Field-Scale Simulation of Production from Oceanic Gas Hydrate Deposits

Reagan, Matthew T.; Moridis, George J.; Johnson, J. N.; Pan, Lehua; Freeman, C. M.; Boyle, Katie L.; Keen, Noel D.; Husebø, Jarle

doi:10.1007/s11242-014-0330-7

Cited by 78 publications

(58 citation statements)

References 12 publications

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“…All hydrate-related physics and the corresponding relationships, as well the corresponding inputs and outputs, are now included in the HYDRATE V1.5 option which, combined with the core TOUGH+ code [Moridis, 2014], can solve the problem of hydrate-bearing system behavior in porous geologic media. The combined TOUGH+HYDRATE code (in the current versions of its two constituents) will be hereafter referred to as T+H for brevity.…”

Section: The Hydrate V15 Codementioning

confidence: 99%

“…It is an option of TOUGH+ v1.5 [Moridis, 2014], a successor to the TOUGH2 [Pruess et al, 1999] family of codes for multi-component, multiphase fluid and heat flow developed at the Lawrence Berkeley National Laboratory. HYDRATE v1.5 needs the TOUGH+ v1.5 core code in order to compile and execute.…”

mentioning

confidence: 99%

“…It is also distributed as a separate entity and cannot conduct any simulations by itself, but needs an additional code unit -named option in TOUGH+ and describing a particular type of problem or Equation of State (EOS) -before it can become operational. Note that therm option -rather the older term module or EOS that were used in the TOUGH2 [Pruess et al, 1999] nomenclature -is used to avoid confusion, as the term module has a particular meaning in the FORTRAN 95/2003 language of TOUGH+.All hydrate-related physics and the corresponding relationships, as well the corresponding inputs and outputs, are now included in the HYDRATE V1.5 option which, combined with the core TOUGH+ code [Moridis, 2014], can solve the problem of hydrate-bearing system behavior in porous geologic media. The combined TOUGH+HYDRATE code (in the current versions of its two constituents) will be hereafter referred to as T+H for brevity.…”

mentioning

confidence: 99%

“…Similarly, T+H allows the definition of interfaces that comprise one or more surfaces, each of which can be defined by several methods (e.g., geometry, listing of the included connections), thus allowing the monitoring of the evolution of flow-related attributes and parameters Based on insights provided by extensive experience with earlier versions of the code [Moridis et al, 2008;2009;2012], numerical 'bottlenecks' were removed, more efficient primary variables and state-changing criteria were selected, and more powerful linearization techniques were employed in T+H, resulting in significant improvements in execution speed and numerical performance. Note that T+H v1.5 still uses most of the inputs (and the input formats) used by the conventional TOUGH2 code [Pruess et al 1999] in order to fulfill the functional requirement (part of the code design) of backward compatibility of the TOUGH+ family codes [Moridis, 2014] with older input data files used in earlier simulations. However, more advanced input data structures and formats are introduced in this version to support and describe capabilities unavailable in earlier code versions.…”

mentioning

confidence: 99%

“…Thus, if the volume of the domain and its subdivision are such that (a) a representative volume can be defined and (b) Darcy's law applies, then T+H can be used for the prediction of the behavior of a hydrate-bearing geological system. Note that hydrate problems involving very large grids and an accordingly large number of equations (>300,000) are more appropriately addressed with a parallel version of the code [Reagan et al, 2014]. system.…”

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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

Moridis¹

2014

101

115

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HYDRATE v1.5 is a numerical code that for the simulation of the behavior of hydrate-bearing geologic systems, and represents the third update of the code since its first release [Moridis et al., 2008]. It is an option of TOUGH+ v1.5 [Moridis, 2014], a successor to the TOUGH2 [Pruess et al., 1999] family of codes for multi-component, multiphase fluid and heat flow developed at the Lawrence Berkeley National Laboratory. HYDRATE v1.5 needs the TOUGH+ v1.5 core code in order to compile and execute. It is written in standard FORTRAN 95/2003, and can be run on any computational platform (workstation, PC, Macintosh) for which such compilers are available.By solving the coupled equations of mass and heat balance, the fully operational TOUGH+HYDRATE code can model the non-isothermal gas release, phase behavior and flow of fluids and heat under conditions typical of common natural CH 4 -hydrate deposits (i.e., in the permafrost and in deep ocean sediments) in complex geological media at any scale (from laboratory to reservoir) at which Darcy's law is valid. TOUGH+HYDRATE v1.5 includes both an equilibrium and a kinetic model of hydrate formation and dissociation. The model accounts for heat and up to four mass components, i.e., water, CH 4 , hydrate, and water-soluble inhibitors such as salts or alcohols. These are partitioned among four possible phases (gas phase, liquid phase, ice phase and hydrate phase). Hydrate dissociation or formation, phase changes and the corresponding thermal effects are fully described, as are the effects of inhibitors. The model can describe all possible hydrate dissociation mechanisms, i.e., depressurization, thermal stimulation, salting-out effects and inhibitor-induced effects. Gas hydrates are solid crystalline compounds in which gas molecules are encaged inside the lattices of ice crystals. These gases are referred to as guests, whereas the ice crystals are called hosts. Of particular interest are hydrates in which the gas is a hydrocarbon. LIST OF TABLESUnder suitable conditions of low temperature and high pressure, a hydrocarbon gas M will react with water to form hydrates according towhere N H is the hydration number.Vast amounts of hydrocarbons are trapped in hydrate deposits [Sloan, 1998]. Such deposits exist where the thermodynamic conditions allow hydrate formation, and are concentrated in two distinctly different types of geologic formations where the necessary low temperatures and high pressures exist: in the permafrost and in deep ocean 2 sediments. The lower depth limit of hydrate deposits is controlled by the geothermal gradient.Current estimates of the worldwide quantity of hydrocarbon gas hydrates range between 10 15 to 10 18 m 3 . Even the most conservative estimates of the total quantity of gas in hydrates may surpass by a factor of two the energy content of the total fuel fossil reserves recoverable by conventional methods. The magnitude of this resource could make hydrate reservoirs a substantial future energy resource. While current economic realities do not...

