In
the present study, three CBM blocks in the central and southern
Qinshui Basin, China, including Fanzhuang, Zhengzhuang, and Changzhi
blocks, were selected. Combined with the data, such as the physical
properties of coal reservoirs, logging, hydrofracture operation, injection/drawdown
well testing, microseismic fracture monitoring technology, and over
2000 days gas production rate, the key factors affecting the gas production
rate of CBM wells were analyzed comprehensively and systematically.
Unimodal and bimodal models can be identified according to the long-term
gas production rate data. The unimodal model corresponds to a declining
pump pressure curve, meaning that caprock integrity is destroyed during
hydrofracture operations, commonly causing poor gas production performance.
The bimodal model is associated with fluctuating-rising and stable
pump pressure curves, indicating good hydrofracture consequences.
On the premise of the relatively high gas content, the gas saturation/critical-reservoir
pressure ratio, permeability, and coal deformation are the major geological
factors that affect the long-term gas production performance of CBM
wells. Engineering factors, including pollution by the drilling fluid
and cement paste, the type of the fracturing fluid, tonstein intercalation,
coal deformation, and in situ stress, affect gas production performances
via the following four mechanisms: the effect of hydrofracture operations
on caprock integrity, the effect of fluids pumped on the pore-fracture
system, the initiation and propagation of artificially induced fractures,
and the performances of proppants pumped. This work can provide guidelines
for the optimization and development of high-rank CBM blocks.