. , Cockram L. , Colombo I. 
Published: November 2024

Abstract
Evaluating the effectiveness of hole cleaning and ensuring wellbore stability is crucial for preventing unwanted events such as kicks or stuck pipes, with consequent minor or major non-productive time (NPT) that, in severe cases, may lead to well abandonment. Beyond the economic implications, these scenarios pose risks of environmental damage and jeopardize the safety of rig personnel. Shale shakers are the first indicator of emerging borehole cleaning and wellbore stability problems and as such, they are a fundamental component of the drilling rig.
Detecting cavings and foreign objects on shale shakers is a task typically assigned to humans, who occasionally monitor shaker areas looking at cuttings, and periodically collecting cuttings samples. Monitoring mud beach level and screen damage to preserve drilling mud quality, is also limited to sporadic human observations. These processes lack continuity in monitoring and rely on subjective interpretation of observed samples, often requiring humans to spend significant time in hazardous zones.
A novel Computer Vision System for an automated and unmanned shale shaker visual monitoring, coupled with Deep Learning (DL) Artificial Intelligence (AI) models has been implemented. It relies on installing high-speed, high-resolution, explosion-proof cameras continuously acquiring clear and focused pictures of the shale shaker screens at any time during drilling operations. Image data is transmitted up to 500 meters distance and processed through powerful edge computing devices, producing high-frequency objectively interpreted real-time data that can be recorded and plotted along drilling parameters. The system alerts humans to come to the shakers only when necessary.
This system has been deployed in three wells across various locations and countries. It aims to replace the traditional human-based monitoring approach by giving a continuous objective detection, and quantification of cuttings, cavings, foreign objects, mud beach level, shaker overflow, and shale shaker screens damage, in real-time.
Real-time machine learning based automated detection and interpretation of the shaker screens can substantially improve rig safety by reducing the need for humans to be present in hazardous conditions with fumes and noises when their direct intervention is unnecessary. This system also provides immediate assessment of borehole instability and mud circulation best practices, enabling safer and more effective drilling operations.
A Pioneer Implementation of Industrial Internet of Things in Khurais
Authors: Abdullah I Abaoud , Vladimir J Gonzalez , Mokhtarudin Abdul Razak 
Published: November 2024

Abstract
This paper sheds light on the pioneer implementation of Industrial Internet of Things (IIoT) technology deployment in Khurais Production Facility (KhPF). It explores the purpose, features, and benefits of IIoT devices, shedding light on their potential to revolutionize plant operations through advanced monitoring capabilities. The advent of the Fourth industrial revolution (IR4.0) has ushered in a paradigm shift in industrial processes, and the heart of this transformation lies the crucial role played by the Industrial Internet of Things (IIoT). In the landscape of IR4.0, where digital technologies seamlessly integrate with the physical systems, IIoT emerges as a linchpin offering unprecedented opportunities to enhance efficiency, optimize the operation, and unlock realms of productivity. This deployment is considered the first integrated IIOT installation in the Middle East, where we tested the devices' capabilities from 5 different reputable vendors under a single On-Prem platform. This deployment introduces a pioneering implementation of IIoT devices within Khurais Production facilities. in this deployment, the installed IIOT devices include corrosion sensors, Temperature gauges, Pressure gauges, and vibration sensors, among others. These devices were strategically installed as part of a trial to enhance performance monitoring. The connectivity backbone relies on the LoRaWAN protocol, enabling seamless data transmission and real-time insights. The abstract explores the purpose, features, and benefits of these IIoT devices. LoRaWAN IIOT Devices are optimized to operate in low power mode and can last up to 10 years on a single coin cell battery. It can also reach a distance from 5 to 10 Km and has a high capacity that can handle up to 1000 devices for one gateway.
Zonal Isolation for Short-Liner Intervals
Authors: Khan Anum Yousuf , Salazar Jose , Bogaerts Martijn , Rashdi Issa , Al Wardi Yasser , Habsi Younis , Parasher Mukesh , Noumani Abdullah 
Published: November 2024

