bluuebunny/crossref_metadata_2025_split huggingface dataset:
Fostering and Sustaining Employees’ Happiness in the Oil, Gas, and Energy Industry: the Role of Organizational Chief Happiness Officer in Implementing Happiness Initiatives and Programs
Authors: Alzain Hassan , AlGhazal Rym , Abu Qurain Ali , Karkadan Mona 
Published: February 2023

AbstractThe well-being of employees is catching momentum among various demanding industries across the world, underlying the importance of introducing and maintaining effective happiness initiatives to foster successful employees ’engagement with their line management to work better together and build loyalty to the workplace. This paper, therefore, aims to detail the strategic benefits of happiness initiatives along with the expected business benefits on long-term basis.A happy employee is defined as a productive and loyal employee. When an employee is happy, they tend to display greater engagement with their job. Similarly, studies have shown that when an individual feels "heard" and that their voice matters, their levels of morale are higher. Moreover, when equipped with the right tools to cope with a stressful environment, a worker's level of productivity and the quality of their work improves. The data collected at the end of each initiative is an important reference and resource for companies with a high number of employees across various specialties. This paper will provide the background of the importance of happiness initiatives, as well as making the first steps towards cultivating a culture of happiness in the more traditional industries, especially including the oil, gas and energy industry.The concept of a happiness initiative, especially in relation to international best practices, is currently not widely applied in traditional industries with evidence on the lack of a true sense of happy and productive engagement across different employees ’levels and contractors. Elevating happiness across organizations is, therefore, essential, as indicated by the fact that good mental health and well-being are core needs for any business to succeed in the post-COVID-19 era. Happiness at work is a relative, attainable concept that can be fostered and sustained in a more professional context, where organizations can play a vital and critical role in the research, establishment, and advancement of workplace happiness policies and frameworks on strategic basis that will positively result in tangible and non-tangible business benefits. This paper will outline mechanisms, best practices and the role of "Chief Happiness Officers" in leading tailor-made happiness initiatives to address organizational-specific needs and emerging issues.
Export Pipeline Material Selection for Extreme Sour Service Application
Authors: Sirilatthaporn Penporn , Komesvarakul Suchat , Kumseranee Sith , Trithipchatsakul Chao , Punpruk Suchada 
Published: February 2023

AbstractWith recent sour gas field discoveries, material selection for export pipeline carrying the sour gas and liquid is one of the key challenges in commercializing the fields especially for the large diameter and long tie-back export pipeline, and it is the focus of this paper. Both CRA clad and Carbon Steel (CS) pipes have been used for sour service pipelines with different benefit and drawback. The study was performed to investigate both technical and commercial feasibility of the two material options. Facility concept has been differentiated between options as CRA clad pipe do not require gas and liquid dehydration and treatment. The conceptual study cover design, fabrication, installation, operation, RAM and risk assessment aspects to identify the key strength and challenges including cost estimation for life cycle cost evaluation. Material selection review including project benchmarking for TMCP CS for sour service has been performed. CRA clad option provides the lowest corrosion and cracking risk leading to minimum requirement for offshore processing facility. However, additional or larger facilities are needed at onshore gas plant such as Slug Catcher and PW treatment. Two main concerns for CRA clad pipe are the buckling due to exporting &gt; 150 deg C fluids and the supply of CRA clad pipes for such a large quantity. TMCP CS option is more conventional for export pipeline with the main concern on the susceptibility for Sulfide Stress Cracking for sour service especially after the Kashagan incident. The study investigates the recent development of LHZ mitigation actions in manufacturing process, new pre-qualification recently published for extreme sour service and project benchmarking for similar H2S concentration. It has been concluded TMCP CS, with qualified manufacturer, is suitable for the extreme sour service application. Life cycle cost estimation indicate CRA clad option is significantly more expensive than CS option with the risk on the supply of cladded pipe. Cracking risk on TMCP CS for extreme sour service is high but manageable with the proven project record and therefore CS option is opted as development concept with the lower development cost than that for CRA clad.
2022 FSO2 Riser Hoses Replacement Project (Bongkot Asset)
Authors: Sayatanan Navakorn , Petchpong Sataporn , Kittithornkul Thamonwan , Charoenphol Juthaporn , Whungkhunnatham Apichart , Thuengsripan Santi , Ploiriang Somchai , Insuk Phitsanusak , Laopornpichayanuwat Nopharut , Sangwattanachai Manisa , Toungsetwut Mahapon , Srijunngam Danai , Aimcharoenchaiyakul Manit , Somroop Ekkalak 
Published: February 2023

