NOVELTY - Stronger adsorbing fluid (SAG) sequestering process in coal bed, involves stimulating a injection well, injecting a SAG into injection well at pressure greater than reservoir pressure (P-R), shutting in injection well for at least 0.5 SAG sorption time (T-S-SAG), and repeating injecting and shutting process at least once.    USE - For sequestering stronger adsorbing fluid (SAG) in coal bed.    ADVANTAGE - The process has increased injectivity due to increased injection rate, reduced near-well flow resistance, increased apparent fracture length and reduced skin factor during injection. The process has reduced injection pressure, high efficiency. The coal bed has decreased absolute permeability. The injection of SAG maintains or increases reservoir pressure and driving force for production of methane is induced. The coal bed with lower or medium permeability is used in the process.    DETAILED DESCRIPTION - Injection well is stimulated by inducing fracture in coal bed by injecting injection fluid in injection well at pressure greater than or equal to crack initiation pressure (P-C) and extending fracture by injecting injection fluid in injection well at pressure greater than or equal to fracture extension pressure (P-C). The SAG is injected into injection well at pressure greater than reservoir pressure (P-R). The injection well is shut for at least 0.5 SAG sorption time (T-S-SAG). The injection and shutting processes are repeated at least once, and SAG in coal bed is sequestered. The coal bed has injection well(s) and P-C greater than P-E greater than P-F greater than P-R.    An INDEPENDENT CLAIM is included for methane recovering process from coal bed, which involves stimulating injection well, injecting SAG into injection well and recovering methane, shutting in injection well and repeating injecting and shutting processes at least once.    DESCRIPTION OF DRAWING(S) - The figure shows a graph relating bottom-hole pressure during carbondioxide injection and elapsed time of shut-in period.