bluuebunny/crossref_metadata_2025_split huggingface dataset:
Backup-Ring Optimization for High-Temperature and High-Pressure Applications Through Dynamic Composition Modification in Composite 3d Printing
Authors: Green J. T. , Rybak I. A. , Glaesman C. 
Published: February 2024

Abstract
Performance optimization was demonstrated in thermoplastic sealing systems for oil and gas equipment using emerging technologies in 3D printing to manufacture multicomponent composite structures. A custom 3D printer was equipped with a patented print head designed for dynamic mixing of individual feed materials and paired with advanced print-planning procedures to enable fabrication of novel thermoplastic structures. Simple flat backup rings used in O-ring sealing connections were manufactured with numerous architectures including homogeneous carbon fiber distributions, consistent with typical commercial processes and products, and novel carbon fiber distributions unique to this study. Specimens were tested in a sealing configuration to determine performance. Backup rings made from polyether ether ketone with uniformly distributed carbon fiber at high concentrations result in lower peak extrusion pressures than do unfilled grades but have the advantage of lower permanent deformation during long periods of steady-state loading. Flat backup rings were produced with discrete regions of each unfilled and carbon filled grades of polyether ether ketone and polylactic acid to optimize extrusion pressure at failure and long-term creep which were found to be dependent on both the volume ratio and orientation of the two regions relative to the primary O-ring seal. Uniform distributions of carbon fiber were outperformed by at least one binary or functionally graded architecture having the same nominal carbon fiber content. This demonstrates the viability of on-demand 3D printing of backup rings and provides a novel means of simplifying multicomponent systems while simultaneously expanding the operating envelope and life expectancy of oil and gas equipment since extrusion resistance and long-term creep in thermoplastic backup systems are major factors influencing service ratings for temperature, pressure, and service life. Innovative technology and methods described in this study enable fabrication of novel composite structures that increase performance when compared to homogeneous materials manufactured through traditional molding processes. In addition to supporting fabrication of sealing components for rapid response in oil and gas equipment, this technique provides a means of improving the overall performance of sealing systems without an increase to the size or complexity of the sealing assembly.
Yielded Zone Characterization While Drilling a Wellbore into Clastic Reservoirs Using Elastoplastic Modeling Approaches
Authors: Hamid Osman , Albahrani Hussain , Suaid Mohammed 
Published: February 2024

ABSTRACT
Drilling a wellbore into a clastic reservoir exhibits complex rock behavior, including plastic deformation and yield zone development, which can affect wellbore stability and hydrocarbon production efficiency. Elastoplastic modeling methods have been increasingly used to simulate the drilling process and predict the location, shape, and size of yielded zones in the reservoir. This study aims to characterize the yielded zones in a sandstone reservoir during a borehole lifetime using elastoplastic modeling approaches. The methodology involves developing a finite element model of the sandstone reservoir using appropriate meshing techniques and boundary conditions definition for the problem. The constitutive model used in this study is the Drucker-Prager yielded criterion, which accounts for the non-linear behavior of the material during plastic deformation and yielding. The numerical method used is the finite element method, which discretizes the reservoir into small elements and solves for the stresses and strains in each element. The drilling process is simulated using incremental loading, miming the gradual application of drilling forces on the reservoir. The stress and strain fields in the reservoir were monitored during drilling, and areas of plastic deformation and yield were identified. The results showed that the elastoplastic modeling approaches used in this study accurately predicted the size, shape, and location of yielded zones in the clastic reservoir. The location and shape of the yielded zones agreed with the field observations.
Additionally, the model predicted the formation of a narrow, highly deformed zone around the wellbore, which is consistent with field observations. The size of the yielded zone depended on the drilling parameters, rock mechanical properties, and in-situ stresses. This study concludes that elastoplastic modeling approaches can be used to predict the size, shape, and location of yielded zones in sandstone reservoirs during wellbore drilling and production operations. The methodology used in this study can be used as a valuable tool for borehole planning and reservoir management. The innovation of this study lies within the use of elastoplastic modeling approaches to optimize drilling parameters and reduce the risk of wellbore instability in sandstone reservoirs. The results of this study can aid in designing drilling strategies that minimize the impact of yielded zones and improve wellbore stability, ultimately leading to increased production efficiency.
Predicting Reservoir Fluid Properties from Drill Cuttings: Application of GPC-UV Method for Reservoir Fluid Analysis
Authors: Yang Tao , Cely Alexandra , Moore Julian , Michael Eric 
Published: February 2024

