Methane solubility in marine hydrate environments

Davie, Matthew; Zatsepina, Olga Ye.; Buffett, B. A.

doi:10.1016/s0025-3227(03)00331-1

Cited by 124 publications

(109 citation statements)

References 22 publications

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“…The use of (1c) is common (Davie et al 2004;Rempel 2012); in Peszyńska et al (2010), we showed little influence of a particular energy model for variable T (x) on methane fluxes over long time period. Instead of (1b), one can find P(x) from the pressure equation defined in the "Appendix.…”

Section: Reduced Model Of Hydrate and Salinity Transport With Methanementioning

confidence: 69%

“…In particular, it is known that the values of χ max lM in HSZ are most strongly controlled by the temperature (Rempel 2012;Davie et al 2004), with only a mild dependence on salinity, and with negligible dependence on the pressure.…”

Section: Model Calibrationmentioning

confidence: 99%

“…Our two-phase three-component physical model is a simplification of comprehensive models in Liu and Flemings (2008), Garg et al (2008), and Daigle and Dugan (2011) and is simultaneously a significant generalization of the simpler models in Xu and Ruppel (1999), Nimblett and Ruppel (2003), and Torres et al (2004), in which simplified kinetic or even simpler mechanisms for fluid equilibria were assumed. In contrast to Torres et al (2004) and consistently with Liu and Flemings (2008), our model fits in the general framework of multiphase multicomponent models such as those in Lake (1989) and Class et al (2002), and implements bona fide equilibrium phase constraints known from thermodynamics (Sloan and Koh 2008;Davie et al 2004), albeit in an approximate manner. In the companion paper Peszynska et al (2016) we present details of numerical discretization with a particular emphasis on the variants of the time-stepping, which are enabled by the approximations proposed here.…”

Section: Introductionmentioning

confidence: 99%

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Methane Hydrate Formation in Ulleung Basin Under Conditions of Variable Salinity: Reduced Model and Experiments

et al. 2016

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In this paper, we present a reduced model of methane hydrate formation in variable salinity conditions, with details on the equilibrium phase behavior adapted to a case study from Ulleung Basin. The model simplifies the comprehensive model considered by Liu and Flemings using common assumptions on hydrostatic pressure, geothermal gradient, and phase incompressibility, as well as a simplified phase equilibria model. The two-phase threecomponent model is very robust and efficient as well as amenable to various numerical analyses, yet is capable of simulating realistic cases. We compare various thermodynamic models for equilibria as well as attempt a quantitative explanation for anomalous spikes of salinity observed in Ulleung Basin.

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Section: Reduced Model Of Hydrate and Salinity Transport With Methanementioning

confidence: 69%

Section: Model Calibrationmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Methane Hydrate Formation in Ulleung Basin Under Conditions of Variable Salinity: Reduced Model and Experiments

et al. 2016

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“…The results showed no significant change in temperature and pressure in the autoclave over 20 hours (Figure 4b). The pressure was 18 MPa at the beginning and 17.5 MPa at the end, and the lost 0.5 MPa was likely due to the methane dissolution in the drilling fluid (the solubility of methane at 18 MPa, 4 °C in the 20% NaCl solution is about 34.32 mM [33], the corresponding dissolution gas volume in the drilling fluid is about 1.5 L at standard condition). Furthermore, the temperature in the autoclave showed almost no change.…”

Section: Hydrate Inhibitionmentioning

confidence: 99%

Polyethylene Glycol Drilling Fluid for Drilling in Marine Gas Hydrates-Bearing Sediments: An Experimental Study

et al. 2011

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Shale inhibition, low-temperature performance, the ability to prevent calcium and magnesium-ion pollution, and hydrate inhibition of polyethylene glycol drilling fluid were each tested with conventional drilling-fluid test equipment and an experimental gas-hydrate integrated simulation system developed by our laboratory. The results of these tests show that drilling fluid with a formulation of artificial seawater, 3% bentonite, 0.3% Na 2 CO 3 , 10% polyethylene glycol, 20% NaCl, 4% SMP-2, 1% LV-PAC, 0.5% NaOH and 1% PVP K-90 performs well in shale swelling and gas hydrate inhibition. It also shows satisfactory rheological properties and lubrication at temperature ranges from −8 °C to 15 °C. The PVP K-90, a kinetic hydrate inhibitor, can effectively inhibit gas hydrate aggregations at a dose of 1 wt%. This finding demonstrates that a drilling fluid with a high addition of NaCl and a low addition of PVP K-90 is suitable for drilling in natural marine gas-hydrate-bearing sediments.

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“…Perform a linear interpolation from the SMT, where the methane concentration is effectively zero, to the depth of the shallowest gas hydrate occurrence (73 mbsf at Site U1325 [Malinverno et al, 2008]), where methane concentrations must reach solubility in equilibrium with gas hydrate. Using the solubility curve of Davie et al [2004], this approach gives a gradient of ∼1 mM/m. However, methane generation below the SMT results in a concave downward profile [Schulz, 2006], and the actual methane gradient at the Figure 2b indicates the methane concentration gradient determined from the first few measurements below the SMT.…”

Section: Iodp Site U1325mentioning

confidence: 99%

Modeling sulfate reduction in methane hydrate-bearing continental margin sediments: Does a sulfate-methane transition require anaerobic oxidation of methane?

Malinverno

Pohlman

2011

Geochem. Geophys. Geosyst.

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[1] The sulfate-methane transition (SMT), a biogeochemical zone where sulfate and methane are metabolized, is commonly observed at shallow depths (1-30 mbsf) in methane-bearing marine sediments. Two processes consume sulfate at and above the SMT, anaerobic oxidation of methane (AOM) and organoclastic sulfate reduction (OSR). Differentiating the relative contribution of each process is critical to estimate methane flux into the SMT, which, in turn, is necessary to predict deeper occurrences of gas hydrates in continental margin sediments. To evaluate the relative importance of these two sulfate reduction pathways, we developed a diagenetic model to compute the pore water concentrations of sulfate, methane, and dissolved inorganic carbon (DIC). By separately tracking DIC containing 12 C and 13 C, the model also computes d 13 C-DIC values. The model reproduces common observations from methane-rich sediments: a welldefined SMT with no methane above and no sulfate below and a d 13 C-DIC minimum at the SMT. The model also highlights the role of upward diffusing 13 C-enriched DIC in contributing to the carbon isotope mass balance of DIC. A combination of OSR and AOM, each consuming similar amounts of sulfate, matches observations from Site U1325 (Integrated Ocean Drilling Program Expedition 311, northern Cascadia margin). Without AOM, methane diffuses above the SMT, which contradicts existing field data. The modeling results are generalized with a dimensional analysis to the range of SMT depths and sedimentation rates typical of continental margins. The modeling shows that AOM must be active to establish an SMT wherein methane is quantitatively consumed and the d 13 C-DIC minimum occurs. The presence of an SMT generally requires active AOM.

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Methane solubility in marine hydrate environments

Cited by 124 publications

References 22 publications

Methane Hydrate Formation in Ulleung Basin Under Conditions of Variable Salinity: Reduced Model and Experiments

Methane Hydrate Formation in Ulleung Basin Under Conditions of Variable Salinity: Reduced Model and Experiments

Polyethylene Glycol Drilling Fluid for Drilling in Marine Gas Hydrates-Bearing Sediments: An Experimental Study

Modeling sulfate reduction in methane hydrate-bearing continental margin sediments: Does a sulfate-methane transition require anaerobic oxidation of methane?

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