Relevant bibliographies by topics / TOUGH + HYDRATE

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Academic literature on the topic 'TOUGH + HYDRATE'

Author: Grafiati
Published: 4 June 2021
Last updated: 11 February 2022

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Journal articles on the topic "TOUGH + HYDRATE"

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Vedachalam, Narayanaswamy, Sethuraman Ramesh, Arunachalam Umapathy, and Gidugu Ananda Ramadass. "Importance of Gas Hydrates for India and Characterization of Methane Gas Dissociation in the Krishna-Godavari Basin Reservoir." Marine Technology Society Journal 50, no. 6 (2016): 58–68. http://dx.doi.org/10.4031/mtsj.50.6.1.

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AbstractNatural gas hydrates are considered to be a strategic unconventional hydrocarbon resource in the Indian energy sector, and thermal stimulation is considered as one of the methods for producing methane from gas hydrate-bearing sediments. This paper discusses the importance of this abundantly available blue economic resource and analyzes the efficiency of methane gas production by circulating hot water in a horizontal well in the fine-grained, clay-rich natural gas hydrate reservoir in the Krishna-Godavari basin of India. Analysis is done using the electrothermal finite element analysis software MagNet-ThermNet and gas hydrate reservoir modeling software TOUGH+HYDRATE with reservoir petrophysical properties as inputs. Energy balance studies indicate that, in the 90% hydrate-saturated reservoir, the theoretical energy conversion ratio is 1:4.9, and for saturations below 20%, the ratio is <1. It is identified that a water flow of 0.2 m3/h at 270°C is required for every 1 m2 of wellhead surface area to dissociate gas hydrates up to a distance of 2.6 m from the well bore within 36 h.
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Zheng, Mingming, Xiaoyu Wang, Zhilin Wang, et al. "Influence of cement slurry heat release on physical properties of marine hydrate reservoirs during well cementing." E3S Web of Conferences 228 (2021): 01017. http://dx.doi.org/10.1051/e3sconf/202122801017.

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Natural gas hydrates gradually become the focus of new energy resources, and the study of hydrate exploitation is growing vigorously during recent years. Well cementing is an important process during energy exploitation, especially when encounters hydrate bearing sediments in deep-water oil and gas drilling, showing great research significance and becoming a research hotspot. In this study, the exploratory well of SH2 of GMGS-1 project is chosen as the object of study, a cementing model of two dimensions based on this exploratory well is build, the invasion process of cement slurry is reappeared by TOUGH+HYDRATE, and the physical properties response of hydrate reservoirs during the cementing process is analyzed based on the numerical simulation data. In which, a view of “continuous stage simulation” to solve the problem of dynamic heat release of cement slurry is created and used for the first time. Result illustrated that the invasion behavior of cement slurry almost only occurred during the stage of holding pressure, the temperature has significantly increased in the area of reservoir which is invaded by cement slurry. At the same time, a large amount of decomposed hydrate have generated gas and water, which form high pressure region and transfer toward the deeper of reservoir. However, the variation in the temperature is not significant and the hydrate barely no longer decomposed in those area which outside or even though close to this area. There also have generated secondary hydrate closed to the area of decomposition and formed high saturation zone of hydrate. The results also proved the feasibility of “continuous stage simulation”, and played a guiding significance for the field well cementing.
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Li, Sheng-Li, You-Hong Sun, Kai Su, Wei Guo, and You-Hai Zhu. "Numerical simulation of CH4 hydrate formation in fractures." Energy Exploration & Exploitation 36, no. 5 (2018): 1279–94. http://dx.doi.org/10.1177/0144598717751180.

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Fracture-hosted methane hydrate deposits exist at many sites worldwide. The growth behavior of CH4 hydrate in fractured media was simulated by TOUGH + HYDRATE (T + H) code. The effects of fracture size, initial condition, and salinity on the growth behavior of hydrate in fractures were investigated. In general, the hydrate layer grew from the two ends and gradually covered on the surface of the fracture. With the formation of hydrate in fractures, the temperature increased sharply since the hydrate acted as a thermal insulation layer. In longer fractures, fast growth of hydrate at the ends of the fracture led to the formation of hydrate plugs with high saturation (called as stopper). In narrower fractures, hydrate dissociation occurred in the middle of the fracture during hydrate growing in the whole fracture due to the cutoff of gas supply by the stopper at the ends. At a low initial subcooling, hydrate formed both on the surface and in the micropores of the media, which was different from that at higher subcooling. In salt solution, the formation of hydrate stopper was inhibited by the salt-removing effect of hydrate formation and the growth of hydrate was more sustainable.
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Huang, Junyi, Jun Xu, Zhen Xia, et al. "Identification of influential parameters through sensitivity analysis of the TOUGH + Hydrate model using LH-OAT sampling." Marine and Petroleum Geology 65 (August 2015): 141–56. http://dx.doi.org/10.1016/j.marpetgeo.2015.04.009.

