3‐D basin‐scale reconstruction of natural gas hydrate system of the <scp>G</scp>reen <scp>C</scp>anyon, <scp>G</scp>ulf of <scp>M</scp>exico

Burwicz, Ewa; Reichel, Thomas; Wallmann, Klaus; Rottke, W.; Haeckel, Matthias; Hensen, Christian

doi:10.1002/2017gc006876

Cited by 41 publications

(97 citation statements)

References 65 publications

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“…Using 10,000 Monte Carlo trials in 153 grid cells, we found that the volume of gas hydrate‐bound gas in the specific study area in Green Canyon ranged from 0.1 to 0.35 TCM. Most likely, ~0.22 TCM of gas at STP is hosted in gas hydrate in the study area, which is in close agreement with the result from Burwicz et al (). This result provides mutual credibility to the basin‐reconstruction 3‐D model by Burwicz et al () predominantly based on seismic data, and the more unconventional Monte Carlo simulation approach of this study based on empirical data set of gas hydrate occurrence from well logs.…”

Section: Resultssupporting

confidence: 91%

“…Regional estimates of volume of gas hydrate‐bound gas have been carried out in small areas in Walker Ridge and Green Canyon areas in the northern Gulf of Mexico (Burwicz et al, ; Frye et al, ). Here we compare our results to Burwicz et al (), who used a comparatively small study area (Figure ). Burwicz et al () used comprehensive basin‐scale 3‐D modeling in a small study area of ~30 × 15‐km 2 dimension in Green Canyon (Figure ).…”

Section: Resultsmentioning

confidence: 99%

“…To compare our gas hydrate‐bound gas volume estimate using empirical data set of gas hydrate occurrences in petroleum industry wells, with the results from Burwicz et al, , we developed a Monte Carlo simulation using equation in the same area (Figure ), through sampling from probability distributions of the three trial variables ( n , f gh , f sand ) and five cell variables ( T HSZ , f , ϕ, S gh , and v ). The study area (~450 km 2 ) consisted of 153 grid cells, ~2.9 km 2 each.…”

Section: Resultsmentioning

confidence: 99%

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The Volume of Gas Hydrate‐Bound Gas in the Northern Gulf of Mexico

Majumdar

Cook

2018

Geochem Geophys Geosyst

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The northern Gulf of Mexico is known to host gas hydrate in submarine sediments. Estimating the amount of gas hydrate for both carbon cycle and resource interest has been ongoing for more than three decades. A large range of estimates (from 0.2 to 680 trillion cubic meters (TCM)) for hydrate‐bound natural gas at standard temperature and pressure exists. We bring a new perspective to resource estimates by using ~800 publicly available petroleum industry well logs assessed for natural gas hydrate. Our resulting probabilistic range of the gas hydrate‐bound natural gas in the northern Gulf of Mexico ranges from 37 TCM (10th percentile estimate) to 78 TCM (90th percentile estimate) of gas hydrate‐bound natural gas, with a mean estimate of 56 TCM. This suggests that the gas hydrate resource density of the northern Gulf of Mexico is 4 times lower than that previously estimated by the Bureau of Ocean Energy Management. Our results also indicate that over half of the gas hydrate in the area is strategically hosted in sand reservoirs, which is significantly higher than that previously estimated.

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Section: Resultssupporting

confidence: 91%

Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%

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The Volume of Gas Hydrate‐Bound Gas in the Northern Gulf of Mexico

Majumdar

Cook

2018

Geochem Geophys Geosyst

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“…As a result, enriched hydrates would form and clog the sediment pores preventing upward gas flow and further feeding hydrate growth above the BHSZ unless the thin clogged layer can be breached and the free gas flow can be restored (Xu & Ruppel, ). Burwicz et al () used this assumption and simulated significant gas hydrate saturations situated directly at the BHSZ by recharge of methane gas from decomposing gas hydrates using a three‐dimensional basin‐scale model.…”

