bluuebunny/crossref_metadata_2025_split huggingface dataset:
Comparative evaluation of facial divine proportions in males and females with average growth pattern
Authors: Sharma Monika , Verma Sneh Lata , Khanna Rohit , Srivastava Kamna , Tikku Tripti , Maurya Rana Pratap 
Published: September 2024

Facial beauty of an individual depends on proportion and its relationship to various facial parts which varies in each individual. The values of measured proportion in beautiful faces are likely to approximate divine proportion and may show variation with ethinicity, sex, growth pattern. Hence, aim of the study was to evaluate and compare vertical and horizontal parameters of facial divine proportions in male and female subjects with average growth pattern. 30 subjects (18-30 yrs age) with average growth pattern (based on cephalometric measurements FMA, Yaxis, GoGn-SN and facial axis angle) were divided into two groups as Group I (Male subjects, n=15) ; Group II (female subjects, n=15). Standardized frontal facial photographs of all the subjects were obtained. Nine vertical and four horizontal parameters were measured on all the facial photographs using IC Measure software and were used to evaluate horizontal and vertical facial proportions and then compared to divine proportions considering 1.618 as 100%. Horizontal and Vertical facial proportion in males were higher than females. Group I showed that three of seven vertical facial proportions were close to divine proportion (1.618) whereas only one vertical facial proportion in Group II were close to divine proportions. Horizontal facial proportions in both the groups deviated more from divine proportion (1.618).There was difference between males and females for the vertical and horizontal facial proportions with values being larger in males. This should be considered as an accessory guideline in planning orthodontic or orthognathic treatment.
Análise comparativa da sustentabilidade de agroecossistemas familiares em transição agroecológica e convencionais (Canutama/Amazonas)
Authors: Nunes dos Santos Jéssica Cristian , Da Costa Francimara Souza , Rebêlo George Henrique 
Published: September 2024

O presente artigo operacionaliza-se sobre o termo sustentabilidade, objetivando avaliar a sustentabilidade dos agroecossistemas do Projeto de Assentamento São Francisco, no sul do município de Canutama, Amazonas, comparando as atividades realizadas entre aqueles que estão em transição agroecológica e os que utilizam práticas do sistema convencional. O estudo foi conduzido em 16 agroecossistemas familiares, analisando a sustentabilidade por meio do método IDEA, a partir do comparativo entre as dimensões agroecológica, socioterritorial e econômica, considerando sistemas de produção agrícola convencional e em transição agroecológica. Encontrou-se níveis aproximados na sustentabilidade dos dois grupos. A dimensão agroecológica obteve os maiores percentuais nos dois grupos, enquanto a dimensão socioterritorial foi o fator limitante nos dois sistemas de produção. Observou-se que a ideia de sustentabilidade precisa ser ampliada entre os assentados e o método utilizado precisa de adaptações para aplicação em condições amazônicas.
Nadlatul Ulama (NU) 1999-2021 M Di Kecamatan Muara Sugihan, Kabupaten Banyuasin, Sumatera Selatan
Authors: Irfan Kurniawan  
Published: September 2024

Penelitian ini menjelaskan mengenai proses masuk serta berkembangnya Organisasi NU di Kecamatan Muara Sugihan Kabupaten Banyuasin Provinsi Sumatera Selatan. Penelitian ini menggunakan data kualitatif. Kerangka berpikir dilakukan untuk memberikan penjelasan mengenai objek dari pokok permasalahan agar lebih rinci, pokok permasalahan yang pertama: bagaimana kondisi umum di Muara Sugihan pada saat masuknya organisasi NU. Kedua, bagaimana perkembangan NU di Muara Sugihan pada tahun 1999-2021. Penelitian ini mengunakan teori perkembangan serta menggunakan metodologi penelitian sejarah dengan empat tahapan yakni: heuristic, Verifikasi, interpretasi, dan historiografi. Sumber data yang digunakan yakni pertama, wawancara yang dilakukan dengan ketua PCNU Muara Sugihan dan Tanfidiyah NU. Sementara dari data sekunder adalah buku-buku, jurnal, dan artikel yang berkenaan dengan penelitian ini.
Effects of Land Use Change on Land Erosion and Land Critical Level Using GIS in the Mayang Watershed
Authors: Rafif Mohamad Andhika , Widiarti Wiwik Yunarni , Hidayah Entin , Saifurridzal Saifurridzal , Ma'ruf Mokhammad Farid 
Published: September 2024

