bluuebunny/crossref_metadata_2025_split huggingface dataset:
Laboratory Evaluation of Single-Phase Retarded Acid System Performance in Limestone and Dolomite Rock - Part 1: Pore Volume to Breakthrough Experiments in Limestone
Authors: Morrow Timothy I. , Kelkar Shrihari , Mogensen Kristian , Leguizamon Javier , Mohammed Abdul Muqtadir , Ahmed Kamran , Nizamuddin Syed , Awan Ehsan Ul Haq , Veetilakath Yehiya 
Published: November 2024

Abstract
The objective of this work is to conduct systematic core acidization testing on commercial limestone and dolomite core plugs to compare different commercial acid systems and identify the most cost-effective recipe(s), including optimum dosage and pumping rate. The work involves state-of-the-art equipment for the acidizing experiment at reservoir conditions and makes use of advanced high-resolution imaging to visualize the results of the pore-volume-to-breakthrough acidization experiments.
Over the past few years, service companies have brought new acid stimulation products to market. These so-called retarded or delayed acid systems aim to slow down the kinetics of the acid-rock reaction to allow acid to penetrate deeper into the rock matrix and thereby increase reservoir contact. Prior to any deployment at scale, these new chemical products must be qualified by an independent lab facility rather than relying solely on performance data supplied by vendors. In addition to acid compatibility with the reservoir fluid, the ability to create deep penetration with the lowest possible acid volume needs to be quantified. A key experiment is called the pore-volume-to-breakthrough (PVBT) test conducted on cylinder-shaped reservoir rock samples called core plugs. Within a certain range of acid velocities, the chemical rock dissolution reaction yields an optimum penetration depth with a minimum acid volume. The lower the volume, the more cost-efficient the acid recipe.
Nine single-phase retarded acid (SPRA) systems were evaluated, and all showed better performance than standard 15% HCl (in limestone) or 28% HCl (in dolomite) cores. Some SPRAs were marginally better than the standard HCl systems while others showed significantly improved performance. This paper will report a ranking of each of the SPRA systems evaluated from best-to-worst. Of particular note is that SPRA systems containing lower retarder dosages showed similar performance to SPRA systems that contain significantly higher retarder dosages. The lowest PVBT, which would represent a single, thin, straight cylindrical wormhole in a linear coreflood may not be optimum in a 3D radial flow pattern. We present a discussion on the need for some degree of branching of the dominant wormhole to enhance the flow into an actual wellbore, depending on the completion type.
This work represents the first systematic comparison of multiple single-phase retarded acid systems at the same test conditions by an independent laboratory.
Planning Developing and Designing Unconventional Lifts for Brownfield Projects
Authors: Korat Hiren , Cherian Litty , Kamal Faris Ragheb 
Published: November 2024

Abstract
In the context of enhancing production facilities within a brownfield, whether to increase output or transition to safer technologies, modifying existing facilities by addition of new equipment and deck extensions becomes imperative. The design, modification and installation of these deck extensions undergoes a rigorous EPC cycle which is undertaken by EPC contractors in co-operation with various contractors. This EPC cycle address all the requirements of the brown field project, start from engineering operational requirements to construction and installation within budgeted cost.
Invariably these modifications need to be carried out in planned manner. Maximizing construction of modules onshore to reduce construction time, achieve good quality and reduce offshore construction time. These modules once constructed at an onshore facility, are loaded on to transportation barges and sent to offshore facility for installation. To receive the module on to the fixed platforms necessary arrangements are made. The arrangements are engineered based on the type of modification.
Often the modifications need to be carried out in area which are not in direct reach of cranes and hence requires engineering additional arrangements such as skidding, use of static rigging etc. to receive deck extensions/modules etc. Often it requires shutdown of the facility and temporary removal of existing facility components. These inaccessible areas can be often accessed easily using unconventional lifts. The unconventional lifting methods employs additional tools depending type of unconventional lift adopted.
Adopting unconventional lifting methodology has its own benefits which are not limited to:-
Reduction in hiring of costly resources and dependence on their availability. Reduction in temporary modifications in existing facility to receive modules. Simple and fast module installation. Reduction in project cost.
This paper will describe in detail concept of unconventional lifting. And will specifically cover unconventional lifting using spreader bar and counterweight mechanism.
Addressing Karst-Related Challenges in Seismic Imaging - A Case Study from Onshore Abu Dhabi
Authors: Hassan Shady , McCarthy David , Brajas Carlos , Seliem Abdulla , Blymyer Dustin , Bernal Maria Cristina 
Published: November 2024

