Abstract: This disclosure includes a message display method and apparatus, a device, and a storage medium. In the method, a message window of a first message group is displayed. The message window is configured to display messages of the first message group from a plurality of user accounts. A first message in the message window of the first message group is added to a grouped message window. The grouped message window is configured to display messages associated with a topic of the first message. Further, the messages associated with the topic are from at least one message group.

Abstract: A production monitoring system includes a distributed acoustic sensing subsystem that includes a first optical fiber for a distributed acoustic sensing signal and a distributed temperature sensing subsystem that includes a second optical fiber for a distributed temperature sensing signal. The production monitoring system, also includes a cable positioned in a wellbore penetrating through one or more subterranean formations. The distributed acoustic sensing subsystem is communicatively coupled to the cable through the distributed temperature sensing subsystem. The cable includes one or more optical fibers used to obtain optical fiber measurements pertaining to the distributed acoustic sensing signal and the distributed temperature sensing signal. The optical fibers include a sensing fiber that is common between the distributed acoustic sensing subsystem and the distributed temperature sensing subsystem.

Abstract: System and methods of controlling fluid diversion during stimulation treatments are provided. Real-time measurements are obtained from a plurality of fiber-optic data sources at a well site during a stimulation treatment being performed along a portion of a wellbore within a subsurface formation. Fracture growth and stress within the subsurface formation surrounding the portion of the wellbore are determined as the stimulation treatment is performed, based on the real-time measurements and a fully-coupled diversion model. An amount of diverter for a diversion phase of the stimulation treatment to be performed along the portion of the wellbore is determined, based on the fracture growth and the stress within the subsurface formation. The diversion phase of the stimulation treatment is performed by injecting the amount of diverter into the subsurface formation via at least one injection point located along the portion of the wellbore.

Abstract: Screen-outs can be detected from acoustical signals in a wellbore. Data based on an acoustic signal generated during a hydraulic fracturing operation in a wellbore formed through a subterranean formation can be received. An expected total flow rate of fluid being injected into the wellbore can be determined based on the data. An actual total flow rate of the fluid being injected into the wellbore can be determined. A screen-out that occurred can be identified by comparing the expected total flow rate and the actual total flow rate.

Abstract: This disclosure includes a message display method and apparatus, a device, and a storage medium. In the method, a message window of a first message group is displayed. The message window is configured to display messages of the first message group from a plurality of user accounts. A first message in the message window of the first message group is added to a grouped message window. The grouped message window is configured to display messages associated with a topic of the first message. Further, the messages associated with the topic are from at least one message group.

Abstract: Fluid allocation in a well can be determined with a distributed temperature sensing system using data from a distributed acoustic sensing system. Flow data indicating a flow rate of a fluid through a perforation in a well based on an acoustic signal generated during a hydraulic fracturing operation in the well can be received. Warm-back data indicating an increase in temperature at the perforation can be received. A fluid allocation model can be generated based on the flow data and the warm-back data. The fluid allocation model can represent positions of the fluid in fractures formed in a subterranean formation of the well.

Abstract: A production monitoring system includes a distributed acoustic sensing subsystem that includes a first optical fiber for a distributed acoustic sensing signal and a distributed temperature sensing subsystem that includes a second optical fiber for a distributed temperature sensing signal. The production monitoring system, also includes a cable positioned in a wellbore penetrating through one or more subterranean formations. The distributed acoustic sensing subsystem is communicatively coupled to the cable through the distributed temperature sensing subsystem. The cable includes one or more optical fibers used to obtain optical fiber measurements pertaining to the distributed acoustic sensing signal and the distributed temperature sensing signal. The optical fibers include a sensing fiber that is common between the distributed acoustic sensing subsystem and the distributed temperature sensing subsystem.

Abstract: Fluid allocation in a well can be determined with a distributed temperature sensing system using data from a distributed acoustic sensing system. Flow data indicating a flow rate of a fluid through a perforation in a well based on an acoustic signal generated during a hydraulic fracturing operation in the well can be received. Warm-back data indicating an increase in temperature at the perforation can be received. A fluid allocation model can be generated based on the flow data and the warm-back data. The fluid allocation model can represent positions of the fluid in fractures formed in a subterranean formation of the well.

Abstract: The disclosed embodiments include a method for determining fluid level drop and formation permeability during wellbore stimulation of a shut-in stage in real time. The method includes receiving an initial permeability value of a formation surrounding a wellbore. Further, the method includes performing, and if necessary repeating at a defined time interval, the following steps until a flowrate of stimulation fluid reaches zero or until a new pumping stage begins. The steps include solving for the flowrate of the stimulation fluid in the wellbore and computing hydrostatic pressure and a computed temperature in the wellbore. Further, the steps include updating a permeability calculation of the formation based on the flowrate of the stimulation fluid.

Abstract: System and methods of controlling fluid diversion during stimulation treatments are provided. Real-time measurements are obtained from a plurality of fiber-optic data sources at a well site during a stimulation treatment being performed along a portion of a wellbore within a subsurface formation. Fracture growth and stress within the subsurface formation surrounding the portion of the wellbore are determined as the stimulation treatment is performed, based on the real-time measurements and a fully-coupled diversion model. An amount of diverter for a diversion phase of the stimulation treatment to be performed along the portion of the wellbore is determined, based on the fracture growth and the stress within the subsurface formation. The diversion phase of the stimulation treatment is performed by injecting the amount of diverter into the subsurface formation via at least one injection point located along the portion of the wellbore.

Abstract: Screen-outs can be detected from acoustical signals in a wellbore. Data based on an acoustic signal generated during a hydraulic fracturing operation in a wellbore formed through a subterranean formation can be received. An expected total flow rate of fluid being injected into the wellbore can be determined based on the data. An actual total flow rate of the fluid being injected into the wellbore can be determined. A screen-out that occurred can be identified by comparing the expected total flow rate and the actual total flow rate.