Gas hydrate exploitation using CO2/H2 mixture gas by semi-continuous injection-production mode

Sun, Yi-Fei; Wang, Yunfei; Zhong, Jin‐Rong; Li, Wenzhi; Li, Rui; Cao, Bo-Jian; Kan, Jingyu; Sun, Chang‐Yu; Chen, Guangjin

doi:10.1016/j.apenergy.2019.01.209

Cited by 62 publications

(23 citation statements)

References 42 publications

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“…At the same time, natural gas as a fuel is much more environmentally friendly than coal and oil since it has a high calorific value; when it is burned, only carbon dioxide and water are formed [9,15]. Four main methods of gas hydrate field development have been proposed [16]: depression [17,18], heating [19,20], injection of inhibitors [21][22][23], and replacement with carbon dioxide [24,25]. In this regard, the study of the formation and decomposition of gas hydrates in porous media is a key point for a fundamental understanding of natural gas hydrates' behavior, the development of technologies for their extraction and practical application in the processes of transportation and storage.…”

Section: Introductionmentioning

confidence: 99%

Influence of Water Saturation, Grain Size of Quartz Sand and Hydrate-Former on the Gas Hydrate Formation

et al. 2021

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The development of technologies for the accelerated formation or decomposition of gas hydrates is an urgent topic. This will make it possible to utilize a gas, including associated petroleum one, into a hydrate state for its further use or to produce natural gas from hydrate-saturated sediments. In this work, the effect of water content in wide range (0.7–50 mass%) and the size of quartz sand particles (porous medium; <50 μm, 125–160 μm and unsifted sand) on the formation of methane and methane-propane hydrates at close conditions (subcooling value) has been studied. High-pressure differential scanning calorimetry and X-ray computed tomography techniques were employed to analyze the hydrate formation process and pore sizes, respectively. The exponential growth of water to hydrate conversion with a decrease in the water content due to the rise of water–gas surface available for hydrate formation was revealed. Sieving the quartz sand resulted in a significant increase in water to hydrate conversion (59% for original sand compared to more than 90% for sieved sand). It was supposed that water suction due to the capillary forces influences both methane and methane-propane hydrates formation as well with latent hydrate forming up to 60% either without a detectable heat flow or during the ice melting. This emphasizes the importance of being developed for water–gas (ice–gas) interface to effectively transform water into the hydrate state. In any case, the ice melting (presence of thawing water) may allow a higher conversion degree. Varying the water content and the sand grain size allows to control the degree of water to hydrate conversion and subcooling achieved before the hydrate formation. Taking into account experimental error, the equilibrium conditions of hydrates formation do not change in all studied cases. The data obtained can be useful in developing a method for obtaining hydrates under static conditions.

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Section: Introductionmentioning

confidence: 99%

Influence of Water Saturation, Grain Size of Quartz Sand and Hydrate-Former on the Gas Hydrate Formation

et al. 2021

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“…The Newton–Raphson procedure is used to minimize the Gibbs energy of the system at a given set of K values. Detailed derivations related to eqs and above would be referred to refs and . To calculate K values in eq , the compositions of gas and liquid phases are calculated by the Peng–Robinson equation of state (EOS) .…”

Section: Theory and Procedures Of Numerical Simulationmentioning

confidence: 99%

“…On the other hand, other additives or other N 2 -related methods have been considered to overcome low recovery efficiency. The CO 2 –H 2 S gas mixture injection, CO 2 –H 2 continuous/semi-continuous (cyclic injection and soaking) injection method, , depressurization-assisted replacement technique, and thermal stimulation combining gas injection were presented. White et al proposed the CO 2 gas injection numerical simulator based on the existing numerical simulator STOMP-HYD using the equilibrium model and the kinetic model.…”

Section: Introductionmentioning

confidence: 99%

Estimation of Methane Recovery Efficiency from Methane Hydrate by the N₂–CO₂ Gas Mixture Injection Method

