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Well type and pattern optimization method based on fine numerical simulation in coal-bed methane reservoir

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Abstract

Coal-bed methane (CBM) is a precious clean energy. A reasonable well type and pattern design is the premise and the key to effective development of coal-bed methane. In this paper, a set of optimization method is presented which includes a fine CBM numerical model with the combina tion of the isothermal adsorption test results. Different Langmuir curves and adsorption–desorption time are corresponding to different grids in the model. The model has advantages over previous models in terms of the CBM reservoir structural characteristics and permeability anisotropy. As in most of CBM mining area, the structural characteristics are so complex that a combination of vertical and U-shaped wells is the best choice to achieve optimum production of gas. To optimize the pattern and spacing between vertical wells, different types of coal-bed cleats pressure drop rules are in consideration. Based on the CBM content in the reservoir, the distribution of different well types can be determined. The optimization method above has been applied in one pilot area in QinDuan Block, China. The result shows that combination of U-shaped and vertical wells in a diamond well pattern will provide the best CBM production scenario. In this diamond well pattern, the optimum well spacing along the long and short diagonals is 350 and 300 m, respectively. The degree of reserve recovery was predicted to up to 56.63 % after 30 years of production.

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Abbreviations

Q L :

Theoretical adsorption (m3/day)

P :

Coal-bed reservoir pressure (MPa)

V L :

Langmuir volume (m3/day)

P L :

Langmuir pressure (MPa)

V m :

Gas adsorption concentration in unit mass of coal matrix (m3)

V E :

Equilibrium adsorption concentration of gas in unit mass of coal matrix (m3)

\(\tau_{\text{p}}\) :

Adsorption time (day)

G c :

CBM content at underground conditions (–)

G co :

CBM content at laboratory conditions (–)

A :

Ash content in the coal-bed reservoir (–)

M :

Moisture content in the coal-bed reservoir (–)

k x :

Permeability in the face cleat direction (×10−3μm2)

k y :

Permeability in the butt cleat direction (×10−3μm2)

\(\overline{k}\) :

Equivalent permeability after coordinate conversion (×10−3μm2)

L f :

Half fracture length (m)

L f0 :

Equivalent half fracture length after coordinate conversion (m)

D x :

Well spacing in the long side direction of the rectangular well pattern or the long diagonal of the diamond well pattern (m)

D y :

Well spacing in the short side direction of the rectangular well pattern or the short diagonal of the diamond well pattern (m)

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Acknowledgments

This work was supported by Major National Science and Technology Project “Large Oilfield and Coal-bed Gas Development”—“The development effect evaluation of water flooding and studies on optimization methods of measures” (Grant No. 2011ZX05052-004); And the creative and scientific research project of Northeast Petroleum University “Study on Non-linearity Seepage Theory in Tight Sandstone Gas Reservoir” (Grant No. YJSCX2014-010NEPU).

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  1. Key Laboratory of Enhanced Oil and Gas Recovery of Education Ministry, Northeast Petroleum University, Daqing, China

    Yikun Liu, Fengjiao Wang, Huimin Tang & Shuang Liang

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  1. Yikun Liu
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Correspondence to Fengjiao Wang.

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Liu, Y., Wang, F., Tang, H. et al. Well type and pattern optimization method based on fine numerical simulation in coal-bed methane reservoir. Environ Earth Sci 73, 5877–5890 (2015). https://doi.org/10.1007/s12665-015-4375-x

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