In situ methane hydrate dissociation with carbon dioxide sequestration: Current knowledge and issues

Goel, Naval

doi:10.1016/j.petrol.2006.01.005

Cited by 253 publications

(141 citation statements)

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“…(1.13); δ 0 is the reference porosity, which is normally chosen as the total porosity δ; is a parameter that determines the decreasing rate of absolute permeability with δ e . This work uses = 0.5 from an assessment of the data from literature (Goel, 2006).…”

Section: Kineticsmentioning

confidence: 99%

“…The relative permeabilities of gas and aqueous phases would be given by a Corey model (Goel, 2006 In Eqs. (1.18) and (1.19), the residual aqueous phase saturation and gas phase saturation, S wr and S gr , are based on the pore volume occupied by fluid phases (namely effective pore volume).…”

Section: Kineticsmentioning

confidence: 99%

“…The gas phase viscosity, κ g (cp), as a function of temperature and density is given by (Selim and Sloan, 1989) : Where C vj is the specific heat at constant volume of phase j, C pj is the specific heat at constant pressure of phase j; subscript "r" stands for rock (sediment skeleton); subscript j refers to phases G, A or H. Here, C pj is the heat capacity and is the throttling coefficient for the phase θ j , respectively. ϕ is the effective thermal conductivity of the sediment given by (Goel, 2006).…”

Section: Kineticsmentioning

confidence: 99%

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Dissociation and Subsidence of Hydrated Sediment: Coupled Models

Pallipurath¹

2009

Energy Exploration & Exploitation

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Thermal dissociation of hydrated sediment by a pumped hot fluid is modeled. A radial heat flow from the hot pipe is assumed. The coordinate system is cylindrical. Three components (hydrate, methane and water) and three phases (hydrate, gas, and aqueous-phase) are considered in the simulator. The intrinsic kinetics of hydrate formation or dissociation is considered using the KimBishnoi model. Mass transport, including two-phase flow, molecular diffusions and heat transfer involved in formation or dissociation of hydrates are included in the governing equations, which are discretized with finite volume difference method and are solved in an explicit manner. The strength deterioration of the hydrate bed as a result of dissociation is investigated with a geo-mechanical model. The way in which dissociation affects the bed strength is determined by plugging in the porosity and saturation change as a result of dissociation into the sediment collapse equations. A mechanism to measure the pore pressure changes occurring due to dissociation is developed. The rate of collapse as dissociation proceeds is determined and the model thus enables the definition of a safety envelope for gas hydrate drilling.

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Section: Kineticsmentioning

confidence: 99%

Section: Kineticsmentioning

confidence: 99%

Section: Kineticsmentioning

confidence: 99%

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Dissociation and Subsidence of Hydrated Sediment: Coupled Models

Pallipurath¹

2009

Energy Exploration & Exploitation

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“…In addition to the equilibrium condition, porous media may affect other thermodynamic properties of hydrates. For example, in Goel's (2006) review of CH 4 production with CO 2 sequestration, a number of contrasting observations were revealed concerning the in-situ enthalpy of dissociation of CO 2 and CH 4 hydrates. Some research indicated that there was an increase in the heat of dissociation between in-situ and ex-situ conditions; whereas, other research indicated the opposite.…”

Section: Gas Exchangementioning

confidence: 99%

“…In geologic media that have distribution of pore sizes, hydrates would form and dissociate over a range of temperatures and pressures according to the distribution of pore radii and accounting for the impact of salts in the residual pore water (MCGRAIL et al, 2007). The critical conclusion from Goel's (2006) drates in porous media is that to understand the gas exchange technology there is a need for quantitative estimates of formation and dissociation processes in geologic media core samples.…”

Section: Gas Exchangementioning

confidence: 99%

Using Carbon Dioxide to Enhance Recovery of Methane from Gas Hydrate Reservoirs: Final Summary Report

