bluuebunny/crossref_metadata_2025_split huggingface dataset:
BUDIDAYA BUAH TIN DALAM RANGKA PENINGKATAN PRODUKSI EKONOMI DESA DURI, SLAHUNG, PONOROGO
Authors: Aini Shofwatul 
Published: June 2023

Abstrak: Salah satu cara untuk meningkatkan perekonomian suatu desa bisa dilakukan dengan memanfaatkan aset yang dimilikinya. Di desa Duri Kecamatan Slahung Kabupaten Ponrorogo memiliki aset yaitu tanaman buah tin. Para petani buah tin sudah menanam buah tin kurang lebih 3 tahun tetapi banyak diantara mereka yang bekum mengolahnya menjadi suatu produk yang bernilai jual tinggi. Oleh karena itu pengabdian ini memiliki dua rumusan masalah yaitu Bagaimanakah budidaya dan pengolahan buah tin agar menjadi produk yang bernilai jual tinggi dan Bagaimanakah pengaruh pengolahan buah tin terhadap pola pikir warga Duri dalam kaitannya dengan peningkatan ekonomi. Pengabdian ini menggunakan metode ABCD dimana penekanan utamanya adalah memanfaatkan aset yang ada. Pengabdian ini dilakukan dalam bentuk sosialisasi budidaya dan pengolahan buah tin di desa Duri. Dari pengabdian bisa disimpulkan bahwa untuk pengolahan buah tin agar menjadi produk yang bernilai jual tinggi diperlukan kesabaran dan ketelatenan. Selain itu, pengolahan buah tin menjadi produk yang bernilai jual tinggi dapat menggugah pikiran warga desa Duri untuk berwirausaha. Keywords: Buah tin, ABCD, peningkatan ekonomi Abstract: One of the way to raise the economic development of a village can be done by using the asset that they have maximally. Duri village is a part of Slahung district in Ponorogo East Java that has many assets, which one of these is Tin fruit. The farmers have planted this fruit for three years, but most of them sell only the fruit. They have not cultivated Tin fruit become something that has a high value economically. Based on this, the research has two main problems to overcome. First, how to plant and cultivate the tin fruit become something with high value economically, and how this cultivating process can influence the mindset of Duri people in becoming a businessman. This research uses ABCD method where the main stressing is on using the asset. To do this, the engagement is conducted in form of the socialization on planting and cultivating Tin fruit in Duri village. The result is to cultivate Tin fruit become something with high value economically needs patience and diligent. In addition, the socialization of cultivating Tin fruit can stimulate the mindset of Duri people to become an entrepreneur. Keywords: Tin fruit, ABCD, raise the economy
First Successful Application of Wellbore Stabilization Technology Eliminates the Need for Contingency Casing and Differential Sticking Risk While Drilling Through Carboniferous-Devonian Formations: A Case Study on an Exploratory Well in the Sub Andean Bolivian Basin
Authors: Monasterio Andrea Soruco , Soriano Victor , Cadena Ramiro , Maldonado Reinaldo , Ahmed Ramadan 
Published: June 2023

Abstract
The South Sub-Andean Bolivian Basin presents significant geological challenges. Carboniferous and Devonian sequences with anomalous pore pressure trends require significantly different wellbore designs. Fluid losses, absence of wellbore stability, low penetration rates, severe vibrations, wellbore tortuosity, and stuck pipe challenges are common non-productive events that can lead to costly side-tracking. This paper addresses the effective use of stabilizing technology to drill two formations with significantly different pressures in a single section.
The integrity of the well was compromised by an unexpected fault in the Devonian at 3353 m (11,000 ft) in the 12.25-inch section that replicated Carboniferous formations. The abnormal upper zone pressure was controlled with 13.5 ppg mud. However, most fluid additives were incompatible with the wellbore and destabilized it. Excessive overbalance and wellbore instability caused fluid losses and differential sticking at 3505 m (11,500 ft), resulting in a stuck pipe event with costs and schedule consequences. The mud properties were improved by introducing novel cellulosic components and slightly reducing the drilling fluid density. The improvement enabled drilling a 975 m (3200 ft) deeper sidetrack section with zero stuck pipe incidents.
Casing the troublesome section was not an option due to the limitations on the hole diameter. Consequently, a novel mud system tailored to the formation was used to stabilize the wellbore. The performance of the fluid was monitored using an HPHT filter press and permeability plugging tester at all times. No fluid losses were observed throughout the weak zone. The 12.25-inch section was drilled up to the depth of 4176 m (13,700 ft) utilizing a 13.2-ppg mud and maintaining a differential pressure of 3000 psi, avoiding a highly costly extra casing section. Two runs of wireline logs consisting of 90 static stations of 30 minutes each were conducted along 1981 m (6500 ft) of the open hole without detecting differential sticking. A 9.625-inch production casing string was run and cemented in place. The cement evaluation log obtained after 78 hours indicated good bonding and hydraulic seal, effective mud displacement, and a successful cement job.
Drilling through abnormal pressure formations was exceptionally challenging due to an unexpected Carboniferous-Devonian fault. The paper describes the first successful application of fluid stabilization technology in Bolivia where 3000 psi of overbalanced pressure was managed while achieving well objectives and ensuring the successful completion of the project.
Explosive-Free Hydromechanical Perforating Technology Alternative During Plug and Abandonment Operations, for Annulus Connectivity Between Casings, Assures Well Integrity Barriers and Prevents External Casing Damage
Authors: Rodríguez Alexis Eduardo , Garay Ruben Joaquin , Guarín Magda Liliana , Rincón Rocio Del Pilar , Duarte Alexander , Maya Diego Martín , Butcher Stuart 
Published: June 2023

