Influence of Shrinkage and Swelling of Coal on Production of Coalbed Methane
and Sequestration of Carbon Dioxide

Siriwardane, H.J.; Smith, Duane H.; Görücü, Fatma; Ertekin, Turgay

doi:10.2523/102767-ms

Cited by 4 publications

(2 citation statements)

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“…Previous studies on the productivity influence factors have largely focused on the analysis of single coal seam from the perspective of geological factors, such as tectonic conditions, coal properties, burial depth, coal thickness and hydrological conditions, as well as engineering factors, such as fracturing parameters (Cai et al., 2014; Iii and Ehrlich, 1998; Lv et al., 2012; Mares et al., 2008; Pan et al., 2012; Pashin and Groshong, 1998; Siriwardane et al., 2006; Tao et al., 2014). Predecessors have also conducted research on the productivity influence factors for multiple coal seams.…”

Section: Introductionmentioning

confidence: 99%

Controlling factors of coalbed methane well productivity of multiple superposed coalbed methane systems: A case study on the Songhe mine field, Guizhou, China

Tang

et al. 2017

Energy Exploration & Exploitation

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The Songhe mine field located in western Guizhou Province of China is the most typical region of multiple coal seam development. However, the coalbed methane development practices of commingled drainage in recent years have been proved to be less ideal. In this work, on the basis of dividing gas system, the correlations between geological and engineering factors and gas production data were studied to determine the controlling factors of coalbed methane well productivity. The results indicated that the gas production had a positive correlation with cumulative thickness and gas content of fractured coal seams overall. However, the large cumulative thickness is generally resulted from the increase of coal seam number, and thus increases the reservoir heterogeneity and interlayer difference. The coalbed methane well productivity performance for this type region was a result of the strong interaction of cumulative thickness, burial depth, gas content, permeability, and reservoir pressure of fractured coal seam. However, the interlayer interference was the most direct factors restricting the productivity of commingle drainage by affecting the speed of dewatering and lowering of pressure and gas desorption time of gas-bearing systems. Additionally, the correlations between gas production and interlayer difference and interference were quantitatively analyzed, and the results showed that the wells with large interlayer difference and interference tend to have a poor productivity performance. As a result, the drainage method was particularly an important factor controlling the well productivity for multiple coalbed methane systems, because a proper combination of gas-bearing system and drainage and dewatering sequence are the keys to decrease the interlayer interference. Finally, the commingled

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Section: Introductionmentioning

confidence: 99%

Controlling factors of coalbed methane well productivity of multiple superposed coalbed methane systems: A case study on the Songhe mine field, Guizhou, China

Tang

et al. 2017

Energy Exploration & Exploitation

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“…During enhanced methane recovery/CO 2 sequestration in coal, adsorption of CO 2 , which has a greater sorption capacity than methane, would cause matrix swelling and thus, in contrast to gas desorption could have a detrimental impact on cleat permeability of coal. A large number of researchers have used different models to evaluate matrix shrinkage/swelling with CO 2 injection (Siriwardane et al, 2006;Gorucu et al, 2007;Mazumder and Wolf, 2008;Balan and Gunrah, 2009;Durucan and Shi, 2009;Pan and Connell, 2009;Siriwardane et al, 2009). For the injection of gas mixture, the production/injection performance, the pressure distribution, the porosity and permeability variation, are more complex than pure gas injection (Durucan and Shi, 2009).…”

Section: Introductionmentioning

confidence: 99%

Influence and Sensitivity Study of Matrix Shrinkage and Swelling on Enhanced Coalbed Methane Production and CO₂ Sequestration with Mixed Gas Injection

Zhou

Yao

Tang

et al. 2011

Energy Exploration & Exploitation

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Matrix compressibility, shrinkage and swelling can cause profound changes in porosity and permeability of coalbed during gas sorption and desorption. These factors affect the distribution of pressure, methane production and CO 2 sequestration.This paper compares the effects of cleat compression and matrix shrinkage and swelling models with the injection of different compositional gas mixtures (CO 2 and N 2 ). It shows that well performance, pressure distribution and properties of the seam are strongly affected by matrix shrinkage and swelling. Matrix shrinkage and swelling also affects net present value of the enhanced coalbed methane recovery scheme. In order to select the best enhanced coalbed methane recovery schemes, economic evaluation and sensitivity studies are necessary.

