bluuebunny/crossref_metadata_2025_split huggingface dataset:
Prediction of Minimum Miscibility Pressure Between CO2 and Crude Oil by Integrating Improved Grey Wolf Optimization into SVM Algorithm
Authors: He Youwei , Zhao Guoqing , Tang Yong , Rui Zhenhua , Qin Jiazheng , Yu Wei , Patil Shirish , Sepehrnoori Kamy 
Published: September 2024

Abstract
CO2 injection can enhance oil recovery and achieve geological carbon sequestration. The miscibility between CO2 and crude oil significantly impacts the CO2 EOR performance. Although the minimum miscible pressure (MMP) can be obtained by slim-tube experiment or slim-tube modeling, it is time-consuming, inconvenient, and complicated. This work aims to enhance the prediction efficiency and accuracy of MMP between CO2 and crude oil under reservoir conditions by improved and integrated machine-learning approaches.
A novel method is proposed to improve the forecasting accuracy and efficiency of the MMP by integrating Grey Wolf optimization (GWO) and improved GWO (IGWO) into the Support Vector Machine (SVM) algorithm. Firstly, data sets are collected and data preprocessing is performed to improve the quality of data sets. Secondly, K-fold cross-validation is applied to enhance the generalization of the model. The MMP is predicted by the SVM algorithm. Thirdly, the MMP prediction can be enhanced by introducing GWO and IGWO algorithms, and the optimal model is investigated to evaluate the effect and convergence of the SVM-GWO and SVM-IGWO algorithms. Fourthly, the predicted MMP and evaluation index (MAE, MAPE) are compared. Finally, the field case study is performed to show the practical potential of the approach.
The dominant factors of the MMP include formation temperature (TR), MwC5+ (Molecular weight of pentane plus), MwC7+ (Molecular weight of heptane plus), Volatile (mole fraction of volatile components including N2 and CH4), and Intermediate (mole fraction of intermediate components including CO2, H2S, and C2–C4). The data set is formed by filling 87 groups of missing values using the K-Nearest Neighbor (KNN) algorithm and removing 19 groups of outliers based on the Box-plot detection method. The accuracy is improved by 37.45% and 40.79% using GWO and IGWO based on the MAE compared to SVM. The calculated MAPE shows that the accuracy can be enhanced by 37.79% and 41.29% after adding GWO and IGWO. The SVM-GWO and SVM-IGWO improved the accuracy by 54.16% and 57.12%. The proposed method can accurately determine the MMP between CO2 and crude oil. The field case study highlights the reliability of the proposed method. The developed method can forecast the MMP between CO2 and crude oil more efficiently and economically.
Estimating Petrophysical Properties Directly from Seismic: A Deep Learning Application to Carbonate Field for CO2 Storage Potential
Authors: Lew C. L. , Fuad M. I. Ahmad , Jaya M. S. , Trianto A. , MacBeth C. 
Published: September 2024