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Moridis, George J., Alejandro F. Queiruga, and Matthew T. Reagan. "Simulation of Gas Production from Multilayered Hydrate-Bearing Media with Fully Coupled Flow, Thermal, Chemical and Geomechanical Processes Using TOUGH + Millstone. Part 1: Numerical Modeling of Hydrates." Transport in Porous Media 128, no. 2 (2019): 405–30. http://dx.doi.org/10.1007/s11242-019-01254-6.

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Reagan, Matthew T., Alejandro F. Queiruga, and George J. Moridis. "Simulation of Gas Production from Multilayered Hydrate-Bearing Media with Fully Coupled Flow, Thermal, Chemical and Geomechanical Processes Using TOUGH+Millstone. Part 3: Production Simulation Results." Transport in Porous Media 129, no. 1 (2019): 179–202. http://dx.doi.org/10.1007/s11242-019-01283-1.

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Queiruga, Alejandro F., George J. Moridis, and Matthew T. Reagan. "Simulation of Gas Production from Multilayered Hydrate-Bearing Media with Fully Coupled Flow, Thermal, Chemical and Geomechanical Processes Using TOUGH+Millstone. Part 2: Geomechanical Formulation and Numerical Coupling." Transport in Porous Media 128, no. 1 (2019): 221–41. http://dx.doi.org/10.1007/s11242-019-01242-w.

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Güney, Aysun, Christina Gardiner, Andrew McCormack, Jos Malda, and Dirk Grijpma. "Thermoplastic PCL-b-PEG-b-PCL and HDI Polyurethanes for Extrusion-Based 3D-Printing of Tough Hydrogels." Bioengineering 5, no. 4 (2018): 99. http://dx.doi.org/10.3390/bioengineering5040099.

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Novel tough hydrogel materials are required for 3D-printing applications. Here, a series of thermoplastic polyurethanes (TPUs) based on poly(ɛ-caprolactone)-b-poly(ethylene glycol)-b-poly(ɛ-caprolactone) (PCL-b-PEG-b-PCL) triblock copolymers and hexamethylene diisocyanate (HDI) were developed with PEG contents varying between 30 and 70 mol%. These showed excellent mechanical properties not only when dry, but also when hydrated: TPUs prepared from PCL-b-PEG-b-PCL with PEG of Mn 6 kg/mol (PCL7-PEG6-PCL7) took up 122 wt.% upon hydration and had an E-modulus of 52 ± 10 MPa, a tensile strength of 17 ± 2 MPa, and a strain at break of 1553 ± 155% in the hydrated state. They had a fracture energy of 17976 ± 3011 N/mm2 and a high tearing energy of 72 kJ/m2. TPUs prepared using PEG with Mn of 10 kg/mol (PCL5-PEG10-PCL5) took up 534% water and were more flexible. When wet, they had an E-modulus of 7 ± 2 MPa, a tensile strength of 4 ± 1 MPa, and a strain at break of 147 ± 41%. These hydrogels had a fracture energy of 513 ± 267 N/mm2 and a tearing energy of 16 kJ/m2. The latter TPU was first extruded into filaments and then processed into designed porous hydrogel structures by 3D-printing. These hydrogels can be used in 3D printing of tissue engineering scaffolds with high fracture toughness.
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Oyen, Michelle L. "The Materials Science of Bone: Lessons from Nature for Biomimetic Materials Synthesis." MRS Bulletin 33, no. 1 (2008): 49–55. http://dx.doi.org/10.1557/mrs2008.14.

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AbstractThere has been considerable recent interest in natural bone as a material, due in part to its interesting combination of mechanical properties: bone is stiff and tough but lightweight. This unusual combination of properties results from a nanocomposite structure of approximately equal volumes of mineral and hydrated organic matter. Much recent effort has been focused on the structure, properties, and performance at different length scales relative to the hierarchical organization of bone. Historically, such bone research has emphasized clinical and medical aspects, including engineering materials for bone augmentation or replacement, bone–biomaterial interactions and interfaces, and more recently, scaffolds for bone tissue engineering. However, within the fast-growing biomimetics field, the bone extracellular matrix is taken as a model for materials development. Efforts have been made both to mimic the bony material itself as well as to mimic the process by which bone forms.
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Zhu, Hu, Olivia W. Lee, Pranav Shah, et al. "Identification of Activators of Human Fumarate Hydratase by Quantitative High-Throughput Screening." SLAS DISCOVERY: Advancing the Science of Drug Discovery 25, no. 1 (2019): 43–56. http://dx.doi.org/10.1177/2472555219873559.

