bluuebunny/crossref_metadata_2025_split huggingface dataset:
Improving Dental and Oral Health Through Empowering Village Youth to Enhance Awareness Regarding the Importance of Dentures
Authors: Prabowo Harly , Ariani Maretaningtias Dwi , Kurdi Abil , Rahmania Primanda Nur , Sona Nabila , Imani Aurellia Della , Indrarini Ratri , Wicaksono Haryo Adhiweno , Ryani Adelisa Devita 
Published: November 2024

Background: Dental and oral health, which is an inseparable part of general body health, is still widely ignored since adolescence. Maintaining the integrity of teeth is an important part of dental and oral health. Tooth loss can cause functional, aesthetic, and social problems, reduce a person's quality of life, and can be an effective indicator of community oral health. Purpose: Empowering and educating about dental and oral health for adolescents to increase their awareness of dental and oral health. Method: Dental and oral health counseling and dental health examinations were conducted on 50 adolescents, students of Madrasah Aliyah Miftahul Ulum, Melirang, Gresik. This study included quantitative and qualitative methods to assess changes in knowledge and perceptions about denture care among participants. The stages of implementation carried out in this study included pre-test, counseling, question and answer, post-test, dental and oral examination. Results: The examination results showed that out of 50 teenagers at MA Miftahul Ulum, Melirang, Gresik, 0 used dentures, 0 had caries + missing teeth, 0 had missing teeth, 3 had restorations, 5 had caries + remaining roots, 9 had remaining roots, 9 had caries, and 29 had no abnormalities. The results of the post-test questionnaire showed an increase in insight, compared to the pre-test. Conclusion: The conclusion of the activity showed that there was an increase in adolescents' knowledge and understanding of dental and oral health, as well as the importance of using dentures.
THE RELATIONSHIP BETWEEN FAMILY SUPPORT AND IDWG VALUES IN CKD PATIENTS UNDERGOING HEMODIALYSIS
Authors: Nurfarida Dian , Adiutama Novian Mahayu , Fauziah Wardah 
Published: November 2024

Introduction: Every month's regular menstrual cycle should ideally span 21-35 days. The menstrual cycle is influenced by several factors, namely stress levels and sleep quality. Menstrual cycle disorders indicate metabolic and endocrine system irregularities. The impact that often occurs due to menstrual cycle disorders is infertility and difficulty identifying the fertile period. The purpose of the study was to determine the relationship between stress levels and sleep quality with the menstrual cycle in seventh-semester nursing students at Universitas Muhammadiyah Lamongan. Methods: This research design uses correlation analytics with a cross-sectional approach using a simple random sampling technique with a sample of 111 respondents. Measured using the Depression Anxiety Stress Scale questionnaire sheet for stress levels and the Pittsburgh Sleep Quality Index questionnaire for sleep quality. After tabulating the data and analyzing it using the Spearmen Rank test. Results: This study showed that almost half of 45 female students (38.7%) experienced mild stress and more than half of the 60 female students (54.1%) had poor sleep quality. Conclusions: Based on the results of the analysis using the Spearmen rank test, the value of p = 0.000, where p <0.05 means that there is a relationship between stress levels and sleep quality with the menstrual cycle in nursing students in semester VII of Universitas Muhammadiyah Lamongan. Based on this research, it is expected that female students can reduce stress, get enough sleep 7-8 hours, diet, and control weight so that the menstrual cycle returns to normal.
MODERN METHODS OF QUANTITATIVE ASSESSMENT OF THE STRUCTURE OF HYDROCARBON RESOURCES OF LARGE PETROLEUM BASINS
Authors: Kontorovich A.E. , Livshits V.R. 
Published: November 2024

The article discusses modern methods of quantitative assessment of the elements of hydrocarbon resource structure in large oil and gas (petroleum) basins. The assessment is based on the law of mass distribution of hydrocarbon accumulations, i.e., the truncated Pareto distribution. The procedure developed is used for: estimation of the truncated Pareto distribution parameters and cumulative hydrocarbon volumes concentrated in pools, prediction of their number and size distribution and total resources within each size-class interval; simulation of spatial distributions of hydrocarbon accumulations with transformation of a population of HC pools into a population of fields; prediction of the number and size-class distribution of total HC resources in pools and fields, and fields distribution by the number of HC pools. The involved analytical approach based on the simulation mathematical modeling is described.
Multi-Stage Selective Completion and Acid Stimulation, Karachaganak Field, Kazakhstan
Authors: Naurzgaliyev Timur , Agambayev Timur 
Published: November 2024