2020

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Methane hydrate (MH) is the best-known unconventional energy resource and has begun to open its promising future, especially for Japan. In 2017, the second offshore gas hydrate field test was conducted in the Eastern Nankai Trough, Japan, where a depressurization technique was adopted for producing methane gas. Alongside the depressurization method, the replacement of CH4 from gas hydrates by a N2–CO2 gas mixture was suggested and adopted to increase performance for both methane gas recovery and carbon dioxide sequestration. The amount of abundant MHs is estimated to exist in the permafrost area; therefore, this method, which does not require any heat source, can be used as a standard method for recovering methane. In this study, experiments to continuously inject a N2–CO2 gas mixture (59 mol % CO2) into hydrate-bearing cores with different MH saturations were conducted. Simultaneously, the numerical simulation model was constructed, and to express the gas exchange phenomenon of CH4–(N2 + CO2), the phase equilibrium analyses were used between the gas mixture and hydrates. Good agreements were obtained between experiments and simulations. At these experiments, the recovery factor of 40.8% and the exchange ratio of 8.22% were recorded as an example. The validation of the simulation with experimental results strongly supported our study to find the efficient injection gas composition for methane recovery. Case studies of the numerical simulation were conducted with various CO2 concentrations of injection gas in the range of 24–72 mol %. Simulation results showed that the highest recovery factor was obtained for the 30–40 mol % CO2 gas injection cases. The higher the N2 concentration of the gas mixture, the more CH4 molecules in the hydrate phase can be replaced. In the gas exchange process, the portion of N2 occupied in guest gas molecules of the hydrate became larger with increasing the N2 concentration of the gas mixture. From the discussion above, we concluded that the CO2 concentration of 30–40 mol % was the most effective for CH4 recovery by the N2–CO2 gas mixture injection method.

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“…Li et al [20] investigated the fracture-filled CH 4 hydrate dissociation by CO 2 and CO 2 /N 2 injection, respectively, and they found that the presence of N 2 could enhance the final accumulative methane recovery ratio and exchange rate. In addition to N 2 , Sun et al [21] also studied the hydrate dissociation using the CO 2 /H 2 mixture injection, and they observed good CH 4 hydrate recovery ratio and CO 2 storage capability.…”

Section: Introductionmentioning

confidence: 99%

Cyclic methane hydrate production stimulated with CO₂ and N₂

Xia

Hou

Wang

et al. 2021

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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The cyclic methane hydrate production method was proposed with CO2 and N2 mixture stimulation. The cyclic production model was established based on actual hydrate reservoir parameters, accordingly, the production characteristics were analyzed, and a sensitivity analysis was conducted. The results show the following: (1) The depressurization mechanism is dominant in the cyclic production. CH4 production and CH4 hydrate dissociation can be greatly enhanced because the cyclic process can effectively reduce the partial pressure of CH4 (gas phase). However, there is a limited effect for CO2 storage. (2) Heat supply is essential for continuous hydrate dissociation. The CH4 hydrate dissociation degree is the highest in the near-wellbore area; in addition, the fluid porosity and effective permeability are significantly improved, and the reservoir temperature is obviously decreased. (3) The initial CH4 hydrate saturation, absolute permeability, intrinsic CO2 hydrate formation kinetic constant, injection time and production time can significantly influence the production performance of the natural gas hydrate reservoir.

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Gas hydrate exploitation using CO2/H2 mixture gas by semi-continuous injection-production mode

Cited by 62 publications

References 42 publications

Influence of Water Saturation, Grain Size of Quartz Sand and Hydrate-Former on the Gas Hydrate Formation

Influence of Water Saturation, Grain Size of Quartz Sand and Hydrate-Former on the Gas Hydrate Formation

Estimation of Methane Recovery Efficiency from Methane Hydrate by the N₂–CO₂ Gas Mixture Injection Method

Cyclic methane hydrate production stimulated with CO₂ and N₂

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Gas hydrate exploitation using CO2/H2 mixture gas by semi-continuous injection-production mode

Cited by 62 publications

References 42 publications

Influence of Water Saturation, Grain Size of Quartz Sand and Hydrate-Former on the Gas Hydrate Formation

Influence of Water Saturation, Grain Size of Quartz Sand and Hydrate-Former on the Gas Hydrate Formation

Estimation of Methane Recovery Efficiency from Methane Hydrate by the N2–CO2 Gas Mixture Injection Method

Cyclic methane hydrate production stimulated with CO2 and N2

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Estimation of Methane Recovery Efficiency from Methane Hydrate by the N₂–CO₂ Gas Mixture Injection Method

Cyclic methane hydrate production stimulated with CO₂ and N₂