Abstract
The karsted UER and Simsima formations in Abu Dhabi represent a major challenge for seismic imaging as well as for drilling. The heterogeneity of the eroded limestone results in strong lateral velocity variations that distort the deeper seismic image. The conventional approach using pre-stack time migration (PSTM) and pre-stack depth migration (PSDM) results in a strong reflection at the top of the UER, with poor imaging quality in the section below. This paper outlines the challenges of this onshore dataset and proposes a new workflow using multi-wave inversion (MWI), TLFWI, wave equation deconvolution, Q-tomography and QPSDM, which helps to better detect the karsts bodies and improve the image quality below UER.
The dataset was acquired and initially processed in 2021. The data were of high quality for most of the survey but deteriorated in the north-east, due to thickening of Miocene evaporites in the near surface and the presence of karsting, which poses challenges for seismic imaging both onshore and offshore Abu Dhabi. A re-processing project was launched in 2023 with the aim to enhance the image quality in the area affected by the thick evaporites and karsting. An advanced velocity model building flow was used.
The combination of multi-wave inversion for the near surface velocity model and 10Hz TLFWI produced a high-resolution velocity model that accurately imaged the complex overburden and the fast velocities associated with the karsts. The application of wave equation deconvolution, alongside standard deconvolution techniques, reduced the presence of high frequency ringing from the shallow evaporite sequence. Q-tomography was able to identify Q anomalies, with interval Q values as low as 20 within the karsts. The final QPSDM image shows improved amplitude fidelity, frequency content, and imaging below the karsts when compared with the legacy data.
By the end, we demonstrate that this combination of high-end approaches, i.e. TLFWI and wave equation deconvolution, solves the encountered challenges, which helps to improve geological understanding and drilling plans as well as to open more opportunities for discoveries in the sections hiding below the karsts.
Exploring the Role of Digital Substations in Driving the Fourth Industrial Revolution
Authors: Elfayoumy M. 
Published: November 2024

Abstract
The next generation of power substations, known as digital substations, are influencing contemporary digital technologies to change how energy is delivered and transported. The objective of the paper is to clearly define how the Industrial Internet of Things (IIoT) can improve the performance and value of assets without requiring replacement of the fleet, reshaping the future of electrical power substations.
The paper introduces a case study that analyses smart digital substations, connecting wind farms to the grid, where both primary and secondary assets and wind turbines data are made available to a SCADA system. Following a methodological approach and considering the off-line (historical data, operators’ inspections, off-line reports) and on-line (interconnected sensors, protection & control IEDs and SCADA parameters) data being captured from assets and are ingested into the platform, breaking the information silos, contributing to assess the risk level for each asset, in a user friendly and easily accessible cloud SaaS (Software as a Service) environment.
The methodological approach deployed in this paper helped to define how to use data to its fullest potential and enable renewable energy sources to provide more dependable power supplies while utilizing the same grid infrastructure. The approach defines a clear path starting by applying predictive maintenance fundamentals through condition monitoring, moving to turning data into information, evolving to turning information into decisions as outcomes from the Asset Performance Management system (APM), and finally Video Analytics technology. As a result of applying this approach on a step-up power transformer and protection relays, APM application is proved to be able to produce more insights, of higher quality and level of detail, that helps in having effective decision-making process.
Application of Laboratory Approach to Offshore Analysis: No Compromise on Fluid Composition
Authors: Pearson S. , Winkworth N. H , Langford M. W. 
Published: November 2024

Abstract
Presented here is the development of a new approach to compositional analysis, allowing data to be generated in offshore and field environments with the same level of quality as established laboratory measurements.
Availability of reliable fluid composition traditionally relies on established, often remote, laboratories, resulting in considerable delays before data is available for reservoir models and other field evaluations. Previous attempts to generate compositional data onsite have compromised quality in order to improve portability and reduce reporting time.
The innovative approach presented is a result of technology assessment, method refinement and extensive testing including comparison with traditional laboratory techniques. Evaluation of deviations in compositional measurements between the techniques was performed, with the analytical uncertainties of the methods considered.
Testing commenced using certified reference materials from a variety of sources and extended to include analysis of real samples available in the lab facility.
Comparison with laboratory techniques showed excellent compositional agreement, well within the expected uncertainties and acceptable tolerances of the methods, and the certified materials.
Improvements in column selection and method optimization allowed the reduction of run times to circa 30 minutes, enabling completion of blank, verification and sample runs within the timespan of a single shift and reporting of fully reviewed data within 8 hours of sample collection or completion of sample restoration.
Samples are run in triplicate, with QC checks that mirror those performed in the laboratory to generate confidence in the offshore data.
This novel approach allows laboratory quality compositional data to be generated in the field without compromising on the calibration, verification and QC processes which give confidence in the measurements.
Earlier availability of this data enables quicker decision-making without compromising on the quality of the measurements.
Improving the Efficiency of Active and Passive DAS Seismic Monitoring in an Onshore CCUS Demonstration Field
Authors: Watanabe Y. , Mouri T. , Nakayama S. 
Published: November 2024