Abstract
Geological carbon capture and storage is vital for reducing carbon dioxide (CO2) emissions. Carbonate Field 1 in Luconia Province, offshore Sarawak is a potential CO2 storage site. Porosity and clay volume (Vclay) estimation from seismic provide valuable spatial and temporal information in characterizing reservoir distribution and overburden for assessing containment integrity and storage capacity. A deep learning inversion method for simultaneous estimation of porosity and Vclay was applied and tested in Carbonate Field 1. UNet architecture, chosen for its ability to preserve spatial resolution, processes post-stack seismic as input and petrophysical properties as outputs. Mean-squared error is implemented as the loss functions during the training on synthetic dataset. We use facies-based geostatistical simulation to generate 1D synthetic petrophysical logs. The petrophysical properties are linked to elastic properties through a carbonate rock physics model and fluid substitution using Gassmann's equation. The computed elastic properties are then used to calculate the angle dependent reflectivities (0°-30°) using the full Zoeppritz equations. The reflectivities are convolved with possible source wavelets derived from the seismic post-stack to generate the synthetic seismograms. These synthetic seismograms are then averaged to obtain a single noiseless synthetic seismic data, prior to addition of estimated field noise. 40,000 realizations of 1D synthetic datasets are generated for the training dataset. An equal distribution of 4000 realizations is allocated for both validation and testing datasets. Each 1D synthetic dataset consists of 128 samples, with a sampling rate of 4ms. The trained network model is applied to the testing data which has not been seen by the network during the training. Using Pearson correlation coefficient (cc) as the metric to evaluate the prediction performance, the model provides promising result (cc&gt;0.80) for the estimated porosity and Vclay when evaluated on the testing data. Application on the field dataset of Carbonate Field 1 demonstrates satisfactory prediction performance, with cc value exceeding 0.65 and 0.85 for both the estimated porosity and Vclay respectively. Low (&lt;0.2) and high (&gt;0.5) estimated Vclay content is interpreted as carbonate and shale respectively. The findings allow interpreter to characterize the heterogeneity of carbonate depositional facies and quality by integrating the estimated porosity and Vclay for CO2 storage planning. The process of estimating the porosity and Vclay directly from seismic using the deep learning approach takes one week, which include training data preparation and implementation.
Two-Way Coupled Flow and Geomechanics Simulation with Advanced Dual-Porosity and Dual-Permeability and Local Grid Refinement for Shale Primary Depletion
Authors: An Jaewoo , Yang Daegil , Chen Jianping 
Published: September 2024

Abstract
This paper represents a new two-way coupled flow and geomechanical simulation model that utilizes an Advanced Dual Porosity Dual Permeability (A-DPDK) model with local grid refinement (LGR). A hydraulic fracture's conductivity is strongly dependent on the effective stress on fracture face. During production, increased effective stress could cause proppant embedment, crushing, and fracture closure. Coupled flow and geomechanical simulation is critical to capture the fracture conductivity changes with stress and perform accurate production forecast. The geomechanical problem with the DPDK can be solved with the constitutive equations for stress and porosity of multiple porosity systems. A fractured reservoir contains different regions in the fracture domain, for example, propped, unpropped, and natural fractures which have different mechanical properties. Our proposed model mathematically represents mapping of mechanical properties in different regions of fracture and matrix domains. In addition, we showed the mapping between a LGR flow system and a non-LGR geomechanical system. We demonstrated a realistic fracture geometry with the A-DPDK LGR system. We validated the numerical convergence of the A-DPDK with LGR by performing grid size sensitivity tests in flow and mechanical grids. The proposed simulation model was applied to oil production from a shale and tight (S&T) reservoir. The proposed simulation approach can model total stress update near fractures more realistically. The new stress and pressure results obtained from the integrated flow and geomechanics workflow allowed us to incorporate stress impact from the depletion of a different bench and the resulting fracture azimuth change. The combination of a LGR flow system and a non-LGR geomechanical system supports reasonable computational time even with two-way coupling simulation, which encourages us to adopt the new simulation approach for modeling oil production and evaluating stress change.
Sanding at Low Oil and Water Flux in Cased and Perforated Wells in Weak Formations
Authors: Xiao Y. , Vaziri H. , Giuliani C. , Guliyev I. 
Published: September 2024

