bluuebunny/crossref_metadata_2025_split huggingface dataset:
Propuesta de la Licenciatura en Filología Intercultural (LIFI) para el estado de Oaxaca
Authors:   Universidad Nacional Autónoma de México, Quezada Rojas Norma Angélica ,   Instituto de Investigaciones Filológicas,   Docencia y Enlace de Posgrados
Published: October 2023

En este artículo pretendo difundir avances de un trabajo que dé una posible solución a la problemática del peligro de extinción de las lenguas originarias, particularmente en el estado de Oaxaca, con una propuesta educativa que puede ser, además de novedosa, provechosa para su población. La población oaxaqueña es una de las más rezagadas en diversos aspectos, incluido el educativo. Lo anterior se refleja en el estudio de pertinencia que desarrollé en 2020, cuyos resultados permitieron identificar el nivel externo de pertinencia (dimensiones educativa, laboral, económico-social, entre otras) del programa educativo para la propuesta de una Licenciatura en Filología Intercultural dirigida al estado de Oaxaca. Este estudio permitió dar soporte a la propuesta con el fin de garantizar la calidad en la formación de los egresados de dicha licenciatura, de modo que puedan contribuir en la solución de las problemáticas y necesidades culturales, educativas, económicas y sociales propias de sus comunidades.
CO2 WAG Huff-N-Puff for Waterflooded Conventional Reservoirs: Design and Field Learnings from Deployment in the Permian Basin of West Texas
Authors: Bandyopadhyay P. , Andel D. , Hampton D. W. , Stone L. D. 
Published: October 2023

Abstract
Single well Huff-N-Puff schemes have been attempted in waterflooded conventional reservoirs in the past, to limited success. The novelty of the method discussed in this paper is the inclusion of a water-injection cycle post CO2-injection "huff". Simulation models showed that this modification significantly increases the yield of incremental oil and increases retention of injected CO2 in the reservoir. A field experiment was designed and implemented in a San Andres field, using a specially designed CO2-gas lift bottom hole assembly that allowed injection and production with the same bottom-hole assembly. This design reduced the need for workover operations between production and injection cycles, as well as allowing injection and production logging of the reservoir zone to better understand the results of the process.
We describe the design process for a cyclic CO2-alternating-water injection scheme for waterflooded conventional reservoirs from simulation to field execution. We also discuss operational learnings and resulting best practices for artificial lift, three-phase separation, and well testing that were developed for this recovery method.
Results from the field pilot yielded peak incremental oil production rates over six times above the baseline water flood at the producer-well level. Additionally, the gas-lift assembly proved effective in allowing real-time wellbore monitoring, which greatly enhanced the understanding of the CO2-HnP in a single-well system.
Experimental Study and Pilot Tests of Autothermic Pyrolysis in situ Conversion Process for Oil Shale Recovery
Authors: Guo Wei , Sun Youhong , Li Qiang , Zhu Chaofan , Deng Sunhua , Wang Yuan , Liu Zhao , Chen Chen , Liu Baochang 
Published: October 2023

