bluuebunny/crossref_metadata_2025_split huggingface dataset:
Prototype Inversion of Multi-Probe Chemical Sensing Data to Estimate Inter-Well Distributions
Authors: Chen Hsieh , Poitzsch Martin E 
Published: January 2023

Abstract
For several years, there has been an interest in responsive "NanoProbes," which, when injected along with waterflooding could sense reservoir properties locally along the trajectories they follow from injector to producer wells, giving a low-cost and very deep formation evaluation upon being collected, evaluated, and interpreted with respect to injection point, arrival point, and timings. Here, we introduce these novel "dual-mode" NanoProbe tracers, which can undergo chemical transformations when encountering target analytes within the reservoirs.
We first built the dual-mode chemical sensing tracer functionality into our reservoir simulator and performed forward simulations to acquire model transformed and untransformed tracer breakthroughs. Specifically, the original tracer chemical (denoted tracer-1) can transform into a different chemical (denoted tracer-2) when encountering specific analytes of interest within the reservoir; and the ratio of tracer-1 and tracer-2 from injector-producer pairs provides information about the inter-well analyte distributions. Furthermore, we developed a history matching algorithm based on the iterative ensemble smoother with a rectifier linear unit transformation (ES-MDA-ReLU) that can successfully interpret the inter-well analyte distributions from the chemical sensing tracer data.
We found that traditional ES-MDA algorithm is ineffective for the history matching of the inter-well analyte distributions form the chemical sensing tracer data if the inter-well analyte distributions are discrete; nevertheless, applying a ReLU filter to the analyte distributions combining with ES-MDA algorithm results in greatly improved history matching results. We also studied the spatial and temporal resolution of the inter-well analyte distributions inverted from the barcoded chemical sensing tracer data, whereby we found that the spatial resolution is sensitive to well spacing as well as the tracer travel paths; and the temporal resolution is sensitive to the shapes of the tracer breakthrough curves (notably, good history matching can already be achieved if the early parts of the breakthrough curves are collected from all producers). Finally, we compared the application of chemical sensing tracers on synthetic reservoir models with homogeneous or heterogeneous permeability fields and found that better history matching can be achieved on heterogeneous fields due to the more diverse travel paths of the chemical sensing tracers.
Even though the responsive NanoProbes concept has been found promising, the details of the NanoProbes’ working principles and data processing have yet to be fully developed. We believe this work will bridge these gaps and begin to demonstrate the NanoProbes’ potential as novel formation evaluation tools with direct-sensing, low-cost, and very deep reservoir characterization capabilities.
Success in Complex Channel Sand Reservoir Development Driven by New Generation of Ultra-High-Definition Multilayer Mapping-While-Drilling Service and Hybrid Rotary Steerable System
Authors: Yang Bin , Li Tong , Wang Fei , Wang Feng Hai , Li Shu Zhong , Wu Kai , Hu Zhong , Wang Li , Chen Yao , Liu Qi Xun , Zhang Yan Xing , Maalouf Janine 
Published: January 2023

Abstract
Accurate real-time characterization of complex channel sand reservoir is very critical for horizontal well drilling and production improvement. CB block located in the southwest part of Bohai Bay which is the main offshore block for SINOPEC Sheng Li. This block is featured by braided river and fluvial deposition environment. The operator faced challenges during horizontal drilling, such as thin sand channels, inner-beds development, severe lateral change, unstable sand structure and low sand connectivity.
A horizontal well drilling campaign was launched in 2021. Through considerable data assessment and feasibility study, the new generation of Ultra-High-Definition multilayer mapping-while-drilling service and rotary steerable system (RSS) as an integrated solution package was deployed to this project to overcome above challenges. Without any a-priori assumptions, the new generation service doubles depth of detection (DOD) range compared with previous bed-boundary detection services, delivers clearer boundary delineation, and is capable of remotely identifying the quantitative subsurface features, including layers’ numbers, resistivity and anisotropy distribution, thickness, and dip etc. Meanwhile, the truly hybrid RSS with near bit measurements ensures accurate and smooth trajectory control and reduces the drilling risk in the soft formation.
The pilot project was successfully completed. With the help from real-time measurements combined with seismic data, and by utilizing the advanced inversion advantage, this technology could depict whole individual sand bodies and their mutual lateral contact relationship clearly, which not only can optimize the reservoir exposure rate but also provide a better way for detailed reservoir characterization. Four wells were geosteered for a total of1026m with 96.1% reservoir exposure rate. Primary production from these 4 horizontal wells exceeded the expected production by 40% with only 10% water cut.
This innovative solution demonstrates its advantage on optimizing a complex channel sand drilling and development. The authors believe that the fit-for-purpose solution could be expanded to other similar projects by showcasing the distinctive case studies in this paper.
Integrated Workflow With Hydraulic Fracture Propagation and Production Simulation Technology for Multi-Stage Length Optimization in Horizontal Wells
Authors: Wang Xiang , Yao Changyu , Zhu Xinchun , Yang Tao , Chang Chang , Li Yueli , Lu Jiaoping , Li Longjiao , Xu Hanbing , Huang Xingning 
Published: January 2023