Abstract
Two Riser hoses attached with FSO2 (Floating, Storage & Offloading) has estimated service life (9.3 years). The next replacement is required before July 2022. Thus, in June 2022 Project team had planned to disconnect and reinstall two newly riser hoses with approach to comingle production stream enable to continue production without any shutdown.
The overall execution plan has learnt best practices from previous operation since 2013. For 15 days offshore execution, collaboration between Project team, Operation & Maintenance, Marine team and specialized contractor is essential. The offshore execution began with preparation steps which include tank offloading, heading control system, pre-installation visual survey, before comingling to operate one riser hose and flushing another. Then, the 5 days operation per hose to disconnect, replace the newly hose. After leak test and hydrotesting all connections was performed, Production team will switch the production via this new hose and repeat similar replacement steps with another hose.
On technical aspects, the riser hose replacement may consider not a complicated task. Although advance preparation prior commencing offshore installation in conjunction with experiences contractor are critical and important. Collaboration with various stakeholders requires full attention to address those concerned areas with mitigation and measures especially on HSE aspects resulted from risk assessment and several workshops.
Strategic approach to perform the riser hoses replacement without interrupting the production is a challenge. Applying comingle strategy requires effort to breakdown related activities and sequential analysis to ensure all the execution will be smooth without jeopardizing the HSE issues. Also, during the contractor selection stage Project team had selected national qualified contractor. It turns out that national contractor also has similar capability to manage and deliver this scale of project with very acceptable quality but competitive price.
Even this is not PTTEP first riser hoses replacement project though the Project team would like to remark great achievement which could only arise from effective teamwork, good collaboration among all relevant stakeholders and benchmarked best practices from our expertise and learned from previous experiences. In addition, it is worth to mention that the offshore execution was performed safely without interrupting the environment and the ongoing production.
Algorithm for Real-Time Field-Data-Driven Automation for Intelligent ESP-Lifted Multilateral Wells
Authors: Sadowska Anna , Meredith Andrew , Goh Kim Fah Gordon , Yassir Ehab , Gambaretto Agustin , Divakaran Dileep , Almana Abdullah 
Published: February 2023

AbstractMultilateral wells with electric submersible pumps and intelligent completions are notoriously difficult to operate and require long testing and frequent retests due to production condition changes and significant transients resulting from the horizontal undulating drains. For human operators, this task is very time-consuming and extremely challenging given the multidimensional and multi timescale system characteristics. However, the process can be automated via optimisation and control, with the proposed algorithm responding to observed production and system changes throughout the well’s life. To that end, a reduced-order well model is derived and validated with real-well-matched synthetic model data, and subsequently an automation algorithm is developed. This innovative and integrated approach to real-time lift and inflow automated control offers the prospect of boosting operators’ production value and investment returns. The algorithm utilises existing or new intelligent completion hardware and instrumentation and the wellsite-deployable smart algorithm, capable of adjusting to varying well conditions and optimally managing the production throughout the well’s life. To achieve that, the algorithm allocates flow-rate and water cut contributions from each lateral or zone and as such recalibrates the well model on the fly using the real-time field data. We present simulation results using a field-data-matched synthetic model and are working with an operator to implement the technology in the field. All in all, such a data-driven automation to autopilot intelligent production is now within sight and could in the future scale towards multiwell/fieldwide solution.
Advanced Multiple Attenuation and Model Building Techniques Provide New Insights Into the Jurassic Play of Timor sea, Offshore Australia
Authors: Pitibhabhong Tanporn , Chakraborty Rupam , Ng Seng Hor , Lim Chee Kiong , Paton Ian , Phantawee Namfon 
Published: February 2023

