Formation pressure testing at the Mount Elbert Gas Hydrate Stratigraphic Test Well, Alaska North Slope: Operational summary, history matching, and interpretations

Anderson, B. J.; Hancock, Steve H.; Wilson, Scott; Enger, Christopher; Collett, Timothy S.; Boswell, Ray; Hunter, Robert

doi:10.1016/j.marpetgeo.2010.02.012

Cited by 73 publications

(57 citation statements)

References 10 publications

(9 reference statements)

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“…The successful depressurization of the reservoir by fluid withdrawal during the MDT program confirms this observation. Analysis of MDT reservoir pressure tests in a variety of advanced reservoir simulators (reviewed by Anderson et al, 2011) has enabled an estimate of 0.12 to 0.17 mD for the insitu effective permeability of the reservoir in the presence of the gas hydrate phase, which compares favorably to the NMR log derived reservoir permeabilities depicted in Fig. 1.…”

Section: Well Log-inferred Gas Hydratementioning

confidence: 94%

“…Following logging, reservoir pressure testing was conducted with the Schlumberger Modular Formation Dynamic Tester* (MDT) at four open-hole stations in two hydrate-bearing sandstone reservoirs (for details on the testing program, see Anderson et al, 2011). Each test consisted of flow and shut-in periods of varying lengths, with one lasting for more than 13 hours.…”

Section: Well Site Operationsmentioning

confidence: 99%

“…The "main hole" was not cased. Drill pipe conveyed formation pressure testing (MDT test as reviewed by Anderson et al, 2011) were conducted at four depths in the Mount Elbert well as depicted in Track 2: MDT Test C1 e 2161 ft (658.6 m), MDT Test C2 e 2151 ft (655.6 m), MDT Test D1 e 2047 ft (623.9 m), MDT Test D2 e 2025 ft (617.2 m).…”

Section: Track 2 Completion Conditionsmentioning

confidence: 99%

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Downhole well log and core montages from the Mount Elbert Gas Hydrate Stratigraphic Test Well, Alaska North Slope

Collett

Lewis

Winters

et al. 2011

Marine and Petroleum Geology

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a b s t r a c tThe BPXA-DOE-USGS Mount Elbert Gas Hydrate Stratigraphic Test Well was an integral part of an ongoing project to determine the future energy resource potential of gas hydrates on the Alaska North Slope. As part of this effort, the Mount Elbert well included an advanced downhole geophysical logging program. Because gas hydrate is unstable at ground surface pressure and temperature conditions, a major emphasis was placed on the downhole-logging program to determine the occurrence of gas hydrates and the in-situ physical properties of the sediments. In support of this effort, well-log and core data montages have been compiled which include downhole log and core-data obtained from the gashydrate-bearing sedimentary section in the Mount Elbert well. Also shown are numerous reservoir parameters, including gas-hydrate saturation and sediment porosity log traces calculated from available downhole well log and core data.Published by Elsevier Ltd.

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Section: Well Log-inferred Gas Hydratementioning

confidence: 94%

Section: Well Site Operationsmentioning

confidence: 99%

Section: Track 2 Completion Conditionsmentioning

confidence: 99%

See 1 more Smart Citation

Downhole well log and core montages from the Mount Elbert Gas Hydrate Stratigraphic Test Well, Alaska North Slope

Collett

Lewis

Winters

et al. 2011

Marine and Petroleum Geology

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show abstract

“…The hydraulic and thermal properties of the various geological media (the HBL and the confining layers) in unit D, as well as the initial conditions, were obtained from data based on the first field test at the site (Anderson et al, 2008(Anderson et al, , 2011a, and are listed in Table 1. We assumed that the initial hydrate and aqueous saturations (S H and S A , respectively) were uniformly distributed in the HBL, and that the overburden and underburden had both the same properties.…”

Section: System Properties and Well Descriptionmentioning

confidence: 99%

Gas production from a cold, stratigraphically-bounded gas hydrate deposit at the Mount Elbert Gas Hydrate Stratigraphic Test Well, Alaska North Slope: Implications of uncertainties

Moridis

Silpngarmlert

Reagan

et al. 2011

Marine and Petroleum Geology

185

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“…The hydraulic and thermal properties of the various geological media (the HBL and the confining layers) for unit D, as well as the initial conditions, were obtained from data based on the first field test at the site (Anderson et al, 2010) and are listed in Table 1. The base case assumed that the initial hydrate and aqueous saturations (S H and S A ) were uniform within in the HBL, and that the overburden and underburden had the same properties.…”

Section: Domain Discretizationmentioning

confidence: 99%

The Effect of Reservoir Heterogeneity on Gas Production From Hydrate Accumulations in the Permafrost

Reagan¹

2010

Proceedings of SPE Western Regional Meeting

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The quantity of hydrocarbon gases trapped in natural hydrate accumulations is enormous, leading to significant interest in the evaluation of their potential as an energy source. Large volumes of gas can be readily produced at high rates for long times from methane hydrate accumulations in the permafrost by means of depressurization-induced dissociation combined with conventional technologies and horizontal or vertical well configurations. Initial studies on the possibility of natural gas production from permafrost hydrates assumed homogeneity in intrinsic reservoir properties and in the initial condition of the hydrate-bearing layers (either due to the coarseness of the model or due to simplifications in the definition of the system). These results showed great promise for gas recovery from Class 1, 2, and 3 systems in the permafrost. This work examines the consequences of inevitable heterogeneity in intrinsic properties, such as in the porosity of the hydrate-bearing formation, or heterogeneity in the initial state of hydrate saturation. Heterogeneous configurations are generated through multiple methods: 1) through defining heterogeneous layers via existing well-log data, 2) through randomized initialization of reservoir properties and initial conditions, and 3) through the use of geostatistical methods to create heterogeneous fields that extrapolate from the limited data available from cores and well-log data. These extrapolations use available information and established geophysical methods to capture a range of deposit properties and hydrate configurations. The results show that some forms of heterogeneity, such as horizontal stratification, can assist in production of hydrate-derived gas. However, more heterogeneous structures can lead to complex physical behavior within the deposit and near the wellbore that may obstruct the flow of fluids to the well, necessitating revised production strategies. The need for fine discretization is crucial in all cases to capture dynamic behavior during production.

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Formation pressure testing at the Mount Elbert Gas Hydrate Stratigraphic Test Well, Alaska North Slope: Operational summary, history matching, and interpretations

Cited by 73 publications

References 10 publications

Downhole well log and core montages from the Mount Elbert Gas Hydrate Stratigraphic Test Well, Alaska North Slope

Downhole well log and core montages from the Mount Elbert Gas Hydrate Stratigraphic Test Well, Alaska North Slope

Gas production from a cold, stratigraphically-bounded gas hydrate deposit at the Mount Elbert Gas Hydrate Stratigraphic Test Well, Alaska North Slope: Implications of uncertainties

The Effect of Reservoir Heterogeneity on Gas Production From Hydrate Accumulations in the Permafrost

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