AbstractDrill cuttings are readily available for all wells we drill. Geochemical analysis has been employed to estimate key oil properties, such as API density and viscosity. However, most studies focus on drill cuttings with water-based mud. Identifying reservoir fluids in highly contaminated drill-cutting samples becomes a significant challenge when drilling wells with oil-based mud. Consequently, there is a high business demand for predicting reservoir fluid properties from drill cuttings with oil-based mud.In 2015, Gel Permeation Chromatography (GPC) coupled with ultraviolet (UV) absorbance detection was introduced in the upstream industry. Elias and Gelin demonstrated the capability of the GPC-UV method to predict API gravity from drill-cutting samples with oil-based mud in unconventional reservoirs. This study extended the GPC-UV approach to conventional reservoirs across multiple fields from the Norwegian Continental Shelf and other global assets. We developed a multiple-wavelength method instead of fixed wavelength detection to explore correlations between GPC-UV detections and reservoir fluid properties.The drill cuttings used in this study are from multiple fields from the Norwegian Continental Shelf and other global assets, where oil-based mud was consistently used for well drilling. Consequently, extracts from these cutting samples are contaminated by oil-based mud. Utilizing the GPC-UV method revealed clear oil peaks with the oil-based mud response appearing on the baseline. Correlating these results with GPC-UV data from stock tank oil samples and known reservoir fluid properties enables qualitative determination of fluid type (gas, oil, or water) and estimation of API from new drill cutting samples.A digital solution based on machine learning, leveraging broad GPC-UV measurements, is needed to improve prediction accuracy further. While ongoing studies aim to establish a comprehensive database of GPC-UV measurements for stock tank oil and drill-cutting extracts, the GPC-UV method demonstrates impressive potential for analyzing reservoir fluids in challenging drill-cutting samples. Given the widespread availability of drill-cutting samples, this new method offers a cost-efficient and accurate means of determining reservoir fluid properties without resorting to downhole measurements or sampling. This method could fulfill the vision of considering "every piece of cutting as a PVT sample," with applications ranging from well placement and reservoir management to production optimization, flow assurance, and plug & abandonment.
Coupling Fluid Flow and Geomechanical Deformation Using AI & FEM Approaches
Authors: Hamid Osman , Almani Tameem , Alqannas Sulaiman , Alshanbari Ghalia 
Published: February 2024

AbstractCoupling fluid flow and geomechanical deformation is a complex and challenging problem in geomechanics and reservoir engineering. The objective of this study is to develop a robust and accurate numerical model for coupling fluid flow and geomechanical deformation using machine learning (ML) and artificial intelligence (AI) techniques in combination with elastoplastic and finite element method (FEM) approaches.The study involves developing an elastoplastic model to simulate the deformation of geologic materials under stress and incorporating fluid flow equations into the model using FEM techniques. The two simulators are coupled sequentially. During every sequential coupling step, the flow simulator sends pore pressures to the geomechanics simulator and receives back updated porosity and permeability values. The frequency of the coupling steps is problem-dependent and subject to further optimization and research. In addition, ML and AI techniques are used to reduce the frequency of the coupling steps, which can lead to substantial computational time savings given the fact that solving the geomechanical model numerically is a computationally intensive task. Furthermore, ML and IA techniques can also be used to optimize the input parameters, improve the accuracy of the model, and reduce overall runtime. The AI-based coupled model is tested against the traditional coupled model to validate the results.The study demonstrates that coupling fluid flow and geomechanical deformation using ML and AI elastoplastic and FEM approaches is a promising area of research that can revolutionize our understanding of complex geological processes. The AI-based numerical model developed in this study provides an efficient and accurate tool for predicting the behavior of geologic materials under stress and can aid in developing more effective strategies for managing natural resources.The use of ML and AI techniques in combination with elastoplastic and FEM approaches provides an innovative and efficient method for coupling fluid flow and geomechanical deformation. The AI-based numerical model developed in this study is a significant contribution to the field of geomechanics. It has potential applications in various industries, including oil and gas exploration, mining, and geothermal energy.
A New Approach for Reducing Sand Production During Water Breakthrough from Semi-Consolidated Sandstone
Authors: Alameen Mohammed B. , Almansour Abdullah , Elraies Khaled A. , Mohyaldinn Mysara 
Published: February 2024