AbstractLong-term monitoring of injected CO2 in Carbon Capture Utilization and Storage (CCUS) projects, particularly seismic monitoring, constitutes a substantial portion of operational costs, despite CCUS's critical role in achieving carbon neutrality. Distributed Acoustic Sensing (DAS) technology offers a solution to reduce the cost and workload associated with monitoring in CCUS projects. This study focuses on improving operational efficiency by reviewing techniques for active seismic acquisition and continuous passive seismic monitoring, as demonstrated by Nakayama et al. (2024a, 2024b, and 2024c) in an onshore CCUS field test at the Minami-Aga field, a depleted oilfield in Japan. For active seismic monitoring, a walk-away DAS vertical seismic profiling (DAS-VSP) survey using a simultaneous source acquisition method, known as the slip-sweep method, was conducted as a baseline seismic survey. The comparison between traditional and slip-sweep acquisition methods revealed no significant differences in data quality, with the slip-sweep method nearly doubling acquisition efficiency. To manage the vast amounts of data generated during continuous passive seismic monitoring, a DAS system and real time data handling framework were employed. Microseismic (MS) events during the CO2 injection test were detected and located using a real time data analysis approach, resulting in the identification of approximately 1,200 events with estimations of their locations and moment magnitudes. The DAS system demonstrated high sensitivity to small-magnitude events. These field trials underscore the importance of enhancing operational efficiency to fully realize the potential of DAS in both active and passive seismic monitoring within CCUS projects.
Successful Reactivation of Offshore Dead Oil Well with the Gas Produced by High Gas Cut Adjacent Well Using a Rig-Less Retrofit Gas Lift System - First Worldwide
Authors: Shokry A. , Biyanni H. , Abdulla M. , Dwivedi V. , Yakovlev T. , El-Sayed M. A. , Najy A. , Agrawal P. , Keshtta O. , Sulaiman A. , ElSheikh H. , Sabri A. , Alhammadi N. , Al-Hassani S. D. 
Published: November 2024

Abstract
Globally, in-active oil-producing strings constitute a substantial portion of the active ones, posing a considerable challenge for NOCs and operators. Monitoring the KPIs of these inactive strings is essential not only to prevent deferred production but also to evaluate operational efficiency and environmental impacts, such as carbon footprints.
For a national oil company in UAE, the objective to reduce the number of in-active string from an offshore oilfield became a catalyst for innovative thinking, leading to the successful revival of a dead oil well.
The well in focus was a natural oil producer (without any provisions of gas lift) that had become in-active due to liquid loading. While the retrofit gas lifting was the preferred solution, there was no availability of lift gas or gas injection network to support the revival plan. A nearby well with very high gas production (HGOR) was identified as the "donor" well to provide the lift gas, resulting in a novel retrofit gas lifting solution.
The paper will describe an innovative approach to rejuvenate the "receiver" well by utilizing the produced hydrocarbons (as lift gas) from the "donor" well in a rig-less intervention environment. The paper aims to present a comprehensive overview of the entire process, from the initial conceptual design and simulation studies to the selection of a retrofit gas lift system (specifically, a straddle packer- based system), as well as the subsequent operation planning and field installation.
The innovative revival approach led to the successful reactivation of the well, resulting in significant production gains, which were confirmed through well testing. This paper will also emphasize the benefits of this approach, including quantifiable cost savings (with minimal CAPEX) and reduced carbon footprints. Additionally, the installation of a retrofit gas lift system can be completed in the short term without the need for an expensive rig workover.
The paper will demonstrate the advantages of the "life of field" gas lift design approach that was implemented for the "receiver" well. This approach involved determining the optimal set points for gas lift depth, injection rate, orifice size, and other parameters to accommodate the varying field conditions for both the "receiver" and "donor" wells.
The "receiver"/"donor" arrangement between the wells was carefully analyzed in accordance with established well integrity guidelines and industry best safety practices. This analysis was used to develop operational procedures and steps that were crucial to the success of the operation and served as a testament to the effectiveness of teamwork with aligned objectives.
Integrating Seismic and Well Data for Cementation Limit Determination: A Case Study in the Upper Arab D Reservoir, Sour Gas Field in the SW of Abu Dhabi, United Arab Emirates
Authors: Isdiawan Agusandi , Al Darmaki Fatima , O'callaghan Earl John , Al Teneiji Moza , Corrales Alvaro 
Published: November 2024