McGrail¹,

Schaef²,

White³

et al. 2007

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Executive SummaryAlthough recent estimates (MILKOV et al., 2003) put the global accumulations of natural gas hydrate at 3,000 to 5,000 trillion cubic meters (TCM), compared against 440 TCM estimated (COLLETT, 2004) for conventional natural gas accumulations, how much gas could be produced from these vast natural gas hydrate deposits remains speculative. What is needed to convert these gas-hydrate accumulations to recoverable reserves are technological innovations, sparked through sustained scientific research and development. As with other unconventional energy resources, the challenge is to first understand the resource, its coupled thermodynamic and transport properties, and then address production challenges.Carbon dioxide sequestration coupled with hydrocarbon resource recovery is often economically attractive. Use of CO 2 for enhanced recovery of oil, conventional natural gas, and coal-bed methane are in various stages of common practice. In this report, we discuss a new technique utilizing CO 2 for enhanced recovery of natural gas hydrate. We have focused our attention on the Alaska North Slope where approximately 640 Tcf of natural gas reserves in the form of gas hydrate have been identified. Alaska is also unique in that potential future CO 2 sources are nearby, and petroleum infrastructure exists or is being planned that could bring the produced gas to market or for use locally.The EGHR (Enhanced Gas Hydrate Recovery) concept discussed in this report takes advantage of the physical and thermodynamic properties of mixtures in the H 2 O-CO 2 system combined with controlled multiphase flow, heat, and mass transport processes in hydrate-bearing porous media. A chemical-free method is used to deliver a L CO2 -L w microemulsion into the gas hydrate bearing porous medium. The microemulsion is injected at a temperature higher than the stability point of methane hydrate, which upon contacting the methane hydrate decomposes its crystalline lattice and releases the enclathrated gas. Conversion of the microemulsion to CO 2 hydrate occurs over time as controlled by heat transfer, diffusion, and the intrinsic kinetics of CO 2 hydrate formation. Sensible heat of the emulsion and heat of formation of the CO 2 hydrate provide a low grade heat source for further dissociation of methane hydrate away from the injectate plume. Process control is afforded by variation in the temperature of the emulsion, ratio of CO 2 and water, and droplet size of the discrete CO 2 phase. Small scale column experiments show injection of the emulsion into a methane hydrate rich sand results in the release of CH 4 gas and the formation of CO 2 hydrate. The experimental results were verified with computer modeling using the STOMP-HYD simulator, which showed over 3X enhancement in production rate using the EGHR technique when compared with warm water injection alone.The gas exchange technology (including EHGR) releases methane by replacing it with a more thermodynamic molecule (e.g., carbon dioxide). This technology has four advantageous: 1) i...

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Imaging methane hydrates growth dynamics in porous media using synchrotron X‐ray computed microtomography

Kerkar

Horvat

Jones

et al. 2014

Geochem Geophys Geosyst

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Commercial-scale methane (CH 4 ) extraction from natural hydrate deposits remains a challenge due to, among other factors, a poor understanding of hydrate-host sediment interactions under low-temperature and high-pressure conditions that are conducive to their existence. We report the use of synchrotron X-ray computed microtomography (CMT) to image, for the first time, time-resolved pore-scale methane CH 4 hydrate growth from an aqueous solution containing 5 wt % barium chloride (BaCl 2 ) and pressurized CH 4 hosted in glass beads, all contained in an aluminum cell with an effective volume of 3.5 mL. Multiple two-dimensional (2-D) cross-sectional images show CH 4 hydrates, with 7.5 mm resolution, distributed in patches throughout the system without dependence on distance from the cell walls. The time-resolved three-dimensional (3-D) images, constructed from the 2-D slices, exhibited pore-filling hydrate formation from dissolved CH 4 gas, similar to natural CH 4 hydrates (sI) in the marine environment. Furthermore, the 3-D images show that the aqueous phase was the wetting phase of the glass beads, i.e., the host and the formed hydrate were separated by an aqueous layer. These results provide some fundamental understanding of the nucleation phenomenon of gas hydrate formation at the pore scale. Pore-filling CH 4 hydrate growth is likely to result in a reduced bulk modulus, and thus, could affect seafloor stability during the reverse phenomenon, i.e., dissociation of natural hydrate deposits.

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In situ methane hydrate dissociation with carbon dioxide sequestration: Current knowledge and issues

Cited by 253 publications

References 35 publications

Dissociation and Subsidence of Hydrated Sediment: Coupled Models

Dissociation and Subsidence of Hydrated Sediment: Coupled Models

Using Carbon Dioxide to Enhance Recovery of Methane from Gas Hydrate Reservoirs: Final Summary Report

Imaging methane hydrates growth dynamics in porous media using synchrotron X‐ray computed microtomography

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