Numerical simulations of depressurization-induced gas production from gas hydrates using 3-D heterogeneous models of L-Pad, Prudhoe Bay Unit, North Slope Alaska

Myshakin, Evgeniy M.; Ajayi, T. R.; Anderson, B. J.; Seol, Yongkoo; Boswell, Ray

doi:10.1016/j.jngse.2016.09.070

Cited by 62 publications

(25 citation statements)

References 21 publications

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“…where k rA and k rG are the relative permeability of the aqueous and gas phases, respectively; S irA and S irG are the irreducible aqueous and gas saturation, respectively; n A is the model parameter, which is set to 5.04 [35]; and n G is the model parameter, which is set to 3.16 [35].…”

Section: Permeability Modelmentioning

confidence: 99%

See 1 more Smart Citation

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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Section: Permeability Modelmentioning

confidence: 99%

“…where p c is the capillary pressure; p c0 is the model parameter, which is set to 10 4 Pa [35]; and k is the model parameter, which is set to 0.77437 [35].…”

Section: Capillary Pressure Modelmentioning

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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show abstract

“…Although relative permeability of conventional reservoir rocks has been studied for a long time 11,12 , to our knowledge, there seems to be no peer-reviewed literature on experimental relative permeability of combined gas and brine flow in hydrate-bearing sediments. Numerical simulations of gas hydrate uses empirical models [13][14][15][16] (e.g. B-C, van Genuchten, etc.)…”

Section: A Novel Relative Permeability Model For Gas and Water Flow Imentioning

confidence: 99%

A Novel Relative Permeability Model for Gas and Water Flow in Hydrate-Bearing Sediments With Laboratory and Field-Scale Application

Singh

Myshakin

Seol

2020

Sci Rep

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In a producing gas hydrate reservoir the effective porosity available for fluid flow constantly changes with dissociation of gas hydrate. Therefore, accurate prediction of relative permeability using legacy models (e.g. Brooks-Corey (B-C), van Genuchten, etc.) that were developed for conventional oil and gas reservoirs would require empirical parameters to be calibrated at various Sh over its range of variation, but such calibrations are precluded because of lack of experimental relative permeability data. This study proposes a new relative permeability model for gas hydrate-bearing media that is a function of maximum capillary pressure, capillary entry pressure, pore size distribution index, residual saturations, hydrate saturation, and four other constants. The three novel features of the proposed model are: (i) requires fitting its six empirical parameters only once using experimental data from any single Sh, and the same set of empirical parameters predict relative permeability at all Sh, (ii) includes the effect of capillarity, and (iii) includes the effect of pore-size distribution. From practical standpoint, the model can be used to simulate multiphase flow in gas hydrate-bearing sediments where the proposed relative permeability can account for the evolving hydrate saturation. The proposed model is implemented in a numerical simulator and the wall time required to perform simulations using the proposed model is shown to be similar to the time it takes to run same simulations with the B-C model. The proposed model is a step forward towards achieving the goal of physically accurate modeling of multiphase flow for gas hydrate-bearing sediments that accounts for the effect of gas hydrate saturation change on relative permeability.

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“…The decomposition of natural gas hydrate is an endothermic process, the reservoir temperature during the depressurization development process gradually decreases, and a secondary generation of hydrate is apt to occur in the near-wellbore area. Myshakin et al established 2D and 3D models to simulate and analyze the rules of secondary hydrate generation and ice blockage during the depressurization development process [16,17]. Ruan et al established a three-phase three-component core-scale hydrate depressurization simulation model and studied the influences of the hydrate secondary generation and permeability change on the development of depressurization [18].…”

Section: Introductionmentioning

confidence: 99%

Investigation on the Secondary Generation of Natural Gas Hydrates in Horizontal Wellbore Caused by Pressure Jump during the Depressurization Development of Hydrate Bearing Layers

Liu

Hou

et al. 2020

Geofluids

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When the depressurization development of a hydrate-bearing layer is initiated, the temperature of the near-wellbore formation quickly decreases to near the equilibrium temperature due to the dissociation of natural gas hydrate Therefore, the secondary generation of natural gas hydrates in the wellbore easily occurs if pressure jumps to a high value due to the changes of production rates or shutdown of the well. Though hydrate generation in the process of high-pressure drilling and gas and water transportation has been widely investigated, the secondary generation of natural gas hydrates caused by pressure jump during the depressurization development process is not fully understood. In this study, the multiphase pipe flow of a horizontal well, the Vyniauskas–Bishnoi generation dynamics of natural gas hydrate, and a decomposition dynamics model developed by Kim and Bishnoi are combined to build a set of horizontal well gas–liquid–solid three-phase flow models, which consider the phase transition in the wellbore and distinguished the secondary hydrate generation area in the wellbore under different temperature and pressure conditions. The results show that when the toe-end pressure is 7 MPa and the environment temperature is 6.4°C, the secondary hydrate generation exists in the horizontal section of the horizontal well, and the maximum hydrate flow velocity in the wellbore is 0.044 m3/d. A high toe-end pressure, low environment temperature, and high gas output will result in a greater hydrate generation in the wellbore, and the wellbore pressure will have a remarkable influence on the amount generated and its range.

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Numerical simulations of depressurization-induced gas production from gas hydrates using 3-D heterogeneous models of L-Pad, Prudhoe Bay Unit, North Slope Alaska

Cited by 62 publications

References 21 publications

Cyclic methane hydrate production stimulated with CO₂ and N₂

Cyclic methane hydrate production stimulated with CO₂ and N₂

A Novel Relative Permeability Model for Gas and Water Flow in Hydrate-Bearing Sediments With Laboratory and Field-Scale Application

Investigation on the Secondary Generation of Natural Gas Hydrates in Horizontal Wellbore Caused by Pressure Jump during the Depressurization Development of Hydrate Bearing Layers

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Numerical simulations of depressurization-induced gas production from gas hydrates using 3-D heterogeneous models of L-Pad, Prudhoe Bay Unit, North Slope Alaska

Cited by 62 publications

References 21 publications

Cyclic methane hydrate production stimulated with CO2 and N2

Cyclic methane hydrate production stimulated with CO2 and N2

A Novel Relative Permeability Model for Gas and Water Flow in Hydrate-Bearing Sediments With Laboratory and Field-Scale Application

Investigation on the Secondary Generation of Natural Gas Hydrates in Horizontal Wellbore Caused by Pressure Jump during the Depressurization Development of Hydrate Bearing Layers

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Cyclic methane hydrate production stimulated with CO₂ and N₂

Cyclic methane hydrate production stimulated with CO₂ and N₂