AbstractThe Sandalford area, located in Australia’s northwestern continental margin, is proximal to the Cash-Maple and Tenacious field discoveries. The area has Eocene-Paleocene Carbonates overlying siliciclastic Cretaceous section, resulting in a strong velocity inversion as well as generating complex free-surface and internal-multiple contaminations at the deeper Jurassic reservoir section. We present a reprocessing case study of a narrow-azimuth, towed-streamer seismic dataset acquired in shallow water using advanced multiple attenuation and earth model building techniques, with the main goal of improving our understanding of the complex geology beneath. The multiple attenuation part of the workflow employs a cascaded approach, initially addressing water-layer multiples, remaining free-surface multiples, and followed with internal multiples. Implementation of high-frequency visco-acoustic full-waveform inversion (Q-FWI) improved the overburden velocity model and combined with effective multiple attenuation algorithms, reduced the uncertainty of primary events in the pre-carbonate section, therefore reducing errors in common image point (CIP) tomography. The results were quality-controlled against the well data, providing new insights with improved structural and stratigraphic delineation.
Experimental Investigation of Cement Compatibility in Underground Hydrogen Storage in Depleted Reservoir
Authors: Cracolici Federico , Iorio Vanessa Silvia , Parrozza Fabio , Sabatino Luigina Maria Flora , Previde Massara Elisabetta , Consonni Alberto , Viareggio Alberto , Altimare Cristiano William , Gori Samuele , Colombo Luigi , Racca Stefano , Poloni Roberto 
Published: February 2023

AbstractUnderground Hydrogen Storage (UHS) is a method to store a large amount of energy to manage its seasonal fluctuations. The selection of proper well materials is a critical aspect, considering the small size of the molecule of H2 and its strong diffusivity. Its impact on materials shall be deeply evaluated and investigated.The work described in this document analyzes the interaction of standard cement slurries used in oil and gas fields with hydrogen at standard reservoir conditions.The cement-hydrogen interaction tests were designed and conducted using the methodological approach typical of the materials/fluids compatibility tests; an autoclave was used as key instrumentation to simulate reservoir temperature and pressure conditions.The samples were left inside the autoclave in contact with hydrogen, at reservoir temperature and pressure condition (90 °C and 150 bar), for 8 weeks. In parallel to the aging in hydrogen, twin samples were aged in an inert atmosphere (nitrogen) for comparison.The effects of the long exposure of the cement to H2 have been analyzed by observing the changes in the chemical-physical properties of the cement itself.To give evidence of the goodness of the cement as a well sealant material in the UHS, compressive strength, saturation and permeability, chemistry of the cement were measured/analyzed pre- and post-hydrogen exposure.In addition to the tests, a theoretical analysis performed using thermodynamic modeling software was also conducted to validate test results. The thermodynamic analysis was focused on the specific interaction of the species, hydrate and not-, constituting the cement and the hydrogen, investigating the spontaneity of the redox reactions that could take place.Preliminary autoclave experimentation results show that hydrogen does not alter overly chemical and physical characteristics of cement samples.This compatibility study of Hydrogen with cement is the first important step to further de-risk any UHS activity.The engineered and adopted testing protocol reported in this paper proved to be effective for the purpose of the study and could be applied for the validation of specific cement slurries in the UHS contexts.
Think Out of the Box – GHG Emission Reduction by Changing the Way We Had Operated Before
Authors: Rungruang Jakree , Swasdiphanich Kolawat , Atibodhi Nopparat , Juengsiripitak Jirat 
Published: February 2023