Abstract
Production histories of five cased and perforated (C&P) wells from four oil fields are presented to show that sanding in C&P wells in weak formations is limited and manageable when the oil and water flux is low. That observation is explained through a finite element numerical model that considers the sanding mechanisms at scale. The fluid flux in this paper is defined as the fluid flow rate per foot length of the flow contributing intervals on the sandface and it dictates the fluid viscous drag. A high flowrate well may still have a low fluid flux if its completed and flow contributing intervals are long. Based on the reservoir formation's unconfined compressive strength (UCS) and the average size of individual sand grains (D50), the five wells are categorized into three groups. The Group-1 well has UCS of slightly above 1000 psi and a D50 of 150-250 microns, the Group-2 wells have UCS of 500-1000 psi and a D50 of 150-250 microns, and the Group-3 wells have UCS of less than 500 psi and a D50 of 70-150 microns. Although all those weak reservoir formation intervals disaggregated in the near-wellbore area from the beginning of their production life, there exists an oil-water flux range within which sanding is limited. Given that sanding is triggered once the fluid drag dominated by the viscous drag exceeds the frictional resistance of sand grains, the limited-sanding oil-water flux range increases with D50 as the larger the D50, the higher the frictional properties and the lower the fluid viscous drag. When D50 is below 110 microns, that flux range becomes quite narrow. Also, a sandface gas flow reduces the limited-sanding oil-water flux range, depending on the frictional properties and D50 of sand grains and the gas flux. Those findings are in contrast to a widely held view that sanding in a C&P well in a weak formation with watercut is severe and unmanageable, and thus an active sand control completion is required. The results of this study provide the technical assurance needed to deploy a simpler and more cost-effective non-active sand control completion in low fluid flux wells where an active sand control completion may be economically and/or technically unviable.
Innovative Redefinition of Well Cementing Utilizing Red Mud
Authors: Mahmoud Ahmed Abdulhamid , Elkatatny Salaheldin 
Published: September 2024

Abstract
This research delves into the incorporation of red mud, a by-product of the aluminum manufacturing process, into the cementing of oil wells to bolster the sustainability efforts of the oil and gas sector. A variety of experimental techniques were utilized to mix cement slurries by combining Saudi Class G cement with red mud at a 90/10 ratio. The objective was to assess the viability of utilizing red mud as a sustainable substitute in cement mixtures while ensuring the quality of the final product. The investigation included a comprehensive analysis, adjustments to viscosifying agents, and the addition of retarder, all aimed at achieving a cement slurry with a density of 15.8 ppg. Rigorous evaluations were made on the slurry's rheological characteristics and thickening time. Initial findings suggested that mixtures solely composed of Saudi Class G cement and red mud fell short of industry standards. However, with the precise addition of retarders and viscosifiers, the slurry's performance was significantly improved, meeting the stringent requirements of oil well cementing. These results indicate that red mud can support environmentally sustainable cementing practices without sacrificing performance. Therefore, this study recommends red mud as a sustainable and responsible material for the oil and gas industry, promoting sustainability while maintaining the necessary performance attributes.
Deploy Distributed Real-Time Data Pipelines Across Cloud and Edge to Process Rig Data for Easy Data Fusion and Processing
Authors: Wang A. , Acosta P. , Whitney R. 
Published: September 2024

Abstract
The need for the distributed real-time data pipeline arises from the requirement to process disparate, asynchronous data streams that emanate from edge devices deployed to remote field locations, like drilling rigs, and in the cloud. These data streams need to be combined in real-time to serve advanced analytics applications like Artificial Intelligence (AI) and digital twins. Because of its distributed nature, this data pipeline not only needs to process data but also manage deployment, containers, and physical and virtual computing appliances. Due to this complexity, today's distributed real-time data pipelines are nearly all built as custom software solutions, incurring expensive development costs, long development time, and introducing an extensive maintenance burden. This paper presents a new framework that builds the data pipelines as interconnected, graphical functional blocks in a single software user interface. Each functional block can be assigned to execute in multiple remote locations. Furthermore, each functional block can be parametrized to support unique properties of each rig. This architecture makes it significantly simpler and faster to build, deploy and scale distributed real-time data pipelines while accelerating data engineering and data science projects that require high-speed, high-volume, distributed real-time data.
Unlocking Well Start-Up Uncertainties with Transient Well Flow Modeling
Authors: Descousse A. , Quintero C. G. , Veiga H. , Hastings J. , Kilic A. , Babayeva L. F. 
Published: September 2024

