Regional long-term production modeling from a single well test, Mount Elbert Gas Hydrate Stratigraphic Test Well, Alaska North Slope

Anderson, B. J.; Kurihara, Masanori; White, Mark D.; Moridis, George J.; Wilson, Scott; Pooladi‐Darvish, Mehran; Gaddipati, Manohar; Masuda, Yoshihiro; Collett, Timothy S.; Hunter, Robert; Narita, Hideo; Rose, Kelly; Boswell, Ray

doi:10.1016/j.marpetgeo.2010.01.015

Cited by 178 publications

(131 citation statements)

References 8 publications

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“…In collaboration with BP Exploration (Alaska) and the U.S. Department of Energy (DOE), the U.S. Geological Survey (USGS) drilled a stratigraphic test well in 2007 to assess the potential of hydrates on the North Slope to become technically and commercially viable gas resource. Results were positive as the core data obtained from wireline Modular Dynamic Testing (MDT) analysis conformed well to pre-drill predictions and modelling techniques were validated and improved [192,193].…”

Section: Mount Elbert Well -Alaskamentioning

confidence: 87%

Review of natural gas hydrates as an energy resource: Prospects and challenges

et al. 2016

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Section: Mount Elbert Well -Alaskamentioning

confidence: 87%

Review of natural gas hydrates as an energy resource: Prospects and challenges

et al. 2016

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“…Some data on the structural properties like mean porosities and intrinsic permeabilities of hydrate-bearing sediments are available for some sites that have been investigated so far (see [14,16,17]). Thus mean porosities reported so far range from 0.2 to 0.5 (e.g., [16,17]), permeabilities range from 0.1 [17] to 1,000 mD [18].…”

Section: Classification Of Hydrate Depositsmentioning

confidence: 96%

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

Janicki

Schlüter

Hennig

et al. 2011

Journal of Geological Research

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In the medium term, gas hydrate reservoirs in the subsea sediment are intended as deposits for carbon dioxide (CO 2 ) from fossil fuel consumption. This idea is supported by the thermodynamics of CO 2 and methane (CH 4 ) hydrates and the fact that CO 2 hydrates are more stable than CH 4 hydrates in a certain P-T range. The potential of producing methane by depressurization and/or by injecting CO 2 is numerically studied in the frame of the SUGAR project. Simulations are performed with the commercial code STARS from CMG and the newly developed code HyReS (hydrate reservoir simulator) especially designed for hydrate processing in the subsea sediment. HyReS is a nonisothermal multiphase Darcy flow model combined with thermodynamics and rate kinetics suitable for gas hydrate calculations. Two scenarios are considered: the depressurization of an area 1,000 m in diameter and a one/two-well scenario with CO 2 injection. Realistic rates for injection and production are estimated, and limitations of these processes are discussed.

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“…Several efficient and feasible gas recovery methods for in-situ CH 4 recovery from the hydrate reservoirs have been proposed, such as hot water injection [4,5], in situ combustion [6,7], depressurization [8][9][10][11], inhibitor injection [12,13], CO 2 replacement [14,15] and the combined methods [16][17][18][19][20]. Using these technologies, extensive research on natural gas production from hydrate in field trials has been conducted within the last decade [21][22][23][24][25]. Natural gas has been successfully extracted by injection of hot water and by depressurization at the permafrost reservoir of the Mallik site in Northwest Canada [21].…”

Section: Introductionmentioning

confidence: 99%

Numerical Investigation of the Production Behavior of Methane Hydrates under Depressurization Conditions Combined with Well-Wall Heating

Ruan

2017

Energies

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Abstract:In this study, a 2D hydrate dissociation simulator has been improved and verified to be valid in numerical simulations of the gas production behavior using depressurization combined with a well-wall heating method. A series of numerical simulations were performed and the results showed that well-wall heating had an influence enhancing the depressurization-induced gas production, but the influence was limited, and it was even gradually weakened with the increase of well-wall heating temperature. Meanwhile, the results of the sensitivity analysis demonstrated the gas production depended on the initial hydrate saturation, initial pressure and the thermal boundary conditions. The supply of heat for hydrate dissociation mainly originates from the thermal boundaries, which control the hydrate dissociation and gas production by depressurization combined with well-wall heating. However, the effect of initial temperature on the gas production could be nearly negligible under depressurization conditions combined with well-wall heating.

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Regional long-term production modeling from a single well test, Mount Elbert Gas Hydrate Stratigraphic Test Well, Alaska North Slope

Cited by 178 publications

References 8 publications

Review of natural gas hydrates as an energy resource: Prospects and challenges

Review of natural gas hydrates as an energy resource: Prospects and challenges

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

Numerical Investigation of the Production Behavior of Methane Hydrates under Depressurization Conditions Combined with Well-Wall Heating

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