bluuebunny/crossref_metadata_2025_split huggingface dataset:
Development and Performance Evaluation of a Novel Nano-Composite Crosslinked Fracturing Fluid for Ultra-Deep Reservoir in Tarim Basin
Authors: Xue Yanpeng , Qin Shiyong , Yang Sasa , Liu Ju , Wang Xin , Xu Hang , Hong Yinglin , Lou Erbiao , Deng Qianxing 
Published: October 2023

Abstract
For major ultra-deep oilwells in Tarim basin, hydraulic fracturing operation are challenged by the actual vertical depth in excess of 6000 m and the temperature at bottom hole over 160 °C. The long injection path from ground to target formation generates considerable friction, resulting in extremely high ground pressure, which usually exceed the limit of operation equipment. Moreover, traditional crosslinked fracture fluids always lost their viscosity and sand-carrying ability at high temperatures. Consequently, it is meaningful to develop and research novel fracturing fluids for hydraulic stimulation in high-temperature, ultra-deep reservoirs.
Nano-composite technology has been proven to be a potential solution to some challenges associated with crosslinked fracture fluid systems. In this work, a kind of low-cost molybdenum disulfide (MoS2) nanosheet was firstly synthesized by hydrothermal chemical method. Afterwards, the MoS2 nanosheets were mixed with polyacrylamide solution with specific molecular weight by ultrasonic dispersion, and a certain amount of organic zirconium crosslinker was added to prepare the nano-composite crosslinked fracturing fluid. Finally, a series of indoor evaluation tests were performed to compare the performance of the nano-composite crosslinked system with the similar crosslinked fluid without adding nanosheets, such as rheology properties, drag reduction efficiency, proppant suspension and retained conductivity.
The obtained experimental results have shown that the thermal stability of the nano-composite crosslinked system is much superior to that of a comparable fluid lacking the MoS2 nanosheets. The introduction of nanomaterial allows the novel fracturing fluid to operate at greatly lower polymer concentrations (0.2%-0.3%) compared with current commercial fluid systems (0.4%-0.5%) designed for 180 ℃ reservoirs. The retained apparent viscosity can be maintained above 75 mPa·s after shearing 120 mins at 180 ℃. Rheological studies have shown that the novel system has superior crosslinking properties, and the crosslinking time can be controlled within 4-10 minutes. In addition, this novel nano-composite crosslinked fracturing fluid has enough sand-carrying viscosity under high-temperature conditions, and allows for efficient cleanup by use of an oxidizer-type breaker. Little or no polymer residue and efficient cleanup are contributing to lower reservoir damage, better fluid conductivity, and improved well production.
Newly proposed nano-composite crosslinked fracturing fluid provides a new solution for fracturing stimulation of ultra-deep high-temperature reservoirs in the Tarim Basin, and hence improving the oil recovery.
Deployment of Novel Wide Dynamic Range Through-The-Bit OBM Borehole Imager Enables Logging in Challenging Environment-Implications for the Ordovician and Silurian Siliciclastic Facies Characterization
Authors: El-Khamry Ayman , Rubaie Naif , Weihua Wang , Hassan El-Saied 
Published: October 2023

