bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reporting and presentation of statistical analyses: instructions for authors of health sciences journals based in South Africa
Authors: Joubert Gina 
Published: February 2024

Background: Statistical analyses are a key component of quantitative research in health sciences.
Objectives: To review the instructions for authors on reporting and presentation of statistical methods by all health sciences journals based in South Africa.
Methods: Health sciences journals based in South Africa that publish original quanti-tative research articles were identified using three sources, namely the list of accred-ited South African journals compiled by the South African Department of Higher Education and Training in 2022, relevant journals covered in Scopus, and web pages of major health sciences publishers in South Africa. The list was cross-checked against the listing of journals in Sabinet, an online database covering South Africa, under the category &lsquo;Collection: Medicine and Health&rsquo;. The instructions for authors given by the journals were accessed through their websites. The form for recording data was based on items listed in the &lsquo;Statistical Analyses and Methods in the Published Literature&rsquo; (SAMPL) guidelines.
Results: All except one of the 52 journals could be located online. Of the 51, 13 (25%) made no mention of statistics in their instructions, and 11 (22%) made only a gen-eral statement regarding statistical content with no further guidance. The statistical item most frequently mentioned was the P value (45% of journals), whereas the rest of the items appeared in the instructions of 20% or fewer journals. Nine journals (18%) referred to the EQUATOR guidelines, mainly CONSORT (10%).
Conclusion: Nearly half of the health sciences journals based in South Africa either did not mention statistics at all in their instructions for authors or made only a cur-sory reference to statistics. The study thus emphasizes that these journals, in their instructions for authors, need to cover in greater detail the reporting and presenta-tion of statistical methods in articles reporting quantitative research.
Vibroacoustic Technology for Real Time Leak Detection in Marine Terminals and Tank Farms
Authors: Gomes A. P. , Marino M. , Cesari S. 
Published: February 2024

Abstract
The objective of this paper is to explore and evaluate the effectiveness of Vibroacoustic Technology as a robust asset integrity monitoring system for marine terminals and interconnecting pipelines in tank farms. Through analysis of test campaigns data, this paper aims to provide insights into the capabilities and potential applications of Vibroacoustic Technology in enhancing the safety and integrity of Oil&Gas facilities.
Vibroacoustic Technology is a resilient detection system utilized in pipeline networks, onshore and offshore, to identify leakages, impacts, and other forms of third-party interferences (TPI). By employing specialized sensors strategically positioned along the pipeline at regular intervals, this technology is capable of detecting vibroacoustic waves generated by such activities as they travel along the pipeline shell and through the transported fluid. In addition to detection capabilities, the Vibroacoustic System is also equipped to accurately determine the location of the identified events in real time.
After the installation of vibroacoustic sensors in two prominent refineries located in Italy, comprehensive test campaigns were carried out to simulate real events that could potentially jeopardize the integrity of the assets, e.g., spillage of different dimensions. The test campaign results allowed not only a performance assessment of the detection system but also its response time. Following the collection of data over a period of approximately one month, the system was calibrated and officially deployed. The pipeline networks at those two Italian facilities are currently monitored utilizing the Vibroacoustic Technology.
Since the release of the Vibroacoustic Technology, extensive research and testing have been conducted on its application worldwide, yielding outstanding outcomes. In this paper we present the results of the test campaigns conducted on pipeline networks of marine terminals/tank farm facilities, to determine the system’s capability to detect various activities that pose potential threats to pipeline integrity, such as excavation, impacts, landslides, and construction work.
Vibroacoustic Technology is a reliable detection system designed to meet the demands of complex pipeline operations. By strategically placing sensors along the pipeline, it can detect even small leakages caused by corrosion and other anomalies in real time. Real time monitoring of pipeline integrity helps prevent severe environmental contaminations associated with leakages, making the system indispensable in ensuring the safety and efficiency of pipeline networks.
Selection of Thru Tubing Screen for Sustained Sand Control Beyond a Year - Methodology and Optimization
Authors: Tyagi V. , Hilmy J. , Gutleber S. 
Published: February 2024

