bluuebunny/crossref_metadata_2025_split huggingface dataset:
Narrowing the Competency Rift: Analyzing Skill Levels with Digital Doubles
Authors: Ahmed Alaa A. A. 
Published: May 2024

Abstract
The baby boomer generation continues to retire and turnover in the process industry (the great resignation) is impacting many manufacturing sites with severe ‘brain drain’ at all levels, especially operators. The industry is searching for ways to make onboarding of new hires and plant specific qualification more efficient and effective. Traditional methods, like classroom training and shadowing experienced colleagues and SMEs for an extended period of time, are important but no longer sufficient.
Moreover, these traditional ways to pass on procedural knowledge tend to be highly dependent on the individual (people), which hinders standardization. Over time, shifts develop different ways of doing things, departing from the original procedure or taking shortcuts. In many instances, this leads to practice in the field not reflecting the written procedure. Our industry has a clear need for more transparency and a higher level of control over the practical procedural knowledge of the workforce (tribal knowledge), as well as a way to check and measure the level of operator knowledge and procedural compliance.
In addition to the shortcomings of traditional training, a common cause for practice in the field not reflecting the written procedures is that the ‘procedure clarity’ is often suboptimal due to the ambiguities or general statements in the procedure steps.
These challenges and shortcomings directly impact operational productivity due to long onboarding times and unplanned equipment downtime as a result of operating errors. They also directly impact plants’ safety performance, especially where actions cannot be automated and secured by safety instrumented systems. The flawless interaction of operators with the asset is an important layer of plant safety.
Enhanced Reality technology has been proven to solve the challenges described above. It allows simulating standard operating procedures in a photorealistic 3D environment (digital replica) for users to review, practice and test on standard operating procedures on-demand and on any device. Manufacturing organizations can capture their practical procedural expertise (Tribal Knowledge) and are able to measure and track procedure competency across their operators. This methodology has been labelled Digital Twin of the Person (DToP) by Gartner (1), referring to the human-centric approach of this technique.
Our presentation will include case studies from some of the process industries biggest companies that demonstrate the impact of improved procedure clarity and more consistent execution, which reduces unplanned events and speeds up operator onboarding while capturing more ‘tribal knowledge’.
A New Subtle Fault Modeling Technique Based on OBN Seismic Data and Production Performance and its Application in X Oilfield, Central Asia
Authors: Tang Zichang , Rouis Lamia , Huang Qingfeng , Caiqin Liu , Talaat Mohamed , Ameish Giamal , Blanco Andres , Aldrin Rondon , Fuli An , Jinlin Cui , Yaliang Xia , Jiajia Li , Weixiang Zhong , Al Mansoori Jasem , Ibrahim Mohamed 
Published: May 2024

Abstract
With the deepening of field development, subtle faults have an increasing impact on reservoir production. However, limited by the resolution of seismic data, the interpretation accuracy of subtle faults is difficult to meet the needs of oilfield development adjustment, which brings great challenges to fault modeling in the middle and late stages of development. Subtle faults can lead to problems such as complex oil-water relationship in reservoirs, poor water injection connectivity, and quite differences in production and pressure drop between nearby wells. In order to improve the accuracy of fault modeling in the middle and late stages of development, this paper proposes a method of subtle fault interpretation and modeling based on production performance driven, integrated of fault cut, FMI and azimuth Ocean Bottom Nodes (OBN) data.
The X oilfield is located in the strike-slip fault zone in Central Asia, its fault system is very complex, after nearly 50 years of production, the distribution of remaining oil is scattered. The conventional small fault identification and modeling methods are difficult to meet the requirement of oilfield development adjustment research, therefore, the technique proposed in this paper is based on production driven and dived into 4 steps: 1) The inter-well connectivity was analyzed by using the reservoir PVT data, pressure and production data, and the distribution of subtle faults between wells was preliminarily speculated;2) Through well correlation study, the subtle fault cut and fault type of the wells were identified, combined with the regional tectonic stress and FMI data to analyze the dip angle and orientation of subtle faults;3) Based on possible faults’ dip and orientation, the seismic attributes and azimuth OBN data were combined to identify subtle faults, and a three-dimensional complex fault model was established to accurately describe the geometric shape and properties of subtle faults; 4) The rationality of subtle fault distribution is verified by fluid contact analysis and production data. The application of this technology in Central Asia X oilfield is good, and the fault model is consistent with the results of fluid contact analysis and production performance analysis results, which proves that this technology can improve the accuracy of the fault model and lay a solid foundation for efficient adjustment in the later stage.
The subtle fault modeling technique proposes a new workflow of fault characteristics. It can better integrate dynamic data into subtle fault interpretation and modeling, improving the rationality and accuracy of subtle fault model, and meet the requirement of remaining oil study in field development.
In Situ Generation of Clean Hydrogen in Gas Reservoirs: Experimental and Numerical Study
Authors: Askarova A. G. , Afanasev P. A. , Popov E. Y. , Cheremisin A. N. , Malaniy S. E. , Volkov D. A. , Cheremisin A. N. 
Published: May 2024

