bluuebunny/crossref_metadata_2025_split huggingface dataset:
Comprehensive Approach for Confirming and Modelling Residual Oil Distribution Below Current Free Water Level in Brown Giant Oil Field, Offshore Abu Dhabi
Authors: Montani Hiroki , Voleti Deepak Kumar , Yamamoto Kazuyuki , Inokuma Yuto , Farooq Umer , Alshamsi Suad Mubarak 
Published: November 2024

Abstract
Optimizing the development of oil and gas, which are finite underground resources, is indispensable for human activities. Historically, humanity has prioritized the extraction of conventional oil and gas, which are easier to produce. However, recent technological advancements have enabled the efficient extraction of unconventional oil and gas, such as shale oil. The target reservoir of this study has similarly focused on conventional oil that is located above current free water level (FWL). Nevertheless, historical core data, log data, and production data of the reservoir indicated the presence of oil below current FWL. The oil below current FWL is considered to be residual oil, which is the result of an imbibition process that occurred after the oil charge. The exact distribution and development potential of residual oil, however, were not well understood. Additionally, since the late 1970s, peripheral water injection (PWI) from outside the current FWL has been implemented in this reservoir to maintain pressure, but it has been ineffective. A hypothesis was formed that the cause of this pressure discontinuity might be the residual oil.
For the above reasons, it became necessary to accurately capture the distribution of residual oil below current FWL to optimize future development plans in this reservoir. Previous reservoir models had not successfully modeled the distribution of residual oil below current FWL. Therefore, this study adopted a new static modelling technique that is most suitable for the heterogeneous and mud-dominant reservoir. To accurately model the distribution of residual oil below current FWL, we created a paleo FWL surface in addition to current FWL and constructed a water saturation (Sw) model based on the paleo FWL surface with saturation height function (SHF) for each static rock type (SRT). This approach allowed us to model the distribution of residual oil below current FWL. As a result, the matching accuracy between the Sw model and Sw log significantly improved compared to previous model. Moreover, the distribution of residual oil obtained from this modelling study was consistent with regional tectonic events. Furthermore, accurately modelling the thick Sw transition zone of residual oil allowed us to reproduce the pressure difference between peripheral water injectors and oil producers in the dynamic model without arbitrary modelling methods. The results of this study led to the optimization of future development plans such as water injector location for pressure maintenance.
Making Non-Metallic Downhole Tubulars a Reality – An Analytical Load Estimation Workflow
Authors: Boubenider Rafik , AlAdawy Ahmed , Cooke David , Mintzas Angelos , Elshamy Omar 
Published: November 2024

Abstract
Non-metallic composite downhole tubulars provide significant value including less carbon footprint and reduced total cost of ownership. However, matching pipe performance envelopes to combined loading in different scenarios cannot be performed using commercially available software, due to various challenges including anisotropic pipe behavior, variation of material properties across the depth and change of well conditions. This publication highlights multidisciplinary collaborative efforts to estimate such loading in composite tubulars and compare to existing use cases.
Load cases and conditions were determined, and analytical calculation workflows were deduced for loads at various depths and conditions across the lifetime. Load cases and alternate loading sequences are listed, interactions between tubular & system components are reflected and proper boundary conditions are applied to estimate such combined loads. Validation was performed against finite element analysis methods and methodology was applied in specific well applications.
Results using suggested analytical methodology show good matching with numerical results using finite element analysis. Loads were matched against pipe performance envelopes with suggested safety margins for different pipe designs. Whilst pipe design changes, variation of pipe effective properties, including stiffness, density, and dimensions, affect the total combined loads acting on the tubular system. Well construction parameters including deviation profile, depth, and geothermal gradient affect conditions inside the well, differential pressure and axial loads. Change of system components including pipe connections, completion, installation tools and ancillaries significantly affects such loading profiles. These system components can be optimized and custom components and installation procedures for non-metallic composite tubulars can be developed and qualified to reduce such loads on the pipe.
Application of reel-deployed thermoplastic composite pipes is unique and novel in downhole applications and must be accompanied by customized design workflows and validation programs. A new analytical design approach was developed for estimating the thermoplastic composite pipe structural response. This publication is bringing an integrated workflow for estimating these loads on non-metallic downhole tubulars, which – to the best of the authors’ knowledge – has not been presented elsewhere.
Mitigating Gas Hydrate Formation in Deepwater Operations Using Red Onion Skin Extract ROSE
Authors: Wachikwu-Elechi Virtue Urunwo , Onyekachi Ndidi Precious , Ikiensikimama Sunday Sunday 
Published: November 2024

