bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Practical Framework for CO2 Transportation and Injection Design by Analyzing Both Technical and Economic Aspects
Authors: Duong Hao , Nguyen Tan C. , Pham Duc Chi , Nguyen Tang , Al-Safran Eissa M. 
Published: September 2024

Abstract
The main objective of this research is to propose a practical framework for CO2 transportation and injection design by analyzing the impact of pipeline length and mass flowrate on cost-effective aspects. Numerical methods are applied using experimental data of CO2 properties at different pressures and temperatures to provide the most accurate model designs for CO2 transporting and injection considering both technical and economic aspects. This paper used an open-source coding language to integrate the physical and thermodynamic properties of CO2 into software to predict phase behavior, viscosity, density, entropy, etc. under different pressure and temperature conditions. This simulator was then expanded using advanced hydraulic models to predict static and dynamic behaviors of CO2 in pipelines and tubing with and without booster pumps. Sensitivity analysis was carried out to study the effects of pipeline length, mass flowrate, and the number of booster pumps on the economic aspect of CO2 transportation and storage. A case study was performed using the developed computational model to optimize a hypothetical CO2 transportation system in the Permian Basin to minimize the CO2 project's cost. The obtained results showed that using the developed computational simulator for designing CO2 transportation and injection provides more reliable prediction for pressure and temperature profiles without using correlations for CO2 properties. The sensitivity analysis reveals that the number of booster pumps and pipe diameter are the two key variables in designing a CO2 transportation and storage system. The next sensitive variables are the mass injection rate and the pipe length. The results from the case study showed that there is no universal design solution when it comes to CO2 transportation and storage design; instead, each project must be tuned and optimized accordingly by varying all the inputs. The developed software can help optimize CO2 transportation based on a specific desired system with a specific desired injection rate.
Utilizing Green-Carbon Nanotubes to Improve Drilling Fluids Rheological Properties: An Experimental Study
Authors: Musa T. A. , Mohamed E. S. , Challiwala S. M. , Elbashir N. O. 
Published: September 2024

Abstract
A revolutionary technology for turning carbon dioxide into useful products, known as CARGEN®, has been developed at Texas A&M University. The technology features a setup of two reactors linked together, providing a special chance to transform two greenhouse gases, namely methane (CH4) and carbon dioxide (CO2), into environmentally friendly carbon nanotubes (GCNTs) and syngas. This research looks into how the newly produced green CNTs affect the flow characteristics of different kinds of water-based drilling fluids, including bentonite mud and brine mud.
Various amounts of carbon nanotubes (0.05 w/v %, 0.1w/v %, 0.15 w/v %, and 0.2 w/v%) were tested experimentally to see how they affect the flow characteristics of bentonite mud and brine mud (NaCl). The comparison of properties like plastic viscosity (PV), yield point (YP), and gel strength (GS) was made between the drilling fluids with carbon nanotubes and their control fluids using a rotating viscometer. The tests were carried out at temperatures ranging from 73°F to 200°F. Polyvinyl pyrrolidone (PVP) was employed for GCNT dispersion.
The findings show that adding GCNT to water-based drilling fluids changes their rheological properties. For bentonite mud, the PV increased by 13% at 0.05 w/v % GCNT and stayed the same at higher concentrations at room temperature. At higher temperatures (120°F and 150°F), the PV increased with more GCNT, but then decreased at 0.2 w/v %. For brine mud, the PV decreased with more GCNT at higher temperatures, but the GCNT improved the PV more than the control mud, showing better thermal stability. The YP and GS also improved with more GCNT, especially at higher concentrations. These results suggest that GCNT have a significant role in improving the performance and stability of water-based drilling fluids in drilling operations.
This research offers valuable insights into the potential use of carbon nanotubes in improving the performance and stability of drilling fluids, contributing to more sustainable industrial practices.
Blockchain Technology in Energy Storage Systems
Authors: Tirmizi Syed Talha , Hussain Aliza , Ali Syed Imran , Louis Clifford , Ul Haq Tirmizi Syed Rizwan , Lalji Shaine Mohammadali , Malik Adan , Arfeen Zeeshan Ahmad 
Published: September 2024