Section: Models Of Methane Hydrate Formation In Geological Systemsmentioning

confidence: 99%

Mechanisms of Methane Hydrate Formation in Geological Systems

You

Flemings

Malinverno

et al. 2019

Reviews of Geophysics

162

110

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Natural gas hydrate is ice‐like mixture of gas (mostly methane) and water that is widely found in sediments along the world's continental margins and within and beneath permafrost and glaciers in a near‐surface depth interval where the pressure is sufficiently high and temperature sufficiently low for gas hydrate to be stable. We categorize the myriad of geological gas hydrate deposits into five characteristic types. We then review the multiple quantitative models that have proposed to describe the genesis of these deposits and describe how each may have formed. We emphasize the importance of coupling multiphase flow (free gas and liquid water) and multicomponent reactive transport with geological history to describe the dynamical processes of gas hydrate formation and evolution in geological systems. A better insight into the kinetics of methane formation from microbial biogenesis and the processes of multiphase flow at the pore scale will advance our knowledge of how these systems form. By understanding the generation and evolution of gas hydrate through time, we will better decipher the role of gas hydrate in the carbon cycle, its potential to contribute to climate change and geohazards, and how to design optimal strategies for gas production from hydrate reservoirs.

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“…Concentrated hydrate deposits tend to form at and just above the base of gas hydrate stability (BGHS). This results in a sharp contrast in mechanical properties at the phase cementing hydrate occupy the pore space [10]. This contrast in physical properties is expressed in seismic data as bottom simulating reflections (BSRs), and BSRs remain our strongest remotely sensed indicator to infer the presence of GH [11].…”

Section: Introductionmentioning

confidence: 99%

Gas-In-Place Estimate for Potential Gas Hydrate Concentrated Zone in the Kumano Basin, Nankai Trough Forearc, Japan

2017

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Methane hydrate concentrated zones (MHCZs) have become targets for energy exploration along continental margins worldwide. In 2013, exploratory drilling in the eastern Nankai Trough at Daini Atsumi Knoll confirmed that MHCZs tens of meters thick occur directly above bottom simulating reflections imaged in seismic data. This study uses 3-dimensional (3D) seismic and borehole data collected from the Kumano Basin offshore Japan to identify analogous MHCZs. Our survey region is located~100 km southwest of the Daini Atsumi Knoll, site of the first offshore gas hydrate production trial. Here we provide a detailed analysis of the gas hydrate system within our survey area of the Kumano forearc including: (1) the 3D spatial distribution of bottom simulating reflections; (2) a thickness map of potential MHCZs; and (3) a volumetric gas-in-place estimate for these MHCZs using constraints from our seismic interpretations as well as previously collected borehole data. There is evidence for two distinct zones of concentrated gas hydrate 10-90 m thick, and we estimate that the amount of gas-in-place potentially locked up in these MHCZs is 1.9-46.3 trillion cubic feet with a preferred estimate of 15.8 trillion cubic feet. Keywords: gas hydrates; Kumano Basin; bottom simulating reflections; methane hydrate exploration; 3D seismic interpretation; Nankai Trough IntroductionNatural gas hydrates (GH) are crystalline inclusion compounds that form within the pore space of marine sediments along continental margins worldwide. These hydrate deposits are stable at specific pressure-temperature relationships, host highly compressed gas molecules (most commonly methane), and are proposed to be the largest dynamic reservoir of organic carbon on this planet [1][2][3]. GHs have enticed global interest for several reasons including climate change and potential slope stability hazards, but primarily because these deposits could prove to be an unconventional energy resource [3,4]. At the exploration stage, it is important to develop systematic GH exploration methods that consider gas source, migration mechanisms into the hydrate stability field, zones of free gas, indicators of gas hydrate accumulation, and at least a first order volumetric gas-in-place estimate for apparent zones of concentrated hydrates [5,6].Seismic imaging is an important tool for identifying GH because both GH and free gas alter the physical properties of marine sediments, which will in turn affect the travel path and attenuation of the seismic wavelet [7][8][9]. Concentrated hydrate deposits tend to form at and just above the base of gas hydrate stability (BGHS). This results in a sharp contrast in mechanical properties at the phase boundary between GH saturated layers overlying a zone where free gas, water, and potentially non-cementing hydrate occupy the pore space [10]. This contrast in physical properties is expressed in seismic data as bottom simulating reflections (BSRs), and BSRs remain our strongest remotely sensed indicator to infer the presence of GH [11...

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3‐D basin‐scale reconstruction of natural gas hydrate system of the Green Canyon, Gulf of Mexico

Cited by 41 publications

References 65 publications

The Volume of Gas Hydrate‐Bound Gas in the Northern Gulf of Mexico

The Volume of Gas Hydrate‐Bound Gas in the Northern Gulf of Mexico

Mechanisms of Methane Hydrate Formation in Geological Systems

Gas-In-Place Estimate for Potential Gas Hydrate Concentrated Zone in the Kumano Basin, Nankai Trough Forearc, Japan

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