Abstract
One of the serious flow assurance issues plaguing the oil and gas industry is Gas Hydrate formation. They are nonstoichiometric glasslike or crystalline compounds that form when water referred to as host molecules encapsulate hydrocarbon or non-hydrocarbon gases (guest molecules) at low temperatures and high-pressure conditions. They cause restrictions/plugging of flowlines when allowed to form which mitigates flow assurance. The use of agro-waste in various process activities is becoming popular due to environmental concerns and public health. This study seeks to address the use of such waste; Red Onion Skin extract (ROSE) as an inhibitor for gas hydrate. A locally formulated High-pressure magnetic stirrer was used to screen varying weight percentages of ROSE (0.01-0.03wt%) and compared to a conventional hydrate inhibitor Polyvinylpyrrolidone (PVP). The performance of the agro waste skin extract (ROSE) was assessed using pressure, temperature plots as well as relevant plots. Gas hydrate formation was indicated by a rise in the temperature of the reactor cell and a drastic reduction in the cell's pressure. The final pressures for 0.01-0.03wt% of ROSE were 11.2, 12.3 and 12 bar while values for the same weight percentage of PVP were 12.3,11.6, and 10.1 bar respectively. The ROSE performed better than PVP at 0.02 and 0.03wt% respectively showing its optimum inhibition performance at 0.02wt%. Although the performance of PVP was better than that of ROSE at the lowest concentration of 0.01wt%, the difference in the final pressure value was about 1.1 bar which shows ROSE's competitiveness at the weight percent. Again the ROSE helps to check environmental degradation, toxicity, and high cost of the convention PVPThe difference in values for ROSE at 0.03 and 0.03wt% was about 0.3 bar which is an indication that inhibition above 0.02wt% was needless and uneconomical. 0.01wt% while for 0.02 and 0.03wt% ROSE out-performed the PVP. The ROSE has been shown to perform better than PVP in most weight percentages used and can be harnessed as an alternative to costly and toxic inhibitors by the Oil and Gas industry taking into cognizance its eco-friendliness and human health compliance.
An Integrated Reservoir Evaluation Technique for Dual Structure Reservoir Based on Geomorphic Features and Seismic Anisotropy and its Application to Granite Buried Hill Reservoir in Central Africa
Authors: Yaliang Xia , Jiawen Song , Xiaodong Wei , Lirong Dou , Jingchun Wang , Jie Hu , Juntao Zhang , Yunpeng Hou , Xin Chen , Zhongfan Wang , Dengyi Xiao , Donghai Liu 
Published: November 2024

Abstract
The basement of Bongor Basin in Chad, Central Africa, is composed of Precambrian granite, gneiss and mixed granite. The basin is a tensile basin formed by the Central African shear strike-slip and tensioning effect. Strong overturning exists in the basin and it suffered long-term weathering and denudation during the Paleozoic and Jurassic periods. Core and drilling data show that both pore and fracture reservoirs are developed in the buried hill, and there are great differences in reservoir patterns and development situation among the buried hills, the reservoir is highly heterogeneous, which have great influence on productivity.
This method is based on wide-band, wide-azimuth and high-density seismic data. Combined with logging, core analysis, imaging and production data, this paper firstly summarized the development model of buried-hill reservoir, divided favorable reservoir sections of buried-hill vertically and identified types of reservoir voids, secondly integrated with the results of three-dimensional seismic structural characterization of buried-hill, completed the classification of buried hill morphology, and summarized the reservoir development characteristics of different types of buried hill. On the basis of fully considering the formation, influencing factors and preservation conditions of buried-hill reservoirs, the pre-stack and post-stack prediction are combined to carry out classification prediction of pore and fracture reservoir, among which the prediction method of porous reservoir based on buried hill geomorphological characteristics and seismic sensitive parameters is proposed for the first time. Pre-stack OVT fracture prediction based on seismic wave anisotropy of different azimuth has become a hot spot in fracture prediction in recent years. The study result clarified the distribution characteristics of buried-hill pore and fracture reservoirs, improved the prediction accuracy of buried-hill reservoirs, and provided a set of reliable technology for buried-hill exploration in this area. It is also suitable for exploration and evaluation of other reservoirs with similar seismic and geological conditions.
Hands-Free Control Line Clamp System to Remove Red Zone Exposure
Authors: Gravouia Mark , Alleman Neil 
Published: November 2024