Abstract
Block-chain technology has garnered significant interest across many industries including energy industry. This paper discusses the role of block-chains in advancing the energy storage systems. Energy storage technology plays an important role to ensure the stable supply of energy and promote widespread application of renewable energy technologies. However, the traditional methods do not unlock the full potential of energy storage facilities due to the lack of energy storage sharing mechanism and misallocation of energy demands and resources. Block-chain-enable energy management system can significantly improve the security, reliability and efficiency of the energy storage systems using a decentralized system with transparency and audibility.
Improving Reliability of Seismic Stratigraphy Prediction: Integration of Uncertainty Quantification in Attention Mechanism Neural Network
Authors: Ang C. T. , Elsheikh A. H. 
Published: September 2024

Abstract
Despite technological advancement, subsurface studies continue to encounter uncertainties caused by structural complexities and data noise, which can result in inaccurate seismic interpretation and drilling locations. Although machine learning holds great potential by enabling the simultaneous analysis of large datasets, its effectiveness is often compromised by data noise and ambiguity, which can degrade the accuracy of the algorithms. Hence, this research incorporates uncertainty quantification into attention mechanism neural network to produce more reliable outcomes in seismic interpretation and stratigraphic mapping. The methodology is also benchmarked against other uncertainty quantification methods such as dropout and randomized ensemble techniques, followed by an evaluation using the Brier score.
Application of Drag Reducer Agents on Multiphase Production Fluids
Authors: Fruteau A. , Lesage N. , Arnault R. , Drouilly C. 
Published: September 2024

Abstract
This paper presents three field cases that aim to demonstrate the efficacy of modelling in predicting potential gains in pressure drop reduction and identifying process issues associated with the injection of Drag Reducing Agents (DRAs). Simulations demonstrate the performance of DRAs and their impact on flow dynamics in multiphase flow systems were evaluated. The modelling approach allows anticipating pressure drop reduction and provides valuable insights into potential process challenges that may arise during DRA injection.
Simulations results reveal promising opportunities for substantial gains. The simulations demonstrate significant potential for reducing pressure drop in complex fields with high water cut rates, among other challenges, thereby enhancing operational efficiency through the implementation of DRAs. Additionally, the modelling approach facilitates the identification of potential process issues.
In conclusion, this study exemplifies how modelling can accurately predict gains in pressure drop reduction and effectively identify process issues associated with DRA injection. The results highlight the potential for achieving gains in multiphase flow fields that have not yet been extensively studied, providing valuable insights for the application and optimization of DRAs in multiphase systems.
Assessment of Protentional Underground Carbon Dioxide Storage in Post Heavy Oil Eor Phase Through Steam, Solvent, or Hybrid Injection: A Field Case Study
Authors: Chai Maojie , Nourozieh Hossein , Chen Zhangxing , Yang Min , Hernandez Andres 
Published: September 2024

Abstract
The Paris Agreement aims to limit global warming to well below 2°C and pursue efforts to limit it to 1.5°C above pre-industrial levels. In response to the Paris Agreement, carbon dioxide storage, also known as carbon capture and storage (CCS), is a critical part of efforts to mitigate climate change in response to the Paris Agreement. Canada has abundant heavy oil resources, but to recover this immobile liquid, hot water or solvents are often injected underground as a heat carrier (SAGD) or dilution (VAPEX) or hybrid (ES-SAGD) to mobilize the heavy oil. However, these processes often result in energy losses and CO2 emissions. Thus, how to effectively treat the produced carbon dioxide seems to be an economic and environmental problem especially under the context of the Paris Agreement and the increasing carbon tax in Canada. To address the urgent problem, this study first establishes the SAGD, warm VAPEX, and solvent-based ES-SAGD process through numerical simulation. Then carbon dioxide is injected underground in the post EOR phase. In steam-based technology (SAGD or ES-SAGD), water is used as an excellent heat carrier to inject underground to displace heavy oil, The left water underground forms an excellent dissolution trapping barrier for carbon sequestration. In solvent-based technology (ES-SAGD or VAPEX), carbon dioxide produced by heating can not only be injected for underground storage in reducing the environmental impact, but also can recover the underground solvent from gas, oil and even water phases further reducing the cost of solvent-based technology. The outcome of this research not only provides potential for carbon sequestration from post-EOR activities, but also supports the transformation of Canada's heavy oil industry towards more solvent-based methods, resulting in economic and environmental benefits.
The Behavior of Microemulsion in Unconventional Reservoirs: Insights from Molecular Dynamics Simulation
Authors: Xiong Hao , Devegowda Deepak , Yuan Na , Hu Zeming 
Published: September 2024