Abstract
Low-permeability gas reservoirs generally have the lowproduction, production rapid productivity decline, and low-ultimate recovery. Staged fracturing is usually conducted for horizontal wells. Hydraulic fracturing technology isgenerally used to improve fracture conductivity and well productivity. How to accurately characterize and simulate the distribution characteristics of hydraulic fracture network in 3D space is particularly important. The stress interference between hydraulic fractures as the objective mechanical behavior in the process of staged fracturing affects the geometry fracture network and the productivity of the reservoir post-fracturing. The hydraulic fractures simulation in natural fractured reservoirs is complex shapes, mainly because natural fractures affect the propagation path of hydraulic fractures. The theoretical model used to describe the hydraulic fracturing in homogeneous reservoirs cannot accurately show the complexity of the spatial morphology of hydraulic fractures in naturally fractured formations. The operatorurgently needs a mechanical model that can show the stress interference behavior between multiple fractures and the direction of hydraulic fracture propagation, and be used to simulate the spatial form of multiple hydraulic fractures in staged fracturing of horizontal wells and their propagation behavior in naturally fractured formations. Aiming at the impact of natural fractures in the reservoir on the propagation path of hydraulic fractures, this paper established a mechanical model for distinguishing interference behavior of natural fractures and hydraulic fractures. And analyzed the stress field at the tip of the hydraulic fracture and the stress field acting on the natural fracture surface based on the theories related to rock mechanics and fracture mechanics. On the basis of coupling the 3D geomechanical model and the 3D Discrete Fracture Network (DFN) model, this paper established the discriminant model for hydraulic fractures penetrating natural fractures in 3D space to conduct hydraulic fracture propagation simulation for the horizontal well. The research results can be used to optimize the hydraulic fracturing treatment design,and provide technical support for the effective production and profitable development of low-permeability reservoir resources.
Full Field Uncertainty Quantification Workflow for Tight Green Fields With Multi-Stage Hydraulic Fracture Wells
Authors: Aly Mohamed Amr , Grilli Francesco , Radice Enzo , Vecchio Emanuele 
Published: January 2023

Abstract
Green Fields are characterized by many static and dynamic uncertainties that mainly impact the decision-making of the full field development phase. The objective of this work is to provide a workflow that considers all the complexities related to all uncertainties, static and dynamic, associated with tight green fields and how these uncertainties are parameterized with the integration of well hydraulic fractures.
Uncertainty and optimization workflow has been adopted in a commercial geo-modeler to consider all the associated uncertainties. Structural uncertainty is parameterized using an in-house plug-in inside the geo-modeler tooldeveloped to apply the structural deformation using the concept of elastic gridding. Hydraulic Fractures are modeled using Local Grid Refinements (LGR) created by a plug-in inside the geo-modeler. A sensitivity analysis has been performed to consider the static uncertainty parameters that impact Hydrocarbon volume in place and dynamic uncertainty parameters that impact cumulative hydrocarbon production, including the LGR (extension and permeability).
Statistical maps on 100 different geological realizations calculated on mobile hydrocarbon column and permeability thickness showed the optimum locations of the infilling wells to consider the spatial and vertical variability. A representative case (P50) on volumes in place is chosen to define the suited development strategy for the full field development phase. Due to the complexity of the field, a creaming curve approach has been adopted for each level to consider the optimum number of drainage points needed. A final completion scheme with an optimum number of wells and their hydraulic fracture stages is defined.
Sensitivity Analysis showed that LGR parameters have a considerable impact on the cumulative hydrocarbon production, and to overcome the limitation of the LGR plug-in, which does not allow to change the completion for every realization, a dedicated study has been performed to define the optimum extension of perforations needed to consider the structural and petrophysical changes over realizations.
Three representative cases (P10 – P50 – P90) on the cumulative hydrocarbon production were selected to represent an uncertainty range of the field volumes and production in the next step of integrated asset modeling.
An automatic strategy and related implementation have been developed for wells with LGR simulation to adapt well completions in the context of hydraulic fracturing and uncertainty quantification.
Feasibility Analysis of Hydrogen Storage in Depleted Natural Reservoirs Through a Multi-Phase Reservoir Simulator
Authors: Huang Tianjia , Moridis George J. , Blasingame Thomas A. , Afifi Abdulkader M. , Yan Bicheng 
Published: January 2023