Abstract
Sand production can cause significant damage to well and facilities, such as erosion of flowlines, choke valves, filling up of downstream equipment causing loss of production. This poses a significant threat to the integrity of the surface flowlines and facilities and eventually can lead to Loss of Containment (LOC), which must be avoided. In Shell, sand prediction and management is a mandated Design Engineering Practice (DEP) that must be carried out as part of the life cycle well design [1].
The well that is subject of this study was designed with an internal cased hole gravel pack to avoid sand production to surface. However, the gravel pack system failed pre-maturely. Lessons learnt from the failure include review of the operating envelope to include the onset of the water production and increase in gas-oil ratio (GOR), improved open-up procedures and surveillance. Further, to safely recover production from the well with minimal risk of LOC, a thru-tubing screen solution was selected, which was designed according to specific well conditions to retain sand downhole.
The selected screen dimensions, number of screen joints, deployment methodology, operating envelope, etc., will be discussed in this paper. This paper provides a standard approach for remedial thru-tubing sand control.
The success and longevity of the thru-tubing screen solution depends on understanding the maximum allowable impact velocity, base pipe velocity etc. so that the right screen OD is selected. Open-up procedures and surveillance are the key to prevent sand related erosion. This will be further detailed in this paper.
Co2 Absorption Inside the Wellbore for Oil Wells
Authors: AlAklubi S. A. 
Published: February 2024

Abstract
The concepts and design precautions for a proposed in-situ electricity generation project including the main goal which is related to reducing the environmental pollution due to the combustion of fossil fuels and emitting carbon dioxide (CO2). This reduction will be attained through a smart gas well design and completion. The design is based on in-situ combustion for a gas flow in a downhole combustion chamber. Oxy-fuel combustion technique is the proposed combustion technique due to the ease of CO2 separation in this process as shown in figure 1. The proper well design will be analogous to the wells used for in-situ oil combustion to handle the high released temperature. Power generation design will combine the fundamentals of geothermal energy deployment for electricity generation. Finally, the produced CO2 from the combustion process will be reinjected downhole into an underground geological structure after being compressed and transferred to the supercritical phase. This process eliminates the CO2 production to the surface and hence reduce the environmental pollution.
Enabling Sand Detection Using Multiphase Flow Meters by a Cloud-Based Digital System
Authors: Pisarev G , Bridge C , Lupeau A 
Published: February 2024

Abstract
Detecting the onset and production of sand and solids from a well is considered of critical value for the safe and economically effective operation of any oil and gas field. Produced sand may cause disruption in the production and/or damage to equipment with severe negative consequences. A key element of production optimization is the ability to determine the maximum sand-free production rate with a high degree of confidence. The reliability of acoustic sand detectors is normally sensitive to various factors, including blind spots due to acoustic interference from, for example, nearby valve actuation, remotely operated vehicle activities, and low-velocity/transient flow regimes. Using a multiphase flowmeter to detect and measure sand and solids in the production stream has been studied for over 10 years. Our study advances the application of multiphase flowmeters to sand detection by adding cloud-based monitoring and quantification algorithms.
Examination of the radioactive source, which is the core of multiphase flowmeter technology, demonstrated that it is difficult to distinguish between sand and water at the expected range of process conditions with a reasonable confidence level in real time. To obtain sand measurements using a multiphase flowmeter, the water content of the fluid must be known and further processing steps developed to reprocess the data and identify sand.
A cloud-based digital condition monitoring system enables real-time collection, storage, and processing of the data obtained from the field, which unlocks additional features that are not possible with a real-time in situ computer. Algorithms for evaluating and differentiating the effect of sand presence and water content fluctuations were developed and tested. Quantification algorithms were created and verified during flow loop testing.
The solution is currently implemented on multiple subsea projects where multiphase flowmeter units have been installed. The multiphase flowmeters are now being used to detect and measure the production of sand and solids in subsea oil and gas wells. Accuracy of the solution is demonstrated by comparing acoustic sand detection sand volumes received at the surface with the output from the cloud sand detection algorithms.
Use of multiphase flowmeter data with a cloud-based monitoring system for sand detection is a reliable solution that reuses available infrastructure without retrofitting additional equipment. This is a critical development in digital technology demonstrating how smart oil fields are becoming a reality and being used today.
Successful Installation Polymer Screen as Primary Sand Control in Onshore and First Stackable System in Offshore Field, East Kalimantan, Indonesia
Authors: Mahardhini A. , Muhammad F. A. , Warno _ , Yahya W. , Pratomo S. A. , Adinda P. , Atmanindar F. C. , Soeparmono M. R. 
Published: February 2024

