Production data analysis of coalbed methane wells to estimate the time required to reach to peak of gas production

Salmachi, Alireza; Yarmohammadtooski, Zahra

doi:10.1016/j.coal.2015.02.006

Cited by 54 publications

(28 citation statements)

References 10 publications

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“…In the case of coal reservoir, gas rate peaks after water and the rising production can last from a few months up to years. As a result, the peak gas rate can be observed up to few years after the start of the production [8].…”

Section: Introductionmentioning

confidence: 88%

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A fully coupled hydro-mechanical model for the modeling of coalbed methane recovery

Bargain

Cerfontaine

Collin

2017

Journal of Natural Gas Science and Engineering

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Section: Introductionmentioning

confidence: 88%

“…Then, after the peak is observed, the gas production exponentially declines. In Figure 23, it results in a straight line on a semi-log plot of gas rate versus time [8]. After 30 years, the cumulative quantity of gas produced is more than 20 millions cubic meters (Figure 24).…”

Section: Synthetic Reference Casementioning

confidence: 99%

A fully coupled hydro-mechanical model for the modeling of coalbed methane recovery

Bargain

Cerfontaine

Collin

2017

Journal of Natural Gas Science and Engineering

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“…The formation of CBM was either biogenically or thermogenically derived by producing CH 4 (the main chemical component of CBM) (Moore 2012). Commercial production of CBM has made significant contribution to increasing the global energy resources and triggered the global activity in the area of CBM exploration (Salmachi and Yarmohammadtooski, 2015;Clarkson, 2013). Currently, conventional methods for the exploration of CBM reservoir are principally core analysis, well-test analysis, geophysical logs, seismic methods etc.…”

Section: Introductionmentioning

confidence: 99%

Rapid determination of coalbed methane exploration target region utilizing hyperspectral remote sensing

Zhang

Qin

Chen

et al. 2015

International Journal of Coal Geology

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“…Production data analysis is a powerful tool assisting researchers in attaining some significant reservoir properties as well as stimulation parameters. Recent advances in production data and rate transient analyses help researchers to obtain vital CBM reservoir properties such as permeability-thickness product (Kh), skin factor, initial gas and water in place, and time of peak gas production (Mohaghegh and Ertekin 1991; Aminian et al 2004; Clarkson et al 2012; Clarkson 2013; Karacan 2013; Salmachi and Yarmohammadtooski 2015). Production data analysis in CBM reservoirs can be complicated due to factors such as adsorption-driven gas storage mechanism, difficulties in determining relative permeability, and stress/desorption-dependent permeability (Clarkson et al 2007a).…”

Section: Introductionmentioning

confidence: 99%

Cross-formational flow of water into coalbed methane reservoirs: controls on relative permeability curve shape and production profile

Salmachi

Karacan

2017

Environ Earth Sci

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Coalbed methane (CBM) wells tend to produce large volumes of water, especially when there is hydraulic connectivity between coalbed and nearby formations. Cross-formational flow between producing coal and adjacent formations can have significant production and environmental implications, affecting economic viability of production from these shallow reservoirs. Such flows can also affect how much gas can be removed from a coalbed prior to mining and thus can have implications for methane control in mining as well. The aim of this paper is to investigate the impact of water flow from an external source into coalbed on production performance and also on reservoir variables including cleat porosity and relative permeability curves derived from production data analysis. A reservoir model is constructed to investigate the production performance of a CBM well when cross-formational flow is present between the coalbed and the overlying formation. Results show that cleat porosity calculated by analysis of production data can be more than one order of magnitude higher than actual cleat porosity. Due to hydraulic connectivity, water saturation within coalbed does not considerably change for a period of time, and hence, the peak of gas production is delayed. Upon depletion of the overlying formation, water saturation in coalbed quickly decreases. Rapid decline of water saturation in the coalbed corresponds to a sharp increase in gas production. As an important consequence, when cross-flow is present, gas and water relative permeability curves, derived from simulated production data, have distinctive features compared to the initial relative permeability curves. In the case of cross-flow, signatures of relative permeability curves are concave downward and low gas permeability for a range of water saturation, followed by rapid increase afterward for water and gas, respectively. The results and analyses presented in this work can help to assess the impact of cross-formational flow on reservoir variables derived from production data analysis and can also contribute to identifying hydraulic connectivity between coalbed and adjacent formations.

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Production data analysis of coalbed methane wells to estimate the time required to reach to peak of gas production

Cited by 54 publications

References 10 publications

A fully coupled hydro-mechanical model for the modeling of coalbed methane recovery

A fully coupled hydro-mechanical model for the modeling of coalbed methane recovery

Rapid determination of coalbed methane exploration target region utilizing hyperspectral remote sensing

Cross-formational flow of water into coalbed methane reservoirs: controls on relative permeability curve shape and production profile

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