Abstract
This paper presents the implementation of explosive-free hydromechanical perforation technology, run on pipe during plug and abandonment P&A operations, connecting the annulus between casings using blades that cut without affecting the integrity of the external casing and subsequently circulate cement slurry through the perforations in order to establish an effective transverse barrier, mitigating the risk of fluid migration from the wellbore to the external environment.
During P&A operations in some fields in Colombia, there are explosive mobilization restrictions, and it is required to perforate the casing to connect the annulus without affecting the external casing to pump a cement plug as an effective transverse barrier. According to this, an alternative to conventional perforating was planned. The hydromechanical perforating technology was implemented in 2 pilot wells with 5-1/2″ and 6-5/8″ production casing, achieving a perforated flow area necessary to circulate a cement slurry to obtain homogeneous returns on surface, and thus placing a barrier that prevents the migration of the fluid from the well to the external environment.
The implementation of the explosive-free hydromechanical perforation technology was successfully carried out in 2 wells for abandonment that had no cement close to surface in the B annulus. The result was an optimization of operational time due to the possibility of activating the tool multiple times in a single run compared with additional wireline runs until circulation on surface is verified. The jobs were performed with no HSE incidents or Not Productive Time, reducing logistics for explosive mobilizations restrictions, and eliminating explosive handling risks and the requirement of a wireline unit. The final schematic after the definitive Plug and Abandonment (P&A) includes on surface an effective cement barrier that covers the inside of the production casing and the annulus between casings, without affecting the integrity of the external casing and preventing contamination of the external environment due to well fluids migration.
The Hydromechanical Perforating Technology is a new option that provides a safer connectivity alternative that replaces explosives and, guarantees that the integrity of the external casing is not affected. Additionally, multiple activations in a single run can be performed until circulation is established to clean the annulus prior to circulating the cement slurry.
Margarita 10: Drilling Strategy of the Fastest Well in the Bolivian Sub-Andean Region
Authors: Bertarelli Mario , Buyers Gary , Barron Jorge 
Published: June 2023

Abstract
Repsol completed a 10-year long drilling campaign in the sub-Andean region of Bolivia the first semester of 2021 with the Margarita 10 infield well, a drilling campaign where some of the most prolific gas producers in south America were drilled. The complexity of these gas projects is well known and includes great geological uncertainty, hard rock from surface to bottom, high pressure and high temperature conditions among others.
Margarita 10 was the last well of the above-mentioned campaign and served to prove that when you combine proper planning with great execution practices, fit-for-purpose technology and artificial intelligence there is no benchmark that cannot be improved, even if it's drilled in the middle of a worldwide pandemic that greatly affected the oil and gas industry and life in general.
This paper will explain how the Margarita 10 was drilled and completed in little over six months when the standard for this type of wells was a year plus, the planning process and all the adjustments made to ensure it was a success even when all the odds were against it. The technology used and the engineering decisions behind it, the learning curve and the lessons learned from the vast experience the operator has in these fields which greatly helped managing the geological uncertainties that come with this type of plays.
Among the technologies discussed we have a 3000 HP rig specifically assembled for this project, robust downhole tools to withstand huge loads, state of the art drilling bits with novel PDC cutters design, premium casing connection, liner and wellbore isolation technology. Special mention is made to Inwell.AI, the in-house developed, Repsol proprietary artificial intelligence tool that allowed the drilling team to reach rates of penetration never reached before in this kind of formations and the longest runs in the Bolivian sub-Andean region.
The Margarita 10 project proved that efficient drilling operations can be achieved even in the most uncertain of environments, reducing historical time and cost estimations in more than half while accomplishing all proposed targets. Margarita 10, besides being an operational success, became one of the biggest gas producers in the country and showed that when things are done right there is no limit to what can be achieved in this industry.
First Successful Application of Geosteering Drilling in Narrow TVD Window: A Case Study on a Deep Horizontal Gas Well in Bolivian Foothills
Authors: Aponte Cristhian , Soriano Victor , Soruco Andrea , Blanco Gustavo , Ahmed Ramadan 
Published: June 2023

