bluuebunny/crossref_metadata_2025_split huggingface dataset:
Injection of Flue Gas Improves CO2 Permeability and Storage Capacity in Coal: A Promising Technology
Authors: Vega-Ortiz Carlos , Panja Palash , McPherson Brian J. , McLennan John D. 
Published: September 2022

Abstract
Swelling of coal thus reducing permeability is the main detrimental for any carbon dioxide (CO2) capture and storage (CCS) projects. Additionally, CO2 capture from flue gas or direct air is an expensive process. The current commercial simulators are impaired of combining various effects such as fluid segregation, adsorption, Darcy's flow, and permeability change in coal. The objective of this study is to develop a numerical model to simulate flue gas injection in coal. The study is motivated by encouraging preliminary results from lab-scale experiments of injection of flue gas (ideally a mixture of Nitrogen and CO2) in coal.
Bench-scale experiments demonstrated the swelling reduction caused by the selective flow of surrogate flue gas N2-CO2 mixture, based on the fluid stratification at sub-critical conditions where the density of pure components in a vertical container causes stratification as predicted from the Grashof number and the thermodynamic properties of fluids. The numerical simulation aims to reproduce and upscale the results from bench-scale Darcy experiments performed in subbituminous coal flowing pure species and mixture of CO2 and N2 at in-situ conditions. A thorough review of the material balance equations coupled with geomechanical stresses and adsorption mechanisms is observed and implemented in a Newton-Raphson model.
The stratified fluid in the vertical column is injected in batches onto the coal sample at reservoir conditions producing a cyclic flow of CO2-rich mixture, followed by a N2-rich phase. The repetitive cycles of batch pumping of the stratified CO2-N2 mixture allow the periodic adsorption and desorption interactions, maintaining a high permeability compared to the reduced flow of pure CO2 and the CO2 adsorption in the coal matrix regulated by its partial pressure. Pure CO2 flow in coal resulted in a permeability reduction from 3 to 0.1 mD. The novel optimized CO2-N2 mixture flow ensures an average permeability of 2 mD, while preserving 70% of the maximum CO2 storage capacity.
Carbon dioxide storage (CCS) in a suitable geologic setting such as unmineable coal seams are getting research attention for fighting global warming. The model provides important guidelines for the optimization of CO2 capture storage (CCS) in coalbed based on novel strategy of flowing a surrogate flue gas N2-CO2, minimizing the coal swelling due to the adsorption mechanisms, and consequently maintaining a high permeability, while ensuring adsorption and consequently permanent storage of CO2.
The proposed methodology offers not only to improve permeability of coal, but also considers the possibility of injecting flue gas mixtures from combustion processes, reducing considerably the cost of surface facilities for CO2 treatment prior to injection. The successful implementation of this technology could potentially solve the problem of global warming at a low-cost process of injection and storage of CO2.
Fluid-Pipe Interaction in Horizontal Gas-Liquid Flow
Authors: Porter Kyle , Pereyra Eduardo , Mesa Jose , Sarica Cem 
Published: September 2022

Abstract
In recent years, internal, two-phase, flow-induced vibration (FIV) has received elevated attention in various fields while assessing piping system fatigue life. Regarding the oil and gas industry, in particular, assessing FIV impact is essential for ensuring the integrity of flow lines, both onshore and offshore.
This study conducted a series of experimental tests at various superficial gas and liquid velocities to investigate the effects of flow parameters on the structural dynamics of a horizontal 6-inch ID polycarbonate test section. The relationship between flow characteristics and the structural response was examined in detail. A novel methodology was developed and implemented to achieve non-intrusive, simultaneous measurement of pipe motion and liquid distribution.
The presented results reveal that downward deflection generally decreased with increasing superficial gas velocity and increased with increasing superficial liquid velocity. It was also found that as superficial gas velocity increased, the range of frequencies experienced by the test section increased, with increased participation from higher frequencies in the range. Film and slug body liquid holdups are strongly related to the observed deflection amplitudes.
Team Coaching in Oil and Gas
Authors: Solway Martin Edward 
Published: September 2022