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Section: The Hydrate V15 Codementioning

confidence: 99%

mentioning

confidence: 99%

mentioning

confidence: 99%

mentioning

confidence: 99%

mentioning

confidence: 99%

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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

Moridis¹

2014

101

115

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The Dependence of Water Permeability in Quartz Sand on Gas Hydrate Saturation in the Pore Space

et al. 2018

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Transport of fluids in gas hydrate bearing sediments is largely defined by the reduction of the permeability due to gas hydrate crystals in the pore space. Although the exact knowledge of the permeability behavior as a function of gas hydrate saturation is of crucial importance, state‐of‐the‐art simulation codes for gas production scenarios use theoretically derived permeability equations that are hardly backed by experimental data. The reason for the insufficient validation of the model equations is the difficulty to create gas hydrate bearing sediments that have undergone formation mechanisms equivalent to the natural process and that have well‐defined gas hydrate saturations. We formed methane hydrates in quartz sand from a methane‐saturated aqueous solution and used magnetic resonance imaging to obtain time‐resolved, three‐dimensional maps of the gas hydrate saturation distribution. These maps were fed into 3‐D finite element method simulations of the water flow. In our simulations, we tested the five most well‐known permeability equations. All of the suitable permeability equations include the term (1‐SH)n, where SH is the gas hydrate saturation and n is a parameter that needs to be constrained. The most basic equation describing the permeability behavior of water flow through gas hydrate bearing sand is k = k0 (1‐SH)n. In our experiments, n was determined to be 11.4 (±0.3). Results from this study can be directly applied to bulk flow analysis under the assumption of homogeneous gas hydrate saturation and can be further used to derive effective permeability models for heterogeneous gas hydrate distributions at different scales.

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Sequential formulation of all‐way coupled finite strain thermoporomechanics for largely deformable gas hydrate deposits

Kim,

Lee

2024

Num Anal Meth Geomechanics

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We develop a numerically stable sequential formulation of thermoporomechanics for largely deformable gas hydrate deposits, extended from the fixed stress split of infinitesimal transformation. Constitutive equations are based on the total Lagrangian approach for both flow and geomechanics, including dynamic full tensor permeability and thermal conductivity updated from the deformation gradient. For space discretization, we take the cell‐centered finite volume and node‐based finite element method for flow and geomechanics, respectively. Then, we propose a sequential implicit method for all‐way coupled thermoporomechanics, where the nonisothermal multiphase flow problem of gas hydrates is solved implicitly first and then the geomechanics problem is solved implicitly at the next step. During solution of the flow problem, we fix the rate of first Pioal total stress for numerical stability as well as apply porosity correction and entropy correction to account for geomechanical effects. We test numerical examples where flow and geomechanics parameters are based on deep oceanic gas hydrate deposits. When applying depressurization, even though the results between the infinitesimal transformation and finite strain geomechanics are similar in the early stages due to small deformation, we find differences between them in the late times as deformation becomes large. Accordingly, permeability and thermal conductivity tensors become nonisotropic full tensors although they are initially isotropic. We identify numerical stability of the developed sequential method from the test cases that exhibit the highly complex coupled gas hydrate systems with large deformation. Thus, the proposed sequential formulation can be applied in largely deformable gas hydrate systems.

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Field-Scale Simulation of Production from Oceanic Gas Hydrate Deposits

Cited by 78 publications

References 12 publications

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

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

The Dependence of Water Permeability in Quartz Sand on Gas Hydrate Saturation in the Pore Space

Sequential formulation of all‐way coupled finite strain thermoporomechanics for largely deformable gas hydrate deposits

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