Abstract
The Remote Clamp Installation System (RCIS), Sheaveless Control Line Manipulator Arm (SCLMA) and Hands Free Hole Cover is an advanced, integrated system that remotely positions control line packages and installs the control line clamp with minimal operator interaction during smart completions. The system is designed to reduce hazards through automated sequencing that eliminates manual operations, hazardous setups, and the need for personnel to enter the red zone.
The Hands-Free Control Line Clamp System can install a control line clamp with no personnel entering the red zone. All functions are operated automatically with a one-touch system of controls and sensors, or it can be manually operated utilizing a remote console. Installed sensors ensure seamless operation of the system and guard against damage of equipment and control lines. Typical red zone manual functions are eliminated, replaced by the Integrated System with increased safety and efficiency through automation and delivers repeatability on every clamp installation.
The control lines run through the SCLMA as opposed to an overhead sheave and are presented correctly to the tubing to ensure the control line clamp can be installed without damaging the control lines. The retainer lids that secure the control lines are installed in the RCIS out of the red zone. Once the SCLMA has positioned the control lines correctly on the tubing, the RCIS is safe to function, the manipulator slews the clamp head in line with the tubing and translates the clamp head to well center. Once in proper position, the clamp head translates the retainer lid to its position and after acknowledgment from sensors, the clamp head will complete the installation by clamping the male and female collars to retain the retention lid and ensure the control lines are secure.
This solution not only enhances the industry's experience with improved safety and reliability, but it is also a paradigm shift that revolutionizes the control line installation process providing a fully autonomous, hands-free solution. This paper will deliver comprehensive details on the novelty of this technology and the solution offered to the industry.
Quantitative Assessment Method and Application of Natural Fracture Risk in Shallow Shale Gas Based on Geomechanics-A Case Study of Zhaotong Shale Gas Area in Southern China
Authors: Zhang Muyang , Xian Chenggang , Huang Xiaoqing , Liu Yunyi , Liu Yang , Liu Mingyang , Wang Jianjun , Liu Cheng , He Yong 
Published: November 2024

Abstract
The presence of natural fractures in the study area, combined with complex stress conditions, poses challenges for accurately quantifying fracture stability, directly impacting block development. This study employed a three-dimensional geomechanical model and a natural fracture model to calculate the critical stress states of natural fractures across the region. It provided a quantitative characterization of fracture shear slip stability through normalized analysis and classified the risk of natural fracture slip. The stress state of the block was quantitatively described using the Q index, and the stability of fractures under different stress conditions was analyzed. Additionally, the study examined the relationship between fracture stability and interference from horizontal well fracturing, casing deformation in horizontal wells, and well productivity. These findings are crucial for optimizing the exploration and development of shallow shale gas resources in southern China.
Offshore Acid Stimulation, Reaching New Limits
Authors: Rivas J. , Prossaird S. , Bakir H. , Faour F. , Elsayed H. , Elhassanat A. 
Published: November 2024

Abstract
With long horizontal sections on carbonate reservoirs being more common on the Middle East, the industry needs to contagiously evolve to match the market needs. Not more than 10 years ago reservoirs were stimulated with acid dosage of 100 to 150 gallons per foot (gpf); nowadays is common to find 10,000 ft. horizontal sections requiring around 24,000 bbl. of acid to meet the 100 gpf request bringing new levels of complexity to offshore operations.
Since the inclusion of the high volume/high pumping rate vessel to our customer's offshore oil fields the average volume is around 5,000 bbl. of acid systems and, thanks to the 200,000 gal. below-deck raw acid storage capability, it was possible to perform an acid stimulation connected to an offshore platform by a high-pressure flexible hose to pump 10,500 bbl. of 15% hydrochloric acid (HCl) system at an average pumping rate of 20 bbl./min. and wellhead injection pressure (WHIP) of ∼2,200 psi. This operation set a milestone for offshore (barges and rigs) operation in the region.
Due to its versatility this stimulation vessel has the capability to also pump at low pumping rates (down to 0.3 bbl./min.) for coiled tubing operations and it has been assigned to execute stimulations in offshore environment and island wells which is a hybrid set-up where, having the vessel docked at the island's jetty, it is required to rig-up up to 5,200 ft. of 3in. treating lines being able to pump acid treatments at 35 bbl./min. in an inland well. All these while transmitting in real-time the operation parameters with our customer in town.
The bigger the better, stability issues have been reduced due to the vessel's length and weight allowing it to stay offshore longer time in a safer and comfortable way for the crew on board. Also, it was possible to reduce the number of vessels trips for re-loading purposes on operations above 3,000 bbl. for 15% HCL systems and 2,000 bbl. for 28% HCL systems, leading to reduce the diesel consumption and CO2 emissions of the rig and barges and the vessel itself (marine and stimulation engines). This time optimization is also considerably reducing the cost of the operation by doing a 10,500 bbl. job in 2 days’ rig-time instead of 6 to 7 days as it was being done before.
Navigating Energy Transition: a Marine Logistics Perspective
Authors: Saxena S. 
Published: November 2024

