Simulation of Methane Recovery from Gas Hydrates Combined with Storing Carbon Dioxide as Hydrates

Janicki, Georg; Schlüter, Stefan; Hennig, Torsten; Lyko, Hildegard; Deerberg, Görge

doi:10.1155/2011/462156

Cited by 26 publications

(22 citation statements)

References 24 publications

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“…MH has attracted research interest in a range of engineering and scientific fields, among which are geophysical exploration [14][15][16][17]; environmental impact [7,18,19]; geohazards (e.g., slope stability, dissociation-induced tsunami events, deep-water mud volcanoes) [20][21][22][23]; mechanical property evaluation [24][25][26][27][28]; macro-and micro-mechanical constitutive modeling [29][30][31][32][33][34][35]; thermo-hydro-chemical-mechanical (THCM) formulations for simulation of gas production and the associated difficulties [36][37][38][39][40][41][42][43][44][45][46][47].…”

Section: Introductionmentioning

confidence: 99%

Micromechanical Investigation of Stress Relaxation in Gas Hydrate-Bearing Sediments Due to Sand Production

2019

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Past experience of gas production from methane-hydrate-bearing sediments indicates that sand migration is a major factor restricting the production of gas from methane-hydrate reservoirs. One important geotechnical aspect of sand migration is the influence of grain detachment on the existing stresses. This paper focuses on understanding and quantifying the nature of this aspect using different approaches, with a focus on discrete element method (DEM) simulations of sand detachment from hydrate-bearing sand samples. The investigation in the paper reveals that sand migration affects isotropic and deviatoric stresses differently. In addition, the existence of hydrate moderates the magnitude of stress relaxation. Both of these features are currently missing from continuum-based models, and therefore, a new constitutive model for stress relaxation is suggested, incorporating the research findings. Model parameters are suggested based on the DEM simulations. The model is suitable for continuum mechanics-based simulations of gas production from hydrate reservoirs.

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Section: Introductionmentioning

confidence: 99%

Micromechanical Investigation of Stress Relaxation in Gas Hydrate-Bearing Sediments Due to Sand Production

2019

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“…To approximate the Jacobian for the Eqns. (28)- (29), due to their piecewise smooth nature, we use the approximate active/inactive sets A (l) α and I (l) α at the l-th Newton step to determine the phase wise NCP equations in each cell,…”

Section: Semismooth Newton Schemementioning

confidence: 99%

“…See[32] for references to P ,[29] for references to k th w , Cp w , µ 0,g , ρ h , N h , k th h , Cp h , D c w , ρ s , k th s , and Cp s , and[18] for references to µ w , D…”

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confidence: 99%

An All-At-Once Newton Strategy for Marine Methane Hydrate Reservoir Models

2020

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Marine gas hydrate systems are characterized by highly dynamic transport-reaction processes in an essentially water-saturated porous medium that are coupled to thermodynamic phase transitions between solid gas hydrates, free gas and dissolved methane in the aqueous phase. These phase transitions are highly nonlinear and strongly coupled, and cause the mathematical model to rapidly switch the phase states and pose serious convergence issues for the classical Newton's method. One of the common methods of dealing with such phase transitions is the primary variable switching (PVS) method where the choice of the primary variables is adapted locally to the phase state 'outside' the Newton loop. In order to ensure that the phase states are determined accurately, the PVS strategy requires an additional iterative loop, which can get quite expensive for highly nonlinear problems. For methane hydrate reservoir models, the PVS method shows poor convergence behaviour and often leads to extremely small time step sizes. In order to overcome this issue, we have developed a nonlinear complementary constraints method (NCP) for handling phase transitions, and implemented it within a non-smooth Newtons linearization scheme using an active-set strategy. Here, we present our numerical scheme and show its robustness through field scale applications based on the highly dynamic geological setting of the Black Sea.

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“…Further information about the model and the parameterization can be found e. g. in [31]. In a two-well approach at one well methane is produced by depressurization to 30 bar and at a second well CO 2 is injected simultaneously at a rate of 8.000 STD m 3 per day and 10 °C.…”

Section: Numerical Simulation Of Hydrate Exploitationmentioning

confidence: 99%

Simulation of Subsea Gas Hydrate Exploitation

et al. 2014

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The recovery of methane from gas hydrate layers that have been detected in several subsea sediments and permafrost regions around the world is a promising perspective to overcome future shortages in natural gas supply. Being aware that conventional natural gas resources are limited, research is going on to develop required and sustainable technologies for the production of natural gas from such new sources since the early 1990s. In recent years, intensive research has focused on the capture and storage of CO 2 from combustion processes to reduce climate impact. While different man-made or natural reservoirs like deep aquifers, exhausted oil and gas deposits or other geological formations are considered to store gaseous or liquid CO 2 , the storage of CO 2 as hydrate in former methane hydrate deposits is another promising alternative. Due to beneficial stability conditions, methane recovery may be well combined with CO 2 storage in the form of hydrates. Regarding technological implementation many problems have to be overcome. Within the scope of the German research project »SUGAR« different technological approaches for the optimized exploitation of gas hydrate deposits are evaluated and compared by means of dynamic system simulations and analysis. Detailed mathematical models for the most relevant chemical and physical processes are developed. The basic mechanisms of gas hydrate formation/ dissociation and heat and mass transport in porous media are considered and implemented into simulation programs. Simulations based on geological field data have been carried out. The effects occurring during gas production and CO 2 storage within a hydrate deposit are identified and described for various scenarios. The behavior of relevant process parameters such as pressure, temperature and phase saturations is discussed for different strategies. Simulation results for different scenarios, e. g. simple depressurization and CO 2 injection, reveal that both the production of natural gas and the CO 2 storage are possible with acceptable rates. In case of simultaneous CO 2 injection an increased production rate can be expected. The results strongly depend on deposit conditions, especially multiphase flow rates are dominated by permeability terms -in other words the reservoir permeability controls production and injection rates. Furthermore, the heat transport within heterogeneous layered deposits leads to enhanced hydrate decomposition and thus higher production rates.

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Simulation of Methane Recovery from Gas Hydrates Combined with Storing Carbon Dioxide as Hydrates

Cited by 26 publications

References 24 publications

Micromechanical Investigation of Stress Relaxation in Gas Hydrate-Bearing Sediments Due to Sand Production

Micromechanical Investigation of Stress Relaxation in Gas Hydrate-Bearing Sediments Due to Sand Production

An All-At-Once Newton Strategy for Marine Methane Hydrate Reservoir Models

Simulation of Subsea Gas Hydrate Exploitation

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