Abstract
The use of microemulsions to enhance well productivity is becoming increasingly popular, especially in unconventional shale wells during fracturing. However, the subsequent behavior and stability of microemulsions remain unclear, particularly in clay-hosted nanopores where clay minerals have unbalanced surface charges. This study uses molecular dynamics (MD) simulations to analyze the behavior and stability of microemulsion droplets in clay-hosted nanopores with varying surface chemistries and salinities in shales, under typical reservoir pressures and temperatures. Our results show that in bulk conditions, microemulsion droplets are stable across all salinities. However, their stability in clay-hosted nanopores depends on the surface chemistry (charge distribution) of the clays and the salinity. When clay surfaces are charge-balanced or have a moderate imbalance, the droplets remain stable. In contrast, a strong charge imbalance creates local electric fields in the slit pore that disrupt the microemulsion droplets. Increasing salinity forms an electrical double layer that reduces the strength of the electric field, thus maintaining the stability of the droplets. This modeling-based study improves our understanding of how salinity variations affect microemulsions in charged clay-hosted nanopores. Significantly, this is the first study to combine and assess the sensitivity of microemulsions to both salinity and pore surface chemistry, opening new possibilities for the effective delivery of EOR agents to shales.
Multiscale Non-Equilibrium Compositional Modeling of Cyclic Gas Injection in Shale Reservoirs
Authors: Ma Ming , Emami-Meybodi Hamid 
Published: September 2024

Abstract
The shale matrix is a multiscale porous medium featuring nanopores, macropores, and micro-fractures, exhibiting distinct transport mechanisms and phase behaviors. This study challenges the assumptions of local thermodynamic equilibrium within each matrix grid and recognizes the significant discrepancy in time scales of fluid transport within nanopores and macropores. This disparity leads to non-equilibrium mass transfer between these distinct scales of pores. Accordingly, we propose a multiscale, multiphase, multicomponent transport model for simulating cyclic gas injection in shale reservoirs while accounting for non-equilibrium thermodynamics in the shale matrix. The multiscale porous media encompasses nanopores, macropores, and micro-fractures. The fluid transport within the nanopore and macropore is modeled using a species transport-based equation, incorporating viscous flow, molecular diffusion, and Knudsen diffusion. Darcy's law is applied in micro-fractures and hydraulic fractures. Phase behaviors in nanopores are computed employing a pore-size dependent Peng-Robinson equation of state (PR-C-EOS), while the PR-EOS governs other porous mediums. Non-equilibrium mass transfer between each pair of porous mediums is derived based on multiple interacting continua (MINC) theory. We simulate the cyclic CO2 injection with a ternary component oil—methane, propane, and n-octane—within a shale matrix. Sensitivity analyses are conducted to analyze the effect of soaking time, natural fracture (micro-fracture) permeability, and pore volume fraction on CO2 cyclic injection enhanced oil recovery (EOR). During the injection phase, CO2 rapidly fills the pore volume of natural fractures and then transfers to macropores and nanopores via non-equilibrium mass transfer. Even during the soaking period, when CO2 injection ceases, non-equilibrium mass transfer continues to significantly change the fluid composition within these continua. Increasing the soaking time remains an effective method to improve oil recovery. A longer soaking period allows more CO2 to move into macropores and nanopores through non-equilibrium mass transfer, thereby promoting CO2 mixing with crude oil. In addition, CO2 cycle injection is an effective method for increasing oil recovery across all volume fractions. Nevertheless, enhanced oil recovery is greater when the macropore volume fraction is higher, primarily because CO2 can be injected more easily into macropores and mixed with the oil. Such a multiscale transport model facilitates a comprehensive understanding of the gas EOR mechanism and provides a valuable framework for designing effective EOR methods for shale reservoirs.
Field Study of the Condensate Banking Effect in an Unconventional Gas Condensate Reservoir with Hydraulically Fractured Wells
Authors: Yin Jichao , Li Han Jake , Ruidiaz-Santiago Cyd Marie , Nguyen Huy , Senior Peter , Raba Osama , Esmaili Soodabeh , Xie Xueying , Liu Shunhua 
Published: September 2024