Abstract
This paper aims to provide an overview of the current state of energy consumption and carbon emissions in marine logistics, and to explore the potential and challenges of energy transition and net zero practices in this sector. Marine logistics accounted for about 2.8% of all global greenhouse gases (GHG) emissions as per a 2020 IMO study, mainly due to the fact that more than 80% of the world merchandise trade by volume is transported by sea.
The paper reviews the literature and data sources on the topic, and analyses the trends, drivers, barriers, and opportunities for energy transition and net zero practices in marine logistics. The paper also presents some case studies of actual implementation of such practices in different regions and contexts.
The paper finds that marine logistics is a significant contributor to global greenhouse gas emissions, and that there is a need and a potential for energy transition and net zero practices in this sector. However, the paper also identifies some technical, economic, regulatory, and social challenges that need to be addressed to enable and accelerate such practices. The paper suggests some possible solutions and recommendations for future research and action.
The paper provides a comprehensive and updated overview of the topic and synthesizes the findings and insights from various sources and perspectives. The paper also highlights some gaps and limitations in the existing literature and data and proposes some directions for further exploration and innovation.
WeLead - Shaping Leaders of the Future Through Mentoring
Authors: Poole A. , Sonika S. , Bhobhiya K. , West S. 
Published: November 2024

Abstract
With the accelerating digital transformation, close cross-communication and knowledge sharing are imperative to deliver the best possible results to our customers and help our employees prepare for their roles in the future.
Mentoring is the process of assisting and encouraging people to take charge of their own education in order to maximize their potential, enhance their talents, optimize their performance, and become the person they aspire to be.
Mentoring is also long used by Fortune 500 companies to improve talent attraction and talent retention, as well as to accelerate employee development. This entry highlights an innovative approach to mentoring that maximizes participant energy and company culture engagement, aligning with the standard mentoring benefits recognized by 84% of FORTUNE 500 companies (Gross 2023).
An inclusive, diverse workforce needs mentoring to promote individual growth, job satisfaction and talent retention. Mentoring program described in this manuscript channels early adopters’ energy to mentor and purposefully reinforce company culture accelerating the alignment of greater organization with company purpose, strategy and culture through "leadership stories" & experience sharing.
High Molecular Weight Polymer Injection in Polymer Flood EOR Project South Oman: Achieving More Oil with Less Polymer
Authors: Riyami Omaira , Riyami Samiya , Abri Hasanaa , Nadeem Muhammad , Farsi Samya , Handali Mahmood , Jabri Reham , Hinai Suliman , Hajri Abdulaziz Hashimi. Mohammed , Busaidi Hamood 
Published: November 2024

Abstract
Since commencement, full field polymer flood application in Marmul field located in southern of Oman has been a worldwide successful polymer enhanced oil recovery project. This project was effective in realizing incremental oil volume on top of water flood, with recent realization of the highest polymer oil gain since the beginning of polymer flood project life cycle. Oil daily rate improved to double comparing to previous years with the same well stock. This achievement was a result of many initiatives like data automation, improvements on troubleshooting, increase in polymer viscosity, high sustainable polymer pump uptime and better equipment maintenance to minimize mechanical issues. Integrated team effort and collaboration between petroleum engineers, production chemists and operation team helped to significantly improve polymer flood performance. Partially hydrolyzed polyacrylamide (HPAM) of a molecular weight of around 20 million Daltons has been used in the project since its start date with target viscosity of around 15 cP at relatively low brine salinity (~5000 ppm) and reservoir temperature (46 °C). In the polymer plant, stabilizing package (isopropanol, thiourea and water, (ITW) has been added to the polymer solution to enhance long-term viscosity stability of the polymer at reservoir conditions. Entire polymer mixing facilities are nitrogen blanketed and maintained in an anaerobic condition. Given that polymer projects are OPEX driven (mainly by chemical consumption), the team has successfully piloted an initiative to increase the polymer molecular weight from around 20 to 25 million Daltons, hence, reducing polymer dosage by 20-25% to achieve target viscosity of 15 cP. This led to the implementation of full field injection of the high molecular weight polymer. The new self-stabilized polymer has been selected based on its excellent injectivity performance validated by labs and field pilot trial. This project is expected to yield savings in the opex & improving the overall project UOC attributed to the use of self-stabilized high molecular weight polymer by eliminating ITW package and achieving viscosity with low concentration.