Abstract
Oil and Gas development in East Kalimantan has been going more than 100 years on offshore and onshore. Most hydrocarbon bearing lies in Balikpapan Formation. Reservoirs penetrated in this area are predominantly deltaic sandstone spread from deep to shallow zone. As for the shallow zone, sand production become one of the big challenges, especially in Sepinggan and Mutiara Field. Sandstone is typically not well sorted and its grain size is heterogeneous. Those aspects resulting standard screen is not an ideal solution.
Standard through tubing stand-alone screen (SAS) will allow sand pass through perforation tunnel and create natural sand pack behind the screen in a well with limited rathole. SAS durability is also limited due to high erosion rate of the sand. In this particular case, screen material technology becomes another challenge. Sand criteria has to be homogeneous to create perfect natural sand pack. Resin based sand consolidation (chemical sand control) might become an option, as it works for heterogeneous sand, but limited to maximum 16 ft interval based on several field applications in East Kalimantan. Case in Offshore Sepinggan Field; with two open intervals, 3ft and 24ft length, which both produces massive sand that proved by 3,000 ft sand deposit at bottom tubing, required sand clean out prior sand control installation. Sand cleanout is challenging due to losses, therefore non-damaging loss circulation material is utilized to cure the losses. Plugged SAS case happened in Onshore Mutiara Field; it is 6 ft perforation interval with a 125-micron SAS installed across the zone. Choke management was done to manage the drawdown before the well was ceased flow due to sand pack behind the screen, which later is proven by well intervention operation.
OCMP (Open Cell Matrix Polymer) screen was chosen to solve sand production issue. Polymer material is designed to be able to expand in the wellbore and packed the sand behind the wellbore. OCMP is not only creating a very effective screen for heterogeneous sand grain but also by mimics proppant pack on gravel pack system and block the sand grain migration into the wellbore. Screen maximum length will be the challenge, as conveyance method and limitation of base pipe size to be considered. However, the screen could be stacked to cover longer perforation interval. Stackable system has never been applied before; this becomes the first successful installation in the world.
This OCMP screen application is successfully improve sand free production rate for both Sepinggan field with 1,253 blpd production and Mutiara Field with 256 blpd. These cases will lead into more installation in the future and became a game changer in sand control for non-homogeneous formation sand.
Isothermal Adsorption of CO2 in Shale as a Caprock at Different TOC
Authors: Izman Izzulsyahmi , Mohshim Dzeti Farhah 
Published: February 2024

Abstract
Carbon dioxide (CO2) emissions are a significant contributor to global carbon and the resulting greenhouse effect. Reducing CO2 emissions, and even achieving carbon neutrality, has become a primary goal of environmental conservation worldwide. Carbon capture and storage (CCS) is a potential solution for reducing CO2 emissions by injecting captured CO2 into formations, such as shale. While shale formations have excellent sealing characteristics, CO2 diffusion into shale can limit the retention and maintenance of injected CO2. Understanding the adsorption behavior of CO2 in shale at different levels of total organic content (TOC) is therefore crucial. This study used a gravimetric approach to quantify the adsorption isotherm of CO2 in Eagle Ford shale sample with TOC value of 2.70 wt% using Magnetic Suspension Balance (MSB) at pressure up to 1.5 MPa and temperature at 25°C with another samples from literature review which from Silurian Longmaxi shale and Ordovician Wufeng shale. The results showed that LMX 1, sample from Silurian Longmaxi shale, which had the highest TOC content (3.04 wt.%), had the highest adsorption capacity for CO2. The Freundlich model was found to be the most accurate in describing the adsorption behavior with an R2 of 0.99 and an ARE (%) of less than 2%. This study highlights the importance of modelling the TOC of shale with adsorption isotherms to determine adsorption properties, especially for predicting the adsorption capacity of organic matter.
Geological Controls on Distribution of CO2 Off the Coast of Sarawak, Offshore Malaysia: Understandings from Regional Study and Petroleum System Modeling
Authors: Masoudi Rahim , Nayak Satyabrata , Panting Alexander Tarang Patrick , Hoesni Jamaal , Tiranda Herwin , Samsuri Muhammad Nazam B , Diah M Amri B M 
Published: February 2024