Abstract
Oil shale has not been applied in large-scale industrial processes owing to its poor efficiency and high energy extraction costs. The autothermic pyrolysis in situ conversion process (ATS) is an oil shale high-efficiency heating extraction method that uses the residual potential heat after kerogen pyrolysis.
Herein, a large-size oil shale (Φ: 100 mm, L: 500 mm) in situ pyrolysis experimental apparatus, which considers the overburden pressure, was designed to study the feasibility, characteristics, and energy efficiency of ATS. Two ATS pilot tests were conducted at different depths (approximately 70 and 480 m) in the Songliao Basin, China. The pilot tests were performed for nine years, from 2013 to the present.
The results demonstrate that the ATS of oil shale is successfully triggered at 300 °C. The autothermic pyrolysis reaction is steadily advancing, proving the feasibility of the method in laboratory-scale experiments. According to their optical characteristics and chemical composition, ATS reaction zones can be divided into residue, autothermic, pyrolysis, preheating, and virgin zones. Compared with the high-temperature nitrogen in situ conversion process, pyrolysis oil obtained from ATS contains more light components. When the oil recovery via ATS reaches 69.1%, the energy efficiency reaches 3.46, which is much higher than 0.51 by nitrogen.
The cumulative oil and gas production of the shallow-ground pilot test was 1.6 ton and 1500 m3, respectively. In addition, the cumulative oil and gas production of the deep-ground pilot test was 3.0 ton and 18,000 m3, respectively. During the two pilot tests, long-life downhole heating technology and equipment were developed and applied. The compound reservoir reconstruction technology, which includes shock wave fracturing, hydraulic fracturing, and acid fracturing, was studied. To improve the pyrolysis efficiency, oil recovery, and quality to the oil shale was studied.
This study shows the advantages and feasibility of ATS using experiments and pilot tests, which can be used for the large-scale commercial development of oil shale.
Excellence in Petroleum Engineering
Authors: Michael Andreas 
Published: October 2023

Abstract
The failed merger attempt between SPE and the American Association of Petroleum Geologists (AAPG) in 2020-21 brought about nonsensical calls for rebranding the petroleum engineering (PE) discipline into something like "energy engineering" and by extension SPE into "Society of Professionals in Energy." This led to the writing of "Petroleum Engineers Need a Strong Professional Society" (SPE-210365). I felt a need to combat heavy-consequence-bearing misconceptions promulgated in the PE community, including a field of great importance: education. Someone had to set the record straight.
PE academic programs interested in facilitating a smooth transition of their graduates into the industry should work in conjunction with the exploration and production (E&P) sector of the oil and gas (O&G) industry to provide the correct balance between theory and practice in their coursework, ensuring that relevant-E&P-job openings are filled with their graduates. The low PE-student enrollment levels frequently reported may be a manifestation of long-standing issues within the PE higher education. Decisions on things like curricula/syllabi design, along with faculty hiring should be governed by a desire to equip PE graduates with a competitive advantage over non-PE graduates vis-à-vis related-E&P domains.
Integrating the many PE subdisciplines (drilling, reservoir, production, and other) in a manner efficient for learning is essential for producing competitive-and-market-attractive young professionals. PE graduates must be cognizant of the basics and fundamentals of their "trade," comfortable in assessing E&P problems efficiently through all their facets. While talks on the transferability of skills that PEs typically feature into peripheral disciplines mainstreams, strengthening the competitive advantage that PE graduates must hold over non-PE graduates is where the focus needs to be. Excellence in PE requires intra-disciplinarism – completeness on all fronts.
This paper presents ten "truisms" (cold, hard realities of the modern-day world), providing explanations behind several status quos impacting the PE discipline, directly or indirectly.
Optimizing ESP Well Analysis Using Natural Language Processing and Machine Learning Techniques
Authors: Alquraini A. H. , Al-Kadem M. S. , Al Bori M. M. , Bukhamseen I. M. 
Published: October 2023