Abstract
It is well recognized that most formations of semi-consolidated sandstone result in significant sand production during water breakthrough. In principle, the amount of sanding mainly depends on the rock strength and, subsequently, the reaction between the injected water and sand formation. Hence, this paper examines the sand (quartz) hydrolysis mechanism during water breakthrough to establish a correlation between silica dissolution and rock strength as a function of water saturation. Static and dynamic experimental approaches were used to correlate silica dissolution and rock strength as a function of water saturation. For the static method, pure quartz fine and coarse particles were utilized at different water compositions and temperatures to examine the reaction between the silica (quartz) and water. Then, selected cases were investigated further as a function of water saturation using a dynamic core flood test. The amount of silica reacted was monitored using a UV-Vis spectrophotometer, while the rock strength was investigated using uniaxial compressive strength. Semi-consolidated and consolidated sandstone core samples were employed for the dynamic tests. Based on the static experiment, the amount of sanding is significantly affected by the water quality (salinity) and pH. Results indicated that freshwater or distilled water has a higher impact on silica dissolution than brine water. Sodium chloride and Potassium chloride have the ultimate effect in silica dissolution in terms of hardness ions. In contrast, pH inconsistently impacts the silica dissolution, and an optimum pH value was selected. For the dynamic experiments, the results showed that an increase in water saturation leads to an increase in silica dissolution, which reduces the core strength. Sand production is, therefore, also a result of silica dissolution, which weakens the grain particles and connection at grain-to-grain contact. In conclusion, the water quality significantly impacts the amount of sand dissolved and the correlation between silica dissolution and rock strength as a function of water saturation was developed. The novelty of this paper is based on understanding the main reasons behind sand production for the semi-consolidated sandstone formation. The finding of this study is helpful in designing the optimum water quality used for water injection while reducing sand production issues.
Study on the Mechanism of Carbonate Formation Strength Degradation Induced by Water-Rock Interaction
Authors: Zhang Dujie , Li Daqi , Jin Junbin , Tu Yulin , Rached Rached 
Published: February 2024

Abstract
The strength deterioration of the wellbore rock induced by water-rock interactions would be an important cause of the delayed instability in the Leikoupo formation located in Western Sichuan Basin, Sichuan Province, China. Taking the carbonate rock sample obtained from the Leikoupo formation as the research object, this study systematically analyzed the composition and the microstructural characteristics of the rock firstly. Then, a series of rock mechanics experiments before and after immersion in deionized water, pH=9, pH=11, and water-based drilling fluid (pH=11.5) was conducted. In order to further analyze the microscopic mechanism, the change in the ion concentrations of the immersed fluid and rock microstructures were analyzed. The results indicated that the Leikoupo formation carbonate rock was mainly limestone with developed micro-fractures. After immersion in alkaline solution, the elastic modulus and compressive strength of the rock decreased obviously. The friction coefficient of the fracture surface decreased as well. The degree of the deterioration became more significant with the increasing solution pH value and the prolonged immersion time. The analysis suggests that the dolomite in the carbonate rock undergone de-dolomitization reaction in high-temperature alkaline solution. It dissolved the micro-protrusions of dolomite on the fracture surface, so as to reduce the surface roughness. The research findings preliminarily reveal that the dissolution-crystallization-expansion mechanism of de-dolomitization reaction was the driving mechanism for the deterioration of carbonate rock due to water-rock interactions, providing a theoretical basis for the development of drilling fluid technology for stable wellbore in fractured carbonate rock formations.
Performance Evaluation of Autonomous Outflow Control Devices in Various Injection Wells, Field Data Review of the Technology Deployments
Authors: Moradi M. , Kvilaas G. F. , Konopczynski M. R. 
Published: February 2024

AbstractThe important role of optimized injection wells has been recognized as a crucial element for optimum field development and enhancing oilfield recovery factors. The functionality of most applied technologies to provide optimum injection conformance has been limited as the properties of injection wells are continuously changing. This paper will present an overview of oilfield production data for using outflow autonomous devices and demonstrate their benefit in various well injection applications by optimizing the well injectivity.The devices have been installed worldwide including in the Middle East, Norway, North America and China. Like other flow control devices, this autonomous device was installed in several zones in wells and has two operating conditions, one as a conventional flow control device, and two, as a barrier when the flowrate through the valve exceeds a designed limit. At the second flow condition, the denied fluid to that specific zone will be distributed among the neighboring zones. This prevents excessive fluid injection into the thief/fracture zones and maintains a balanced fluid distribution across the full targeted injection zone.This paper describes the completion design workflow and field data including injection logging tool (ILT) and DTS and step-rate and injectivity test data when available for the cases.The field results have proven the success of autonomous outflow control devices both in terms of achieving the target injection profile and controlling the thief zones. The objectives of installations include controlling faults, natural and thermal fractures, and high perm zones for injection of water, gas and polymer in both carbonate and sandstone reservoirs. For example, in one well the production logging results from data post and before installation confirmed that the flow control devices were successful in controlling the water injection into the suspected thief zones by 42%. Another example in polymer injection well supported by Distributed Temperature Sensor (DTS) data as well as other surveillance data, it was confirmed that 93% of the anticipated conformance has been achieved and the water cut from the oil producers nearby drastically dropped resulting in less production of unwanted fluid and therefore more sustainable oil production.The paper will provide an elaborate showcase reviewing field data for deployment of autonomous flow control devices in injection wells and evaluate the resulting enhanced well injectivity performance and hence overall field development efficiency. The outflow control device enables operators to deliver optimum water, polymer, acid and gas injection techniques resulting in more sustainable production while avoiding costly and often complex well interventions.
Navigating the Seas of Sustainability: A Study on Maritime Scope 3 Emissions Through Digital Innovation
Authors: Vedat Kris , Neal Benjamin , Eldred Morgan , Sonne-Schmidt Carsten , Suboyin Abhijith , Thatcher Jimmy , Rehman Abdul 
Published: February 2024