Summary
Unstable supply of renewable energy arises with the inevitable seasonal dependency, which contradicts with periodic energy demand. As hydrogen shows high energy density and mobility, yet low solubility and residual saturation, underground hydrogen storage (UHS) becomes a promising solution of scalable energy storage to rebalance demand and supply. Depleted gas reservoirs (DGR) are one of the most appropriate options for UHS because of the integrity of their caprock and storage system. In this study, we developed a numerical model based on TOUGH+RGB simulator (code) to simulate the flow and thermal transport during UHS in reservoirs such as DGR. Given the different transport and thermodynamic properties of hydrogen, different Equation-of-State (EOS) for modeling the phase behavior of hydrogen-included mixtures are calibrated with literature (lab) data, and further are coupled with the simulator. This benefits our numerical experiments to exam various cushion gas pre-injection strategies for pressure maintenance, boundary conditions, and potential hydrogen leakage into caprock. Hence, we can comprehensively assess the seasonal gas recovery factor of hydrogen stored in DGR. The calculated density of hydrogen-methane mixture based on GERG-2008 EOS and Soave-Redlich-Kwong (SRK) EOS is in perfect agreement with experimental data, while that from Peng-Robinson EOS is not quite consistent. Due to the accuracy and efficiency, SRK EOS is employed in our simulator. Hydrogen injection-idle-withdrawal operation is simulated in a synthetic heterogeneous anticline DGR. Due to gravity segregation, we observe that hydrogen displaces pre-existing methane and resides at the top of the storage zone. When the caprock permeability ranges from 10(-5) to 10(-3) mD, only 0.05% of the injected hydrogen at maximum leaks into the caprock. Besides, an open boundary condition connecting with the storage zone helps the pressure maintenance in the storage and lowers the leakage, since with a close boundary condition the leakage rises to 0.35%. Further, about 1% of injected hydrogen is dissolved into the aqueous phase. Those results demonstrate that UHS in DGR has become a feasible choice. Nevertheless, only about 75% amount of hydrogen can be withdrawn if the bottom-hole pressure of producing well is 2MPa below the reservoir pressure. Therefore, cushion gas is necessary for the UHS project to increase hydrogen recovery. This work provides an in-depth investigation of various physics important to UHS, including EOS, hydrogen transport, capillary pressure, mixing, and dissolution. We quantitatively evaluated the hydrogen loss problem, including leakage to caprock, dissolved in water, and mixing with other gas molecules, which is the first-of-its-kind analysis in literature to the authors’ best knowledge. The modeling study is useful for the feasibility analysis of hydrogen storage in the depleted gas reservoir.
Quantitative Characterization of Heavy Oil Threshold Pressure Gradient in Porous Media
Authors: Xin Xiankang , Liu Saijun , Yu Gaoming , Ma Ruicheng , Xu Peifu 
Published: January 2023