Abstract
The process of extracting and searching for well and field historical data is an essential element in production engineering as it helps capture anomalous events and mitigate measures during critical well operations and analysis. Thus, a new methodology utilizing Machine Learning (ML) and Natural Language Processing (NLP) was used to create an advance model to automate this process. This study explores the process of automating exploring artificially lifted well data via the utilization of ML and NLP algorithms.
The proposed method introduces an intelligent petroleum engineering system that takes users’ input and analyze Electrical Submersible pumps (ESP) wells using an advanced ML and NLP model. Moreover, text extraction, cleaning and validation tasks are initially performed to ensure data quality prior to machine and language modeling. Also, word embedding techniques were used to train the model to learn semantic level relationships such as well and field names. The developed model takes the user's questions and transform them to Structured Query Language (SQL) to be executed on cloud servers and evaluated ESP wells using real time data in order to generate the targeted analysis.
The NLP system was implemented utilizing engineers’ daily workflows, and evaluated on its ability to retrieve users’ targeted results in the data set based on query entered by the users. Moreover, performance of the system on extraction, mapping and mitigation attributes were evaluated using F1 scores performance matrix. Validating and testing the NLP model disclosed a promising outcome. It’ is worth noting that the advance NLP system scored significantly high F1 record which indicated high reliability of the model to retrieve critical well information. The developed model enabled engineer in the field to utilize such system to explore and extract targeted results from cloud solutions using advanced ML and NLP algorithms. This yielded significant impact on cost as well as time savings of more than 40% due the system ability to provide engineers with intended results during critical times.
The developed NLP model enhanced the way engineers explore and study well historical data as the proposed system lead to a fast and substantial improvement in acquiring a desired result. Also, the system provides a detailed well description and analysis to its users. This resulted in significant money and time saving especially in offshore operations where a fast and reliable data is needed to make critical decision in a timely manner leading into avoiding production losses.
Thermally Conductive Proppants to Improve Heat Extraction in Geothermal Systems
Authors: Balushi Faras Al , Taleghani Arash Dahi 
Published: October 2023

Abstract
Due to the low permeability of geothermal reservoirs, hydraulic fracturing could provide conductive pathways to improve fluid flow and heat exchange. Fractures in geothermal systems not only provide channels for fluid flow, but also provide a larger contact area for heat transfer to achieve an efficient and economic heat extraction. Since commercially available proppants have low thermal conductivity, we present a method to improve heat exchange inside propped fractures by increasing thermal conductivity of the proppant packs using conductive coating. Accurate numerical modeling requires a representative proppant pack sample with particle size distribution, sorting, and shape similar to a physical sample. Thus, using a dynamic method of generating a granular packing, we construct a proppant pack under the influence of gravity through discrete element method to obtain a sample under representative in-situ conditions. We apply uniform conductive coatings of different thickness to the proppants by taking advantage of image processing techniques. Finally, we simulate heat transfer through the proppant pack using finite volume methods to compute the effective thermal conductivity of the coated proppants and determine the improvement in heat exchange inside the propped fractures achieved by applying such a conductive coating. To calibrate our model, we conducted a validation simulation and compared the results to the available analytical results. Particle-scale analysis revealed the effectiveness of using conductive coating in improving the thermal conductivity of the proppant used. Adding a thin layer of copper coating to sand proppant is observed to increase its thermal conductivity by more than a 100%. Results also showed a positive correlation between the thickness of the conductive coating and the resulting effective thermal conductivity of the proppant. The observed increase in the proppant thermal conductivity can increase the rate of heat exchange by providing additional surface area for heating up the circulating fluid and thus allowing more heat extraction from geothermal reservoirs. Through modeling proppants at the particle-scale, we find that applying a conductive coating can remarkably increase the effective thermal conductivity of the proppant pack and promote heat exchange between the proppants and the circulating fluid in addition to fracture walls. Particle-scale modeling allows to understand how individual proppants interacts with each other under elevated temperatures and high closure stress and how such particles interactions control the effective thermal conductivity of the proppant pack.
Integrated Solution to Tackle Sand Production Using Inhouse Sand Agglomeration Technology: A Pilot in Offshore Malaysian Oilfield
Authors: Hendraningrat L. , Ramli N. A. , Riyanto L. , Zainal S. , Shafie N. A. , Baharuddin S. , Rajasekaran P. K. , Mahadi K. A. , Zubir M. I. , Shafie S. K. H. 
Published: October 2023