Abstract
With teams becoming a more critical element, tasked to deal with ever changing scenarios, while operating in increasingly complex environments, this research looks at the role of team coaching in the oil and gas industry. Whether it is being used today and how as an intervention it can help with the current and future challenges the industry faces.
The research was centred around answering three questions:
Where is team coaching being used today in the oil and gas sector and how effective has it been on increasing team performance? What challenges or desires does the industry have, where team coaching could help? How can the industry more widely adopt and implement effective team coaching?
Solway (2021)
To help answer the questions posed, data was collected from a range of sources including a questionnaire and interviews with Human Resources Leaders, Business Leaders, and Coaches (Solway, 2021). Public third-party data was used from the main coaching bodies. The findings suggested a significant percentage of the participants have used team coaching in some form. However, apart from senior leadership teams, other team-based activities such as team facilitation were found to be the predominate form of intervention, perceived as team coaching (Solway, 2021).
Three themes emerged from the findings. These included a need for defining what is team coaching and how it can add value to the oil and gas industry; identification of some of the key challenges where team coaching can potentially help; and a focus on operations and how team-based activities are used today (Solway, 2021). An industry specific definition for Team Coaching was offered, along with a team coaching model, specific to oilfield operations teams.
A Deep Learning Formation Image Log Classification Framework for Fracture Identification – A Study on Carbon Dioxide Injection Performance for the New Zealand Pohokura Field
Authors: Katterbauer Klemens , Qasim Abdulaziz , Al Shehri Abdallah , Al Zaidy Rabeah 
Published: September 2022

Abstract
We have presented a new deep learning framework for the detection of fractures in formation image logs for enhancing CO2 storage. Fractures may represent high velocity gas flow channels which may make CO2 storage a challenge. The novel deep learning framework incorporates both acoustic and electrical formation image logs for the detection of fractures in wellbores for CO2 storage enhancement and injection optimization. The framework was evaluated on the Pohokura-1 well for the detection of fractures, with the framework exhibiting strong classification accuracy. The framework could accurately classify the fractures based on acoustic and electrical image logs in 98.1 % for the training and 85.6 % for the testing dataset. Furthermore, estimates of the fracture size are strong, indicating the ability of the framework to accurately quantify fracture sizes in order to optimize CO2 injection and storage.
Validation of a Novel Beta Diversion Design Factor for Enhancing Stimulation Efficiency Through Field Cases and Near Wellbore Diversion Model
Authors: Almulhim Abdulrahman , Khan Abdul Muqtadir , Hansen Jon , Alobaid Hashem , Emelyanov Denis 
Published: September 2022

Abstract
The design of fracture diversion in tight carbonates has been a challenging problem. Recently, a conceptual and theoretical workflow was presented using a β diversion design parameter that uses system volumetric calculations based on high-fidelity modeling and mathematical approximations of the etched system. A robust field validation of that approach and near-wellbore diversion modeling was conducted to extend the application.
Extensive laboratory and yard-scale testing data were utilized to realize the diversion processes. Fracture and perforation modeling coupled with fracture diagnostics was used to define system volumetrics, defined as the volume where the fluid needs to be diverted away from. Multimodal particulate pills were used based on a careful review of the size distribution and physical properties. Bottomhole reactions and post-fracturing production for multiple wells and 100 particulate pills were studied to see the effect of the β factor on diversion and production performance. A multiphysics near-wellbore diversion model was used for the first time to simulate the pill effect.
Representative wells were selected for the validation study; these included vertical and horizontal wells and varying perforation cluster design, stages, and acid treatments. A complex problem was solved with reaction modeling coupled with near-wellbore diversion for the first time based on given lithology and pumped volumes to match the treatment and diversion differential pressures. Final active fractures and stimulation efficiency were computed through etched geometry. The results showed a range of etched fracture length from 86 to 109 ft and width of 0.05 to 0.08 in. A similar approach was used for perforation system analysis. Diversion pills from 2 to 15 per well were investigated with a 5- to 12-bbl particulate diversion pill range. Finally, the β factor was calculated for each case based on the diversion material and system volumetric ratio. The parameter was plotted against the average diversion pressure achieved and showed an R2 of 0.87. Based on the comprehensive theoretical, numerical modeling, and field-coupled findings, a β factor of 0.8 to 1.0 is recommended for optimum diversion and production performance. For multiple cases, stimulation efficiency and production performance have been enhanced up to 200%.
From the field results, it is evident that the design of near-wellbore diversion needs to be strategic. The unique diversion framework provides the basis for such a well- and reservoir-specific strategy. Proper and scientific use of diversion material and modeling can lead to advances in overall project management by optimizing the cost–efficiency–quality project triangle. Digital advancements with digitized cores, fluid systems, and advanced modeling have significant potential for the engineered development of tight carbonates.
The Importance of Early Investments in Local Content: Lessons Learned from Guyana's Enterprise Development Centre Five Years in
Authors: Scott Susan , Gaskin-Peters Natasha 
Published: September 2022