Abstract
A large number of laboratory physical experiments and oilfield production practices show that the flow of heavy oil in porous media no longer follows Darcy's law, but needs to overcome a certain threshold pressure gradient (TPG), which determines the difficulty of heavy oil flow, directly affects the development effect of heavy oil reservoirs, and has important engineering significance. However, the current quantitative characterization methods of TPG of heavy oil have limitations. In this paper, the TPG of heavy oil is measured through experiments, and its influencing factors are comprehensively analyzed. Finally, a new quantitative characterization is proposed. The results show that when the viscosity and permeability are the same, the TPG of heavy oil is not necessarily the same; The TPG of heavy oil increases with the increase of asphaltene content or resin content, and decreases with the increase of aromatics content, saturates content, permeability or temperature. The TPG of heavy oil can be scientifically characterized by the above factors, and ordered according to influence from high to low: temperature, permeability, asphaltene content, saturates content, aromatics content, and resin content. The accurate characterization of the TPG of heavy oil has great significance for the development evaluation, remaining oil characterization and enhanced oil recovery of heavy oil reservoirs.
Regional and Temporal Variability of Indian Summer Monsoon Rainfall in relation to El Niño Southern Oscillation
Authors: Athira K S , Roxy Mathew Koll , Dasgupta Panini , Saranya J S , Singh Vineet Kumar , Attada Raju 
Published: January 2023

Abstract
The Indian summer monsoon rainfall (ISMR) exhibits significant variability, affecting the food and water security of the densely populated Indian subcontinent. The two dominant spatial modes of ISMR variability are associated with the El Niño Southern Oscillation (ENSO) and the strength of the semi-permanent monsoon trough and related variability in monsoon depressions, respectively. ENSO strongly influences the ISMR, but the temporal and regional variability of this teleconnection is not well understood. Our analysis shows that the teleconnection between ENSO and ISMR increased consistently between 1901 to 1940, from a moderate to substantially strong correlation, remained stable at a strong correlation during 1941 to 1980, and then decreased consistently again to a moderate correlation in the recent period, 1981 to 2018. We have also explored the regional variability based on the consistency in the ENSO–ISMR relationship. We identify three regions—namely north, central and south India, where the variability in ENSO–ISMR relationship is moderate, high and consistent —and investigate the mechanisms behind the varying teleconnections. The overall decrease in ISMR is related to warm SST anomalies in the eastern Pacific Ocean suggesting El Niño conditions. Meanwhile, the decrease of rainfall over the Indo-Gangetic Plains and an increase over the southern peninsula is associated with warm SST anomalies over the Indian Ocean. We find that the temporal changes in ENSO–ISMR relation in different regions of the country are due to the overlying influence of the monsoon trough and related variability in monsoon depressions.
Development of a scoring model for the prediction of gangrenous/perforated appendicitis
Authors: Kobayashi Toshimichi , Hidaka Eiji , Koganezawa Itsuki , Nakagawa Masashi , Yokozuka Kei , Ochiai Shigeto , Gunji Takahiro , Sano Toru , Tomita Koichi , Tabuchi Satoshi , Chiba Naokazu , Kawachi Shigeyuki 
Published: January 2023

Abstract
Background: The mortality rate of gangrenous/perforated appendicitis is higher than that of uncomplicate appendicitis. However, non-operative management of such patients is ineffective. This necessitates their careful exam at presentation to identify gangrenous/perforated appendicitis and aid surgical decision-making. Therefore, this study aimed to develop a new scoring model for predicting gangrenous/perforated appendicitis in adults based on objective findings.
Methods: We retrospectively analyzed 151 patients with acute appendicitis who underwent emergency surgery between January 2014 and June 2021. We performed univariate and multivariate analyses to identify independent predictors of gangrenous/perforated appendicitis, and a new scoring model was developed based on logistic regression coefficients for independent predictors. Receiver operating characteristic (ROC) curve analysis and the Hosmer–Lemeshow test were performed to assess the discrimination and calibration of the model. Finally, the scores were classified into three categories based on the probability of gangrenous/perforated appendicitis.
Results: Among the 151 patients, 85 and 66 patients were diagnosed with gangrenous/perforated appendicitis and uncomplicated appendicitis, respectively. Using the multivariate analysis, c-reactive protein level, maximal outer diameter of the appendix, and presence of appendiceal fecalith were identified as independent predictors for developing gangrenous/perforated appendicitis. Our novel scoring model was developed based on three independent predictors and ranged from 0 to 3. The area under the ROC curve was 0.792 (95% confidence interval, 0.721—0.863), and the Hosmer–Lemeshow test showed a good calibration of the novel scoring model (P = 0.716). Three risk categories were classified: low, moderate, and high risk with probabilities of 30.9%, 63.8%, and 94.4%, respectively.
Conclusions: Our scoring model can objectively and reproducibly identify gangrenous/perforated appendicitis with good diagnostic accuracy and help in determining the degree of urgency and in making decisions about appendicitis management.
Isorhamnetin exerts antifibrosis effects by attenuating PDGF-BB--induced HSC-T6 cells activation via suppressing PI3K-AKT Signaling Pathway, a new remedy for liver fibrosis
Authors: Rashidi Mojtaba , Matour Emad , Nasab Hasti Beheshti , Cheraghzadeh Maryam , Shakerian Elham 
Published: January 2023