The increasing population in an area often triggers heightened development, leading to diminished land availability and subsequent land conversion. This transformation, predominantly observed in agricultural and plantation lands, is driven by the need for residential areas. However, continuous land use changes contribute to erosion, a natural process wherein soil is transported, leading to sedimentation and eventual flooding. This study aims to identify critical areas prone to erosion and land degradation. To address this, we used the Universal Soil Loss Equation (USLE) method for erosion prediction, leveraging its simplicity and accuracy. This study focuses on the Mayang watershed in East Java, utilizing a combination of USLE, spectral index modeling, and Geographic Information System (GIS) techniques to estimate soil erosion and land criticality. By integrating methodologies and analyzing data spanning from 2011 to 2021, the study reveals shifts in erosion danger levels and land use patterns. While regions with low erosion remained stable, areas with medium to high erosion declined, yet those with very high erosion exhibited a worrisome increase. Changes in land use, including forest loss and urban expansion, underscore the ecological shifts exacerbating erosion hazards. The study emphasizing the necessity for targeted conservation strategies and comprehensive land management plans to mitigate erosion risks and preserve environmental sustainability.
OPTIMASI PERTUMBUHAN PLANLET ANGGREK Dendrobium gabriella suryajaya MENGGUNAKAN MEDIA ALTERNATIF AB MIX DAN AIR KELAPA SECARA IN VITRO
Authors: Dewanti Parawita 
Published: September 2024

Tanaman anggrek merupakan salah satu tanaman yang sulit melakukan perkembangbiakan secara generatif, termasuk anggrek Dendrobium gabriella suryajaya sehingga diperlukan suatu cara agar tanaman anggrek dapat berkembang biak dalam waktu yang cepat dan terhindar dari patogen. Salah satu cara yang dapat dilakukan adalah dengan teknik kultur jaringan atau In Vitro dengan penambahan suplemen organik yaitu air kelapa sebagai Zat Pengatur Tumbuh (ZPT). Secara umum, teknik kultur in vitro menggunakan bahan kimia untuk media kultur dan ZPT. Oleh karena itu, penggunaan media alternatif dan suplemen organik air kelapa diperlukan dalam penelitian ini untuk mengurangi pengggunaan bahan kimia. Penelitian ini bertujuan untuk mengetahui pengaruh air kelapa dan media alternatif AB Mix terbaik, serta interaksi keduanya terhadap pertumbuhan planlet anggrek Dendrobium gabriella suryajaya. Penelitian menggunakan metode Rancangan Acak Lengkap (RAL) secara faktorial dengan dua faktor perlakuan yaitu konsentrasi media kultur AB Mix dan konsentrasi ZPT air kelapa, di mana masing-masing faktor terdiri dari 3 taraf. Variabel yang diamati meliputi jumlah tunas, tinggi tunas, waktu pembentukan tunas, jumlah helai daun, jumlah akar, tinggi planlet, persentase planlet hidup, warna daun. Analisis data menggunakan Analysis of Variance (ANOVA) dan apabila hasil analisis berbeda nyata maka akan dilakukan uji lanjut DMRT dengan. Konsentrasi AB Mix terbaik adalah M3 (AB Mix 1500 ppm) yaitu pada jumlah tunas sebanyak 2, tinggi tunas sebesar 1,38, jumlah akar sebanyak 15, jumlah helai daun sebanyak 7, tinggi tanaman senilai 2,59 cm, dan jumlah Planlet hidup dengan persentase 100%. Serta Konsentrasi air kelapa terbaik adalah K4 (Air Kelapa 30%) yaitu pada tinggi planlet senilai 2,99 dan presentase planlet hidup sebesar 100%.
First Installation of Hydraulic Jet Pump for High Viscous Oil in Shaikan Oil Field with Significant Concentration of Hydrogen Sulfide
Authors: Rehman Abid ur , Abdebary Marwan , Alzayat Amer , Quintero Jose 
Published: September 2024

