A primer on the occurrence of coalbed methane in low-rank coals, with special reference to its potential occurrence in Pakistan

SanFilipo, John R.

doi:10.3133/ofr00293

Cited by 7 publications

(8 citation statements)

References 13 publications

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“…Among them, the methane carbon isotopic composition is the main indication for identifying the CBM origin. It is often considered that the methane 13 C value being equal to 55‰ is the critical one for distinguishing the biogenic and thermogenic gases [15,17,18] . Traditionally, the gas with methane 13 C values less than -55‰ is regarded as the biogenic origin; conversely, it is assumed to belong to the thermogenic origin [18 20] .…”

Section: Geochemical Evidence For Coalbed Gas Originmentioning

confidence: 99%

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Evolution of the CBM reservoir-forming dynamic system with mixed secondary biogenic and thermogenic gases in the Huainan Coalfield, China

et al. 2005

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The secondary biogenic gas is an important original type of the coalbed methane (CBM) in China. Based on the analyses of sedimentary and burial history of the Permian coal-bearing strata, combined with thermal history and gas generation process of coals, the CBM reservoirforming dynamic system with mixed secondary biogenic and thermogenic gases in the Huainan Coalfield is subdivided into four evolutionary stages as follows: (i) shallowly-buried peat and early biogenic gas stage; (ii) deeply buried coal seams and thermogenic gas stage; (iii) exhumation of coal-bearing strata and adsorbed gas lost stage; and (iv) re-buried coal-bearing strata and secondary biogenic gas supplement stage. The Huainan CBM reservoir-forming model has the features of the basin-centered gas accumulation. The evolution of the reservoir-forming dynamic system proves that the thermogenic gas is not the main gas source for the Huainan CBM reservoir. Only the secondary biogenic gases as an additional source replenish into the coal bed after basin-uplift, erosional unroofing and subsequent scattering of thermogenic gases. Then this kind of mixed CBM reservoirs can be formed under suitable conditions.

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Section: Geochemical Evidence For Coalbed Gas Originmentioning

confidence: 99%

“…Many scholars [12,17,27] recognize that the basin-centered gas accumulation or/and synform enrichment is the most common CBM reservoir-forming model. It implies that its shape is like a bowl rather than having the domed configuration of most conventional traps, and the gas is below the hydrostatic head rather than above it.…”

Section: Explorationmentioning

confidence: 99%

Evolution of the CBM reservoir-forming dynamic system with mixed secondary biogenic and thermogenic gases in the Huainan Coalfield, China

et al. 2005

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“…The major elemental ratios and their correlation coefficient (r2) show that the origin of its constituting silica content is detrital, which is further confirmed by differences in the source of silica and alumina [13]. Therefore, the studied sediments have potentially deposited along the fringe of basin of deposition in deltaic to near shore depositional environment.…”

Section: Depositional Modelmentioning

confidence: 77%

An Overview of CBM Resources in Lower Indus Basin, Sindh, Pakistan

Nazeer¹,

S²,

Sa³

et al. 2017

J Geol Geophys

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“…Chatterjee and Paul studied the coal bed methane potential in Jharia coalfield, India and estimated the methane content to be around 11 m 3 per ton of coal. Thar coal seams are similar in age and rank to Powder River Basin of the U.S. and Cambay Basin of India . Within the range of coal rank for likely targets, methane adsorption capacities in the range of 1.5 to 5.5 m 3 /ton of coal may be expected at the reservoir conditions.…”

Section: Introductionmentioning

confidence: 97%

Application case study of enhanced coal bed methane recovery process in thar coal fields

Zahid

2017

Env Prog and Sustain Energy

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Enhanced coal bed methane recovery (ECBM) process is an important developing technology because of its dual advantage, i.e., producing methane gas and sequestering CO2 at the same time. CO2 have been used for enhanced oil recovery (EOR) for more than five decades but available storage sites for EOR are only limited to oil rich countries. Pakistan has one of the largest coal reserves in the world accounting to more than 185 billion tons. In this study, CO2 sequestration in the coalbeds of Thar coal field located in the South of Pakistan is explored from the technical and economical point of view. Potential CO2 storage capacity and methane gas‐in‐place has been calculated for the Thar coal fields. Next, an economic analysis has been performed to evaluate the cost of CO2 storage and to explore any economic benefit from the methane production. Usually, coal reservoirs are saturated with water, hence water production along with methane is inevitable. This study analyzed various water treatment methods and recommended shallow re‐injection technology to be the most suitable for the Thar coal ECBM process. In addition, carbon balance has been investigated to calculate the CO2 avoided during the ECBM process. Finally, a sensitivity analysis has been performed on some of the important design variables in order to analyze their effect on the cost of CO2 storage. © 2017 American Institute of Chemical Engineers Environ Prog, 37: 900–911, 2018

show abstract

A primer on the occurrence of coalbed methane in low-rank coals, with special reference to its potential occurrence in Pakistan

Cited by 7 publications

References 13 publications

Evolution of the CBM reservoir-forming dynamic system with mixed secondary biogenic and thermogenic gases in the Huainan Coalfield, China

Evolution of the CBM reservoir-forming dynamic system with mixed secondary biogenic and thermogenic gases in the Huainan Coalfield, China

An Overview of CBM Resources in Lower Indus Basin, Sindh, Pakistan

Application case study of enhanced coal bed methane recovery process in thar coal fields

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