Abstract
The Absheron field is located offshore Azerbaijan in the Caspian Sea about 100km south-east of Baku and 25km north-east of Shah Deniz field, with a water depth of approximately 500m. After a successful exploration well in 2011 and several development studies, production started in July 2023 through an Early Production Scheme (EPS). This EPS consists of a single subsea well, drilled in 2019, and a 35 km insulated production line going to the existing Oil Rocks facilities.
To anticipate the start-up behavior of the Absheron well, Transient Well Flow Modeling simulations integrating the well and the flowline were performed. As such simulations include hydrodynamics (conservation laws for mass, momentum and energy), thermodynamics (fluid description) and thermal exchanges with surroundings (architecture, annulus fluid, rocks…), they enabled the evolution of rates, pressures and temperatures to be predicted for the well ramp-up, in particular to establish the hydrates management procedure. Sensitivities were performed to account for uncertainty on well productivity (from the initial testing and logging data), the wellbore content, chemical injection rates and network pressure.
This paper describes the successful work achieved for unlocking challenging uncertainties of Absheron offshore high-pressure gas condensate well start-up. The various sensitivities performed allowed to properly anticipate well behavior. The simulation of several well start-up sequences based on in-house experience, as well as discussions with local offshore teams in charge of operations, helped in establishing operating guidelines grounded on shared understanding and highlighted the main risks linked to the start-up phases. This therefore facilitated the confirmation of the well ramp-up strategy including the expected pressure evolution both at wellhead and at reservoir wellbore interface, as no rate monitoring was available subsea. This ensured well integrity and effective well production. The criticality of hydrates prevention for this high-pressure gas system was handled by optimizing hydrate inhibitor injection rates and flowline pressure.
The work performed for this well highlights the benefits of integrated and transverse work and modeling through the integration of both well and flowline to establish optimal and flexible start-up guidelines.
MWD and Gyro Survey Tool Quality Management System
Authors: Noy K. A. , Elshabrawy M. S. , Bezemer J. J. , Appelboom R. S. , Albloushi A. M. A. , Al-Ajmi M. F. , Hassan Y. A. , Al-Ajmi S. A. 
Published: September 2024

AbstractThis paper describes a Measurement While Drilling and gyro survey tool quality management system. A first objective of the system is determining a definitive survey, by use of real time quality control parameters. A definitive survey is meant to have a quality that is meeting its theoretical or planned and approved wellbore position uncertainty. Further, field examples of the system application are presented and reviewed. A second objective of the system is delivering a self-contained reference for survey data quality management containing a quality control process, quality control procedures and quality control tolerances.
Enhancing Sustainable Oil and Gas Operations: Produced Water Treatment Using Biological Oxidation
Authors: Shah Karan Dinesh , Conway Bryce 
Published: September 2024

Abstract
In navigating the imperative of sustainable practices, the oil and gas industry faces a growing need for efficient and environmentally conscious produced water management. Challenges in produced water disposal encompass regulatory compliance, environmental considerations, induced seismicity risks, and the pursuit of economically sustainable solutions. There is a compelling need to explore efficient treatment methods that encourage the reuse of produced water while simultaneously providing long-term storage solutions to alleviate the strain on freshwater resources.
Biological oxidation, employing microorganisms to metabolize organic pollutants, has emerged as a promising and sustainable approach for produced water treatment. Applied at the secondary treatment stage, this technology significantly reduces contaminant and suspended solid concentrations post-primary treatment in the tank battery. The aim of this treatment method is to decrease the biological load in the produced water by introducing facultative microbes that prevent the pit from souring and halting H2S production. Additionally, aeration of the produced water impoundment is essential to introduce dissolved oxygen (DO) and enhance the performance of robust microbial strains.
The introduction of aeration proved instrumental in enhancing produced water treatment, facilitating the efficient dispersion of chemical amendments within impoundments through enhanced recirculation and mixing. Biological oxidation treatment resulted in below detection levels (BDL) of H2S, and post-treatment analysis revealed the absence of sulfate-reducing bacteria (SRB) activity, preventing souring in saltwater disposal (SWD) compared to conventional biocide or flop and drop treatments. Key indicators, such as dissolved oxygen and oxygen reduction potential (ORP), crucial for water stabilization, remained consistently stable over a six-month period without requiring further intervention.
The introduced biological oxidation process represents a cost-effective solution for treating produced water from diverse oil and gas extraction operations. A notable advantage is the absence of chemical or polymer sludge residue in the water impoundments, contributing to a cleaner treatment outcome. Beyond immediate benefits, biological oxidation plays a pivotal role in achieving long-term stabilization, fostering an efficient reuse program, and presenting a viable alternative to conventional water disposal methods.
Stimulation Design Improvements for Optimized Well Performance in Shallow Coal Bed Methane Wells
Authors: Pandey Vibhas J. , Flottman Thomas , Ganpule Sameer , Dewar Steven , Renwick-Cooke Tristan , Yang Shuyan , Hage Andrew , McAloon Corey 
Published: September 2024

