Establishment of dynamic permeability model of coal reservoir and its numerical simulation during the CO2-ECBM process

Fang, Huihuang; Sang, Shuxun; Liu, Shiqi

doi:10.1016/j.petrol.2019.04.095

Cited by 46 publications

(47 citation statements)

References 49 publications

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“…: pore volume of sample , cm 3 : bulk volume of sample , cm 3 ∅: effective porosity , fraction The permeability was measured for the all core plug samples using the conventional steady state method with injecting of nitrogen gas through the plug samples with known viscosity of the applied gas, Figure ( The gas permeability for all samples were run with five points of mean pore pressure including (150,175,200, 225,250) psi respectively. The results of gas apparent permeabilities of each sample were plotted with the inverse of applied pore pressure for each permeability measurement, as shown in Figure (5).…”

Section: Methodsmentioning

confidence: 99%

“…Permeability is an essential parameter for the evaluation of reservoir potentiality and production rate estimation of a specific field. In addition, this parameter can be used in reservoir simulation of particular rock type [1,2,3,4,5]. The liquid permeability only measure for a specific rock interval and from a limited number of core samples.…”

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Liquid and Gas Corrected Permeability Correlation for Heterogeneous Carbonate Reservoir Rocks

Mustafa¹,

Rashid²,

Ismail³

2020

KJAR

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Permeability is considered as an efficient parameter for reservoir modelling and simulation in different types of rocks. The performance of a dynamic model for estimation of reservoir properties based on liquid permeability has been widely established for reservoir rocks. Consequently, the validated module can be applied into another reservoir type with examination of the validity and applicability of the outcomes. In this study the heterogeneous carbonate reservoir rock samples of the Tertiary Baba Formation have been collected to create a new module for estimation of the brine permeability from the corrected gas permeability. In addition, three previously published equations of different reservoir rock types were evaluated using the heterogenous carbonate samples. The porosity and permeability relationships, permeability distribution, pore system and rock microstructures are the dominant factors that influenced on the limitation of these modules for calculating absolute liquid permeability from the klinkenberg-corrected permeability. The most accurate equation throughout the selected samples in this study was the heterogenous module and the lowest quality permeability estimation was derived from the sandstone module.

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Section: Methodsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Liquid and Gas Corrected Permeability Correlation for Heterogeneous Carbonate Reservoir Rocks

Mustafa¹,

Rashid²,

Ismail³

2020

KJAR

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“…The key parameters for the numerical simulation are mainly derived from engineering data of FZ well group, experimental data of coal samples collected from #3 coal seam of southern Qinshui basin, and data published by other scholars (Fan et al, 2018b;Fang et al, 2019aFang et al, , 2019bShi et al, 2008;Zhou et al, 2016). The key parameters are shown in Table 1.…”

Section: Key Parametersmentioning

confidence: 99%

Numerical analysis of drainage rate for multilayer drainage coalbed methane well group in Southern Qinshui basin

Hu¹,

Liu

Sang

et al. 2020

Energy Exploration & Exploitation

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Multilayer drainage is one of the important technologies for coalbed methane (CBM) production in China. In this study, a multi-field fully coupled mathematical model for CBM production was established to analyze the multilayer drainage of CBM well group in southern Qinshui basin. Based on the numerical simulation results, the characteristics of CBM well production under different drainage rates and key factors influencing the CBM production were further discussed. The results show that the effect of an increased drainage rate on gas production of CBM wells and CBM recovery of No.3 coal seam is not significant. However, it significantly improved the gas production of CBM wells and CBM recovery of No.15 coal seam. After a long period of production, the CBM content in No.3 coal seam has reduced to a low level and the pressure drop potential of No.3 coal seam is insignificant, which are important reasons for the insignificant increase of CBM production even under a drainage rate of 2 to 7 times. Conversely, No.15 coal seam has larger residual CBM content and increasing the drainage rate can significantly improve the pressure drop and superimposed well interference of No.15 coal seam, which means No.15 coal seam has greater production potential than No.3 coal seam. Therefore, it is recommended to improve the gas production and CBM recovery in No.15 coal seam by increasing the drainage rate, and the average hydraulic pressure drop should be 0.018–0.031 MPa/day. The influence of effective stress is weak in No.3 and No.15 coal seam, and the coal seam permeability is largely influenced by the shrinkage of coal matrix caused by CBM desorption. This indicates the feasibility of increase in gas production from CBM wells by increasing the drainage rate.

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“…During the ECBM process, the permeability in the vicinity of the injection well gradually decreases, whereas in the vicinity of the production well it first increases and then decreases. This phenomenon is connected with the process of permeability changes within the ECBM technology [7]. The transformation of pore and cleat structures of coal connected with the supercritical CO 2 leads to the increase in permeability within the zone of coal strata, which constitutes a key factor for CO 2 sequestration and the efficiency of CH 4 production [8][9][10].…”

Section: Introductionmentioning

confidence: 99%

Research on the Processes of Injecting CO2 into Coal Seams with CH4 Recovery Using Horizontal Wells

et al. 2020

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The paper presents a research study on modeling and computer simulation of injecting CO2 into the coal seams of the Upper Silesian Coal Basin, Poland connected with enhanced coal bed methane (ECBM) recovery. In the initial stage of the research activities, a structural parameter model was developed specifically with reference to the coal-bearing formations of the Upper Carboniferous for which basic parameters of coal quality and the distribution of methane content were estimated. In addition, a lithological model of the overall reservoir structure was developed and the reservoir parameters of the storage site were analyzed. In the next stage of the research, the static model was supplemented with detailed reservoir parameters as well as the thermodynamic properties of fluids and complex gases. The paper discusses a series of simulations of an enhanced coalbed methane recovery process with a simultaneous injection of carbon dioxide. The analyses were performed using the ECLIPSE software designed for simulating coal seam processes. The results of the simulations demonstrated that the total volume of CO2 injected to a designated seam in a coal mine during the period of one year equaled 1,954,213 sm3. The total amount of water obtained from the production wells during the whole period of the simulations (6.5 years) was 9867 sm3. At the same time, 15,558,906 sm3 of gas was recovered, out of which 14,445,424 sm3 was methane. The remaining 7% of the extracted gas was carbon dioxide as a result of reverse production of the previously injected CO2. However, taking into consideration the phenomena of coal matrix shrinking and swelling, the total amount of injected CO2 decreased to approximately 625,000 sm3.

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Establishment of dynamic permeability model of coal reservoir and its numerical simulation during the CO2-ECBM process

Cited by 46 publications

References 49 publications

Liquid and Gas Corrected Permeability Correlation for Heterogeneous Carbonate Reservoir Rocks

Liquid and Gas Corrected Permeability Correlation for Heterogeneous Carbonate Reservoir Rocks

Numerical analysis of drainage rate for multilayer drainage coalbed methane well group in Southern Qinshui basin

Research on the Processes of Injecting CO2 into Coal Seams with CH4 Recovery Using Horizontal Wells

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