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Fumarate hydratase (FH) is a metabolic enzyme that is part of the Krebs cycle and reversibly catalyzes the hydration of fumarate to malate. Mutations of the FH gene have been associated with fumarate hydratase deficiency (FHD), hereditary leiomyomatosis and renal cell cancer (HLRCC), and other diseases. Currently, there are no high-quality small-molecule probes for studying human FH. To address this, we developed a quantitative high-throughput screening (qHTS) FH assay and screened a total of 57,037 compounds from in-house libraries in dose–response. While no inhibitors of FH were confirmed, a series of phenyl-pyrrolo-pyrimidine-diones were identified as activators of human FH. These compounds were not substrates of FH, were inactive in a malate dehydrogenase counterscreen, and showed no detectable reduction–oxidation activity. The binding of two compounds from the series to human FH was confirmed by microscale thermophoresis. The low hit rate in this screening campaign confirmed that FH is a “tough target” to modulate, and the small-molecule activators of human FH reported here may serve as a starting point for further optimization and development into cellular probes of human FH and potential drug candidates.
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Dissertations / Theses on the topic "TOUGH + HYDRATE"

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Barros, Parigi Rafael. "Methane hydrates: Investigating the influence of sediment type on modeled methane escape in the high latitude Northern Hemisphere." Thesis, Stockholms universitet, Institutionen för geologiska vetenskaper, 2021. http://urn.kb.se/resolve?urn=urn:nbn:se:su:diva-192841.

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Methane hydrates have drawn the attention of climate scientists in the past decades due to the potency of methane as a greenhouse gas and the widespread occurrence of hydrates both in terrestrial and marine environments, which, if destabilised, could enhance global warming. This study aims to investigate how much impact sediment type has on modeled methane escape at the feather edge of stability for methane hydrates in the high latitude Northern Hemisphere (45° to 75° N). This area is characterised by cool bottom-water temperatures leading to a shallow gas hydrate stability zone (GHSZ), and has been disproportionally influenced by contemporary seawater warming. Calculations were performed to establish the depths of the upper and lower boundaries of the feather edge of the GHSZ. These limits were used to estimate seafloor areas covered by three select sediment types that have different petrophysical properties - hemipelagic clay, calcareous ooze and siliceous ooze. Modeling of methane flux for 300 years following a 3°C warming during the first 100 years was performed using TOUGH + HYDRATE for each of the three sediment types. The sediments behaved significantly differently, with siliceous ooze releasing the most methane gas, and calcareous ooze releasing the least. Estimates of total methane gas release were also performed on the areas covered by the three sediments between latitudes 45° to 75° N, and showed that, over the course of 300 years, up to 5 times the current methane concentration in the atmosphere could become susceptible to leaving methane hydrate reservoirs.
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Alp, Doruk. "Gas Production From Hydrate Reservoirs." Master's thesis, METU, 2005. http://etd.lib.metu.edu.tr/upload/12606241/index.pdf.

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In this study<br>gas production by depressurization method from a hydrate reservoir containing free gas zone below the hydrate zone is numerically modeled through 3 dimensional, 3 phase, non-isothermal reservoir simulation. The endothermic nature of hydrate decomposition requires modeling to be non-isothermal<br>hence energy balance equations must be employed in the simulation process. TOUGH-Fx, the successor of the well known multipurpose reservoir simulator TOUGH2 (Pruess [24]) and its very first module TOUGH-Fx/Hydrate, both developed by Moridis et.al [23] at LBNL, are utilized to model production from a theoretical hydrate reservoir, which is first studied by Holder [11] and then by Moridis [22], for comparison purposes. The study involves 2 different reservoir models, one with 30% gas in the hydrate zone (case 1) and other one with 30% water in the hydrate zone (case 2). These models are further investigated for the effect of well-bore heating. The prominent results of the modeling study are: &amp<br>#8226<br>In case 1, second dissociation front develops at the top of hydrate zone and most substantial methane release from the hydrate occurs there. &amp<br>#8226<br>In case 2 (hydrate-water in the hydrate zone), because a second dissociation front at the top of hydrate zone could not fully develop due to high capillary pressure acting on liquid phase, a structure similar to ice lens formation is observed. &amp<br>#8226<br>Initial cumulative replenishment (first 5 years) and the replenishment rate (first 3.5 years) are higher for case 2 because, production pressure drop is felt all over the reservoir due to low compressibility of water and more hydrate is decomposed. Compared to previous works of Holder [11] and Moridis [22], amount of released gas contribution within the first 3 years of production is significantly low which is primarily attributed to the specified high capillary pressure function.
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Reports on the topic "TOUGH + HYDRATE"

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Moridis, George J., Michael B. Kowalsky, and Karsten Pruess. TOUGH+HYDRATE v1.2 User's Manual: A Code for the Simulation of System Behavior in Hydrate-Bearing Geologic Media. Office of Scientific and Technical Information (OSTI), 2012. http://dx.doi.org/10.2172/1173164.

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Moridis, George, George J. Moridis, Michael B. Kowalsky, and Karsten Pruess. TOUGH+Hydrate v1.0 User's Manual: A Code for the Simulation of System Behavior in Hydrate-Bearing Geologic Media. Office of Scientific and Technical Information (OSTI), 2008. http://dx.doi.org/10.2172/927149.

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Moridis, G. User's Manual for the Hydrate v1.5 Option of TOUGH+ v1.5: A Code for the Simulation of System Behavior in Hydrate-Bearing Geologic Media. Office of Scientific and Technical Information (OSTI), 2014. http://dx.doi.org/10.2172/1165986.

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