Recovery of coalbed methane (CBM) can trigger a series of coal-gas interactions, including methane desorption, coal deformation, and associated permeability change. These processes may impact each other. A primary objective of this analysis is to simultaneously quantify these interactions and their impacts during CBM recovery. To achieve this and other objectives, a rigorously coupled adsorption strain permeability model was developed. Gas adsorption, coal deformation, and cleat permeability characteristics were described using simplified local density (SLD) adsorption theory, a theory-based strain model, and matchstick-based permeability models, respectively. The strain model was verified against measured methane adsorption-induced coal strain data published during the past 60 years, and the coupled model was tested using well test data measured in the San Juan Basin of New Mexico in the United States. Results suggest that the strain model is very consistent with measured coal deformation data for fluid pressure up to 80 MPa, and the average relative errors between measured and predicted results are all <15.51%. Generally, simulated volumetric strain first increases then decreases with pressure, and the maximum volumetric strain occurs at a pressure of similar to 20 MPa, which is strikingly different from the pressure corresponding to maximum Gibbs adsorption. Simulation results also suggest that methane adsorption/desorption, coal deformation, permeability evolution, and their coupled impacts are quantitatively reasonable and consistent with observed data. Several cleat permeability models were coupled and tested, and the improved Palmer and Mansoori model exhibited the best performance among those tested. Since methane sorption-induced volumetric strain of typical San Juan Basin coal is 5-9 orders of magnitude larger than that due to reservoir compaction, matrix shrinkage dominates and leads to a monotonic increase of permeability during CBM recovery.