Simulation and Economics of Coalbed Methane Production in the Powder River Basin

Ried, G.W.; Towler, B.F.; Harris, H.G.

doi:10.2523/24360-ms

Cited by 6 publications

(5 citation statements)

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“…The influence of sorption time in the production of water and gas has been investigated by several researchers using different solutions [31][32][33][34][35]. However, the importance of this influence is not established in the same form by all the studies.…”

Section: Sorption Time Dependency Of Cbm Generationmentioning

confidence: 96%

Influence of sorption time in CO 2 -ECBM process in Indian coals using coupled numerical simulation

Vishal

Singh

Ranjith

2015

Fuel

141

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Section: Sorption Time Dependency Of Cbm Generationmentioning

confidence: 96%

Influence of sorption time in CO 2 -ECBM process in Indian coals using coupled numerical simulation

Vishal

Singh

Ranjith

2015

Fuel

141

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“…Coal permeability is an important parameter for CBM production and ECBM recovery [18][19][20]. There are generally two competing effects on the absolute permeability evolution of the coal.…”

Section: Introductionmentioning

confidence: 99%

Evolution of Production and Transport Characteristics of Steeply-Dipping Ultra-Thick Coalbed Methane Reservoirs

et al. 2020

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The large spatial variability of in-situ stress and initial reservoir pressure in steeply-dipping ultra-thick coalbed methane (UTCBM) reservoirs exert strong control on the initial distribution of stress-sensitive permeability. This results in significant differences in the propagation of reservoir depressurization, gas production characteristics, distribution of fluid saturation, and evolution of permeability relative to flat-lying and thin counterpart coalbed methane (CBM) reservoirs. We contrast these responses using the Fukang mining area of the Junggar Basin, Xinjiang, China, as a type-example using coupled hydro-mechanical modeling. Production response indicates: (1) Dual peaks in CBM production rate, due to the asynchronous changes in the gas production rate in each the upper and lower sections of the reservoir; (2) higher depressurization and water saturation levels in the lower section of the reservoir relative to the upper at any given distance from the production well that ameliorate with time to be similar to those of standard horizontal reservoirs; (3) the heterogeneity in effective stress is further amplified by the asymmetry of the initial pressure drawdown distribution of the reservoir to exert extreme control on the down-dip evolution of absolute permeability—with implications for production. Field drainage data and simulation results obtained in this study more accurately reflect the drainage characteristics of the steeply-dipping UTCBM reservoirs. For ultra-thick low-rank coal seams, permeability anisotropy plays an important role in determining the utility of horizontal wells and hydraulic fracturing to maximize rates and yields CBM production, and requiring further study.

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“…The figure contains 'primary', 'secondary', 'tertiary' and 'master cleats'. In this analysis, the length, spacing, and apertures are measured from all of these cleat types fluid flow during CBM extraction (Harpalani 1999;Palmer 2009;Reid et al 1992;Sparks et al 1995) and controlling the stability of the coal seams during mining operations are already recognized (Pattison et al 1996). From the study of coal core samples of the San Juan and Warrior Basin, Puri et al (1991) showed that Darcy flow dominates in the cleat system and contribution from coal matrix in fluid flow can be neglected.…”

Section: Introductionmentioning

confidence: 99%

Dependence of fluid flow on cleat aperture distribution and aperture–length scaling: a case study from Gondwana coal seams of Raniganj Formation, Eastern India

Bandyopadhyay

Mallik

Ghosh

2019

Int J Coal Sci Technol

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Dimensions and mutual relationships amongst fracture (cleat) parameters such as maximum aperture width, average aperture width, length, spacing etc. control the connectivity within a fracture network and the fluid flow in a coal seam as the matrix permeability, here, is negligible. In this paper, we document cleat size distributions and investigate lengthaperture relationships from coals of Raniganj coalfield in Eastern India. This coalfield has a proven extractable reserve of six billion tons of coal and holds immense potential to be one of the largest coal bed methane fields serving India's growing energy needs. Here, cleat length (L) correlates with corresponding maximum aperture width (D max) in a power-law function with an exponent of 0.84 (D max a L 0.84) instead of the commonly observed exponents of 1 or 0.5 applicable for other natural 'opening-mode' fractures. The conventional wisdom pertains that laminar fluid flow (Q) through an isolated, smooth-walled, parallel-plate fracture, embedded in an impermeable matrix, is directly proportional to the cube of its aperture width (b, equivalent to D avg ; cubic law: Q a b 3). This assumes a linear relationship between length and fracture aperture. However, the modified relationship between cleat length and average aperture width changes the cubic law applicable for Raniganj coal seam and now fluid flow correlates with aperture width in a power-law function with an exponent of 4.25 (Q a b 4.25) instead of 3 (cube). Such simplifications will come handy for the modeling and estimation of fluid flow as it will reduce the effort of cleat length measurement which is anyway difficult and can be misleading due to the risk of undersampling.

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Simulation and Economics of Coalbed Methane Production in the Powder River Basin

Cited by 6 publications

References 0 publications

Influence of sorption time in CO 2 -ECBM process in Indian coals using coupled numerical simulation

Influence of sorption time in CO 2 -ECBM process in Indian coals using coupled numerical simulation

Evolution of Production and Transport Characteristics of Steeply-Dipping Ultra-Thick Coalbed Methane Reservoirs

Dependence of fluid flow on cleat aperture distribution and aperture–length scaling: a case study from Gondwana coal seams of Raniganj Formation, Eastern India

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