Abstract
This case study provides a simplified overview of Scope 3 emissions within industry, focusing on a global offshore logistics provider. With total emissions from offshore logistics projected to increase by 250% by 2050 as per IMO, reducing emissions without impacting productivity and operational efficiency is a key challenge.
The assessment used industry-standard methods and procedures and involved a thorough process of data collection and analysis. This includes leveraging industrial data to conduct preliminary analysis and estimations. The detailed calculations were also based on assumptions and emissions factors from various sources such as GHG Emissions Calculator, IEA, US EPA, ICCT, IMO, and ORR. The comprehensive assessment included emissions from its supply chain to end use of sold services. Categories include purchased goods and services, capital goods, fuel and energy-related activities, upstream transportation and distribution, waste generated in operations, business travel, employee commuting, upstream leased assets, downstream transportation and distribution, processing of sold products and use of sold products.
The company found that its Scope 3 emissions accounted for a significant portion of its overall GHG footprint, and identified several key areas where emissions reduction efforts could be focused. These areas included optimizing shipping routes, improving the energy efficiency of its vessels, and collaborating with suppliers to reduce emissions across the supply chain. These optimizations combined can lead to significant reduction (12 – 25%) in environmental impact in long term along with savings in costs, time, and even potential application in other industrial operations. The findings of this study can assist entities to identify its major emission sources and develop strategies to reduce its carbon footprint.
Our case study offers a simplified overview of Scope 3 emissions, with calculations for each category, aimed at enhancing understanding of emissions categories and calculations for Scope 3. The findings can benefit policymakers and regulators by highlighting areas where offshore logistics can focus their efforts to reduce their Scope 3 emissions.
Water Saturation Profile Analysis and Modeling: Case Study in a Tight Carbonate Reservoir
Authors: Mukhtar Sardar Owais , Khan Mohammad Rasheed 
Published: February 2024

Abstract
The complexity in carbonate reservoir evaluation stems from their intricate pore topology and mineralogical classifications. Classical approach to determine fluid distributions is through resistivity logs, however, this is marred by drawbacks as the resultant water saturation (Sw) can sometimes exhibit a profile that has limited to no usage as it is modeled with porosity and lithological volumes only. Significant uncertainties in Sw calculations from logs in heterogeneous tight carbonate rocks combined with the difficulties in measuring reliable pressure gradients, render the interpretation of transition zones and free water levels challenging. This case study describes the integration of limited core capillary pressure (Pc) measurements, formation pressures, conventional and Nuclear Magnetic Resonance (NMR) logs to define a saturation height model that explains the Sw profiles of a tight gas carbonate reservoir.
The log derived Sw and its associated uncertainty have been computed using input logs and electrical parameters from cores. The NMR log is at the center of the saturation modeling. It integrates the pore size distribution into a synthetic Pc, establishes the irreducible water saturation by adjusting a variable T2 cut-off, and defines a permeability transform adjusted to core data and adapted for wells with conventional logs data only. The pressure gradients analysis, core and synthetic Pc and the petrophysical properties determined from logs have ultimately been combined to define a Saturation Height Function (SHF) for all the wells.
The Sw profiles and the differences in free fluid level positions between the wells cannot be explained by structural or stratigraphic compartments. The assumption of undisturbed initial saturation conditions has been questioned, and further supported by the initial pressure data that could involve earlier production from nearby field. The porosity permeability and Swi estimation from logs are coherent with core data including routine and special core analysis. A key observation was the mismatch of transition zone from core Pc data relative to the Sw profile and Free Water Level (FWL) from gradient analysis; therefore, Sw profile is believed to be more reliable. Uncertainty in Sw calculations exists at high Sw, however, it seems that residual gas exists below the "current" FWL. Moreover, GWC in some wells cannot be explained with the existing reservoir compartmentalization.
This study reveals how the analysis and modeling of the Sw profile can change the understanding of reservoir compartments and field history and have significant impact on its development. A major concern highlighted is regarding those fields having wells at original saturation conditions as if there is a common deeper FWL and variable swept areas leading to different contacts. Finally, relating poro-perm rock typing to lithofacies association and depositional environment can be advanced through core descriptions and thin sections.