Study of Parameters Affecting Enhanced Coal Bed Methane Recovery

Katyal, S.; Valix, Marjorie; Thambimuthu, K V

doi:10.1080/009083190965433

Cited by 21 publications

(14 citation statements)

References 18 publications

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“…Up to this date, many studies have been conducted to investigate the effect of coal mass physical properties such as macerals and minerals [10][11][12][13][14][15][16][17][18], ash yield content [19][20][21], carbon content [5,15,[21][22][23][24], and moisture content [2,[25][26][27][28] on gas sorption capacity in coals.…”

Section: Coal Mass Physical Propertiesmentioning

confidence: 99%

“…The unnecessary amount of carbon dioxide (CO 2 ), the leading greenhouse gas content in the atmosphere, is the main cause for this problem. Among the various atmospheric CO 2 mitigating methods, capture and restoration of CO 2 in deep unminable coal seams have become famous due to the reason that its potential to produce CH 4 as a byproduct during the CO 2 sequestration process [1,2]. In addition, this method has an extra benefit as it uses an unusable resource (unminable coal seams) to reduce the atmospheric CO 2 level.…”

Section: Introductionmentioning

confidence: 99%

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Estimation of Gas Adsorption Capacity in Coal: A Review and an Analytical Study

Perera

Ranjith

Choi

et al. 2012

International Journal of Coal Preparation and Utilization

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Adsorption plays an important role in carbon dioxide sequestration and methane recovery processes in deep coal seams. If the effects of coal physical properties on its gas adsorption capacity are considered, it increases with vitrinite content and pressure and reduces with liptinite, mineral matter, moisture contents, and temperature and follows a U-shaped variation with carbon content. Furthermore, CO 2 has higher adsorption capacity compared to other gases. There are two main methods to estimate the amount of gas adsorbed in a coal seam, which are called direct and indirect methods. The latter method is more common for coal. In the direct method, the volume of gas released from a coal mass into a sealed desorption canister is measured, and under the indirect method, adsorption isotherms and empirical relations are used. However, any of those methods are unable to count the effect of swelling-induced strain and, therefore, fail in measuring the absolute adsorption in coal. Moreover, among various adsorption models, Langmuir and DubninRadushkevich (D-R) equations are the most widely using models. However, since gas can be absorbed through both adsorption and absorption processes for coal, it is important to have an additional term to count the missing absorption mechanism in both the Langmuir and D-R models. Finally, a new descriptive model for gas adsorption capacity of coal as a function of effective factors is proposed. The new model is based on the existing D-R equation, which was modified by inserting a new expression for the term of micropore capacity. Two types (CO 2 and N 2 ) of gas adsorption data for coal from five different locations (British Colombia and Alberta in Canada and Victoria, Sydney and Bowen in Australia) at three different temperatures (273, 296.5, and 318 K) were considered for the model development. According to the model results, new gas adsorption equations can fairly well accurately predict the adsorption capacity in coal.

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Section: Coal Mass Physical Propertiesmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Estimation of Gas Adsorption Capacity in Coal: A Review and an Analytical Study

Perera

Ranjith

Choi

et al. 2012

International Journal of Coal Preparation and Utilization

View full text Add to dashboard Cite

show abstract

“…[1] Recently, hydraulic and carbon dioxide fracturing have been widely employed for enhancing the recovery of coal-bed methane. [2][3][4] When the drainage and pressure are lowered, the pressure drop around the borehole can be reasonably distributed by reconstructing the connectivity between the wellbore and the coal-bed natural fracture network. As a result, the energy and gas desorption rate significantly increase, possibly leading to a faster release of coal-bed methane from the borehole.…”

Section: Introductionmentioning

confidence: 99%

Design and Implementation of a Coal-Bed Methane Fracture Monitoring System based on Virtual Instrument Technology