Abstract
Background
Liver inflammation and fibrosis are the results of chronic liver injuries, which activated myofibroblasts in the liver to produce more proteins in the extracellular matrix. The origin of myofibroblasts is quiescent hepatic stellate cells. Isorhamnetin as a natural flavonoid widely distributed in fruits and vegetables has anti-inflammatory activity and avoids cell proliferation and migration.
Objectives
We studied the effect of Isorhamnetin as an antifibrotic following stimulation by PDGF- BB in the HSC-T6 cells, as well as related mechanisms in vitro.
Methods
First of all, we used PDGF- BB to activate the HSC-T6 cells. After that, we used Isorhamnetin to treat activated cells for 24h. Finally, we compared the mRNA expression amount of collagen1 (COLA1), Alpha Smooth Muscle Actin (α-SMA), and level of phosphorylated AKT protein with our control group.
Results
The obtained data revealed the expression of the COLA1, α-SMA genes, as well as the amount of phosphorylate-AKT protein in the cells treated with PDGF-BB, significantly rose in comparison with our control. In addition, 75 and 100 µM concentrations of Isorhamnetin markedly declined the COLA1, α-SMA expression, and the phosphorylated AKT protein in the HSC-T6 cells.
Conclusions
Isorhamnetin significantly decreased HSC-T6 activation by preventing the PI3K-AKT cell signaling and reducing the expression of COLA1, α-SMA within liver fibrosis in vitro, so Isorhamnetin can prohibit liver fibrosis progression. In terms of these data, Isorhamnetin use can be recommended as a helpful therapeutic factor to treat liver fibrosis.
Self-gripping mesh in laparoscopic obturator hernia repair: clinical experience in a single institution
Authors: Sugiyama Tomohiro , Takeuchi Yuji , Kinoshita Osamu , Mori Yoshihiro , Ishikawa Akira , Kominami Hiroaki , Urano Naomi , Higuchi Ichiro , Hasuike Yasunori 
Published: January 2023

Abstract
Purpose: We propose a treatment strategy for obturator hernia repair using a self-fixating mesh. An obturator hernia is a relatively rare type of abdominal hernia with a high mortality rate, with surgery being the only treatment option. Various approaches to repairing obturator hernia using meshes and tackers have been proposed. Nonetheless, postoperative complications such as chronic inguinal pain and hemorrhage have been reported with tacker-fixated mesh approaches.
Although the self-adhesive property of a self-fixating mesh enables tacker-less hernia repair, it is rarely used in inguinal hernia repair. Tacker-less repair reduces the likelihood of chronic pain development; however, the difficulty in handling the mesh in the abdominal cavity must be overcome.
Methods: We have been using a self-fixating mesh (PG mesh; ProGrip™ laparoscopic self-fixating mesh) for obturator hernia repair since April 2020. In two cases preceding the introduction of the PG mesh for obturator hernia repair, we experienced difficulty attaching the PG mesh; nevertheless, we successfully performed obturator hernia repair by simplifying the method, using three steps, to attach the PG mesh.
Results: Between April 2020 and October 2022, we encountered seven cases of obturator hernia. Of these cases, five were repaired using the PG mesh. Postoperatively, one patient had a small subcutaneous hematoma with no postoperative complications, including chronic pain and hemorrhage. The postoperative recovery time was not prolonged, and there was no recurrence of symptoms during the observation period.
Conclusion: PG mesh appears to be suitable for obturator hernia repair.