Abstract
There has been a growing trend in the energy sector toward hydrogen generation due to the market’s rising need for hydrogen. This change has led to a larger emphasis on creating methods and tools for subsurface hydrogen production from hydrocarbons. This research determines the features of the process of In-situ Hydrogen Generation (ISHG) and interprets the results of laboratory tests to build a scheme of kinetic reactions.
A combustion tube experiment of methane combustion in porous media was conducted to reproduce the process of hydrogen synthesis from methane under reservoir conditions (high pressure and temperatures) created by the In-situ Combustion (ISC) technology. Further numerical modelling allows validating the kinetic model typical for methane combustion in a pores medium, removing uncertainties and determining the favorable conditions for hydrogen generation (temperature, steam-methane ratio, injection rate).
During numerical simulation, good convergence of numerical simulation results with experimental data was obtained, namely the temperature profile, cumulative gas production, and molar concentrations of gas components such as H2, CH4, CO and CO2, as the main indicators of the kinetic model adaptation quality. The methane steam reforming and methane cracking reactions demonstrated the highest contribution to producing gases. The constructed kinetic model was history-matched to the experiment of the combustion tube to assess the advancement of the high-temperature front, the transformations occurring in a given zone of elevated temperatures and the adaptation of the curves of relative-phase characteristics for the subsequent assessment of the method’s effectiveness. The obtained kinetic model and relative permeability curves were used in field-scale modelling. The up-scaled field model considered a few development strategies using existing infrastructure to optimize the hydrogen generation yield.
This paper determines the features of the process of ISHG and interprets the laboratory test results to build a scheme of kinetic reactions. The obtained kinetic model was used further in a field-scale model to assess the feasibility of hydrogen generation using existing infrastructure.
Exploring the Potential of Natural Gas Reservoirs for Underground Hydrogen Generation
Authors: Afanasev P. A. , Alekhina T. V. , Mukhametdinova A. Z. , Popov E. Y. , Cheremisin A. N. 
Published: May 2024

Abstract
The major trends over a few last decades have been focused on the strategies to decrease global warming affection and to develop a new environmentally friendly and sustainable method to fulfill hydrogen demand as a highly promising energy carrier. Nowadays, hydrogen is produced through steam methane reforming (SMR), resulting in up to 10 kg of CO2 emissions per 1 kg of H2. One potential approach for producing low-carbon hydrogen directly in hydrocarbon-rich reservoirs, leaving all greenhouse gases stored in the reservoir, is a novel hybrid catalytic-thermal process. In the current study, we report results on the experimental study of in situ hydrogen generation conducted in an autoclave setup with samples of reservoir rock. A heated reactor containing the natural core model was continually loaded with methane and a water solution of nickel-based catalyst. The tests were carried out with varying steam-to-methane ratios, at pressure of 80 bar and at temperatures between 500 and 800°C.
The results show that temperatures of no less than 600°C are necessary to convert a significant amount of methane to hydrogen-containing gas, likewise increased steam-to-methane ratio. Since the catalyst precursor forms nickel nanoparticles during the process, the study validates that a cheap, nickel-based catalyst precursor delivered in an inactive, water-soluble state can potentially be used to activate the primary hydrogen generation processes. So, in order to develop gas reservoirs, especially depleted ones, a novel proposed approach that converts methane into hydrogen can be used. A simple technique of introducing and applying hydrocarbon conversion catalyst confirmed its effectiveness despite the harmful influence of reservoir conditions. The proposed technology can make a significant contribution to global sustainability efforts via low carbon hydrogen production.
Dynamic Characterization of Viscous Fingering During Grading Viscosity Polymer Flooding (GVPF) in Heterogeneous Sandstone by Core-Scale Simulation
Authors: Qi Chuangchuang , Haroun Mohamed , Kobaisi Mohammed Al , Rahman Md Motiur 
Published: May 2024

