Coalbed methane enrichment model of low-rank coals in multi-coals superimposed regions: a case study in the middle section of southern Junggar Basin

doi:10.1007/s11707-021-0917-6

Front. Earth Sci.

2021, Vol. 15

Issue (2) : 256-271 https://doi.org/10.1007/s11707-021-0917-6

RESEARCH ARTICLE

Coalbed methane enrichment model of low-rank coals in multi-coals superimposed regions: a case study in the middle section of southern Junggar Basin

Haihai HOU^1,²(

), Guodong LIANG¹, Longyi SHAO²(

), Yue TANG³, Guangyuan MU²

¹. College of Mining, Liaoning Technical University, Fuxin 123000, China
². College of Geoscience and Surveying Engineering, China University of Mining and Technology, Beijing 100083, China
³. Oil & Gas Resource Survey Center, China Geological Survey, Ministry of Land and Resource, Beijing 100029, China

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Abstract

The Middle Jurassic Xishanyao Formation in the central section of the southern Junggar Basin has substantial amounts of low-ranked coalbed methane (CBM) recourses and is typically characterized by multi superimposed coal seams. To establish the CBM enrichment model, a series of experimental and testing methods were adopted, including coal maceral observation, pro-ximate analysis, low temperature nitrogen adsorption (LTNA), methane carbon isotope determination, porosity/permeability simulation caused by overburden, and gas content testing. The controlling effect of sedimentary environment, geological tectonic, and hydrogeological condition on gas content was analyzed in detail. The results demonstrate that the areas with higher gas content (an average of 8.57 m³/t) are mainly located in the Urumqi River-Santun River (eastern study area), whereas gas content (an average of 3.92 m³/t) in the Manasi River-Taxi River (western study area) is relatively low. Because of the combined effects of strata temperature and pressure, the gas content in coal seam first increases and then decreases with increasing buried depth, and the critical depth of the inflection point ranges from 600 m to 850 m. Affected by the changes in topography and water head height, the direction of groundwater migration is predicted from south to north and from west to east. Based on the gas content variation, the lower and middle parts of the Xishanyao Formation can be divided into three independent coal-bearing gas systems. Within a single gas-bearing system, there is a positive correlation between gas content and strata pressure, and the key mudstone layers separating each gas-bearing system are usually developed at the end of each highstand system tract. The new CBM accumulation model of the multi-coals mixed genetic gas shows that both biological and thermal origins are found in a buried depth interval between 600 m and 850 m, suggesting that the coals with those depths are the CBM enrichment horizons and favorable exploration regions in the middle section of the southern Junggar Basin. An in-depth discussion of the low-rank CBM enrichment model with multi-coal seams in the study region can provide a basis for the optimization of CBM well locations and favorable exploration horizons.

Keywords Xishanyao Formation multi-coal seams superimposed region low rank coal main controlling factors enrichment model

Corresponding Author(s): Haihai HOU,Longyi SHAO

Online First Date: 13 August 2021 Issue Date: 26 October 2021

Cite this article:

Haihai HOU,Guodong LIANG,Longyi SHAO, et al. Coalbed methane enrichment model of low-rank coals in multi-coals superimposed regions: a case study in the middle section of southern Junggar Basin[J]. Front. Earth Sci., 2021, 15(2): 256-271.

URL:

https://academic.hep.com.cn/fesci/EN/10.1007/s11707-021-0917-6
https://academic.hep.com.cn/fesci/EN/Y2021/V15/I2/256

Fig.1 (a) Geotectonic sketch map of the Junggar Basin. (b) Structural characteristics of the study area showing the locations of CBM wells, coal mines, coal samples and horizontal maximum stress directions.

Fig.2 The coal-bearing strata of the Middle Jurassic Xishanyao Formation showing lithology, depositional environment, sequence stratum, core pictures and main aquifers in Well ZK101 close to Hutubi River.

Fig.3 Gas content variation of the Xishanyao coals in the middle part of southern Junggar Basin.

Tab.1 The well testing data, gas content, roof and floor lithology of major coal seams in several CBM parameter wells, southern Junggar Basin

Fig.4 Typcial surrounding rock combinations of Xishanyao coals in the middle part of southern Junggar Basin.

Fig.5 The division of multi-superimposed gas system of the Xishanyao Formation in the MM-3 well (R.P.—Reservoir pressure; R.P.G.—Reservoir pressure gradient; R.Pe.—Reservoir permeability; S.S.A.—Specific surface area; T.P.V.—Total pore volume).

Fig.6 The synclinal axis of Qingshuihe nearby Hububi River (a) and the characteristics of fracture and permeability of Xishanyao coals in different zones (b), (c), (d).

Fig.7 Relationships between porosity, permeability and overburden pressure of low-rank coals in the middle part of southern Junggar Basin.

Fig.8 The total dissolved solids (TDS) values and flow pathways of groundwater in the middle section of the southern Junggar Basin.

Tab.2 Hydrogeological parameter statistics for the middle section of the southern Junggar Basin

Fig.9 Relationship between coal depth and δ¹³C₁ of methane from three CBM wells.

Fig.10 The CBM enrichment model for a multi-coal seams superimposed region in the middle part of southern Junggar Basin.

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