Abstract
The wells completed in shallow coal seam gas reservoirs of Surat basin, eastern Australia, have been fracture stimulated for more than a decade with ever evolving treatment designs. In a recent fracturing campaign, critical design changes led to improvements in well performance and in mitigating issues related to proppant flow back and fines production. The paper discusses the improvements in treatment designs that helped achieve these favorable results.
The Jurassic age Walloons coal measures present in Surat basin were formed as a part of an extensive intra-continental sag basin where the non-pay interburden is mainly composed of water sensitive layers of mudstones, siltstones and reactive clays that often disintegrate when exposed to non-native water. The wells are completed in multiple stages using coiled-tubing based pin-point stimulation that targets various coal seams with small average thickness of 0.4 m (1.31 ft). The treatment designs are intentionally varied to account for varying stress regimes from normal to reverse stress regime as a function of depth.
The fracture treatment deign improvements were aimed at accelerating dewatering, improving the well performance, and mitigating proppant flowback while remaining constrained on total proppant volumes earmarked for the treatments. The major changes included reduction of pad volume, lowering gel viscosity, increasing maximum proppant concentration, re-arrangement of proppant stages and volumes in pumping schedules, introduction of rate-ramp to contain vertical fracture growth, packing the proppant to generate enough net pressure for consolidation, and dewater/flowback using new guidelines.
The new treatment designs aimed at improving performance successfully demonstrated the need for constant evolution of treatment parameters to counter the challenges observed in the field development process. Often, the solutions to typically occurring problems can be found by altering the approach and testing engineering limits of designs. The approach adopted in this study can be readily implemented on similar completions worldwide.
CFD Modelling of Multiphase Flow in Horizontal Pipe Annulus: Effect of Sweeping Pills on Drill Cuttings Removal
Authors: Aliyeva T. , Czuprat O. , Byrski P. 
Published: September 2024

Abstract
Effective hole cleaning plays a crucial role in drilling operations, especially with the ever-increasing number of deviated and horizontal wells. Sweeping pills are commonly pumped into the annulus to assist in cleaning of borehole from cuttings that have not been removed after the usual drilling fluid circulation. Hole cleaning becomes even more challenging with increasing inclination since the cuttings tend to settle down to the lower side of the annulus due to higher gravity effects.
The sweeping performance of different pills has been studied by taking an advantage of computational fluid dynamics (CFD) approach and subsequently, confronting the results with the outcomes of experimental work conducted previously [SPE 201634]. Multiphase flow simulations have been carried out where varying combinations of pill type, cuttings diameter, and inner pipe rotation were tested to study their influences on the final cuttings recovery. The results obtained from CFD simulations are compared to the experimental ones with the aim of catching the consistencies and discrepancies in the observed flow behaviors. Furthermore, the insights gained emphasize the intricate interplay between inner pipe rotation and the effective suspension & transport of cuttings, shedding light on the nuances that can impact drilling efficiency.
Furthermore, the study offers valuable recommendations for future research directions as well as field implications.