Abstract
Karachaganak is a giant oil, gas and condensate field located in north-western Kazakhstan, operated by Karachaganak Petroleum Operating b.v. (KPO b.v.). Karachaganak was discovered in 1979 and the production began in 1984. The field comprises Permian and Carboniferous reservoirs with complex geological and fluid properties. The reservoir fluids consist of gas-condensate and oil with strong compositional gradients.
Since 1997, the focus of the field development has been on the oil rim with the objective of producing low GOR oil. This is being achieved by drilling sub-horizontal wells. The design of these wells is aimed at maximizing the reservoir contact to overcome the challenges of significant heterogeneity present in the field. It also allows to access to partially or fully isolated compartments associated with both reservoir heterogeneity and the presence of clinoforms formed during the evolution of Carboniferous platform.
Initially horizontal wells were completed open-hole. Since 2011 new horizontal wells start being completed with multi-stage stimulation completions (swelling packers and sliding sleeves). Previous attempts at analyzing the benefit of multi-stage stimulation were hampered by a small population size for meaningful statistics. Today, the number of wells completed with multi-stage completions with available data is over 50. It's now therefore possible to make firmer conclusions regarding the potential benefits of multi-stage completions.
Three specific areas of potential benefits of multi-stage completions over open holes have been identified and reviewed, these are as follows: Impact on well PI – Initial well PI (Deliverability);Flow Distribution – Percentage of wellbore contributing to flow (Enhanced sweep efficiency), andEase of well re-entry for rig-less operations – Data acquisition and remedial jobs.
The available data indicate that multi-stage stimulations improve well productivity, downhole flow profile and the number of zones that contribute to flow. In addition to these primary benefits, there is an improvement in the ability to intervene in wells for data gathering. Based on these findings, it can be concluded that multi-stage completions result in a net positive contribution.
New Reserves Classification in Kazakhstan. Will it Happen Now?
Authors: Mukanov A. R. , Jussupbekova A. 
Published: November 2024

Abstract
Nowadays, the President of Kazakhstan, Kassym-Zhomart Tokayev, has announced the term "New Kazakhstan", and changes are occurring in many areas as well as in the oil industry. As a result, the Ministry of Energy has timely raised necessary initiatives, and the reserves system is on that list. The issue was already a hot topic 7-8 years ago, but with no outcomes. This is the second attempt, and the time may come to implement it.
The SPE-PRMS is actively proposed as a model to which the whole concept should move. Several scenarios are discussed, and the main one is that the PRMS methodology should be applied as the reserves’ assessment tool without any modifications. Nevertheless, the reporting and approval processes will be subject to local regulations. The authors suggest that in place volumes should be incorporated into field development projects, which are then expertized by the Geology Committee at the first stage of FDP's approval process, while the reserves by the Central Committee of Exploration and Development at the second stage.
As a result, we expect to resolve several issues. First, incorporating the reserves into the FDP will dramatically shorten the procedure by eliminating the reserves report approval by the State Committee of Reserves, called GKZ, of the Geology Committee. Generally, in order to start commercial production, operators need to spend at least two years on reserves reports and FDP. Secondly, in most cases, the GKZ insists on overestimated recovery factors, which leads to overestimated FDP production and drilling scope forecasts. Thus, the whole picture does not reflect reality. On the contrary, the PRMS principles are fully based on commercially, not just technically, recoverable reserves. Thirdly, the shift to a new reserves system will allow Kazakhstan to be clear and transparent for the international petroleum community. All parties will talk in common language and understand each other. That will definitely contribute to the attractiveness of the Kazakhstani oil businesses for investors, as the oil-producing countries are competing in a fierce fight for investments. Indeed, this was a reason for the 74th step of the "100 Concrete Steps of the Nation Plan" initiated by the first president, Nursultan Nazarbayev.
A possible move to a new reserves system will have a profound impact on the industry. This includes stimulating the field works, having real figures and business plans for all parties, and integrating into global society to attract new players under the market conditions. However, it is a big question if the fixed mindset will change to the needs of the hour and if it happens now or needs another 7-8 years.
Water Wells Injectivity Enhancement via Hydraulic Fracturing in Open Hole Completions
Authors: Yudin A. , Eltaher E. , AlYaseen A. , Al-Jalal Z. , Faisal M. 
Published: November 2024

