Method to reduce torsional vibration in a drilling tubulars string during a wellbore drilling process wherein use is made of a wellbore drilling installation comprising a top drive device, which top drive device comprises: - multiple electric top drive motors (31, 32, 33, 34; 331,332) each having a rotor, - a transmission to which said rotors of said multiple top drive motors (31, 32, 33, 34; 331,332) are operatively connected, wherein at least one, preferably each, of said top drive motors (31, 32, 33, 34; 331,332) has an operable clutch device (31a,32a,33a,34a) configured to selectively connect and disconnect upon command the rotor relative to the transmission, - a rotary stem or quill operatively connected to said transmission allowing said rotary stem or quill to be driven by said top drive motors (31, 32, 33, 34; 331,332), wherein the drilling tubulars string is connected to the rotary stem or quill of the top drive device, characterized in that the wellbore drilling installation further comprises: - a downhole drilling tubulars string rotation sensor configured to sense the actual rotational speed and/or rotational acceleration of a downhole end of the drilling tubulars string, or to sense a parameter from which said rotational speed and/or rotational acceleration is deductible, - a top drive rotation sensor that is adapted to sense the actual rotational speed and/or rotational acceleration of the upper end of the drilling tubulars string, wherein the wellbore drilling installation further comprises a computerized electronic controller for a wellbore drilling top drive device, the controller comprising: - a processor; - a program executed by the processor, wherein the program has been programmed to selectively control one or more clutches (31a,32a,33a,34a) of said wellbore drilling top drive device in order to reduce the occurrence of rotational vibration of the drilling tubular string driven by said top drive device, wherein the method comprises: - sensing the actual rotational speed and/or the rotational acceleration of the downhole end of the tubulars string, or sensing a parameter from which said rotational speed and/or rotational acceleration is deductible; - sensing the actual rotational speed and/or rotational acceleration of the upper end of the drilling tubulars string; - detecting stick slip occurrence on the basis of the output of the downhole drilling tubulars string rotation sensor and the top drive rotation sensor; - providing a command to said one or more top drive motors (31, 32, 33, 34; 331,332) having a clutch device (31a,32a,33a,34a) so as to selectively connect and disconnect the rotor thereof relative to the transmission by operating said clutch (31a,32a,33a,34a) on the basis of any detected stick slip occurrence. - multiple electric top drive motors (31, 32, 33, 34; 331,332) each having a rotor, - a transmission to which said rotors of said multiple top drive motors (31, 32, 33, 34; 331,332) are operatively connected, - a rotary stem or quill operatively connected to said transmission allowing said rotary stem or quill to be driven by said top drive motors (31, 32, 33, 34; 331,332), - a downhole drilling tubulars string rotation sensor configured to sense the actual rotational speed and/or rotational acceleration of a downhole end of the drilling tubulars string, or to sense a parameter from which said rotational speed and/or rotational acceleration is deductible, - a top drive rotation sensor that is adapted to sense the actual rotational speed and/or rotational acceleration of the upper end of the drilling tubulars string, - a processor; - a program executed by the processor, wherein the program has been programmed to selectively control one or more clutches (31a,32a,33a,34a) of said wellbore drilling top drive device in order to reduce the occurrence of rotational vibration of the drilling tubular string driven by said top drive device, - sensing the actual rotational speed and/or the rotational acceleration of the downhole end of the tubulars string, or sensing a parameter from which said rotational speed and/or rotational acceleration is deductible; - sensing the actual rotational speed and/or rotational acceleration of the upper end of the drilling tubulars string; - detecting stick slip occurrence on the basis of the output of the downhole drilling tubulars string rotation sensor and the top drive rotation sensor; - providing a command to said one or more top drive motors (31, 32, 33, 34; 331,332) having a clutch device (31a,32a,33a,34a) so as to selectively connect and disconnect the rotor thereof relative to the transmission by operating said clutch (31a,32a,33a,34a) on the basis of any detected stick slip occurrence.