Abstract
Several oil fields in the Malaysian oilfields have experienced sand production issues, which caused a reduction in production. Moreover, if artificial lift systems such as ESP is installed, it can lead to frequent failures, which will have a significant impact on cost due to pump downtime. Mechanical solutions that are commonly used, such as sand screen and gravel packs, are suboptimal because they decrease inflow area and make optimization activities difficult. This paper describes an integrated solution that employs inhouse sand agglomeration chemical (SAC) technology and mechanical solution to address the sand production problem from laboratory to pilot in an offshore oil well.
Extensive laboratory tests confirmed the SAC viability for sand production in Field-S. A pilot well candidate was selected based on a history of frequent well interventions due to sand production in the past, as well as the completeness of core samples, mineralogy data, and fluid samples. The test was conducted with an actual downhole sand sample and a sand screen, while flowrate and pressure were monitored. Produced sand was collected for particle size distribution measurement and scanning electron microscope, static and dynamic thermal stability tests, chemical and agglomerated sand particles were aged at downhole temperature and pressure. During pilot, the SAC was injected near the wellbore, and then a sand screen was installed, with post-injection monitoring.
A novel multipolymers chemical concept SAC was proposed, which provides larger agglomerates of grains sands and stronger bond strength between particles, resulting in longer agglomerated sand particle longevity. Meanwhile, the sand screen was installed, and injection was done simply with a bullhead and no squeeze required. After applying SAC in the laboratory, a strong sand agglomeration was observed on the produced sand sample. The SAC can reduce the non-uniformity of agglomerated sand particles, lowering the risk of screen plugging and improving permeability. It also reduces the risk of sand screen plugging and opens more flow channels for hydrocarbon to flow through.
This first pilot was successfully executed in a well at Field-S. The knowledge and experience gathered during this first pilot will be utilized as a reference for future replication to other candidates in the Malaysian oilfields with similar issue.
3D Modeling of the Utah Forge Reservoir Stimulation with Proppant Transport and Deposition
Authors: Kumar D. , Liu B. , Ghassemi A. 
Published: October 2023

Abstract
The paper presents 3D modeling and analysis of hydraulic stimulations conducted at the DOE Utah FORGE EGS site. We simulated the Stage-3 field stimulation along with proppant transport and deposition and examined the injection pressure history, produced fracture geometry, and potential stimulated reservoir volume. For the hydraulic and natural fracture propagation and interactions, we used our state-of-the-art simulator model. The solid rock and fracture surface mechanical deformation are simulated using the boundary element method, the fluid flow inside the fracture is model using the finite element method, and the fracture propagation is implemented in the framework of the linear elastic fracture mechanics, whereas the proppant transport and deposition implement using cell-centric finite volume method. The findings show that asymmetric height growth is expected under the stress regimes and lithology often found in EGS and that rock mass discontinuities such preexisting fractures, rock anisotropy, and lithological boundaries might impede height growth. The results in Utah FORGE's Stage-3 stimulation seems to indicate upward growth and interaction with natural fractures that result in a moderately complicated stimulated reservoir volume (SRV) with an HF/NF network. The transport and deposition of proppant in geothermal reservoirs are significantly impacted by thermal impacts, according to numerical calculations. High temperature can accelerate proppant settling as it greatly reduces the viscosity of the fracturing fluid. Low viscosity fracturing fluids, like slick water, can cause a narrow, propped fracture network and very severe proppant settlement near the injection point in geothermal reservoir stimulation. The findings show that because micro-proppants are smaller size particles, they tend to be carried into complex HF/NF networks, potentially increasing their conductivity, and facilitating heat circulation path in the EGS reservoir.
Accounting for Exterior Flow Using the Modified Logistic Growth Model for Unconventional Geopressured Shale Gas Reservoirs
Authors: Salvatierra Julio C. Villarroel , Lake Larry W. , DiCarlo David 
Published: October 2023