Abstract
The production objectives of any gas well are largely dependent on zonal isolation. Zonal isolation becomes additionally challenging for short-interval cementing. This paper presents the best practices and lessons learnt from short-interval liner cementing in the Abu Butabul field in northern Oman where the operator had a series of short liners in which the perforation interval was located just below a previous casing shoe. The complexity increased by the presence of loss zones in the open hole, which limited the hydrostatic pressure of the cement column.
The methods this paper presents not only cover slurry design but the placement practices as well. The main challenge with short liners is the small theoretical slurry volume, which is prone to high contamination from fluid mixing in the pipe alone. Through software simulations, the optimum volume was determined to resist or at least minimize contamination across the zones of interest. Liner overlap length was also increased as was the shoe track. The standoff of the liner was optimized despite the reactive shales in the section, The length of both the overlap and shoe track was based on software simulations, which this paper will present. The slurry height above the liner hanger was also adjusted so as not to compromise the fracturing gradient due to increased hydrostatic pressure.
Then the next step was slurry design to maximize rheological and density hierarchies. The additional preventative slurry testing included thickening time selection to allow safe tool release and liner packer setting despite the increase in slurry volume above the top of liner. Design steps to boost compressive strength and slurry formation interaction despite the increased thickening times will also be presented.
Lift pressures during pumping were verified against expected design pressures and no indication of loss was observed. The excess considerations were first verified with post-job circulation returns where uncluttered slurry returns were noted above the liner hanger. The final indication of the operation's success was the cement evaluation log, which displayed good cement coverage across the zone of interest.
Short liners had been an operator challenge in the field, especially for perforations across formations immediately below the previous shoe. The operator has agreed to carry forward the lessons learnt for cementing similar profiles in the field's Block 60.
Flexural Attenuation and Annulus Velocity for Cement Evaluation Enabled Fast Well Delivery
Authors: Hurtado Noe , Fituri Aiman , Al Menhali Abdulla , Al Shaigy Ahmad , Al Amri Abdulrahman , Beber Antonela 
Published: November 2024

Abstract
Well integrity is a constant concern in the oil and gas industry, as the specifications for all new wellbores must ensure that its original fluids—oil, gas and water—are kept confined to the formation or the oil and gas well system, successfully preventing any leaks from the system to the surface, subsurface bodies, or the surrounding environment.
Good cement coverage and accurate cement evaluation are of prime importance for the integrity of oil and gas wells, to prevent crossflow, leaks and sustained casing pressures. Post-cement placement wait time to enable cement hardening and establish compressive strength contribute to additional ideal rig time. On many occasions traditional cement evaluation measurements fail to evaluate complicated cases of cement at early stages or lower density slurries, the flexural ultrasonic attenuation, and velocity measurements achieved detecting cement accurately behind the casing where traditional ultrasonic and cement bond log-variable density log (CBL-VDL) measurements were not able to detect solids. This situation is especially observed in the early stages of the compressive strength build up for any slurry system. During this transition, traditional evaluation methods are very limited, and it requires additional time for significant increase in compressive strength and multiple runs to have an acceptable, realistic hydraulic evaluation.
The asset integrity policies and management are crucial to the oil and gas industry to ensure safety, profitability, performance, compliance with local and international regulations, and to protect society and the environment. So it is, to have a very accurate evaluation to ensure optimum balance between strict integrity policies and sustainability.
At various phases of a well's life cycle, the integrity of the well barriers and/or well barrier elements are verified. This verification may require pressure measurement and monitoring, barriers identification, confirmation and tagging, pressure testing, leak testing, leak off confirmation and testing, flow rate measurement, temperature monitoring, and well logging evaluation, especially for the hydraulic isolation confirmation and analysis.
Development of Biodegradable Surfactants for Oil Spill Remediation
Authors: Alshamsi S. , Hussain K. 
Published: November 2024

Abstract
Oil spills in ocean habitats present very serious risks to sea ecosystems, prompt and efficient remediation approaches are needed. Regular chemical surfactants use in oil spill cleanup can pose risk and difficulties because of their toxicity to the environment and ocean habitats, leading to long-lasting ecological damage. This study presents the development of a biodegradable surfactant, termed BioClean-Surf, which is developed using principles of green and eco-friendly chemistry from natural sources like coconut oil, soybean oil, and amino acids. The aim is to develop an effective and environmentally friendly surfactant that can emulsify and disperse oil to reduce its long-lasting effects on marine environments.
Laboratory experiments were conducted to assess the performance of BioClean-Surf in real-world conditions. The surfactant was synthesized through esterification and saponification processes, with its chemical structure and purity confirmed using advanced techniques like nuclear magnetic resonance (NMR) spectroscopy, mass spectrometry (MS), and Fourier-transform infrared (FTIR) spectroscopy. Experiments evaluated the surfactant's ability to emulsify and disperse oil in water across three different surfactant-to-oil (S:O) ratios (1:5, 1:10, 1:50). The biodegradability of BioClean-Surf was tested using the OECD 301 standard, and toxicity was assessed through bioassays on aquatic organisms. Measurements of oil droplet size reduction, water turbidity, and bacterial cell count were continuously monitored over 60 days to observe the surfactant's efficacy.
The results demonstrated that BioClean-Surf effectively emulsifies and disperses oil, significantly reducing residual oil in water samples and achieving optimal performance at an S:O ratio of 1:10. Biodegradability tests confirmed that BioClean-Surf breaks down rapidly in natural conditions, minimizing its long-term ecological footprint. Toxicity evaluations indicated that the surfactant is non-toxic to marine life, ensuring safe application in natural water bodies. These findings confirm that BioClean-Surf offers a highly effective and environmentally sustainable solution for oil spill remediation, aligning with global efforts to promote green technologies and reduce marine pollution.
Integrated Process and Power Simulation to Validate the Design and Operation of Green Hydrogen Facilities
Authors: Willetts Ian , Muir Ryan , Qureshi Ata Ur Rehman 
Published: November 2024