Abstract
In the field development stage, it is typical to use water injector wells to maintain reservoir pressure and maximize oil recovery factor. In many cases, these water injectors are drilled in the edge areas of the reservoir, often having reduced properties which leads to challenges in water injection. This study describes best recommended methodology for improving the injectivity in such wells through hydraulic fracturing, particularly in an open hole type of completions in carbonate rocks.
The study represents an integrated approach covering all aspects of well completion and stimulation with use of advanced simulation software. Medium permeability reservoir was considered as a target of the research with extended reach well candidates. Sensitivity analyses were done for the various types of completion and near wellbore zone status – damaged, non-damaged, stimulated with longitudinal fracture and stimulated with multiple transverse fractures. The injectivity index was calculated for each scenario based on a model which was calibrated with injection history match.
Both proppant and acid fracturing scenarios were modeled and described in detail within the study showcasing the advantages of multiple acid fracturing stages with transverse orientation. Considering open hole completion, a technique with dynamic diverters based on degradable multi-size particulates was shown to be an optimum in terms of operational efficiency and cost-effective solution to enhance injectivity. To ensure representative comparison, a fixed volume of acid was simulated in each scenario, irrelevant to the number of generated fractures. Thus, scenarios of lower number but larger size fractures were compared to a scenario of higher number but lower size of the fractures under essentially the fixed cost of well completion. Analysis have shown that increasing the number of fractures brings higher injectivity rates and more reliable connectivity of the open hole wellbore with the fractures aimed at bypassing the near wellbore damage. Overall, existing skin factor (positive 8) was calibrated based on history match leading to more than double reduction of injectivity index when compared to a non-damaged reservoir. When the open hole wellbore is stimulated with massive acid fracturing, the injectivity index is increased by a factor of 10 to 15 from base case or by a factor of 5 to 7 from zero skin scenario.
The study represents one of the few documented projects of large size fracturing in water injector wells completed with open holes. Innovative method introduced to maximize number of fractures via injecting degradable diverting pills for the enhanced operational efficiency. Comprehensive modeling approach including fracturing and injectivity sensitivity studies are described to serve as a useful tool to engineering society in the middle eastern countries.
Implementation of Smart Leak Detection and Repair Program at ADNOC Distribution's Oil Storage Facilities
Authors: Ali B. , Ali A. , Harbi M. 
Published: November 2024

Abstract
Fugitive emissions are hazardous for the health and safety of the site personnel, environment, and contribute to hydrocarbon product loss. Leak Detection and Repair (LDAR) Program is a best industry practice typically deployed to arrest fugitive emissions and develop a maintenance program for leaking components (Jeff Kuo, 2018). This paper discusses execution approach and results of a Smart Leak Detection and Repair (SLDAR) Program implemented by ADNOC Distribution at one of its oil storage terminals.
SLDAR Program was implemented in-line with ADNOC's vision of net-zero emissions and contributing to the global clean energy transition with the sole purpose of reducing fugitive emissions and subsequently reducing risks related to health and safety of personnel, environment, and production loss. SLDAR Program began with identifying all the Potential Leaking Sources (PLS) which included piping, valves, flange connections, etc. For the survey, Toxic Vapor Analyzer (TVA) was used for identification and quantification of accessible sources, and Optical Gas Imaging (OGI) camera was deployed for screening purposes and monitoring of inaccessible leaking sources. Leak definition was set as per US EPA guidelines and the leaks exceeding the threshold limit, as per leak definition, were marked on the field using physical tags. Maintenance was conducted for all major and moderate leaking components, and post• repair survey was carried out to confirm that the leaks have been arrested. All the PLS were recorded and captured in the Leak Register and the Component Integrity Management System (CIMS) to prepare SLDAR database for emission calculation purpose. Subsequently, all PLS were marked on Piping and Instrumentation Diagrams (P&IDs) and Process Flow Diagrams (PFDs) for future reference. Out of 21,318 PLS monitored, 0.1% PLS were found to be leaking of which 40.9% of leaking PLS were in major/moderate leak range and the remaining 59.1% were found to be in minor leak range. 1.31% of total PLS were Difficult-To-Monitor (DTM) due to location constraints and were only screened using OGI camera. All the PLS in major and moderate leak ranges were taken out of service for immediate maintenance and repair. A post-repair survey was carried out to confirm all the leaks have been arrested or brought below the leak threshold. The SLDAR survey and post-repair maintenance activities resulted in overall reduction of fugitive emissions by 24%.
This paper describes all the stages of SLDAR Program and its implementation and provides baseline results that can be used as reference for any oil storage terminal. The study covers identification of possible leaking sources, fixing/repairing the leaks, and computing fugitive emissions. Implementing SLDAR Program as described in this study will result in improving the health and safety of the personnel, lowering fugitive emissions, and reducing financial losses.
Micro Tubing Leak Investigation with High Resolution Detection Technology and Leak Remediation with Pressure Activated Sealant – A Case Study
Authors: Kantarbayev Azamat , Jumamukhambetov Tilek 
Published: November 2024

