Numerical Studies of Gas Production from Methane Hydrates

Moridis, George J.

doi:10.2118/75691-ms

Cited by 55 publications

(10 citation statements)

References 15 publications

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“…On the other hand, different authors show that the water permeability versus porosity of the hydrate‐sediment system depends on the way GH accommodates the pore spaces (grain coating or pore filling). Several theoretical models were developed in the recent years in order to define the link between GH content and relative permeability (Katagiri et al, ; Kleinberg et al, ; Moridis, , among others).…”

Section: Discussionmentioning

confidence: 99%

Hydromechanical Properties of Gas Hydrate‐Bearing Fine Sediments From In Situ Testing

2018

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The hydromechanical properties of gas hydrate‐bearing sediment are key in assessing offshore geohazards and the resource potential of gas hydrates. For sandy materials, such properties were proved highly dependent on hydrate content (Sh) as well as on their distribution and morphology. Owing to difficulties in testing gas hydrate‐bearing clayey sediments, the impact of hydrates on the behavior of such materials remains poorly understood. Hence, to provide insight into the characterization of clayey sediments containing hydrate, this study relies on a unique database of in situ acoustic, piezocone, and pore pressure dissipation measurements collected in a high gas flux system offshore Nigeria. Compressional wave velocity measurements were used as means of both detecting and quantifying gas hydrate in marine sediments. The analysis of piezocone data in normalized soil classification charts suggested that contrary to hydrate‐bearing sands, the behavior of gas hydrate‐bearing clays tends to be contractive. Correlations of acoustic and geotechnical data have shown that the stiffness and strength tend to increase with increasing Sh. However, several sediment intervals sharing the same Sh have revealed different features of mechanical behavior; suggesting that stiffness and strength of gas hydrate‐bearing clays are influenced by the distribution/morphology of gas hydrate. Pore pressure dissipation data confirmed the contractive behavior of gas hydrate‐bearing clays and showed that at low hydrate content, the hydraulic diffusivity (Ch) decreases when Sh increases. However, for Sh exceeding 20%, it was shown that an increase of Ch with Sh could be linked to the presence of fractures in the hydrate‐sediment system.

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Section: Discussionmentioning

confidence: 99%

Hydromechanical Properties of Gas Hydrate‐Bearing Fine Sediments From In Situ Testing

2018

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“…The phase diagram of methane and water mixture in (a) pressuretemperature (P-T) space and (b) temperature-composition space at a typical pressure for methane hydrate system (freshwater, not plotted to scale, modified from Sloan & Koh, 2007). Figure 3a is plotted using the model presented in Sun and Mohanty (2006) and Moridis (2002).…”

Section: Influence Of Salinity and Capillary Pressure On The Methane mentioning

confidence: 99%

Mechanisms of Methane Hydrate Formation in Geological Systems

You

Flemings

Malinverno

et al. 2019

Reviews of Geophysics

161

110

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Natural gas hydrate is ice‐like mixture of gas (mostly methane) and water that is widely found in sediments along the world's continental margins and within and beneath permafrost and glaciers in a near‐surface depth interval where the pressure is sufficiently high and temperature sufficiently low for gas hydrate to be stable. We categorize the myriad of geological gas hydrate deposits into five characteristic types. We then review the multiple quantitative models that have proposed to describe the genesis of these deposits and describe how each may have formed. We emphasize the importance of coupling multiphase flow (free gas and liquid water) and multicomponent reactive transport with geological history to describe the dynamical processes of gas hydrate formation and evolution in geological systems. A better insight into the kinetics of methane formation from microbial biogenesis and the processes of multiphase flow at the pore scale will advance our knowledge of how these systems form. By understanding the generation and evolution of gas hydrate through time, we will better decipher the role of gas hydrate in the carbon cycle, its potential to contribute to climate change and geohazards, and how to design optimal strategies for gas production from hydrate reservoirs.

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“…Tsypkin (2000) considered the formation of ice upon hydrate dissociation. Moridis (2002) developed a numerical model to simulate the kinetic or equilibrium dissociation of gas hydrates with heat transfer and multiphase fluid flow in porous media. The model solved continuity equations for each of the three phases (gas, liquid, and hydrates) and used relations between the saturations of the phases and the rates of mass transfer of the phases.…”

Section: Introductionmentioning

confidence: 99%

Drilling Through Gas-Hydrate Sediments: Managing Wellbore-Stability Risks

Khabibullin

Falcone

Teodoriu

2011

SPE Drilling &Amp; Completion

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As hydrocarbon exploration and development moves into deeper water and onshore Arctic environments, it becomes increasingly important to quantify the drilling hazards posed by gas hydrates. To address these concerns, a 1D semianalytical model for heat and fluid transport in the reservoir was coupled with a numerical model for temperature distribution along the wellbore. This combination allowed the estimation of the dimensions of the hydrate-bearing layer where the initial pressure and temperature can dynamically change while drilling. These dimensions were then used to build a numerical reservoir model for the simulation of the dissociation of gas hydrate in the layer. The bottomhole pressure (BHP) and formation properties used in this workflow were based on a real-field case. The results provide an understanding of the effects of drilling through hydrate-bearing sediments (HBS) and of the impact of drilling-fluid temperature and BHP on changes in temperature and pore pressure within the surrounding sediments. It was found that the amount of gas hydrate that can dissociate will depend significantly on both initial formation characteristics and bottomhole conditions) namely, mud temperature and pressure). The procedure outlined in the paper can provide quantitative results of the impact of hydrate dissociation on wellbore stability, which can help in better design of drilling muds for ultradeepwater operations.

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Numerical Studies of Gas Production from Methane Hydrates

Cited by 55 publications

References 15 publications

Hydromechanical Properties of Gas Hydrate‐Bearing Fine Sediments From In Situ Testing

Hydromechanical Properties of Gas Hydrate‐Bearing Fine Sediments From In Situ Testing

Mechanisms of Methane Hydrate Formation in Geological Systems

Drilling Through Gas-Hydrate Sediments: Managing Wellbore-Stability Risks

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