Abstract
A significant productivity loss occurs when the pressure in an oil reservoir is depleted to the point where the wells no longer flow. Post-pandemic COVID-19, operators worldwide are looking for an increase in production from the existing wells so that the cost of drilling new wells is minimized. Some means of an artificial lift must be adapted to efficiently bring the well fluid to the surface.
For this application, a highly viscous crude oil (17.5 API) but inactive well with no natural production was selected as a candidate well and the data from the customer was utilized to construct a Jet Evaluation and Modeling Software (JEMS) model. A reverse circulation jet pump with a 12B combination was installed in the sliding sleeve door (SSD) at a depth of 5,250 ft using a slickline. The production performance was achieved by injecting the power fluid into the annulus via a jet pump to generate the required drawdown and to lift the reservoir fluid through tubing to the surface. The monitoring of the production rate was performed based on the surface pumping parameters.
Initially, the injection pressure and injection rates were kept low to gently offload the well. The flow behavior was further optimized at an increased pumping rate where the effect of injection pressure and the flow rate (1,700 psi and 2,350 barrels per day) was adjusted to optimize the production performance. The production enhancement of approximately 1,400 barrels per day (BPD) was noticed when the injection pressure was set at 1,700 psi. The production was routinely monitored in the customer facility for investigating the jet pump performance evaluation and further fine-tuning of surface parameters. The setup was further extended to safely handle 120,000 ppm of Hydrogen Sulfide and would be flared in case of any emergency release.
This paper will discuss in detail the operation which generated 1,400 BPD additional production for the operator from a heavy oil well, which was previously inactive, with exceptionally lesser operational costs. This was the first jet pump installation for this operator, and the project's success significantly increased their production and revenue. The pump has been producing for the last thirty six months without any maintenance being done to the pump, which significantly reduces the cost of the operation. The operator considers the application of this technology to be a success and will consider installation in more wells in the future.
Proxy Equation Using Data Analysis for Benchmark Recovery Factor Estimation in Gas Cap Reservoir
Authors: Sinha Ankaj Kumar , Jalan Shlok , Ranjan Rakesh 
Published: September 2024

Abstract
Reservoir Performance Benchmarking (RPB) is a proprietary tool developed by PETRONAS for Malaysian Oil reservoirs which uses a combination of analytical equations and data driven approach to compute Reservoir Complexity Index and Benchmark Recovery Factor. Reservoir benchmarking tool considers water injection in an oil reservoir to evaluate potential recovery factor based on data analytics algorithm which has been calibrated to good performing oil reservoirs of Malaysia. However, for reservoirs with gas cap, the benchmark recovery factor has been observed to be overestimated. This necessitated requirement of a correction factor to be included in tool algorithm for benchmark recovery estimation in oil reservoirs with a gas cap.
For reservoirs having current pressure below original bubble point, correction factor is being applied for opportunity validation to account for changes in fluid PVT properties (SPE-202459). For gas-cap reservoirs, an additional correction factor needs to be computed to account for reduction in recovery factor due to presence of gas-cap. This paper describes the methodology for computation of correction factor for gas-cap reservoirs which involves three key steps. Step-1 focuses on selection of key reservoir parameters which may impact oil recovery under water flood mechanism in gas cap reservoirs. Step-2 outlines generation of test experiments with a range of values of identified reservoir parameters that can be used as a sample database of results. Step-3 defines a proxy equation using reservoir parameters and obtaining a good match to actual test results for correlation validation. With these three steps, a correlation has been developed for estimation of correction factor.
This paper illustrates the methodology of computing this correction factor through application of simple simulation models for test experiments and generation of proxy equations using data analysis tools of python and numerical simulation applications. The paper also outlines the impact of this correction to opportunity volumes identified through benchmarking tool in Malaysian reservoirs.
Although the methodology has been developed for correction to benchmark recovery factor, it can also be applied to other oil reservoirs as well. In addition, this correlation also provides a quick assessment of recovery factor for water flood application in a gas cap reservoir.
Exceeding the Limits by an Integrated Workflow to Optimize Hydraulic Fracturing Treatments to Achieve Highest Sustained Oil Production Rate in Tight Carbonate Mauddud Reservoir, East Kuwait
Authors: AlRagheeb S. , AlNaqi A. , AlZaabi R. , Jalan S. , AlAjmi S. , Naik V. , AlMazeedi H. , Hassan H. , AlKandari Y. , Behbehani H. , Ali A. , AlAli B. , AlMukaizeem K. , Kamal A. , Salem A. , Peiwu L. , Elsebaee M. , Zacharia J. , Ayyad H. 
Published: September 2024