Abstract
Enterprise Development Centres (EDCs) have emerged as a best practice in building local content and capacity and driving economic development in emerging economies. In 2017, prior to Final Investment Decision (FID) of any oil field, ExxonMobil Guyana launched the Centre for Local Business Development (The Centre) in Guyana, managed by DAI Global. This early investment was key to show ExxonMobil's commitment to optimizing local content. The Centre's early mission was to build local competitiveness and support Guyanese businesses in accessing opportunities in the emerging oil & gas sector through capacity building, training, awareness and education.
This paper looks at lessons learned five years into the operation of the Guyana Centre for Local Business Development. The objective is to help identify learnings that can be shared with other similar institutions and economic development programs to support implementation of successful strategies especially in relation to supply chain development. This paper focuses on the evolving mission of the Centre from training towards more mentorship of the local supply chain and the process of this evolution and lessons learned along the way. Further, the paper will use empirical findings over the last five years to show the importance of early investments in the supply chain and how this helps to support a growing and evolving economy.
What's the Best Way to Stabilize Oil in the Permian? An Examination of Different Facilities Layouts
Authors: Chan Isabel , Baaren Sander , Sarcletti Anthony 
Published: September 2022

Abstract
Operators in the unconventional shale oil space are becoming increasingly focused on methods to reduce emissions, mitigate issues due to NGL production, increase sales oil production, and increase safety. Moreover, for facilities to operate unmanned facility designs are required to be simple and robust.
Each facility configuration optimizes for a different utility: some allow more flexibility for the economic investment, while others offer familiarity of operation. The option that adds the most flexibility per dollar invested focuses on low-pressure separation with simultaneous heat introduction with minimum necessary storage tanks.
Three different facilities are compared utilizing hydrocarbon recovery, NGL production, gas production, compression power, and Reid Vapor Pressure as key metrics. The three layouts include: a heater treater, a vapor recovery tower, and a novel elevated heated separation design that combines the utility of a heater treater and vapor recovery tower.
The novel low-pressure stabilization system allows for stabilized oil to be pumped either to storage tanks or directly to the custody transfer point. Emissions stemming from tank vapor and tank vapor management systems are avoided as the oil is stabilized before entering the storage tanks or being transported directly to custody transfer.
The novel system can be scaled for higher production rates seen at central processing facilities where traditional equipment such as heater treaters would require operating several parallel production trains. The novel design avoids known operational safety and maintenance issues regarding direct fired heaters and tanks; thus, improving safety and operational cost.
Existing facilities designs include equipment such as direct fired heater treaters, inline heat exchangers, vapor recovery towers and tanks. The results from all process simulations and operational data is summarized in an overview comparing the performance of the various facility designs.
A Semi-Analytical Model for Water Injection Wells in Tight Reservoir Considering the Multi-Dynamic Closure Phenomenon- Case Studies in X Oilfield, China
Authors: Wang Zhipeng , Ning Zhengfu , Guo Wenting , Cheng Qidi , Wang Wuchao , Li Gexuan , Wang Yang 
Published: September 2022

Abstract
It is well known that waterflooding will induce fractures. The extensive direction, length, and conductivity of the induced fractures will largely determine the performance of producing wells. The quantitative characterization of the fractures can help prevent water breakthrough in time. This paper proposes the waterflooding-induced dynamic fracture model (WIDF) to monitor the fracture half-length at any time and extend the stable production period. The rock mechanics principles are applied to characterize the dynamic extension and closure of fractures during water injection and build-up periods. The model was solved using the point source function approach. The phenomenon of multi-dynamic closure causes the fluid to be squeezed several times, creating a storage effect and a non-constant conductivity within the fracture. Experimental results show that the conductivity of water injection-induced fracture follows an exponential function. Finally, Duhamel's principle was used to couple the pressure response of the wellbore and the fracture. The field case is shown in the paper to verify the accuracy and practicality of the WIDF model. Multi-peak appears in the pressure derivative curves. The actual data match well, and the parameter values obtained are close to the actual values. However, the conventional finite-conductivity model treats pressure response data with multiple peaks as incorrect values. This behavior will result in the length of dynamic closed fracture being ignored and the interpreted fracture half-length being smaller than the actual value. Misidentification of fracture lengths will affect the determination of reasonable injection volumes and even cause producing water early, which can severely impact the performance of production wells. The storage effect caused by multiple dynamic fracture closures reasonably explains the significant storage effect obtained by the conventional model. The WIDF model enables researchers can monitor induced fracture half-length at any time, allowing them to take measures in time. The model has been successfully applied to the X oilfield in China and has significantly improved the performance of injection wells and increased the stable production period of production wells. The fluid compressed by dynamic fractures reasonably explains the significant storage effect in injection wells. The identification and interpretation of multiple dynamic fracture closure phenomenon make us obtain more accurate fracture half-length parameters, which monitors and suppresses the occurrence of water breakthrough effectively and help researchers take measures to increase the stable production period of production wells.
Micro-Continuum Approach for Modeling Coupled Flow and Geomechanical Processes in Fractured Rocks
Authors: He Xupeng , AlSinan Marwah , Zhang Zhen , Kwak Hyung , Hoteit Hussein 
Published: September 2022

