High pressure rheology of gas hydrate formed from multiphase systems using modified Couette rheometer

2017 ◽  
Vol 88 (2) ◽  
pp. 025102 ◽  
Author(s):  
Gaurav Pandey ◽  
Praveen Linga ◽  
Jitendra S. Sangwai
Keyword(s):  
High Pressure ◽  
Gas Hydrate ◽  
Multiphase Systems ◽  
Couette Rheometer

Measured temperature and pressure dependence of Vp and Vs in compacted, polycrystalline sI methane and sII methane–ethane hydrate

2003 ◽  
Vol 81 (1-2) ◽  
pp. 47-53 ◽  
Author(s):  
M B Helgerud ◽  
W F Waite ◽  
S H Kirby ◽  
A Nur
Keyword(s):  
High Pressure ◽  
Shear Wave ◽  
Pressure Dependence ◽  
Gas Hydrate ◽  
Pressure Vessel ◽  
Wave Speed ◽  
Measured Temperature ◽  
Shear Wave Speed ◽  
Temperature And Pressure ◽  
Fixed End

We report on compressional- and shear-wave-speed measurements made on compacted polycrystalline sI methane and sII methane–ethane hydrate. The gas hydrate samples are synthesized directly in the measurement apparatus by warming granulated ice to 17°C in the presence of a clathrate-forming gas at high pressure (methane for sI, 90.2% methane, 9.8% ethane for sII). Porosity is eliminated after hydrate synthesis by compacting the sample in the synthesis pressure vessel between a hydraulic ram and a fixed end-plug, both containing shear-wave transducers. Wave-speed measurements are made between –20 and 15°C and 0 to 105 MPa applied piston pressure. PACS No.: 61.60Lj

In situobservation of gas hydrate behaviour under high pressure by Raman spectroscopy

2002 ◽  
Vol 14 (44) ◽  
pp. 11395-11400 ◽  
Author(s):  
T Komai ◽  
T Kawamura ◽  
S Kang ◽  
K Nagashima ◽  
Y Yamamoto
Keyword(s):  
Raman Spectroscopy ◽  
High Pressure ◽  
Gas Hydrate

scholarly journals Separation Process of Nonpolar Gas Hydrate in Food Solution under High Pressure Apparatus

2014 ◽  
Vol 2014 ◽  
pp. 1-8 ◽  
Author(s):  
Yohanes Aris Purwanto ◽  
Seiichi Oshita ◽  
Yasuhisa Seo ◽  
Yoshinori Kawagoe
Keyword(s):  
High Pressure ◽  
Gas Hydrate ◽  
Formation Rate ◽  
Hydrate Formation ◽  
Separation Process ◽  
Liquid Food ◽  
Screen Size ◽  
Solubility In Water ◽  
Gas Hydrate Formation ◽  
Inner Diameter

Separation process of nonpolar gas hydrate formation in liquid food was experimentally studied under high pressure container. Xenon (Xe) gas was selected as hydrate forming gas and coffee solution was used as a sample of liquid food. The high-pressure stainless steel container having the inner diameter of 60 mm and the volume of 700 mL with a U-shaped stirrer was designed to carry out this experiment. A temperature of 9.0°C and Xe partial pressure of 0.9 MPa were set as a given condition. The experiment was designed to examine the effect of steel screen size, formation rate, temperature condition, and amount of Xe gas dissolving in the solution on the separation process which was indicated by concentration efficiency. Screen size of 200 and 280 mesh resulted in higher concentration efficiency than that of 100 mesh. The higher stirring rate caused the higher formation rate of Xe hydrate and created the smaller Xe hydrate crystals. At the condition giving the same solubility in water, temperature of 14.8°C resulted in lower concentration efficiency than 9.0°C. The increase in the amount of Xe gas dissolving in coffee solution caused the concentration efficiency to decrease; however, the concentration ratio between the final and initial concentration of the solution increased.

Surface Treatment Strategies for Mitigating Gas Hydrate & Asphaltene Formation, Growth, and Deposition in Flowloops

2021 ◽  
Author(s):  
Marshall A Pickarts ◽  
Jose Delgado-Linares ◽  
Erika Brown ◽  
Vinod Veedu ◽  
Carolyn A. Koh
Keyword(s):  
High Pressure ◽  
Crude Oil ◽  
Surface Treatment ◽  
Memory Effect ◽  
Gas Hydrate ◽  
Hydrate Formation ◽  
Flow Assurance ◽  
Stainless Steel Surface ◽  
Pipe Surface