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Permeability Variations in an Upper Freeport Coal Core Due to Changes in Effective Stress and Sorption

Jikich

McLendon

Smith

2009

SPE Annual Technical Conference and Exhibition

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Permeability is a key property for injectivity of carbon dioxide in enhanced coalbed methane/carbon sequestration projects. In addition to cleat spacing and connectivity, permeability is affected by the in situ stresses, the geomechanical properties (Young's modulus, Poisson's ratio) of the coal, the amounts and compositions of the fluids (e.g., CH4, CO2) sorbed by the coal matrix, and the dependence of the matrix swelling on the amounts and compositions of the sorbed fluids. In this paper, we have tested bituminous coal coal cores from the Upper Freeport formation, Marshall County, West Virginia in the Appalachian Basin. This coal has generated considerable interest, because of a current industry/DOE/NETL sponsored project to inject carbon dioxide into this seam for the purpose of developing and testing carbon sequestration. The cores were tested in a composite core holder allowing hydrostatic confinement and X- ray computerized tomography (CT). Permeabilities for helium, methane, and carbon dioxide were measured using a conventional method of simultaneous pressure-drop and flow-rate measurements. Compressibility and carbon dioxide sorption of the sample were calculated from CT measurements of density variations in the core. Permeability was reduced considerably by increases of effective stresses in the coal, and by sorption of carbon dioxide in the coal. Due to the heterogeneous nature of the coal, its sorption and elastic properties varied greatly among different locations within the core. As a corollary, samples from the same well and coal seam may show large variations in methane content, carbon dioxide storage capacity, permeability, and mechanical properties. Introduction The Upper Freeport coal sits in the Allegheny formation, consisting of inter-bedded sandstones, siltstones, shales, limestone and coalbeds, as illustrated by Figure 1. Coalbed methane is produced from Lower and Upper Freeport, Kittaning and Clarion coals. The total gas in place for Allegheny coalbeds was estimated at 50.5 tcf, out of an estimated 61 tcf for all coals of the Northern Appalachian coal basin, which includes parts of southwestern Pennsylvania, northwestern West Virginia, and western Ohio (West Virginia Geological and Economic Survey, 1996). The National Energy Technology Laboratory (NETL) and industrial partners (Consol) are performing a field pilot in Marshal Co., WV, in the Upper Freeport formation to develop CO2 sequestration /enhanced coalbed methane technologies (Cairns, 2003). The production of gas from coal seams, and the injectivity and storage of CO2 into coal, are highly dependent on two parameters: permeability, and storage. Coal seams are treated as dual porosity reservoirs with the majority of the gas stored in the primary porosity system (coal matrix), while the permeability of the coal seam is governed by the natural fractures and cleats in coal that constitute the secondary porosity system (Mavor, 2006). The natural fracture (or cleat) porosity and permeability are dependent on location, pressure in the reservoir, and geomechanical properties (Young's modulus, Poisson's ratio) of the coal, the amounts and compositions of the fluids (e.g., CH4, H2O, CO2) sorbed by the coal matrix, and the dependence of the matrix swelling on the amounts and compositions of the sorbed fluids.

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Influence of Shrinkage and Swelling of Coal on Production of Coalbed Methane and Sequestration of Carbon Dioxide

Cited by 4 publications

References 0 publications

Controlling factors of coalbed methane well productivity of multiple superposed coalbed methane systems: A case study on the Songhe mine field, Guizhou, China

Controlling factors of coalbed methane well productivity of multiple superposed coalbed methane systems: A case study on the Songhe mine field, Guizhou, China

Influence and Sensitivity Study of Matrix Shrinkage and Swelling on Enhanced Coalbed Methane Production and CO₂ Sequestration with Mixed Gas Injection

Permeability Variations in an Upper Freeport Coal Core Due to Changes in Effective Stress and Sorption

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Influence of Shrinkage and Swelling of Coal on Production of Coalbed Methane and Sequestration of Carbon Dioxide

Cited by 4 publications

References 0 publications

Controlling factors of coalbed methane well productivity of multiple superposed coalbed methane systems: A case study on the Songhe mine field, Guizhou, China

Controlling factors of coalbed methane well productivity of multiple superposed coalbed methane systems: A case study on the Songhe mine field, Guizhou, China

Influence and Sensitivity Study of Matrix Shrinkage and Swelling on Enhanced Coalbed Methane Production and CO2 Sequestration with Mixed Gas Injection

Permeability Variations in an Upper Freeport Coal Core Due to Changes in Effective Stress and Sorption

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Influence and Sensitivity Study of Matrix Shrinkage and Swelling on Enhanced Coalbed Methane Production and CO₂ Sequestration with Mixed Gas Injection