Abstract
Coupling flow with geomechanical processes at the pore scale in fractured rocks is essential in understanding the macroscopic processes of interest, such as geothermal energy extraction, CO2 sequestration, and hydrocarbon production from naturally and hydraulically fractured reservoirs. To investigate the microscopic (pore-scale) phenomena, we propose an efficient and accurate flow-geomechanics coupling algorithm to advance the fundamental flow mechanism from the micro-continuum perspective. Further, we investigate the stress influence on fluid leakage caused by matrix-fracture interaction. In this work, we employ a hybrid micro-continuum approach to describe the flow in fractured rocks, in which fracture flow is described by Navier-Stokes (NS) equations and flow in the surrounding matrix is modeled by Darcy's law. This hybrid modeling is achieved using the extended Darcy-Brinkman-Stokes (EDBS) equations. This approach applies a unified conservation equation for flow in both media (fracture & matrix). We then couple the EDBS flow model with the Brown-Scholz (BS) geomechanical model, which quantifies the deformation of rock fractures. We demonstrate the accuracy of the coupled flow-geomechanical algorithm, in which the accuracy of the EDBS flow model is validated by a simple case with a known analytical solution. The BS geomechanical model is demonstrated with experimental data collected from the literature. The developed flow-geomechanical coupling algorithm is then used to perform sensitivity analyses to explore the factors impacting the fluid leakage caused by the matrix-fracture interaction. We found that the degree of fluid leakage increases as matrix permeability increases and fractures become rougher. Fluid leakage degree decreases with the increase of inertial forces because of the existence of eddies, which prevents the flux exchange between the matrix and fracture. We also investigate the stress influence on fluid leakage and further on fracture permeability under the impact of matrix-fracture interaction. We conclude the fracture permeability would increase with the consideration of the fluid leakage and exhibits an exponential relation with the effective stress.
Multiscale Carbonate Rock Reconstruction Using a Hybrid WGAN-GP and Super-Resolution
Authors: Zhang Zhen , Li Yiteng , AlSinan Marwah , He Xupeng , Kwak Hyung , Hoteit Hussein 
Published: September 2022

Abstract
The X-ray micro-Computed Tomography (μ-CT) is the primary tool for digital rock imaging, which provides the foundation for numerically studying petrophysical properties of reservoir rocks at the pore scale. However, the finite resolution of μ-CT imaging cannot capture the micro-porosity at the sub-micrometer scale in carbonate rocks. The tradeoff between the resolution and field of view (FOV) is a persisting challenge in the industry. The machine-learning-based single-image super-resolution techniques has rapidly developed in the past few years. It is becoming a promising approach to "super-resolve" low-resolution carbonate rock images. In this study, we present a fast super-resolution generative adversarial network to enhance the image resolution of carbonate rocks. A pre-trained VGG network is implemented to extract important high-level features, from which the perceptual similarity is evaluated between the generated and ground-truth images. The novelty of this study is two-fold. First, the generator is significantly simplified with a fast super-resolution convolutional neural network. On the other hand, the spatial and channel squeeze-and excitation block is applied to recalibrate nonlinear feature mapping so that the quality of super-resolved images is promising even with much fewer residual blocks.
To quantify the quality of the super-resolution images, we compare difference maps between the generated and ground-truth images. Numerical results indicate that the proposed network shows excellent potential in enhancing the resolution of heterogeneous carbonate rocks. In particular, the pixel errors are minor, and the super-resolution images exhibit clear and sharp edges and dissolved mineral texture. This study provides a novel machine-learning-based method using a simple generative adversarial network with squeeze and excitation blocks to super-resolve μ-CT images of carbonate rocks.