Acoustic characterization and mapping of flow from a perforation zone of a well. As a wireline probe containing acoustic sensors moves through the well, the acoustic sensors record acoustic pressure measurements of flow for each perforation in the well casing. The acoustic data is recorded and compiled into a three-dimensional flow model showing flow of hydrocarbons within and/or out of perforation tunnels. The three-dimensional flow models generated can be combined with historical data to form four-dimensional models illustrating flow over time, and both the three and four-dimensional models can be used to determine effectiveness of perforation charges as well as future flow from the well.

Acoustic characterization and mapping of flow from a perforation zone of a well. As a wireline probe containing acoustic sensors moves through the well, the acoustic sensors record acoustic pressure measurements of flow for each perforation in the well casing. The acoustic data is recorded and compiled into a three-dimensional flow model showing flow of hydrocarbons within and/or out of perforation tunnels. The three-dimensional flow models generated can be combined with historical data to form four-dimensional models illustrating flow over time, and both the three and four-dimensional models can be used to determine effectiveness of perforation charges as well as future flow from the well.

A system includes a processor(s), and a memory coupled to the processor(s) having instructions stored therein. When executed by the processor(s), the instructions cause the processor(s) to perform functions to: apply a treatment for stimulating production to at least a first well in a subterranean formation; determine a flow distribution based on at least one of a first-well measurement or a second-well measurement, the first-well measurement taken at the first well, and the second-well measurement taken at a second well; determine a length of a fracture between the first and second wells, based on the determined flow distribution; determine if the applied treatment at the first well interferes with the second well, based on the determined length of the fracture; and apply a diverting material at the first well if it is determined that the applied treatment interferes with the second well, in order to control well bashing.

A system includes a processor(s), and a memory coupled to the processor(s) having instructions stored therein. When executed by the processor(s), the instructions cause the processor(s) to perform functions to: apply a treatment for stimulating production to at least a first well in a subterranean formation; determine a flow distribution based on at least one of a first-well measurement or a second-well measurement, the first-well measurement taken at the first well, and the second-well measurement taken at a second well; determine a length of a fracture between the first and second wells, based on the determined flow distribution; determine if the applied treatment at the first well interferes with the second well, based on the determined length of the fracture; and apply a diverting material at the first well if it is determined that the applied treatment interferes with the second well, in order to control well bashing.

A technique facilitates use of sensor data, e.g. pressure data, associated with hydraulic control lines. According to an embodiment, a well string is deployed in a borehole and comprises a tool coupled with a hydraulic control line and operated via hydraulic inputs delivered through the hydraulic control line. Additionally, a sensor is coupled to the hydraulic control line to monitor pressure in the hydraulic control line. The sensor may be located permanently downhole proximate the tool. A control module is configured to collect data from the sensor and to compare the data to a baseline pressure profile associated with the tool. The sensor data may be used to determine characteristics related to operation of the tool.

A technique facilitates use of sensor data, e.g. pressure data, associated with hydraulic control lines. According to an embodiment, a well string is deployed in a borehole and comprises a tool coupled with a hydraulic control line and operated via hydraulic inputs delivered through the hydraulic control line. Additionally, a sensor is coupled to the hydraulic control line to monitor pressure in the hydraulic control line. The sensor may be located permanently downhole proximate the tool. A control module is configured to collect data from the sensor and to compare the data to a baseline pressure profile associated with the tool. The sensor data may be used to determine characteristics related to operation of the tool.

Spherical projectiles may be used to form one or more holes in geologic or other material. These holes may be used for drilling, tunnel boring, excavation, and so forth.

Spherical projectiles may be used to form one or more holes in geologic or other material. These holes may be used for drilling, tunnel boring, excavation, and so forth.

A plunger lift system, as well as a method for monitoring plunger parameters within a wellbore using such a plunger lift system, are provided. The plunger lift system includes a lubricator attached to a wellhead at the surface and a plunger dimensioned to travel through the production tubing upon being released from the lubricator. The plunger lift system also includes magnetic sensor systems installed along the production tubing, where each magnetic sensor system includes a magnetic sensor for detecting the passage of the plunger as it travels through the production tubing, as well a communication device for transmitting communication signals between the magnetic sensor systems and a computing system located at the surface, where the computing system includes a processor and a non-transitory, computer-readable storage medium including computer-executable instructions that direct the processor to dynamically determine the plunger position and/or velocity based on the received communication signals.

Embodiments for determining a stuck pipe location include determining that a pipe is stuck in a wellbore due to an obstruction; deploying a fiber optic stuck pipe location detector inside the pipe, activating a first fiber optic sensor to detect a baseline reading, and manipulating the pipe. Some embodiments include detecting micro-noises caused by the stretching of the pipe, wirelessly acquiring data related to the micro-noises from the first fiber optic sensor, and determining a location of the obstruction by comparing the baseline reading with the data related to the micro-noises. Some embodiments include recovering the pipe at a predetermined point around the location of the obstruction while leaving the first fiber optic sensor inside the pipe.