Developmental geology of coalbed methane from shallow to deep in Rocky Mountain basins and in Cook Inlet–Matanuska basin, Alaska, U.S.A. and Canada

Johnson, Ronald C.; Flores, Romeo M.

doi:10.1016/s0166-5162(97)00016-5

Cited by 65 publications

(27 citation statements)

References 60 publications

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Section: Genesis Of Saturated Coalbed Methane Reservoirmentioning

confidence: 99%

“…Thereby, for the coalbed methane reservoir, the opinion that the free gas can be as a supplement of the absorbed gas is hard to understand. In Rocky Mountain of the US, during recent 10 Ma, the uplift movement leads to the subnormal pressure of the peripheral gas reservoir in the central basin [16] .(2) The different adsorption models of the coalbed methane in high temperature and pressure. The Langmuir adsorption model is based on monomolecular adsorption, with the precondition of dynamic absorption equilibrium, homogeneous solid surface, non interaction force between absorbed molecules and the absorption only in the monomolecular layer.…”

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confidence: 99%

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Influence of overpressure on coalbed methane reservoir in south Qinshui basin

2005

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In theory, from the high temperature and pressure during the coal generating gas to the present low temperature and pressure of coalbed methane reservoir, the accumulation of coalbed methane was from oversaturated to undersaturated. The gas content of the coalbed methane reservoir in the south Qinshui basin was 12 35.7 m 3 /t. According to the isotherm and measured gas content of No. 3 coal, the adsorbed gas content in some wells was highly saturated and oversaturated, which was hard to theoretically understand. In addition, there were no thermogenic and biogenic gases at the late stage in the south Qinshui basin. This article proposed that the overpressure was the main reason for the present high saturation of the coalbed methane reservoir. In early Cretaceous, the coalbed methane reservoir was characterized by overpressure and high saturation caused by gas generation from coal measure source rocks. In late Cretaceous, the coalbed methane reservoir was rapidly uplifted, and with the temperature and pressure decreasing, the pressure condition of adsorbed gas changed from overpressure to normal-under pressure, which resulted in the high saturation and gas content in the present coalbed methane reservoir. IssuesThe coalbed methane reservoir in south Qinshui basin is located in the Jingcheng of south Qinshui basin, with the biggest proven reserve of the coalbed methane in China. The total proven reserve in Zaoyuan, Fanzhuang and Panzhuang is 754.44 10 8 m 3 . The coalbed methane reservoirs are mainly distributed in No. 3 coalbed of Shanxi Formation of Permian (P 1s ) and No. 15 coalbed of Taiyuan Formation of Carboniferous (C 2t ). The vitrinite reflectance of coal is 3.0% 4.5% [1] . The boundary of the reservoir is Sitou fault in west and oxidation zone in east and south [2] . The north boundary is groundwater divide. The depth of reservoir is 300 700 m, with the temperature ranging from 18 to 35 . According to the results of the injection/pressure drop and DST well testing , the pressure gradient of the gas reservoir in depth of 292 888 m is 0.0038 0.012 MPa/m with the average of 0.0071 MPa/m, indicating the normal-under pressure conditions [3] .The gas content in the coalbed methane reservoir of the south Qinshui basin was mainly 12 35.7 m 3 /t, of which the high value occurred in the stagnation belt of groundwater. According to the adsorption isotherm map of No. 3 coal, in some wells the gas saturation was over 90%, up to or near saturated (Fig. 1). In the coalbed methane bearing basins of the US, such as San Juan basin, the high gas saturation also often appeared. Fig. 1. The gas content of No.3 coalbed in the south Qinshui basin under the present-day pressure. The dashed part was the change scope of adsorption isotherm of No.3 coal. The data were quoted from refs. [3, 5 7]. The pressure data of Jinshi-1, CQ-9 and Pan-1 were measured by the injection/pressure drop while the other data was calculated with pressure gradient. The gas content of CQ-9 and Jinshi-4 was over the theoretical value, probably resulting f...

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Section: Genesis Of Saturated Coalbed Methane Reservoirmentioning

confidence: 99%

mentioning

confidence: 99%

Influence of overpressure on coalbed methane reservoir in south Qinshui basin

2005

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“…Reported gas contents for coal in the Vermejo Formation vary from 115 to 492 ft 3 /short ton (3.6-15.5 cm 3 /gm) while coals in the Raton Formation contain from 23 to 193 ft 3 /short ton (0.72-6.07 cm 3 /gm) (Tyler and others, 1995). As of 1998 there were about 85 coalbed methane wells in the Raton Basin producing about 17.5 million cubic feet of gas per day (Johnson and Flores, 1998) with a significant number of new coalbed methane wells having been drilled since 1998. Wells are completed mainly in the Vermejo Formation.…”

Section: Coalbed Methane In the Raton Basinmentioning

confidence: 99%

Basin-centered gas systems of the U.S.

Popov¹,

Nuccio²,

Dyman³

et al. 2001

Open-File Report

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“…Basin-scale investigation of the CBM resource have been performed in the Piceance and Matanuska basins in the United states (Johnson and Flores, 1998;Payne and Ortoleva, 2001), the Bowen and Sydney basins in Australia (Boreham et al, 1998;Faiz et al, 2007), and the Qinshui and Ordos basins in China (Wang et al, 2013;Cai et al, 2014). Previous reports and papers show that geologic structure is the most important control factor of reservoirs of CBM.…”

Section: Introductionmentioning

confidence: 99%

Geologic Structural Controls on Coalbed Methane Content of the No. 8 Coal Seam, Gujiao Area, Shanxi, China

Xia¹

2017

Appl Ecol Env Res

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Abstract. Gas contents are highly heterogeneous in coalbed methane (CBM) reservoirs of the Gujiao area, Shanxi province, China. Diverse geologic data and stimulate methods were used to provide insight into the origin of this variability and the consequences of gas content in the No. 8 coal seam. The results show that the No. 8 coal seam experienced two gas-generating periods and one fluctuant period, and has stepped into migration period since the Late Cretaceous. The distribution of gas content of the No. 8 coal seam in the Gujiao area is mainly dominated by structural form, water level and burial depth, all of which are structural related parameters. The gas content in the subarea A is much lower than that in the subarea B because the subarea A is deformed severely and the subarea B is a gentle monocline. The gas content first increases and then decreases with increasing burial depth, and the turning burial depth is about 600.0 m. Strong runoff area is harmful for preserving gas due to the washing effect in it. The analyzing results show that: gentle and simple monocline blocks with burial depth ranges from 500.0 m to 800.0 m, water level lower than 900.0 m is the most important "sweet spots" for CBM development in the Gujiao area.

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Developmental geology of coalbed methane from shallow to deep in Rocky Mountain basins and in Cook Inlet–Matanuska basin, Alaska, U.S.A. and Canada

Cited by 65 publications

References 60 publications

Influence of overpressure on coalbed methane reservoir in south Qinshui basin

Influence of overpressure on coalbed methane reservoir in south Qinshui basin

Basin-centered gas systems of the U.S.

Geologic Structural Controls on Coalbed Methane Content of the No. 8 Coal Seam, Gujiao Area, Shanxi, China

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