Abstract
The paper discusses a cost-effective approach involving the implementation of a high-resolution detecting technology to identify a micro-tubing leak and further remediation by applying a method of injecting a pressure activated sealant to eliminate the leak.
Well A in field Kashagan was completed using 5 ½″ in single-string cased hole completion intersecting carbonate zones. It produced up to 20,000 BPD (3180 M3/D) on self-drive starting from March 2017. The reservoir pressure is up to 780 bar (11,300 psi) and well fluid composition is with 16% H2S and 5% CO2 mol.
In July 2018, an increase in A-annulus pressure up to 3.6 bar/day was observed. The diagnosis suggested an issue with a downhole tubing section above the production packer indicating a need to identify the leak point and remediate the leak to bring the well online.
A detailed analysis of various techniques for bringing the well in production was conducted keeping in mind the associated cost and time for each method. After performing a detailed technical and economic analysis, the decision was made to perform the operation in two stages. The first stage is to identify the micro-leak with high resolution spectral noise logging tool, while the second stage is to rectify the leak with straddle pack or pressure activated sealant.
This operation is also considered to be a proactive approach in reducing emissions, as it limits the emission sources, and those parameters controlling the individual emissions; and finally obtaining knowledge of the economic impact. The operation in well A was successfully executed and the well integrity was regained allowing bringing the well back online in shortest time (minimal as compared to the workover operations, far safer and more cost-effective).
Fracture Characterization by Integrating Seismic-Derived Attributes with Production Well Data in an Offshore Super-Giant Carbonate Field, North Caspian Basin
Authors: Taubassova M. Zh. , Gabdullin A. M. 
Published: November 2024

Abstract
The research presents a case study of fracture characterization through the integration of well production data and a suite of interpreted seismic attributes from an offshore super-giant carbonate field in Kazakhstan. The goal of the study is to map the distribution and connectivity of the fracture network and subtle faults within the carbonate field's platform interior and rim areas to aid field development planning and to understand the existing well behavior and production performance.
The well data analyzed includes core descriptions (orientation and fracture types), image logs, and dynamic data (PTA, interference, and mud loss). Multiple 3D seismic attributes were calculated using two different seismic volumes, such as diffraction and least-squares – reverse time migration (LSRTM or LSR). Volume-based attributes (dip and azimuth, curvature, coherency, chaos, variance, structural smoothing, and ant-tracking) were calibrated against production data to create an optimal structural framework that describes the range of connectivity controls within the carbonate reservoir. Throughout the study, well recognized features, such as seismic scale natural fracture swarms were observed in both seismic volumes, and clearly identified using complex attributes. A qualitative correlation with the well data was also noted, where mud loss intervals are aligned with the position of the identified fracture networks.
This research has enhanced the understanding of how multiple seismic attributes can be used to characterize the fracture networks within the carbonate reservoir. Additionally, it could assist future well placement strategies, potentially reducing the number of connected development wells and resulting in significant cost savings for the project.
Best Practice Case to Improve Oil Recovery: Revisit of the Largest Oilfield in China
Authors: Lu X. G. , Sun S. Q. , Xu J. H. 
Published: November 2024

Abstract
Placed onstream in 1960, as the largest oilfield in China and possessing the largest chemical flood project in the world, the Lamadian-Saertu-Xingshugang (La-Sa-Xing) Field has produced more than 16,570 MMBO with a water-cut &gt;95%. This paper reviews its improved oil recovery journey and key reservoir management practices at extra-high water-cut stage, and summarizes its successful experiences and lessons learned.
This paper begins with an introduction of the main reservoir characteristics and its heterogeneity. Then, the authors illustrate field production history. Next, we expound key IOR/EOR practices, e.g., three rounds of infill drilling, field-wide polymer flood and surfactant flood applications, optimized redevelopment strategy and effective reservoir management effort at extra-high water-cut stage, which have successfully mitigated the decline trend and further increased recovery. Finally, the main understanding and lessons learned are discussed.
The multi-layered sandstone reservoir in the field consists of &gt;100 flow units with three types of reservoir sand identified, i.e., higher permeability Type I Sand, medium permeability Type II Sand and lower permeability Type III Sand. The field was initially developed by waterflood through commingled production. The first- and second-round infill drilling increased recovery by 13.1% and 3.2%, respectively. Polymer flood started in 1996, achieving an incremental recovery of 12% STOIIP. Industry-scale ASP flood application increased recovery by 20%. Field production maintained its plateau at approximately one million BOPD for 24 years. Since 2005, when water-cut exceeded 90%, a series of redevelopment activities have been implemented. These techniques include subdivision of individual injection-production interval and reduction of well spacing, realignment of injection pattern, improved zonal injection, thick pay channeling control, development of marginal Type III Sand followed by chemical flood utilizing the same wellbores and so on. Early start of water injection, pilot study before implementation of key IORs/EORs, deliberate reservoir and remaining oil characterization, progressive infill drilling, fit-for-purpose water injection optimization and successful chemical flood increased the recovery factor from 34% to 55%.
Early water injection strategy maintaining reservoir pressure at largely the initial level, sustained water injection optimization, step-out infill drilling, field-wide chemical flood, and effective reservoir management practices to improve sweeping efficiency, all proved to be effective for the strongly heterogeneous sandstone reservoir with weak natural drive energy. It provides a road map for improved oil recovery of reservoirs with similar characteristics.