Abstract
Bolivia produces hydrocarbons from the Tertiary, Carboniferous, and Devonian formation systems. A horizontal well was planned to be drilled in a sand gas reservoir with reduced thickness to increase reservoir contact and gas production. The plan included an estimated 400-meter horizontal interval that was determined as the ideal length to be completed with sand control using 125-micron filters along its entire length. To achieve this plan and navigate through the reservoir with a 6-inch diameter bit, a vertical pilot well was drilled to acquire the necessary information, such as formation dip and petrophysical characteristics of the reservoir through wireline logs in an 8.5-inch open hole section.
Various difficulties were encountered during the execution of the build section with an 8.5-inch bit, such as poor directional control, low ROP, high torque, and differential sticking, which were overcome through a detailed analysis of the unplanned events. This paper shows all the steps that led to successfully drilling a horizontal well through a Devonian sand formation with a narrow TVD window for the first time.
Overcoming the Operational Challenges of the Amazon Basin and Setting a New Performance Benchmark Using Monobore Wells: A Case Study in Onshore Brazil
Authors: Fernandes G. , Quinones H. , Carvalho J. , Harada L. , Medeiros T. , Sena H. 
Published: June 2023

Abstract
The success of the first wells campaign in the Azulão Field, North Brazil, was significantly influenced by leveraging the technical and economic advantages of slim monobore wells, a well design methodology that has been successfully utilized for gas production in onshore Brazil. Based on the learnings from the first campaign, the Operator designed an optimization plan to establish a new benchmark for well operations performance and justify further activity expansion in the area.
The plan was grounded on an aggressive performance strategy for both the top and production hole sections, using new tech PDC bits, robust mud motors and well trajectory refinements to maximize rate of penetration (ROP). The critical operational risks were confined to the intermediate hole section, namely: severe to total mud losses through hard, naturally fractured diabase rocks and difficult downhole dynamics (shocks and vibrations). And to mitigate their impact, each well location was built with a continuous water supply to allow drilling without interruptions, and the BHA strategy was adjusted to reduce the likelihood of downhole tool failures.
From a drilling standpoint, the 12 ¼-in top hole ROP improved by 165%, by using a PDC bit with optimized cutting geometry and a "kick off early and stay slightly above plan" approach for the directional work. Likewise, the 6 1/8-in production hole ROP improved by 70%, by switching to a 5-bladed, 13 mm cutter PDC bit, using a 5-in high differential pressure mud motor and a "zero" sliding approach with the wellbore precisely placed to anticipate the expected formational tendencies down to the geological target.
During the last 3 wells, a total of 4 rig days were saved due to the aggregate effect of flat time optimizations. By way of example, a semi-compact wellhead system, which was specifically designed for the slim monobore well design, brought average time savings of +- 10 hours per well.
Overall, when compared to the first campaign, the meterage rate from spud to total depth improved by 95%. This, in turn, translated into a 43% metric cost reduction. Similar results were also obtained across 3 wells in a newly discovered area, with a 50% improvement on the meterage rate from spud to total depth, thus contributing towards a 33% metric cost reduction.
Capital discipline, synergies and operational efficiencies will be the keystones for success during the current cycle of activity growth in the Brazilian O&G onshore market. This recipe turns particularly critical for remote, logistically and operationally complex environments. Through this paper, the Operator aims to demonstrate the performance evolution and value of slim monobore wells, as one of the best methods to monetize gas production in the Amazon Basin.
The Use of Machine Learning to Estimate Key Properties in Vaca Muerta Play
Authors: Bernhardt C. , Horowitz G. , Gallart D. , Cambra J. N. , Silka M. , Sanchez M. G. , Lopez L. L. Vera 
Published: June 2023