Abstract
As unconventional assets mature, gas condensate reservoirs are increasingly being targeted for development. However, gas condensate reservoirs are prone to wellbore productivity losses due to a two-phase flow caused by condensate banking when pressures drop below the dewpoint. Conventional reservoir mitigation strategies minimize condensate banking by maintaining flowing bottomhole pressures close to dewpoint pressures. However, using this approach with unconventional reservoirs raises concerns, as primary depletions and hydraulic fractures in long horizontal wells make maintaining dewpoint pressures implausible. Therefore, to provide a more effective mitigation solution for optimal field development, the severities of unconventional well condensate banking must be reevaluated.
This paper investigates condensate banking effects on well performance by conducting field modeling studies on Delaware Basin deep Wolfcamp condensate producers using compositional simulation models with hydraulic fractures. Three-dimensional (3D) geologic models were constructed based on facies distributions. Fracture models were based on high-fidelity geomechanical models. A 11-component Equation of State (EOS) model was calibrated using a pressure/volume/temperature (PVT) sample. Full field reservoir simulation models were built to match well pressure and production rates.
The models found condensate banking to be of minimal concern, as condensate dropped out mostly in fracture networks and could be efficiently produced through highly conductive fractures. An optimal development plan with an aggressive flowback strategy, validated by actual Permian Basin gas condensate well performance, is therefore proposed, which should improve the project value without a condensate banking risk.
Comparative Analysis of Microbiological Testing Technologies Used in the Energy Industry
Authors: Taylor N. M. , Walker A. , Nicoletti D. , Po K. , Goldsmith C. , Gieg L. M. , Demeter M. 
Published: September 2024

Abstract
Within the energy industry, there are several technologies used to quantify microbiological contamination of fluids and assets. Some of these technologies can also be used to identify or characterize microorganisms of interest. It is important to understand the scope of detection and limitations of individual assays so that accurate, data-driven decisions can be made.
Three fluids varying in chemical composition and origin within the energy sector were tested in this study. Serial dilution for detection of acid producing bacteria (APB) and sulfate reducing bacteria (SRB), activity-reaction tests measuring SRB, an assay quantifying bacterial hydrolases, and adenosine triphosphate (ATP) quantification were compared and assessed against molecular microbiological methods (MMM). Data were collected to determine the ease of use, precision, and comparability of the testing technologies to each other. A kill study using organic biocides evaluated the performance of these tests in quantifying changes in the microbiological populations over time.
The testing technologies delivered results on the order of minutes (ATP and enzymatic assays) to days (activity-reaction tests and MMM) to weeks (serial dilution). Comparing data from 1stgeneration ATP and the bacterial hydrolase tests to the data generated by the other technologies proved challenging due to the lack of reference standards and equivocal nature of the raw output from those technologies. A relatively high limit of detection was determined for 1st generation ATP technology in fluids where the bioburden was estimated below 104 cells/mL. Interpretation of results in culture-dependent activity-reaction tests was found to be subjective, requiring users to distinguish between visual indicators to estimate bioburden. This was further confounded when testing fluids for industrial uses that have complex mineral content and turbidity. The choice of culture-dependent technology to enumerate SRB resulted in up to 3-log SRB/mL variance compared to other tests. Variable responses of assayed biomolecules to chemical treatment (e.g., biocide) were notable in the kill study, where the choice of testing technology impacted the interpretation of biocide effectiveness.
Accurate evaluation of microbiological contamination is essential to operational decision-making in the energy industry. Understanding the strengths and limitations of different testing technologies ensures optimized chemical treatments, reduced costs, and improved environmental outcomes.
Deepwater Open Water Work Drilling Optimization
Authors: Lafferty C. , Thomas J. , Rashid A. , Fazal A. , Kudlaev I. , Rawlins S. 
Published: September 2024