Abstract
Between 2015 and 2018, over one million metric tons of green Hydrogen were produced worldwide. If governments implement more ambitious climate policies to comply with the Paris Climate Agreement, green Hydrogen production could potentially reach 160 million metric tons per year by 2050 [1].
However, green Hydrogen projects present unique business and technical challenges. The variability of the renewable energy supplies, the operational complexity of electrolyzers, and the potential interaction of the Hydrogen production with downstream processes, e.g., green Ammonia, makes the final design and operation of facilities highly challenging. The interdependency of the renewable power supply and the highly non-linear process systems is one critical factor that must be factored into the conceptual and detailed design.
This paper discusses the challenges related to green Hydrogen projects and how these challenges can be tackled, from four different perspectives: The investor who needs to assess the expected financial return on the project before making a Final Investment Decision (FID)The process engineering team responsible for the conceptual and detailed design of the highly non-linear and non-continuous green Hydrogen productionThe electrical engineering team who must identify the optimum electrical topology considering, for example, size and cost of any battery energy storage (ESS) and also operational performance including power flows and equipment loadingThe owner/operator who wants to know that the facility can be operated safely and profitably and commissioning and startup time can be minimized
All four stakeholders must work collaboratively, outside of their respective disciplinary silos, to advance to a successful conclusion of a financially and environmentally rewarding project.
Implementation of Key Reliability Indicators Led to a Reduction of Inactive Strings Count. A Lesson Learned in a Major Middle East Oil Company
Authors: Davila Rayner , Al Braiki Warda Awadh , Molina Adriana , Azhar Mohammed , Shaik Zayed Iqbal , Alyaqobi Afra Saeed , Rashed Marwa Mohamed 
Published: November 2024

Abstract
This paper demonstrates lessons learned of adopting reliability indicators such as Mean Time Between Failure (MTBF), Mean Time To Failure (MTTF), Well Failure Rate (WFR), and MTTR (Mean Time To Repair) for managing wells under the context of well Inactivity. Historical data and statistics are analyzed and correlated at all Company Levels. The study unlocks the potential of re-directing the strategy of monitoring the well reactivation performance, resources planning and inactive strings prediction for certain Well inactivity categories.
Reliability indicators (Level 2 KPI's) were introduced to enhance the management of Inactive wells. Historically, other metrics were used to measure the Company performance in terms of number of inactive strings over the total of number of operating strings on monthly/yearly basis. This approach is continued but is now complemented. Well Inactivity data starting from Jan-2016 until Dec-2023 was used to estimate MTBF, MTTF, Well Failure Rate, and MTTR at Company, Assets, Field and Well levels. Formulas and general assumptions will be described in the paper.
Reliability metrics are usually applied to equipment (pumps, compressors, etc.) within specific conditions, this study doesn't intend to contradict or bypass the well stablished pertinence of those indicators. The assumption is to consider a Well as unique ecosystem that is composed of multiple sub-systems, and when the well is not able to sustain production for at least 7 days during a month, then this condition is counted as a failure.
Implementation occurred within a specific module (Level 2 KPI Module) contained in the Inactive Strings Management System (ISMS), a comprehensive web-based application created internally and fully implemented throughout the Company. For further details on ISMS, see SPE-211040-MS.
Adopting level 2 KPI's has revealed the potential of re-directing the strategy of monitoring the well reactivation performance, resources planning, and inactive strings prediction for certain well inactivity categories. It supported the reduction of the inactive strings stock by improving the estimation of required resources such as manpower, rig & rigless units, and surface actions. Furthermore, they have been instrumental in constantly revisiting the Company's business plan and ensuring inactive strings year-end targets can be exceedingly met.
By incorporating these advanced reliability indicators into the management process, the Company has gained a more granular understanding of the underlying issues causing well inactivity. This strategic shift has led to more targeted interventions and optimized resource allocation, ultimately enhancing the overall efficiency and effectiveness of well operations.
HiGAS Marine Scrubbers – Revolutionizing Shipping Industry for MARPOL and Decarbonization
Authors: Shankar J. , Durga K. Vijaya , Kumar K. Madan , Kumar T. A. Rajiv 
Published: November 2024