Abstract
Mauddud reservoir in Greater Burgan field is a thin, tight carbonate cretaceous reservoir. Sustaining the production has been always a challenge for the past few decades. Objective of this paper is to share the knowledge of a new innovative and integrated workflow which allowed to achieve the highest and the most sustainable production in the history of the reservoir.
An integrated production enhancement study has broken the field historical production record for the tight Mauddud in East Kuwait. The integrated workflow and analysis among petrophysics, reservoir, well integrity, geology, and production and stimulation domains has proven success to achieve the best results for such a challenging reservoir. By running data gap analysis and identifying the right candidates through advanced characterization cased hole technologies like advanced cased hole Sonic log to map nearby open fractures and stresses magnitude and direction, acid fracturing treatments were designed and optimized accordingly utilizing a fit-for-purpose treatment fluid and diverter.
Most of the wells perforated across Mauddud were originally completed for deeper reservoirs and are only transferred to Mauddud post sweeping out the deeper reservoirs. Therefore, the well placement, completion, trajectory, and logs are not optimized for the tight Mauddud reservoir since it was not the primary objective of drilling the well.
Earlier multiple approaches were conducted utilizing different techniques such as matrix acidizing treatments, radial drilling, fishbone completion and many more to recover oil from this tight Mauddud reservoir. However, the results were unsustainable, and the wells ceased to flow in less than a month.
In the new process, across 6 existing wells, oil production increased from nearly zero to over 6,000 BOPD after multiple victorious hydraulic fracturing treatments accurately engineered based on the cased hole evaluation study and results. Advanced cased hole Sonic log utilized for generating 1D geo-mechanical properties, and core lab data and analysis used for designing the optimum frac recipe.
This paper demonstrates the capability of advanced technologies coupled with unique multi-domain integration to unlock the potential of complex tight carbonate and heterogenous reservoirs.
Innovative Methods for Drilling Extended Reach Wells in Challenging Reservoirs
Authors: Hashmi Muhammad Asef 
Published: September 2024

ERD (Extended Reach Drilling) and MRC (Maximum Reservoir Contact) wells are classified by the ratio of measured depth (MD) to true vertical depth (TVD). Wells with a ratio above 2 are defined as ERD wells, and those with a horizontal hole length exceeding about 8,000 to 9,000 feet are considered MRC wells. Various factors drive the need for such well designs, including surface locations, geopolitical situations, environmental impact, and government-defined sensitive areas.
The subject well qualifies as both ERD and MRC, with a measured depth of 37,600 feet (MD) and a true vertical depth of 8,979 feet (TVD), resulting in an ERD ratio of 4.188. Horizontal wells offer a better productivity index than vertical or deviated wells but designing and planning these wells present significant challenges. It is crucial to balance reservoir exposure and well profile to maximize productivity. The primary advantage of drilling an EMRC (Extended Maximum Reservoir Contact) well is placing it in the most productive part of the reservoir, especially in thin oil reservoirs with gas caps. However, real-time geo-steering requires numerous reactive adjustments to manage drilling and subsurface requirements, which can sometimes limit accessibility for post-drilling activities and reduce rigless options. The subject well was planned with a limited entry liner, necessitating careful planning to ensure well accessibility for lower completion.
Mitigation was best achieved by visualizing and simulating subsurface geometry and making proactive, smooth alterations rather than aggressively geo-steering the well in search of the oil-water contact (OWC). Planning this extensive ERD well involved directional planning, bit and BHA design, hole cleaning calculations, directional control points/formation markers, and mud design.
Application of Autonomous Inflow Control Valve Technology for Ultralight Oil in a Mature Field in Malaysia
Authors: Ng N. , Siew C. , Nasir H. , Rahman R. , Ali A. , Deris N. Mat , Zulhairi S. B. , Samah F. Abu , Hillis F. , Ismail I. Mohd , Bandara Y. 
Published: September 2024