Significantly higher concentrations of carbon dioxide (CO2) have been systematically documented within multiple hydrocarbon fields situated offshore Sarawak, Malaysia. Several hydrocarbon findings in the highly prolific Sarawak offshore region are rendered economically unviable due to elevated levels of carbon dioxide (CO2). Numerous wells and fields within the Central Luconia and west Luconia province have registered substantial concentrations of CO2, exceeding 40% at maximum. Characterizing the distribution of CO2 in this region has been always challenging. To address this, an integrated investigation incorporating geological, geophysical, and geochemical datasets was conducted to elucidate the factors influencing the spatiotemporal variations in CO2 distribution within the region. Various geological factors controlling the genesis and spatial dispersion of CO2 in the investigated locale have been identified and deliberated.
Additionally, a comprehensive three-dimensional basin modeling analysis was carried out, concentrating on the processes of hydrocarbon and CO2 generation, migration, and accumulation. The primary aim of this study was to enhance our comprehension of the origins of CO2 and its prediction which will help in de risking prospects and monetizing stranded high contaminants fields. This novel method employing an integrated Geology and Geophysics (G&G) coupled with a model-based approach has been utilized to produce CO2 concentration and risk maps for the Sarawak Basin. This innovative model enables the inclusion of subsurface geological processes pivotal in the CO2 accumulation within traps. This approach presents a notable advantage compared to the conventional method of extrapolating observed data for generating CO2 concentration and risk maps, especially when predicting beyond the established control points.
The Nautilus Robotic Solution: A Single Robot that Integrates Inspection + Maintenance + Repair Capabilities for Subsea Pipelines and Tubulars
Authors: Carlsen C. , Nagadhana T. 
Published: February 2024

Abstract
The Pipeline Inspection, Maintenance and Repair robot, "Nautilus", can deliver full pipeline Inspection, Maintenance and Repair (IMR) service with less time, less resources, and less risk. Delivering all tasks in a single robot represents a major achievement, and a significant reduction in CO2 emissions since all the IMR activities are performed in a single trip of a vessel and with a single crew. By performing all repairs in a closed habitat, all debris from the repair is brought back to the surface for disposal.
In the Oil and Gas industry, subsea pipelines are the vital part of installed subsea infrastructures. As these pipelines age, they are subjected to different forms of degradation, including internal corrosion. In the worst cases, this degradation eventually leads to through-wall defects, leaks and production shutdown. Currently, underwater pipeline repairs are conducted by saturation divers to stop or prevent product leakage.
Nautilus is an integrated robot that can deliver full pipeline services for spot repair including Inspection, Repair and Maintenance. Subsea interventions can be performed with less time, resources and risks. Combining all the pipeline repair tasks into a single robot represents a major achievement for the industry. The Nautilus technology is capable to repair all pipeline diameters. The current robot covers all sizes from 8" – 20" in.
AI Driven Carbon Storage Well Connectivity - A Kemper CO2 Storage Analysis
Authors: Katterbauer Klemens , Qasim Abdulaziz , Al Shehri Abdallah , Yousef Ali 
Published: February 2024

Abstract
Carbon dioxide (CO2) from industrial process emissions is collected before it is discharged into the atmosphere and then stored in subterranean geologic formations in order to support sustainability goals. Carbon capture storage and utilization represents an important part of reducing carbon dioxide emissions into the atmosphere and maximize value generation. Carbon capture, utilization and storage is a useful instrument for combating CO2 reduction in the environment since it enables business to function while producing less greenhouse gases. But storage needs to be useful, economical, and safe. Both onshore and offshore regions may have storage formations, and each kind of geologic formation has advantages and disadvantages of its own. The placing of CO2 underground for safe long-term storage and encompasses the evaluation of a variety of factors to ensure the gas is effectively trapped. In general, a range of factors are to be taken into consideration in order to determine the favorable formations, such as saline formations, oil and natural gas reservoirs, impenetrable coal seams, organic-rich shales, and basalt formations. The Kemper CO2 storage Project, which is being built in Kemper County, Mississippi, is crucial to understand and acquire experience in how to effectively sequester CO2 and gaining expertise with managing carbon storage projects. It was first built by Mississippi Power, a division of Southern Company, and is alternatively referred to as Plant Ratcliffe or the Kemper County Energy Plant. The project’s objective was to incorporate CO2 sequestration to lower the volume of carbon emissions it generated. Kemper County was chosen as the plant’s location in order to use the region’s undeveloped brown coal potential and offer regional variety, which would assist to balance the state’s energy demand and produce energy. The paper describes a novel directed well connectivity method that makes use of similarity learning to determine well connection for carbon storage. When comparing the connectivity between the injectors and producers, similarity learning can help with connectivity determination for CCUS through categorization and grouping as well as by incorporating different to non-Euclidean metrics in order to assess similarity. In order to foresee prospective CO2 sequestration issues or take corrective action, similarity learning may also be used to detect abnormalities. The association between rising CO2 injection volumes and subsequently observed CO2 quantities in the characterization wells was confirmed by the results, which showed a high correlation between the injector and producer wells. For CCUS well location and sequestration optimization, the approach could serve as a valuable toolkit.