Abstract Numerous solids including gas hydrates, waxes, and asphaltenes have the potential to form in the production lines of gas and oil fields. This creates a highly non-ideal scenario as the accumulation of said species leads to flow assurance issues, especially with long-term processes like deposition. Since an ever-increasing amount of material is deposited in place at the pipe surface, production stoppage or active mitigation efforts become inevitable. The latter production issues result in increased safety risks and operational expenditures. Therefore, a cost-effective, passive deposition mitigation technology, such as a pipeline coating or surface treatment is especially appealing. The ability to address multiple pipeline flow assurance issues simultaneously without actively disrupting production would represent a dramatic step forward in this area. This study is part of a long-term ongoing effort that evaluates the performance and application of an omniphobic surface treatment for solids deposition prevention in industrially relevant systems. In particular, this specific work concentrates on the efficacy and robustness of the treatment under fully flowing conditions. The apparatuses utilized for this include two flowloops: a lab-scale, high-pressure flowloop for gas hydrate and surface treatment durability studies, and a bench-scale, atmospheric pressure loop for crude oil and asphaltene experiments. Film growth in high-pressure flowloop tests corroborated previous reports of delayed gas hydrate nucleation observed in rocking cells. Without the aid of the memory effect, treated oil-dominated experiments never experienced hydrate formation, spending upwards of a week in the hydrate stability zone (at the subcooled/fluid test conditions). Subsequent tests which utilized the memory effect then revealed that the hydrate formation rate reduced in the presence of the surface treatment compared to a bare stainless-steel surface. This testing was part of a larger set of trials conducted in the flowloop, which lasted about one year. The surface treatment durability under flowing conditions was evaluated during this time. Even after experiencing ∼4000 operating hours and 2 full pressure cycles, no evidence of delamination or damage was detected. Finally, as part of an extension to previous work, corroded surface asphaltene deposition experiments were performed in a bench-top flowloop. Treated experiments displayed an order of magnitude reduction in both total oil (all fractions of crude oil) and asphaltene fraction deposited.

A new high-pressure gas hydrate phase in the sulfur hexafluoride–water system

2000 ◽  
Vol 10 (6) ◽  
pp. 235-236 ◽  
Author(s):  
Andrei Yu. Manakov ◽  
Eduard G. Larionov ◽  
Aleksei I. Ancharov ◽  
Dmitrii S. Mirinskii ◽  
Alexander V. Kurnosov ◽  
...  
Keyword(s):  
High Pressure ◽  
Gas Hydrate ◽  
Sulfur Hexafluoride ◽  
Water System ◽  
Hydrate Phase

Natural gas exploitation by carbon dioxide from gas hydrate fields—high-pressure phase equilibrium for an ethane hydrate system

1998 ◽  
Vol 212 (3) ◽  
pp. 159-163 ◽  
Author(s):  
S Nakano ◽  
K Yamamoto ◽  
K Ohgaki
Keyword(s):  
High Pressure ◽  
Phase Equilibrium ◽  
Natural Gas ◽  
Gas Hydrate ◽  
Phase Behaviour ◽  
High Pressure Phase ◽  
Natural Gas Hydrate ◽  
Public Attention ◽  
Hydrate Water ◽  
Pressure Phase

Natural gas hydrate fields, which have a large amount of methane and ethane deposits in the subterranean Arctic and in the bottom of the sea at various places in the world, have become the object of public attention as a potential natural gas resource. Here the idea of natural gas exploitation from natural gas hydrate fields combined with CO2 isolation using CO2 hydrate has been presented. As a fundamental study, high-pressure phase behaviour for the ethane hydrate system was investigated in a high-pressure cell up to a maximum pressure of 100 MPa, following a previous study of CO2 and methane hydrates. Consequently, the phase equilibrium relationship of an ethane hydrate—water—liquid ethane mixture was obtained in the temperature range from 290.4 to 298.4 K and over a pressure range of 19.48 to 83.75 MPa. The observed phase boundary corresponds to the three-phase coexisting line with a non-variant quadruple point of ethane hydrate—water—liquid ethane—gaseous ethane at 288.8 K and 3.50 MPa, similar to the CO2 hydrate—water—liquid CO2 system.

scholarly journals Research on Prediction Methods of Wellbore Hydrate Formation of Ultra-Deep Gas Wells in Northwest Sichuan

2021 ◽  
Vol 329 ◽  
pp. 01076
Author(s):  
Qilin Liu ◽  
Jian Yang ◽  
Lang Du ◽  
Jianxun Jiang ◽  
Dan Ni ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Natural Gas ◽  
Gas Hydrate ◽  
Hydrate Formation ◽  
Natural Gas Hydrate ◽  
Gas Wells ◽  
Prediction And Control ◽  
Sulfur Containing ◽  
High Temperature High Pressure

According to the formation and handling situation of hydrate in ultra-deep high-pressure sulfurcontaining gas wells in northwest Sichuan, the formation conditions of natural gas hydrate was studied based on previous studies on hydrate, the molecular dynamics of natural gas hydrate and the multiphase flow law of high-temperature high-pressure high-sulfur-containing gas wellbore were combined, and the pressure prediction model with high-temperature high-pressure sulfur-containing gas wells as the target was built. The chemical and physical control methods of wellbore hydrate plugging were discussed to provide the scientific theoretical basis for the prediction and control of hydrate in high-temperature high-pressure high-sulfurcontaining gas wells.

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