Abstract
Acquiring borehole resistivity image logs on drill-pipe conveyance operations has some operational and data quality challenges especially in challenging hole conditions and complex well trajectories. These challenges include operation efficiency, sticking issues, proper pad contact and pads overlapping which significantly affect the produced image quality and accordingly the geological interpretation reliability. To address these, a new through-the-bit imaging technology in oil-based Mud (OBM) is introduced, the new technology design has been proven to be reliable and effective in challenging hole conditions.
This deployment technique allows acquiring high-definition micro-resistivity images in conditions where conventional wireline conveyance techniques cannot be used, such as unstable boreholes, tortuous or rugose wells, loss zones, or severe washouts. The distinctive operational advantage of the through-the-bit imaging technology is deploying the tool through the drill-pipe and reaming bit while performing a wiper trip, which saves rig time and significantly reduces fishing risk through the avoidance of cable and tool sticking. Moreover, it improved operations with full well control and the ability to retrieve logging tools at any time. In addition to the high-resolution images produced with the new technology, an inversion workflow has been developed to quantitatively interpret images. The interpretation results are compared with the analysis performed on the images acquired on tough logging conditions (TLC) operations in the same hole.
This paper evaluates the outcome of deploying two electrical borehole imaging technologies through two different conveyance techniques. The innovative through the bit micro-resistivity OBM images are proven reliable in low- and high-resistivity formations, significantly reduced sticking and eliminated the overlapping of pads towards the bottom of the logged interval due to the lighter weight of the through-the-bit technology.
The evaluation included the comparison with the existing conveyance method and covered a full range of well profiles from vertical to deviated, including highly deviated wells and long laterals. The high-resolution image produced allowed identifying various sedimentary and structural features within the target formations. These sedimentary features included thin laminations, cross bedding, soft sediment deformation and structural elements such as natural fractures and faults. Additionally, with inverted standoff images, open and closed natural fractures were identified and utilized in the fracture modeling of the field. All the forementioned identified features have been incorporated into the facies and the structural model of the studied area. The models are more reliable and can be used with confidence for well trajectories optimization and stimulation designs.
Metagenomic Sequencing of Formation Water Sample of Upper Assam Oil Fields and Its Possible Applications in Microbial Enhanced Oil Recovery
Authors: Bhattacharjee Saurav , Mech Borkha , Ahmed Naved Wasim , Khataniar Ankita , Das Aparoov 
Published: October 2023

Abstract
In this study, we describe a metagenomic approach which is a Next Generation Sequencing Technique (NGS) for the identification of biosurfactant-producing microbes present in the formation water sample in the oil fields of Upper Assam. This study also intends to investigate the possible use of the Bacillus subtilis OQ957160 strain (sb23) in the brown fields of Upper Assam for improving recovery of crude oil. Biosurfactant-producing strains like Bacillus Subtilis, Bacillus licheniformis, Pseudomonas Putida, and Pseudomonas aeruginosa were isolated using 16s rRNA gene sequencing and were described and examined based on their capacity to degrade crude oil to produce biosurfactants. Bacillus subtilis OQ957160 strain (sb23) was selected for further study based on its biosurfactant production capability and better interfacial tension reduction (IFT) and surface tension (ST) properties. Through changes to the growing environment, such as carbon source, temperature, pH, and salinity, the dynamics of growth research of the identified strain sb23 was done. Lipopeptide (Surfactin) was identified as the produced biosurfactant. After 70 hours of incubation under ideal conditions, the maximum biosurfactant production of 6000 mg/L and the minimum interfacial tension & surface tension of 0.98 and 23.8 mN/m were attained. At the value of 475 mg/L the biosurfactant solution exhibited critical micelle concentrations (CMC). Additionally, the biosurfactant exhibits outstanding surface activity throughout a wide temperature range of 35-95°C and at salinities ranging from 0.0-16.0% (w/v) and pH 2.0 -10.0. Under reservoir conditions, the produced biosurfactant from strain (sb23) is used in microbial flooding tests to recover an additional 7.85% of heavy crude oil. As a result, the isolated strain sb23 has the potential to significantly improve oil recovery from depleted oil fields of Upper Assam.
Experimental Investigation on Hydrate Formation and Decomposition Behaviors in Micro-Pore Channels
Authors: Zhang Jianbo , Liu Shujie , Xu Yilong , Zhang Binbin , Wang Zhiyuan , Yin Bangtang , Li Shuxia , Gao Yonghai , Sun Baojiang 
Published: October 2023