Abstract
The scope of this work is to assess the flow beyond boundary-dominated flow, defining the existence of a third flow regime (after transient linear flow and boundary-dominated flow) that we call "exterior flow" for further use in decline curve analysis in unconventional reservoirs. Thus, exterior flow is defined as the linear flow of gas from the non-stimulated matrix feeding into the edges of the depleted stimulated reservoir volume (SRV), at late times, far away (predicted by Lee 2021; and anticipated by Marder et al. 2021). Sometimes referred as "flow beyond the tips" or post-SRV flow (Blasingame 2019).
Because of the existence of this third flow regime, the production curves of over-pressured shale gas reservoirs, such as the Haynesville formation, seem to not be fitted by a single hyperbolic model or any of the modern rate-time relations (Power law exponential, Stretched exponential, Duong, etc.). We believe that the over-pressured condition of the formation—close to the lithostatic gradient in the Haynesville Shale for example—yields such high pressure drawdowns that all flow regimes (transient linear flow, boundary-dominated flow, and exterior flow) occur sooner compared to other basins. Additionally, this paper shows that a new member of the logistic growth family of curves, called the "modified Logistic Growth Model" in its 2023 version (m-LGM 2023) solves the problem of curve-fitting production data from horizontal wells in the Haynesville Shale.
Furthermore, two novel diagnostic plots are presented for rate-time analysis to obtain the characteristic time of switching from boundary-dominated to exterior flow, which enables the prediction of additional volume to be produced under this flow regime. Finally, given that the current literature of the SPE-PRMS 2022 does not provide specific guidelines for the categorization of probable reserves (P2) in shale gas, we believe this work could signify a contribution for future reserves using this category for unconventional formations. The volume expected from exterior flow could be justified as probable reserves (P2) in shale gas wells.
Dynamics of Surfactant Imbibition in Unconventional Reservoir Cores
Authors: Wei B. , Wang Y. , Wang L. , Li Q. , Lu J. , Tang J. 
Published: October 2023

Abstract
Despite the promising results observed from the utilization of interfacial-active additives in enhancing imbibition-based oil recovery from tight reservoirs, the predominant mechanisms governing this process remain inadequately understood. A meticulously designed workflow was implemented to conduct experimental and modeling studies focusing on imbibition tests performed on tight cores utilizing surfactant and microemulsion. The primary objective of this research was to investigate the response of oil recovery to these additives and to develop a robust and reliable model that incorporates the intricate interactions, thereby elucidating the underlying mechanisms.
We systematically designed and prepared two imbibition fluids, namely surfactant (AES) and microemulsion (mE), while utilizing brine as a reference fluid. A comprehensive investigation was conducted to analyze the physicochemical properties of these fluids, encompassing phase behavior, density, viscosity, and wettability alteration, with the aim of establishing fundamental knowledge in the field. Imbibition tests were carried out on oil-wet cores to observe the response of oil production and optimize the experimental methodology. Subsequently, we proposed a numerical model that fully coupled the evolution of relative permeability and capillary pressure with the dynamic processes of emulsification, solubilization, and molecular diffusion.
All tested fluids exhibited favorable density (1.05-1.07 g/cm3) and viscosity (1.0 cp) at the reservoir temperature of 44 °C. AES effectively reduced the oil-water interfacial tension (IFT) to 10−1 mN/m, while mE achieved an ultralow IFT of 10−3 mN/m, accompanied by strong emulsification capability and a high solubilization ratio. Both solutions demonstrated the ability to alter the wettability of the rock surface from oil-wet to water-wet, albeit through different mechanisms (adsorption for AES and solubilization for mE). In line with the IFT and phase behavior experiments, imbibition tests on cores revealed that aqueous solutions with interfacial-active additives resulted in significantly higher oil recovery compared to pure water. Notably, the core treated with mE exhibited the highest oil recovery, reaching 36.5% of the original oil in place (OOIP). To further elucidate the observed effects, a modeling study was conducted, considering the aforementioned mechanisms. The results demonstrated the crucial role of emulsification/solubilization in the imbibition process.