Abstract
The objective of this paper is to demonstrate the advantages of integrating seismic and well data in the Upper Arab D Reservoir for defining the cementation limit (CML) and improving the reliability of field and reservoir dimension for Gas in Place estimation by employing a scientific method that includes data interpretation, attribute analysis, and reservoir characterization to minimize uncertainties. The results demonstrate the value of this methodology, providing a fuller understanding of reservoir heterogeneity (porous and cemented rocks) and enabling reduced GIP estimation uncertainty. This approach contributes significantly to reservoir management strategies, aiding in reservoir modeling and development planning in the complex reservoirs of the Upper Arab D. The process of continuously updating the CML grid and integrating it into the reservoir model progresses geological understanding and improves operational decision making for future development wells.
Enhancing Pipeline Integrity Data Management through Power BI and PI Dashboard Approach
Authors: Bulushi K. Al , Mawali F. Al , Alrashdi I. 
Published: November 2024

Abstract
With ageing facilities, maintaining integrity of the pipeline via proactive maintenance becomes vital to reduce the operation risk level and zero harm to surroundings. Data-centered approach allows stakeholders to prioritize critical assets, allocate resources efficiently, and ensures proactive measures to maintain the integrity. The novel approach present success story of integrating massive data that affects the pipeline integrity by providing visionary analysis of all findings from different used inspection techniques, as a result it prioritizes inspection and repair program with minimizing downtime and disruptions due to unpredicted damage and defect, through utilizing available digital resources.
This paper presents an innovative approach to of data management and interpretation in the oil and gas industry: ensuring integrity, safe, and reliable operation of the critical pipelines as part of Oxy management system. The focus lies on introducing advanced data analytics through the implementation of a Microsoft Power BI visualization and OSI PI dashboards. This by integrating real-time Integrity Operating Windows (IOW) WITH inspection reports to address potential damage mode affecting segment of a pipeline. The tool accelerates maintenance program via data-driven decision making, by proactive identification of potential issues and leak points that affect the environment to ensure not leaving any barrel behind. The tool starts by examining the latest two In Line Inspection (ILI) reports via aligning common features such as joint number and distance of defect from the weld to illustrates differences in wall thickness and pitting depth of reported anomalies in the pipeline. Then, the data integrated with pipeline layout (topography) and other Cathodic Protection (CP) surveys, such as ON Off survey, Direct Current Voltage Gradient (DCVG) and Close-Interval Potential Survey (CIPS), so that condition and defects aligned with pipeline chainage. On the other side, the tool also gathers data for corrosion inhibitor treatment program performance, readings of bacteria, corrosion coupons, basic sediment, and water (%BS&W) and integrity operating windows (IOW). The dataset correlated to create Power BI and PI dashboards that effectively communicates operational and statistical data points through informative graphs and simplified tables, providing deep overview of the pipeline's operational condition and up-to date results from related datasets.
Successful Deployment of Ultra Smartwell Enable Maximum Reservoir Contact for Enhanced Production Recovery
Authors: Juvarajah Navindran , Mirza Omar T. , Nasser Reem , Saqib Talha , Keshtta Osama M. , Al Hajri Saaed Salem , Sabri Abdel Moez M. , Alhammadi Yousef A. 
Published: November 2024

Abstract
The focus of this paper is the effective implementation of an "ULTRA SMARTWELL", a smart completion system integrated with advanced remote sensing and monitoring technology, employed across a substantial long horizontal drain section. It encompasses the utilization of the longest intelligent completion design ever utilized in the UAE, extending 18,800 feet, from an offshore jack-up rig situated in Offshore Abu Dhabi, UAE. This approach optimized on achieving maximum reservoir contact, leading to enhanced production recovery
During the concept selection phase, a thorough engineering feasibility study was conducted. Traditional intelligent completions typically require drilling and completing various horizontal drains, increasing operational risks and costs. The innovative "ULTRA SMARTWELL" design calls for a single 8-1/2 in horizontal well and a non-cemented 7in liner with swell packers for zonal isolation and segmentation. This approach includes remote sensing and live monitoring to manage any water or gas breakthrough, greatly enhancing oil recovery. It also boasts a design that minimizes the need for interventions because surface-controlled downhole valves and gauges allow for remote well performance monitoring.
The paper will examine various procedures and difficulties encountered while implementing the completion string in the lengthy horizontal segment, following post-completion intervention. This innovative deployment method also achieved considerable capital expenditure savings by cutting approx.16 days from rig operations. Additionally, a notable increase in value was achieved with enhanced hydrocarbon recovery totaling up to ~4.67 million stock tank barrels (MMSTB), attributable to remote sensing and the capacity to manage high gas/oil ratios and water/gas entry, thereby prolonging the productive life of the well.