Abstract
The evaluation of shale reservoir requires solving key properties: total organic carbon (TOC), porosity (PHIT) and water saturation (SW). The determination of these properties with precision, requires laboratory data and high-tech logs. In Vaca Muerta play, the most legacy wells do not have this data. This work presents the Machine Learning as a methodology to estimate TOC, PHIT, cementation factor (M) and saturation exponent (N) with basic logs.
Synthetic logs are generated with different predictive models, taking readily available conventional wire logs as input data (Resistivity, Density, Sonic and Neutron). Regarding of PHIT and saturation parameters (M and N), the models are trained with wells in which these logs are available; in the case of TOC, measures in core are used. Once the target log has been defined, an exploratory analysis is carried out. These results feed the machine learning models. The different models are trained and validated, to obtain the best result. For each synthetic log, a 90% confidence interval is also calculated.
Linear and non-linear models are developed, and their effectiveness is measured by dividing the data randomly, using 80 % of the data as a training set and the remaining 20% as validation set. Moreover, the validation "leave one out" is also performed. The models are applied to more than 170 vertical wells, in all cases, the synthetic curve is accompanied by a confidence interval. The results of these confidence intervals show that the synthetic logs have a precision that makes them reliable and relevant for decision-making by the specialist. The implementation of this technique provides relevant information for landing zone definition, making maps and volumetrics of greater areal detail.
The application of machine learning techniques for the generation of synthetic logs is a procedure that has recently begun to be used in the oil and gas industry. In the particular case of the Vaca Muerta oil field, the series of synthetic logs developed and tested in this work is a complete novelty.
Strategy to Manage Mature Oilfields with Renewable Energies
Authors: Quintero E. , Valdirio J. , Bastardo J. , Huerta V. , Lorbes H. 
Published: June 2023

Abstract
In the case of the Venezuelan Maracaibo Lake Basin, the existence of mature represents a good opportunity to recover them using renewable energy, even worldwide exploration efforts become are almost inaccessible and environmentally sensitive places. Therefore, many companies have shifted his strategies to revitalize mature fields, increase their recovery factor and extend their life cycle.
This study proposes an integrated approach to revitalize mature fields, but in a sustainable way. by incorporating renewable sources to supply part of the energy field consumption; thus, allowing monetizing more oil (usually used as fuel consumption), and improving asset management by implementing a production monitoring system (based on field automation and remote-control processes).
The integrated approach to revitalize mature fields includes the following steps: Reserves management upon best practices recommended in PRMS 2018 and follow up based on performance and sustainability indicators.Artificial lift technologies to optimize production performance.Identification of potential opportunities to substitute fuel consumption with renewable energy sources; incorporated to production optimization, energy efficiency and remote monitoring programs.Implementation of energy transition programs focused on maximizing asset value and improving corporate reputation.
It should be noted that Solar and Eolic energy sources were preliminarily identified as the best suited to contribute with revitalization of mature fields, by substituting in between 10 to 15% of fuel consumption; besides this, uncertainty in renewable energy supply, as well as "the state of the art" technologies to extend energy storage should be take into consideration for implementing energy transition programs. In addition, future applications of renewable energy sources in EOR projects may be further investigated considering the benefits in production performance and reservoir management.
Automating Dynamometer Charts Interpretation with Machine Learning
Authors: del Pino Fiorillo Mario Antonio 
Published: June 2023

Abstract
This work objective is to develop a comprehensive methodology for constructing a mathematical model capable of automating the interpretation of Dynamometer Charts from Sucker Rod Pumps (SRPs). The methodology describes the complete data-handling pipeline that allows for the proper ingestion, normalization, transformation, and evaluation of charts, comparing the predictive performance of multiple well-known Machine Learning models. The methodology delivers a properly tuned model with a high predictive performance that can interpret any chart shown to it, as well as quantifying the similarity of any given chart to that of pre-defined behavioral classes.
To develop the methodology, a sample of 293 Dynamometer Charts was evaluated to determine the equipment status, based on known patterns described in the existing bibliography. The resulting dataset was used to train and test around 1,000 different models. These models include Support Vector Machines, Decision Trees, Nearest K-Neighbor, Neural Networks, among others. Each model was tested multiple times to account for bias and overfitting. This way, a best-performing model was found based on performance scores, allowing to determine model family and hyperparameters required for optimal performance.
The study demonstrated that many Machine Learning models can be properly trained for performing interpretations of SRPs operational status. The best performing models were those based on the XGBoost algorithm, although Random Forest algorithms proved to be significantly accurate in certain circumstances. Results were differentiated between surface dynamometer and bottom-hole dynamometers, with the intention of demonstrating the potential implementation of models with no data manipulation in between, such as the one caused by using the wave-function transformation.
This paper not only shows how Machine Learning algorithms can be used to automate some workflows of the production engineering discipline, but also provides a methodology for validating model performance and determining the best performing model among many candidates. Finally, it shows practical ways in which these models results can be used to generate visual tools to improve the decision-making process of engineers and operators.