Abstract
To support the Company direction of GHG emission reduction in PTTEP operation, GBS, APEX and OMI have initiated fuel optimization to minimize fuel gas consumption. Over 80% of total fuel gas consumption is fed to Turbo Compressor to convert mechanical power to gas energy by compression system. To improve overall efficiency of fuel consumption, the whole gas compression process has been reviewed and analyzed.
From preliminary review, there is a room to improve efficiency in part of gas cooling gas treatment process equipped with JT valve (Joule-Thomson, pressure reducing valve) that requires inlet pressure about 63-65 barg and outlet pressure of 55 barg to have cooling effect that decreases gas temperature from 45°C to 25°C. This cooling method takes huge energy from gas compressed in previous system. To improve overall process efficiency, the whole gas compression and cooling system was reviewed thoroughly. Consequently, it was found that the cooling margin of upstream equipment can compensate some cooling effect of JT valve leading to energy optimization of gas compression system without any additional modification and investment.
After process tuning with the margin of Booster Compressor Discharge Cooler and Wet Gas / Gas Liquid Heat Exchanger upstream of JT valve, the required inlet pressure of JT valve can be reduced that leads to Booster Compressor discharge pressure declined from 64 barg to 61 barg while JT valve outlet temperature is still maintained at of 25°C as design condition without changing any other related operating condition of the systems before process tuning. The lower pressure of compressor discharge, the lesser fuel gas consumption is expected for energy transformation of compression system.
Jasmine Field, Gulf of Thailand, Fill and Spill History Across Faults: A Fault-Seal Calibration
Authors: Davies Russell , Wilson Paul , Povey Danny , Prasongtham Pattarapong , Shibano Siriporn , Ampaiwan Tianpan , Saifuddin Farid 
Published: February 2023

AbstractCompartmentalization of reservoirs in operating fields is commonly caused by sealing of faults (Cerveny et al., 2004; Davies and Handschy, 2003;Davies et al., 2019; Knipe, 1992; Yielding et al., 1997; Yielding et al., 2010). Calibrating this seal, however, is difficult without adequate subsurface data. A local region across the central part of the Jasmine Field, Jasmine A, along the northern extent of the Pattani basin in the Gulf of Thailand, was selected in this study for detailed fault-seal analysis calibration. The objective was to present the details of the fill and spill history from a juxtaposition analysis across the faults. The large number of well penetrations with fluid and lithofacies data and the 3D models of mapped permeability distribution provided a subsurface framework to reduce the uncertainty and allow a more comprehensive analysis of the crossfault reservoir juxtaposition and fluid contact levels. Crossfault flow behavior and fill and spill history were evaluated by examining fluid contacts in a strike view of the fault, with the properties juxtaposed.The Jasmine Field is a narrow structural high that is cut by many NE-SW and NNW-NNE trending faults forming fault-bounded compartments. Reservoirs in the field are typically thin, stacked high-permeability fluvial sandstones of primarily Miocene age separated by thin shale beds that occur over a depth range of several thousand meters. Many of the sands have unique hydrocarbon-water contacts of oil or gas and water. Reservoir juxtaposition across the faults suggests that fault seal plays a major role in the trap. By comparing fluid contacts in each fault block, cases with different contacts across the fault likely represent a fault membrane seal. Contacts occurring at the same height suggest crossfault leakage.The evaluation was done by estimating permeability distributions across the fault. These results, however, were not adequately determined simply from the fluid contacts on either side of the fault: fill histories in adjacent fault blocks and lateral structural controls also had to be accounted for. The results together allowed a unique fill and spill history to be defined. The results of the juxtaposition analysis for the main faults bounding the local structural trap in Jasmine A provided a calibration for a 3D analysis of the faults, including estimation of fault-rock properties.
Post-Salt Structural Domains in Lower Congo Basin, Offhsore West Africa
Authors: Upadhyay Abdhes Kumar , Jaiswal Jyoti Shah , Osman Syamir B 
Published: February 2023