Abstract
The use of motorized rotary steerable system (RSS) and advanced measurement-while-drilling (MWD) tools optimized the open-water work (OWW) scope of deepwater drilling operations in Guyana. The objective was to improve drilling efficiency, reduce slide mode drilling, and enhance directional control. While similar BHAs had been used in vertical wells in the Gulf of Mexico, their application in the challenging OWW scope in Guyana was a novel endeavor.
To overcome the limitations of the standard bottomhole assembly (BHA), a novel approach was adopted, incorporating a 26-in. rotary steerable system, straight mud motor, and advanced MWD for dynamic surveying. Detailed planning and tool selection, including RSS and motor tendencies analysis, were crucial for establishing initial motorized RSS BHA design. Ten out of fourteen planned wells used motorized RSS BHA, while the remaining four employed a motor and gyro due to anticollision concerns. The study involved optimizing BHA configuration, drilling parameters, and survey acquisition processes to enhance performance.
The implementation of the motorized RSS along with advanced MWD tools led to significant improvements in deepwater drilling operations in Guyana. A 75% improvement in drilling efficiency was achieved compared to previous conventional drilling assemblies. The use of the motorized RSS BHA design resulted in the elimination of slide mode drilling, enabling directional objectives to be met more effectively. The average 26-in. section drilling time was reduced by 18 to 28 hours per well. This method allowed for better control and reduced borehole tortuosity, ultimately improving well performance. The success of this approach has now become the standard for future OWW campaigns in the region.
Apart from the enhancement in drilling efficiency, this case study has not only pinpointed solutions to overcome directional challenges but has also paved the way for the industry to attain higher inclinations in top hole. This achievement, in turn, addresses challenges encountered in intermediate and production sections by facilitating the creation of smoother catenary curves and delivering less tortuous boreholes. The implications extend to the realm of production and completion, providing a foundation for more streamlined processes and improved precision in the installation of production and completion components.
Experimental Investigation on CO2-Sensitive Gel-Type Sealant for Sealing Leaky Carbon Sequestration Wellbores
Authors: Anwar Ishtiaque , Meng Meng , Carey J. William , Gilbertson Robert , Zandanel Amber , Himmelberg Nevan , Zhang Weicheng , Tao Emily , Neil Chelsea , Nair Rajesh 
Published: September 2024

Abstract
Potential upward leakage of CO2 and reservoir fluid within a leaky sequestration well poses potential environmental and economic risks. This study explores the latest methods for fixing wells in challenging situations where CO2 is present. An in-depth series of tests was carried out to examine how a special methyl methacrylate-based gel, modified to react to CO2, behaves and functions in carbon capture areas. The experiment looked at how much the gel expanded over time using laser profilometry to measure its growth under various conditions. The study also measured the gel's properties and its ability to seal when there was no CO2 present by comparing the behavior of different concentrations of sealant. Tests using thermogravimetric analysis and thermo-stability measurements were carried out to understand the sealant's reactions at higher temperatures, as well as carbon dioxide leak tests under downhole conditions, were also part of the research. The study found that the gel's effectiveness in sealing wells is influenced by several factors including exposure time, concentration of gel (monomer), substance used to trigger the reaction (CO2, for instance), and temperature. The research demonstrated that the gel-based sealant was able to expand up to 20 times its original size when exposed to CO2 and moisture. Additionally, the sealant showed a high capacity to resist, maintain its structure, and work at high temperatures (up to 140°C) and CO2 pressure (approximately 1550 psi). Moreover, experiments suggested that the sealant naturally formed a seal with CO2 over time, reducing the chance of leaks and completely stopping them at the right concentration.