Abstract
The primary objective of this research is to investigate the dynamic immiscible viscous fingering that occurs during grading viscosity polymer flooding in a heterogeneous core using simulations. The study also aims to assess the enhanced oil recovery (EOR) performance, including incremental oil recovery and the polymer utilization factor. Five bespoke core-flooding cases (full water flooding, full polymer flooding, polymer flooding followed by chase water, double-slug polymer flooding followed by chase water, and triple-slug polymer flooding followed by chase water) were conducted and analyzed to confirm the relationship between immiscible viscous fingering patterns and polymer EOR performance. This research has proven the potential of grading viscosity polymer flooding to improve oil recovery and delay water breakthrough with reduced polymer usage. The study also demonstrates the significance of accurately characterizing miscible viscous fingering to understand the performance of GVPF in core-flooding experiments and potential pilot implementation. This research contributes to selecting proper injection mode that can improve EOR performance while reducing polymer usage.
Synergistic Effect of Ionic Liquid and Surfactant for Enhancing Imbibition in Carbonate Reservoirs
Authors: Qi Z. Y. , Huang T. P. , Alotaibi M. B. , Boqmi A. 
Published: May 2024

Abstract
Chemical imbibition technology is an effective way to enhance oil production for fractured carbonate reservoirs. Surfactants have been reported frequently in the literature to enhance imbibition process, while the combination of ionic liquid and surfactants is less investigated. This study aims to analyze the synergic mechanisms of the combination contributing to imbibition process to assist in the application of chemical imbibition technology.
The laboratory experiments consisted measurement of several parameters: contact angle, interfacial tension (IFT), and zeta potential. Effectiveness of chemicals were evaluated by spontaneous imbibition using Amott cells. Three functional surfactants and four ionic liquids were investigated. Carbonate core plugs and chips were aged in crude oil at 95°C for more than 3 weeks to render them oil-wet prior to spontaneous imbibition and contact angle tests, respectively. Effect of ionic liquids on wettability alteration, IFT change and ultimate imbibition potential were analyzed.
The three surfactants and four ionic liquids were used with different IFT and wettability alteration ability. The ionic liquids have limited effects on IFT change and zeta potential on carbonate rock surface for all the tested surfactants, while the ionic liquid EMIM Ac and one anionic surfactant can modify the oil-wet carbonate surface to water-wet effectively, with contact angle reduced from ∼140° to ∼56°. The ionic liquid can enhance the stability of oil-water interface film, thus keeping the water-wetness status longer, compared with surfactant alone. Using the combination of ionic liquid and surfactant, the imbibition production can be improved by at 6 % compared with surfactant imbibition. The more water-wetness caused by ionic liquid contributes to the incremental oil production. An optimized imbibition agent formulation with high imbibition production potential and relatively lower chemical cost was developed for up-scale consideration.
This study investigated the synergistic effect of ionic liquid and surfactant on different parameters, especially the wettability alteration, which helps better understand the complex chemical imbibition phenomenon. The optimized imbibition agent has potential for further investigation.
EOR Mechanisms and Applications of Thermal Composite Technologiesin Deep Heavy Oil Reserves
Authors: Tang Y. , Ge Q. , Lun Z. , Yin X. , Wu M. , Ma T. , Qi Y. , Zhang S. 
Published: May 2024

Abstract
The heavy oil reservoirs in China are predominantly deep-seated, with high heterogeneity and oil viscosity. Heavy oils situated at depths exceeding 900m constitute 62% of the nation's total reserves. By the increase of steam stimulation cycles, traditional thermal recovery techniques tend to yield diminishing benefits. Thus, Sinopec is establishing a series of thermal composite EOR technologies, primarily targeting deep, heavy oil reserves.
In this study, we've engineered high-temperature and high-pressure micro-visualization experiments to elucidate the microscopic mechanisms underlying thermal composite oil recovery. Our findings show the presence of wall-adhering oil films and filamentary flows during low-temperature hot water flooding. Specifically, at 150°C, the phenomenon of oil-water slug displacement occurs. At 350°C, steam manifests as isolated, nebulous clusters within the oil phase, subsequently leading to the oil phase's adherence to the wall in a turbid state. Upon encountering small pores, steam induces capillary condensation, indicating its liquefaction and heat release in regions with low permeability, thereby enhancing thermal efficiency. Chemical flooding has been observed to yield fine oil-in-water emulsions at pore throats due to its occlusive action, optimizing flow capacity. Notably, the combination of high-temperature steam and chemical agents promotes spontaneous emulsification upon contact with crude oil, generating a flow of finer oil-in-water emulsions. Our "heat+CO2" findings show that at 0.3 MPa, gaseous CO2 tends to form bubbles, subsequently leaving an oil film after gas flooding. Contrastingly, after supercritical CO2 flooding at 10 MPa, almost no oil film residues are found on the wall. At 20 MPa, CO2 dissolution and extraction make the oil phase components segregate at later stage. The combined effects of "steam, chemical agents, and gas" have been identified to significantly enhance oil extraction rates.
Based on our understanding of EOR mechanisms, we have conducted field tests. A thermochemical composite steam drive was executed in the highly-heterogeneous Ng5 block deep heavy oil reservoir in Shengli Oilfield, which has suffered from gas channeling induced by steam. This makes the horizontal displacement more uniform. The coefficient of variance in steam injection speed is significantly reduced to 0.13, surging daily oil extraction by up to fourfold. The recovery rate is increased by 27 percentage points, achieving 62.2%. For the challenges of steam injection impediments and crude oil recovery issues in the Zheng 411 block of deep super heavy oil in Wangzhuang Oilfield, a pilot scheme was launched to bolster thermal development through the combined effects of viscosity-reducing agents and CO2. Our data indicates that single-well production soared from 127 tons to 1,812 tons—a staggering 13.3-fold increment—with the oil-to-steam ratio peaking at 0.88.
Proposing an Adaptable Subsurface Data Assessment Workflow for Identifying Fluid Pathways in Fractured Carbonate Reservoirs
Authors: Olmeda Mariana , Funk Erich 
Published: May 2024