AbstractThe objective of this study is to understand the configuration of different deformation styles in post-salt sedimentary succession of Lower Congo Basin. Emphasis is placed on structural characteristics with respect to the thickness of salt and the geometry of the base of salt detachment.Owing to its weak visco-plastic properties, salt is very effective at decoupling deformation in pre- and post-salt sequences. Gravity and density driven deformation in the post-salt sediments is predominately controlled by salt thickness and changes in dip at the base of salt. Variations in these elements change across the basin which control the nature and timing of trap development. Using regional 2D and 3D seismic depth cubes, interpretation focused on the Aptian Salt and post-salt Cretaceous-Tertiary sedimentary succession. Here we map and identify various deformation styles in salt tectonics across the basin within which we observe consistent trap geometries which are containing hydrocarbons and resulting one of the prolific basins in the world for oil production.The post-salt sediments, present a classic example of gravity driven deformation associated with salt tectonics at a passive margin. Gravity driven structuration of (i) Extension, (ii) Translation and (iii) Compression can be observed along regional dip-sections. Through detailed mapping, various sub-domains provide an insight into the regional structural trends and tectonic evolution in the post-salt succession. Overall, ten structural domains have been identified from Shelf to distal basin along the regional dip section.Well defined structural domains can play a major role in classifying the trapping styles for hydrocarbon accumulations in post-salt successions. Identification of these domains provides a framework to de-risk different trap styles or highlights those traps which carry a higher trap risk. Timing of trap formation due to salt movement also plays a major role to further de-risk these traps. The main source rock for Post-salt section is located in Senonian interval, the charge modelling suggests the peak expulsion of hydrocarbon in Early Miocene time, therefore those traps formed in Oligocene to Early Miocene intervals have higher chance of trapping hydrocarbons, however traps formed from Mid – Miocene to younger levels have higher risk of trapping smaller or no hydrocarbons due to lack of charge availability.
Influence of Inorganic Solid Particles in the Formation and Stability of Crude Oil Emulsion
Authors: Hattori Tokima , Hao Xingjuan , Shimokawara Mai , Kato Yoshitake , Kitamura Ryuta , Elakneswaran Yogarajah 
Published: February 2023

AbstractWater-in-oil (W/O) emulsion could be formed during the transportation, refining, and storage of crude oils. In the stockpiling tanks, the emulsion and sludge formation were observed by storing of crude oils for a long period of time and cleaning of tanks. It has been reported that the presence of solids affects the emulsion types as well as the stability of emulsions produced. In addition, the surface properties of inorganic particles could influence the crude oil/water interface and thus affect the crude oil-water emulsion stability. Therefore, in this study, the presence of inorganic solid particles on the formation and stability of emulsion was quantitatively evaluated. A crude oil and synthetic brine were used for emulsion evaluation. In addition, calcite and kaolinite were selected as inorganic solid particles. Emulsions were prepared by mixing crude oil and synthetic brine at a ratio in volume of 1:9. The prepared emulsion was allowed to rest for 24 h and then centrifuged to separate crude oil and water. The volume and pH of resolved water were measured to assess emulsion stability in the presence of inorganic solids. It is found that the addition of inorganic solid particles increased the volume of resolved water and destabilize the emulsion compared to that of without inorganic solid particles. The concentration of solids influences the formation of stable emulsion: high concentration decreases the stable emulsion formation. The dissolution of inorganic solids increases the pH of the water and promotes the demulsification due to high surface potential of crude oil. Moreover, the solid particles enhance the formation of oil-in-water-in-oil (O/W/O) emulsion and thus generates unstable emulsion. Increase of temperature and addition of inorganic solids decrease the emulsion height, which was predicted by emulsion layer growth model where coagulation rate constant was a tuning parameter. High value of the coagulation rate constant implies strong coagulation between water droplets and facilitate emulsion instability.