Abstract: Systems and methods for using pressure signals to assess effectiveness of a diverter in a stimulation wellbore are disclosed. A pressure signal in an observation wellbore in the subsurface formation may be assessed using a pressure sensor in direct fluid communication with a fluid in the observation wellbore. The fluid in the observation wellbore may be indirect fluid communication with a fracture emanating from the observation wellbore. The pressure signal may include a pressure change that is induced by a fracture being formed from a stimulation wellbore in the subsurface formation. The pressure signal may be a pressure-induced poromechanic signal. The slope in the pressure signal before and after the diverter are provided into the stimulation wellbore may be assessed to determine the effectiveness of the diverter.

Abstract: Systems and methods for using pressure signals to assess effectiveness of a diverter in a stimulation wellbore are disclosed. A pressure signal in an observation wellbore in the subsurface formation may be assessed using a pressure sensor in direct fluid communication with a fluid in the observation wellbore. The fluid in the observation wellbore may be indirect fluid communication with a fracture emanating from the observation wellbore. The pressure signal may include a pressure change that is induced by a fracture being formed from a stimulation wellbore in the subsurface formation. The pressure signal may be a pressure-induced poromechanic signal. The slope in the pressure signal before and after the diverter are provided into the stimulation wellbore may be assessed to determine the effectiveness of the diverter.

Abstract: Systems and methods for assessing geometric fractures parameters in a subsurface formation are disclosed. A first pressure signal and a second pressure signal in a first (observation) wellbore in the subsurface formation may be assessed using a pressure sensor in direct fluid communication with a fluid in the first wellbore. The fluid in the first wellbore may be in direct fluid communication with at least a first fracture in the subsurface formation. The first pressure signal may include a pressure change that is induced by a second fracture being formed from a second (stimulation) wellbore in the subsurface formation. The second pressure signal may include a pressure change that is induced by a third fracture being formed from the second wellbore. One or more geometric parameters of the second and third fractures may be assessed using the first pressure signal and the second pressure signal.

Abstract: Systems and methods for using pressure signals to assess effectiveness of a diverter in a stimulation wellbore are disclosed. A pressure signal in an observation wellbore in the subsurface formation may be assessed using a pressure sensor in direct fluid communication with a fluid in the observation wellbore. The fluid in the observation wellbore may be indirect fluid communication with a fracture emanating from the observation wellbore. The pressure signal may include a pressure change that is induced by a fracture being formed from a stimulation wellbore in the subsurface formation. The pressure signal may be a pressure-induced poromechanic signal. The slope in the pressure signal before and after the diverter are provided into the stimulation wellbore may be assessed to determine the effectiveness of the diverter.

Abstract: Systems and methods for using pressure signals to assess effectiveness of a diverter in a stimulation wellbore are disclosed. A pressure signal in an observation wellbore in the subsurface formation may be assessed using a pressure sensor in direct fluid communication with a fluid in the observation wellbore. The fluid in the observation wellbore may be indirect fluid communication with a fracture emanating from the observation wellbore. The pressure signal may include a pressure change that is induced by a fracture being formed from a stimulation wellbore in the subsurface formation. The pressure signal may be a pressure-induced poromechanic signal. The slope in the pressure signal before and after the diverter are provided into the stimulation wellbore may be assessed to determine the effectiveness of the diverter.

Abstract: Systems and methods for assessing geometric fractures parameters in a subsurface formation are disclosed. A first pressure signal and a second pressure signal in a first (observation) wellbore in the subsurface formation may be assessed using a pressure sensor in direct fluid communication with a fluid in the first wellbore. The fluid in the first wellbore may be in direct fluid communication with at least a first fracture in the subsurface formation. The first pressure signal may include a pressure change that is induced by a second fracture being formed from a second (stimulation) wellbore in the subsurface formation. The second pressure signal may include a pressure change that is induced by a third fracture being formed from the second wellbore. One or more geometric parameters of the second and third fractures may be assessed using the first pressure signal and the second pressure signal.

Abstract: Systems and methods for using pressure signals to assess effectiveness of a diverter in a stimulation wellbore are disclosed. A pressure signal in an observation wellbore in the subsurface formation may be assessed using a pressure sensor in direct fluid communication with a fluid in the observation wellbore. The fluid in the observation wellbore may be in direct fluid communication with a fracture emanating from the observation wellbore. The pressure signal may include a pressure change that is induced by a fracture being formed from a stimulation wellbore in the subsurface formation. The pressure signal may be a pressure-induced poromechanic signal. The slope in the pressure signal before and after the diverter are provided into the stimulation wellbore may be assessed to determine the effectiveness of the diverter.

Abstract: Systems and methods for assessing geometric fractures parameters in a subsurface formation are disclosed. A first pressure signal and a second pressure signal in a first (observation) wellbore in the subsurface formation may be assessed using a pressure sensor in direct fluid communication with a fluid in the first wellbore. The fluid in the first wellbore may be in direct fluid communication with at least a first fracture in the subsurface formation. The first pressure signal may include a pressure change that is induced by a second fracture being formed from a second (stimulation) wellbore in the subsurface formation. The second pressure signal may include a pressure change that is induced by a third fracture being formed from the second wellbore. One or more geometric parameters of the second and third fractures may be assessed using the first pressure signal and the second pressure signal.