Abstract
The marine industry, responsible for over 80% of global merchandise transport, significantly impacts environmental sustainability through greenhouse gas (GHG) and sulfur oxides (SOx) emissions. The International Maritime Organization (IMO) targets a 50% reduction in GHG emissions by 2050, necessitating cleaner technologies and low-carbon fuels. The IMO's MARPOL Annex VI regulations also mandate a global sulfur cap of 0.5% for marine fuels. Compliance options include low sulfur fuels or scrubbers, with over 5,000 vessels using scrubbers by 2023.
Compliance poses challenges for refiners and shippers. On-ship scrubbing of exhaust SOx and CO2 offers an economical solution. Yet, existing ship scrubbers face drawbacks: towering size, weight, and poor efficiency. Enter HP-HiGAS, an innovative technology by Hindustan Petroleum Corporation Limited (HPCL), India, tailored for exhaust gas scrubbing. Utilizing a Rotating Packed Bed (RPB) with high surface area packing, HP-HiGAS leverages centrifugal forces to vastly enhance gas absorption and mass transfer rate.
Successfully implemented at HPCL's Visakh Refinery, HP-HiGAS has demonstrated practical viability in removing H2S from refinery fuel gas. The technology's compact design and superior performance make it suitable for marine applications, offering a robust solution for decarbonizing and desulfurizing marine exhaust gases. By enabling the maritime sector to meet stringent environmental regulations, HP-HiGAS plays a crucial role in reducing the industry's environmental footprint and supporting global sustainability efforts.
First Low-Carbon, Geopolymer Cement-Free Primary Cementing in the Middle East: A Case Study in Oman
Authors: Salazar Jose , Madani Raghdah , Hinai Abdullah Al , Peng Fei , Kapoor Saurabh , Abad Carlos , Wei Anna , Blanco Victor , Al Aufi Yousuf , Sutomo Wijanarko 
Published: November 2024

Abstract
A crucial step in the decarbonization of well cementing operations is the replacement of conventional cement with a cement-free system. One metric ton of carbon dioxide (CO2) is released to the environment for every metric ton of Portland cement manufactured. A geopolymer cement-free system, customized for downhole temperature and pressure conditions, was implemented in Oman. This case study presents an innovative, at-scale application of geopolymers in oilfield well cementing. In addition, it represents the first well cemented in the Middle East using the low-carbon geopolymer cement-free system.
The geopolymer cement-free system uses aluminosilicates as raw material activated in an alkali environment to produce a set material with similar or better properties than Portland cement. This provides a sustainable alternative to conventional cement with a comparable performance while contributing to efforts to decarbonize cementing operations.
This approach also considered the use of local raw materials to minimize the transportation-related carbon footprint. Several Omani raw material sources were evaluated until a suitable material was identified to meet the performance criteria.
The laboratory pilot tests performed included full sensitivities to produce a robust cement-free slurry that was suitable for cementing the candidate well successfully.
This case study confirms that the low-carbon geopolymer cement-free system integrates seamlessly into standard oilfield cementing workflows without requiring changes to the design process, onsite execution, or post-job evaluation.
Following the cementing jobs using the geopolymer cement-free system, a wireline evaluation log was performed, and zonal isolation was confirmed. This first primary casing cementing in an oil well using the low-carbon geopolymer cement-free system designed using local Omani raw materials represents the first step, paving the path toward decarbonization cementing operations in Oman and across the Middle East.
In this manuscript we will present the methodology used for the planning, execution, and evaluation of these cementing jobs. Close collaboration between the operator and cementing service company was fundamental to the success of this job. Details regarding the fluid selection, software simulation, laboratory testing, and final evaluation will be presented in this paper.
Prior to field application, a yard test was performed to confirm the handling (bulking) and transfer of the new cement-free blend and its mixing and pumping with a standard high-pressure cementing unit. Furthermore, the implementation of this innovative solution was complemented by a quantification of the carbon footprint using a sustainability assessment tool based on life-cycle analysis.