Abstract
The understanding of reservoir fluid pathways and their dynamic behaviour through time is essential for a successful development of a fractured carbonate reservoir. This work aims to propose an adaptable data analysis workflow to optimize the characterization of the reservoir throughout its life cycle. Accounting for different maturity stages and geological scenarios, the proposed evaluation sequence supports an optimum assessment of the reservoir architecture and the understanding of its production behaviour and evolving performance.
The methodology involves the dynamic evaluation and integration of geo-parameters, such as fault damage zones, fracture corridors and connected vuggy layers. The corresponding workflow enables a flexible data assessment of flow-dominating permeability zones and the degree of their spatial connectivity between wells and areas of undrained reservoir potential. The interpretation of image logs, regional field work and outcrops, seismic-scale faults, karstic sections, fractures and sub-seismic damage zones are combined to characterize flow zones and their corresponding hydraulic hierarchy expressed in the dynamic behaviour at well-scale.
The results integrate all information extracted and interpreted from available data sets, determining the preferential networks for fluid movement and how these can be linked to current field development strategies and reservoir management initiatives. The utilized flexible workflow accommodates both parallel and sequential tasks and is adaptive to each given geological case, supporting a streamlined data analysis towards an optimized understanding of reservoir dynamics. The reservoir assessment based on this methodology allows to establish conceptual flow scenarios and their potential impact on field performance. This analysis does also help identifying favourable areas for well placement, including refinements of optimum well design, strategic packer placement and production mitigations aimed towards a stable and sustained field life.
This paper is a contribution to the continuous learning process in field development optimization of heterogeneous fractured carbonate reservoirs. By implementing a flexible data analysis workflow, adaptive to complex geological and variable data scenarios, this work identifies the dynamic range of potential hydrocarbon and water pathways that will determine reservoir performance and helping to optimize the strategy for its development.
Addressing Complex Structural Imaging Challenges in Southern Caspian Sea Through Modern OBN Acquisition and Processing
Authors: Hu Xin. , Lyu Xiaolin. , Wang Wei. , Ding Cengzhen. , Khdhaouria Mourad. , Rouis Lamia. , Rondon Aldrin. , Qi Qunli. , Zhao Min. 
Published: May 2024

Summary
The Greater Cheleken Area (GCA) developed by Dragon Oil, is situated on a complex NW-SE dextral transcurrent zone which separates the Northern from the Southern Caspian Basin (SCB). Complex fault systems such as highly faulted Pliocene-Pleistocene flower structures and various mud volcanoes creating slow-velocity and high-absorption dimming zone, which bring huge difficulties and challenges in seismic imaging.
In 2022, an OBN seismic acquisition survey was carried out aiming to resolve the imaging problems that exist in a legacy dataset. The main objectives for the 3D OBN seismic survey are: proper imaging of structures, faults and fractures characterization, stratigraphy, petrophysical properties, gas columns and clouds mitigation and fluid contacts in clastic reservoirs cited between1500-4700m depth. The implementation of the seismic acquisition is successful, and a fast-track 3D data cube has been produced showing good results.
The meticulous processing sequence has been completed and the results of the 3D seismic data processing and interpretation are very encouraging, showing a clear improvement compared to the legacy 3D seismic data set. This processing workflow and key techniques used in the project are presented in this manuscript.