Abstract
Kinabalu field is a mature field which has been in production since 1998 and faces significant challenges with excessive gas and water production issues. The presence of a large gas cap and moderate aquifer strength in this reservoir results in early water and gas breakthroughs which reduced the oil production and recovery due to poor influx distribution along the wellbore.
Due to the unique feature of the Autonomous Inflow Control Valve (AICV) which operates autonomously in ultra-light oil, two Kinabalu wells were completed with AICV joints and annular isolation packers for compartmentalization of production intervals. AICV technology is based on the difference in the pressure drop in a laminar flow element (LFE) compared to a turbulent flow element (TFE) and has the capability to shut-off the main flow autonomously when an unwanted fluid such as water or gas breakthrough occurs.
This paper presents the key design aspects for designing the AICV application including reservoir characterization, flow modeling, and selection of appropriate valve configurations. Besides, the comparison between pre and post AICV application will also be discussed and explained.
In the first part, the calibrated subsurface simulation was used to model the fluid flow to determine the most optimum AICV installation. It involves the understanding of how to distribute the AICVs and isolation packers within the horizontal well section. It is crucial to ensure the balance between pressure drawdown and maximum fluid flow for each compartment designed.
Next, the design was re-optimized once the post drilling logs were available. The actual permeability and saturation logs were analyzed and used as the key input. In this case study, the packers were placed in the low permeability zones to maximize the effect of zonal isolation. Besides, additional packers were also being installed at the heel of the high permeability zone to control the unwanted gas breakthrough.
The post-installation performance evaluation showed that AICV managed to choke back gas. The updated post drilling subsurface model was discussed to predict the performance of AICV installed. The paper shed some light on the actual field experience and interesting lessons learned to be considered for AICV application for very thin prolific oil sand.
Optimisation of the Smart Plunger Lift Work System and a New Method for Diagnosing Working Conditions
Authors: Xing Zhisheng , Han Guoqing , Cao Guangqiang , Yang Zhenhua , Chen Huapeng , Liang Xingyuan 
Published: September 2024

Abstract
Liquid loading in natural gas wells is a widespread problem worldwide. The plunger lift is one of the most effective methods for deliquification. The smart plunger, as a novel technology, is equipped with sensors at the plunger bottom to monitor pressure and temperature at each production stage. In recent years, numerous scholars have proposed optimization methods for plunger lift work system. However, most of these methods rely on theoretical calculations and fail to consider actual reservoir conditions, resulting in significant discrepancies between calculated outcomes and real-world observations. Also, the working condition of the plunger lift is monitored by changes in tubing and casing pressure, which cannot diagnose complex situations such as wellbore waxing and blockages. In this study, a judgment diagram referring to working condition is established using real-time data from wellhead tubing and casing pressure, and an optimization method for the smart plunger work system is proposed based on the dynamic prediction of reservoir conditions. This approach combines theoretical calculations with field data and uses real-time measurements, adjusting the theoretical calculations to get more accurate dynamic reservoir predictions than traditional optimization methods for plunger lift. Additionally, the smart plunger can automatically adjust the work system through programming. Moreover, based on the sensor data of the smart plunger, a plunger position versus pressure "Dynamometer card" has been proposed, which can more effectively identify faulty plunger lift conditions. This method can accurately identify previously undetectable conditions such as wellbore waxing and downstroke oscillations. The optimization and condition diagnosis of the plunger lift system requires manual tracking to make timely adjustments work system. However, the current process is time-consuming, labor-intensive, and lacks intelligence. For this condition, the smart plunger can provide real-time adjustment of the work system and condition diagnosis, significantly improving deliquification performance and extending the plunger's service life.
Acid Treatment Challenges and Solutions in Sandstone Formation with Various Formation Damages
Authors: Pham Hoanh V. , Tran Minh H. , Phan Hiep V. , Sanchez Juan P. , Nguyen Thang T. 
Published: September 2024

Summary
This paper presents a systematic approach to design acid treatment for a well that was successfully completed into a sandstone formation initially had a high production rate of nearly 5,000 barrels of oil per day for approximately 50 days, then experienced a sharp decline to less than 1,000 barrels of liquid per day, at the same time as the water cut increased. A thorough investigation was performed to identify the damage mechanisms, followed by matrix acid stimulation, to enhance productivity. Following the initial acid treatment aimed at removing downhole scale, the well productivity index increased from 0.2 stbpd/psi to 0.4 stbpd/psi. A further treatment targeting the removal of fines migration resulted in a stable productivity of 0.7 stbpd/psi one month after the acid treatment, and the well is currently producing at approximately 3.2 stbpd/psi, close to its initial productivity before the sharp decline. This case study can serve as a reference for other acid treatments aimed for sandstone formation under similar conditions.