Jia

Yang

et al. 2014

Instrumentation Science & Technology

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& Monitoring of fracture orientation is of significance in the exploration and development of coal-bed methane; for this purpose, a monitoring system, based on the principle of differential electric resistivity tomography, has been widely used. The resolution and monitoring scope determine the detection depth of the coal-bed methane fracturing layer. In this article, a coal-bed methane fracture monitoring system with a resolution of less than approximately 10 mV and 90 channels is reported using virtual instrument technology. Based on the three-dimensional geoelectric field of vertical finite line source by the finite-difference method, the surface potential difference between different depths and the scope of surface fracture anomaly was calculated, which demonstrated the feasibility of this system. The system exhibited satisfactory performance for a coal-bed methane well in Jixian, Shanxi Province. Compared with a microseismic monitoring system, the coal-bed methane fracture system was more convenient and achieved similar results of fracture orientations at a depth of 1263 m. Moreover, it avoided the uncertainty of a single method. Therefore, it is expected that this system may be widely applied to the fracture monitoring of coal-bed methane.

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“…The production of coalbed methane with CO 2 injection is synergetic with CO 2 sequestration, as the injected CO 2 is stored in the underground coalbed (Gentzis 1998). Because of the world's growing energy consumption (World Energy Outlook 2002) and concerns on global warming (Metz et al 2005), CO 2 enhanced coalbed methane production, and the concurrent CO 2 sequestration receive much interest (Yu et al 2007;Hackley et al 2005;Katyal et al 2007). The global coalbed methane reserves have been estimated to range from 84 to 262 Tm 3 (White et al 2005).…”

Section: Introductionmentioning

confidence: 99%

Estimate of Equation of State Uncertainty for Manometric Sorption Experiments: Case Study With Helium and Carbon Dioxide

et al. 2009

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The sorption of gases on coal is of great importance for the use of gas injection to enhance coalbed methane production. Furthermore, when injecting carbon dioxide (CO 2 ), the project is eligible for carbon credits as the CO 2 is sequestrated.Accurate measurements of sorption at in-situ conditions have proven to be a complicated matter. Especially, the sorption of CO 2 , pure or in a mixture, are particularly sensitive to experimental errors, because common in-situ conditions of deep coalbeds are near the critical point of CO 2 . One source of uncertainty in sorption measurements is the accuracy with which gas densities have been determined. Accurate determinations of gas densities at in-situ conditions are complex and require the inclusion of specialized equipment. Therefore, gas densities are usually calculated from pressure and temperature measurements using an Equation of State (EoS). The accuracy of this EoS then influences the uncertainty in the sorption measurement. Therefore, it is essential that an EoS is used that is most accurate at the experimental conditions. However, there is generally little information available on the accuracy of an EoS for the conditions of interest. This is particularly true for the calculation of densities of mixtures with an EoS. This paper describes an experimental method to estimate the accuracy of an EoS using a manometric sorption apparatus. This is demonstrated by using He and CO 2 at 318.11 K and pressures between 0.1 and 17 MPa, which covers the range of interest for deep coalbeds.The accuracies of the following EoSs have been estimated: Peng-Robinson with Stryjek-Vera modification for CO 2 ; Peng-Robinson with an alpha parameter proposed by Twu in 1995 for He; multiparameter crossover equation of state by Sun, Kiselev, and Ely for CO 2 ; modified Benedict-Webb-Rubin EoS by McCarty and Arp for He; and the reference EoS for CO 2 by Span and Wagner.The experimental method provides a lower limit estimate of the accuracy for an EoS. This estimate can be used as a first approximation of the EoS accuracy in the a priori error analysis of manometric sorption experiments.

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Study of Parameters Affecting Enhanced Coal Bed Methane Recovery

Cited by 21 publications

References 18 publications

Estimation of Gas Adsorption Capacity in Coal: A Review and an Analytical Study

Estimation of Gas Adsorption Capacity in Coal: A Review and an Analytical Study

Design and Implementation of a Coal-Bed Methane Fracture Monitoring System based on Virtual Instrument Technology

Estimate of Equation of State Uncertainty for Manometric Sorption Experiments: Case Study With Helium and Carbon Dioxide

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