Abstract
Hydrate formation and decomposition are important factors affecting fluid flow in porous media. To reveal the characteristics of hydrate formation and decomposition in the pores of porous media, pore-scale experiments under different types of flow in micromodel were conducted using a visual microflow experimental apparatus. The experimental results suggested that heterogeneous hydrates were formed in the pore channels, which was mainly affected by the gas-water distribution and temperature & pressure. Compared with the gas-dominated and water-dominated flow, the hydrate formation rate was the maximum under gas-water two-phase flow, and the risk of hydrate blocking the flow channel was the maximum. Moreover, the hydrates were gradually decomposed from the pressure-reduced outlet to the inlet. The methane produced by hydrate decomposition in the pore channel would gather and form a continuous gas flow channel under pressure difference, and the methane dissolved in the water phase would also gradually precipitate out as the pressure decreases to form bubbles, which would form large methane bubbles with adjacent bubbles, thus driving the surrounding water phase flow. This paper lays a foundation for future research on hydrate formation, decomposition and flow in porous media.
Investigating the Effect of Salt, Polymer and Magnetic Nanoparticles on Critical Drilling Parameters—Coupled with Novel 3D Image Processing Technique
Authors: Khan Muhammad Arqam , Aamir Muhammad , Asad Muhammad , Junaid Muhammad , Lalji Shaine Mohammadali , Ali Syed Imran , Ahmed Hashir , Lashari Zeeshan Ali , Lv Kaihe , Li Mei-Chun , Sun Jinsheng 
Published: October 2023

Abstract
Drilling fluid properties have a significant impact on drilling operations. The drilling fluid system suspends and conveys cuttings to the surface using its rheological parameters within the desired operating range. To achieve this, drilling fluids require sufficient viscosity to suspend particles and control fluid loss into the formation. This study aims to address the swelling characteristics of the Middle Indus basin in Pakistan by utilizing a drilling fluid containing different classifications of additives. Eight mud samples were prepared by adding Sodium Alginate, Magnetic Bead Nanoparticles, and KCL at various concentrations to a base mud. The mud samples underwent pH and stability tests, followed by rheological properties tests, including Gel Strength, Viscosity, Shear Stress, Dynamic Viscosity, Plastic Viscosity, Yield Point, Apparent Viscosity, Flow Index, and Consistency Index. Filtration tests were performed to determine filtrate volume loss and mud filtrate cake morphology. The mud samples were evaluated by immersion in the Ranikot shale pallet. Contact angle measurements, 3D surface analysis, and intensity profile surface plots were conducted on the mud filtrate cake and samples. Results of the study reveal that all the mud samples exhibited shear thinning behavior, with dynamic viscosity decreasing as the shear rate increased. Among the tested samples, Sample 7 exhibited the highest dynamic viscosity, which can be attributed to its higher particle concentration. In terms of rheological behavior, Sample 4 performed the best among all the samples. Notably, except for Sample 4, all other seven samples demonstrated cuttings less than 1.5. The power law model provided the most accurate predictions, with the lowest mean absolute error and highest R2 value. Contact angle measurements and intensity profile surface plots highlighted the influence of the mud system on shale sample wettability and surface morphology. The results underscored the importance of KCL, Magnetic Bead Nanoparticles, and Sodium Alginate concentrations in determining the success of a drilling fluid system. These particles also modified the surface properties of the shale samples as observed through 3D image processing techniques. Magnetic Bead Nanoparticles exhibited superior performance compared to others by encapsulating the shale sample and preventing water molecule migration within it.
Track & Reduce Carbon Emission Using Planning Model to Make More Sustainable Operation for Refineries and Olefins
Authors: Jain Piyush 
Published: October 2023

Abstract
Balancing the dual challenge of reducing emissions while still ensuring profitable operations is top of mind for refiners and olefins producers around the world. Advancements in digital optimization technology can help industry leaders navigate the energy transition, meet sustainability goals, and optimize operations and enable companies to meet emission targets and still ensure profitable operations.
Typically, the analysis in LP models is economically focused, balance tradeoffs between different operating parameters to determine how it affects the gross margin of the asset. However, LP models can be used to make operations more sustainable by improving energy efficiency and enabling sustainability decisions such as sourcing renewable electricity for your plant.
Production Optimization using LP models can be used to predict and optimize the tradeoff between emissions and profits and help refiners to find a balance. Use of industrial AI (i.e., Hybrid model) can be a key enabler to make this decision with high confidence.
Nanoparticles Improved Sedimentation Stability of Oil-Based Completion Fluids while Drilling Ultra-Deep Wells
Authors: Yan L. L. , Wang J. H. , Ni X. X. , Sun J. S. , Zhang J. W. , Wang R. , Zhang J. Q. , Cui X. B. 
Published: October 2023

