Assessment of shrinkage–swelling influences in coal seams using rank-dependent physical coal properties
Introduction
ECBM recovery technique increases methane production significantly and leads to CO2 sequestration. As being the most important parameter affecting both methane recovery and CO2 sequestration, absolute fracture (cleat) permeability depends on the balance between effective stress in the cleats and shrinkage & swelling (SS) of coal matrix. Around production wells, depletion of methane begins within cleats. Subsequently, adsorbed methane inside the coal matrix desorbs and diffuses to feed the cleats due to concentration difference. During this process, the effective stress in the cleats increases and coal matrix shrinks as a result of desorption. Former decreases permeability by getting closer the cleat surfaces and latter does the opposite. As for injection well, CO2 results in swelling owing to relatively higher affinity of coal to CO2 than CH4, which decreases the absolute cleat permeability. On the other hand, depending on its magnitude, injection pressure can reduce swelling effect by expanding the fracture aperture mechanically (Mavor and Gunter, 2004).
Relative permeability has also an important role on the production of coalbed methane. As the reservoir pressure is reduced in the cleat system by production of water, methane desorbs into the cleat system. At this point, and for the remainder of the life of the producing wells, two-phase flow occurs in the cleat system. Under two-phase flow conditions, the relative permeability relationships between gas and water control the relative flow of gas and water in the reservoir. Thus, it is important to determine the relative permeability characteristics of the coal being analyzed. Furthermore, changes in fracture porosity due to shrinkage and swelling during application of ECBM recovery technique controls fluid saturations that in turn lead to changes in relative and effective gas permeability (GRI, 1996).
In the literature, there are parametric simulation studies (Smith et al., 2003, Davis et al., 2004, Maricic et al., 2005) investigating the effects of physical coal properties on primary and enhanced coalbed methane recoveries. The trend is generally to change a model parameter in its given range and to observe its impact on TMRB. In this study, however, a new approach was followed during preparation of input data for a commercial compositional simulator, CMG (Computer Modeling Group)/GEM module (CMG, 2007). Instead of using a real field or a hypothetical data set, rank-dependent coal properties in the literature were gathered to construct a database. This database enabled us to acquire more realistic outputs from the simulator. Impact of SS on TMRB and CO2 sequestration were studied by using this database. In the following section, methodology followed up during preparation of rank-dependent coal properties is explained.
Section snippets
Methodology
Most of the rank-dependent coal properties in the literature are provided with respect to vitrinite reflectance and carbon contents of coal. Intervals of these parameters corresponding to a specific rank of coal are provided in Table 1. Moreover, simulation inputs with respect to coal rank are given with their references in Table 2, Table 3. Data obtained from literature includes different types of coal samples (meshed, crushed samples and plates), since all of the data were gathered to give an
Simulation cases
After determining rank and component dependent simulation parameters, three different cases namely, rank of coal, reservoir types and molar compositions of injected fluid were run to observe the behavior of our data set. In addition, parameters in the extended Palmer & Mansoori model was collected from the published papers and high, medium, low cases were defined for each parameter to make a sensitivity analysis. In all simulation cases, well-pattern, drainage area, fracture permeability and
Results and discussion
In this study, TMRB includes ten-year primary methane recovery and succeeding enhanced coalbed methane (ECBM) recovery up to CO2 breakthrough for all simulation cases, except methane-saturated dry coal reservoir case. CBM recovery is the primary recovery at the end of the ten years. Moreover, throughout the injection period the displacement ratio is defined as:
Owing to economical reasons, it is better to obtain a lower displacement ratio, since reduction in
Conclusion
In this study, it was shown that it is possible to construct a rank-dependent coal property database for enhanced coalbed methane recovery simulations. According to this data set, various simulation cases were run and some major conclusions were drawn as:
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Shrinkage and swelling effects lead to an increase in total methane recovery at CO2 breakthrough for all ranks of coal, but there is no relationship between rank of coal and the magnitude of increase. However, change in displacement ratio, CO2
Nomenclature
- a
ash content, weight fraction
- cf
fracture compressibility, 1/kPa
- D
diffusion coefficient, m2/s
- De
effective diffusivity, 1/s
- E
elastic modulus, kPa
- Gs
gas storage capacity at pressure “P” and temperature “T”, Sm3/ton
- K
bulk modulus, kPa
- kf
fracture permeability, md
- kfi
initial fracture permeability, md
- M
constraint axial modulus, kPa
- m
moisture content, weight fraction
- n
number of diffusing species
- nc
number of free gas components inside cleats
- P
pressure inside cleats, kPa
- Pi
initial pressure inside cleats, kPa
- Pinf
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