Abstract
The deep and ultra-deep oil and gas resources are important sources to meet the increasing oil and gas demands. But they are difficult to be explored because their buried geological conditions are extremely complex, such as high temperature (HT), high pressure (HP), thick salt and gypsum beds and borehole collapse. Oil-based drilling fluid (OBDF) is the preferred drilling fluid for ultra-deep wells due to its better wellbore stability and higher lubricity than water-based drilling fluid. Meanwhile, the oil-based completion fluid (OBCF) is also the first choice for operators because it can be turned directly by the OBDF, which is convenient and reusable. However, barite sag is often encountered because the completion fluid is required to be static for 7 to 15 days at a high temperature of more than 180°C, which results in serious problems, pipe sticking, density variation and well control problems, in ultra-deep wells. It is urgent to improve the sedimentation stability of OBCF while drilling the ultra-deep wells.
In this paper, a modified nano-silica stabilizer was prepared to improve the sedimentation stability of OBCF. Its dispersity in a water-in-oil (W/O) emulsion with an oil-water ratio of 80:20 was observed by a cryo-scanning electron microscope and the viscosity at low shear rates was also tested. Then OBCF formulations with different densities were developed and modified by the prepared nano-silica stabilizer. The rheology and sedimentation stability were evaluated on HTHP rheometer and sedimentometer, respectively. The HTHP sedimentometer can work at a pressure up to 105 MPa and a temperature up to 300 °C.
Results indicated that the novel nano-silica stabilizer could disperse stably in the water-oil interface and in the oil phase. The viscosity of the W/O emulsion at low shear rates was significantly increased after adding the nano-stabilizer. Meanwhile, the HTHP rheology and sedimentation stability of the high-density OBCF were improved by the nano-stabilizer due to its surface and size effects, and the HTHP sedimentation stability of the oil-based fluids was positively related to its HTHP rheological stability. The modified OBCF by the new stabilizer was successfully applied in a deep well with a temperature more than 200°C in China. The completion operation was smooth without downhole issues, and the casing was run to the bottom hole at once. The oil-test operation was perfectly completed for about two months, and no barite sag happened.
In a word, the modified OBCF by the new nano-silica stabilizer in this work possessed excellent HTHP rheology and sedimentation stability, expecting to be applied widely in deep and ultra-deep wells.
Application of Artificial Neural Networks in Predicting Discharge Pressures of Electrical Submersible Pumps for Performance Optimization and Failure Prevention
Authors: Mahmoud M. A. , AbuObida M. , Mohammed O. , Hassan A. M. , Mahmoud M. A. 
Published: October 2023

Abstract
The pump discharge pressure is a critical parameter that indicates the performance of the electrical submersible pumps (ESPs). Predicting the discharge pressure accurately can help in optimizing the ESP's performance, improving well productivity, and reducing operational costs. This paper presents a novel approach using artificial neural networks (ANNs) to predict the discharge pressure of electrical submersible pumps. The proposed model will enable early detection of possible failures and reduce downtime. Also, the effectiveness of the ANN model will be compared against the performance of different ANN models under various conditions.
In this study, a dataset of more than 12000 data points collected from 40 different wells was used to train and test various ANN models with different input parameters. The performance of ANN models was evaluated using a coefficient of determination (R2), root mean squared error(RMSE), average absolute deviation(AAD), and absolute percentage error (APE). The model inputs and ANN structure were adjusted in order to minimize the prediction errors. The results during the training and testing phases were compared to select the most accurate and efficient model. Finally, the performance of the selected model was evaluated using physical analysis of the results and error profile visualization.
The results showed that the ANN model with 16 inputs and 1 hidden layer with seven neurons is the most accurate model, with an R2 of 0.95 for training data and 0.94 for testing data, and an AAPE of 1.74 for training data and 1.84 for testing data. The model was able to accurately predict the discharge pressure of ESP under different operating conditions, with an average accuracy of 94%. In addition, anomaly detection was also performed on the predicted values to identify any failures or anomalies in the system. This helps in proactive maintenance and troubleshooting of the system to prevent any significant failures. Finally, a new equation was developed utilizing the optimized ANN model. The developed equation provides fast and reliable estimations for the ESP discharge pressure with an error of less than 3%.
Overall, the proposed approach provides novel and additive information to the existing literature by demonstrating the effectiveness of using ANNs to predict the discharge pressure of ESPs. Furthermore, the ability to accurately predict discharge pressure can lead to the early detection of possible anomalies, which can prevent costly failures and reduce downtime. Future work may explore the use of other AI techniques to further improve the accuracy of discharge pressure predictions and ESP failure prevention and explore the prediction of other important parameters in ESPs.
Estimation of Well Interference by Integrating Fracture-Driven Interactions (FDIs) and Post-Stage Fall-Off
Authors: Ibrahim A. F. , Assem A. I. , Sinkey M. , Johnston T. 
Published: October 2023

Abstract
Hydraulic fracturing near depleted fractured rocks is one of the main causes of fracture hits. Fracture hits damage the parent wells in addition to the loss of fracture efficiency of the child well due to the massive loss of fracture fluids and proppant to the parent well. Child well productivity typically diminishes by more than 50%. This behavior is a function of tight well spacing and the depletion time of the parent wells. The current study aims to combine real-time fracture-driven interactions (FDIs) and post-stage pressure transient analysis (PTA) to estimate an accurate fracture half-length for each stage during the frac job.
During hydraulic fracture operations, a pressure gauge is installed in the offset well(s) to measure pressure change during each stage completion in the child well to account for well interference. The connected fracture surface area (FSA) is then calculated using the post-stage fall-off pressure data. When FDI with an offset depleted zone is higher than a certain threshold, a higher stage fracture half-length is estimated, representing a lower cluster efficiency. The well interference value can then be estimated from the summation of these stages with high fracture half-length.
Actual field cases from oil and gas shale frac data are presented with live FDIs measurements for each stage followed by stage-by-stage PTA. The preliminary results showed that more than 20% of the stages experience fracture hits due to the higher fracture half-length and lower cluster efficiency. Finally, the well interference value has been validated by actual production data.
Integrating FDI measurements with PTA for detecting frac stage interference for unconventional wells presents a faster, more accurate, and cheaper fracture diagnostic tool, that will help optimize well spacing.
Achieving Accurate History Matching in Polymer-Flooded Reservoir Through Advanced Simulation of Polymer Properties
Authors: Negre A. , Suzanne G. , Charonnat S. , Delamaide E. 
Published: October 2023

Abstract
This study aimed at history-matching a full-field numerical model representing a mature oil field that underwent polymer flooding for several years. The main technical challenge was to account for the polymer thermal degradation and the change of polymer molecule that occurred during the development of the field. Accurately representing these changes was crucial for satisfactory oil production history matching. Advanced simulation software was used to simulate all relevant mechanisms, resulting in a successful history matching of the production data.
An innovative workflow based on an integrated approach to define geobodies and connections between injectors and producers was implemented to obtain a satisfactory model calibration on the initial water flooding phase. To model the subsequent polymer flooding phase, a single polymer model was not sufficient to accurately represent the impact of polymer injection on oil production rate, in particular towards the end of the historical period. The simulation model was therefore improved using advanced EOR capabilities involving multi-polymer simulation, advanced adsorption model and thermal degradation. Adjusting these properties supported by laboratory data yielded a robust history-match on the whole polymer flooding period.