The disclosure relates to a system, downhole device and method for monitoring a wellbore, in particular in a lateral section, during stimulation, with an equipment enabling retrieval in many conditions. The method includes monitoring the wellbore with a distributed fiber optic sensor to determine one or more characteristics of the stimulation operation using detected backscattered optical signals on the distributed fiber optic sensor. The cable is retrieved by exerting a traction force. The disclosure also relates to a downhole device for receiving a cable and retainers to maintain the cable and having a weakpoint configured to break when subjected to a force along the longitudinal axis greater than a predetermined threshold. The system comprises the cable having the distributed fiber optic sensor, the downhole device and a surface monitoring system for determining the characteristic of the stimulation operation using detected backscattered optical signals on the distributed fiber optic sensor.

The disclosure relates to a system, downhole device and method for monitoring a wellbore, in particular in a lateral section, during stimulation, with an equipment enabling retrieval in many conditions. The method includes monitoring the wellbore with a distributed fiber optic sensor to determine one or more characteristics of the stimulation operation using detected backscattered optical signals on the distributed fiber optic sensor. The cable is retrieved by exerting a traction force. The disclosure also relates to a downhole device for receiving a cable and retainers to maintain the cable and having a weakpoint configured to break when subjected to a force along the longitudinal axis greater than a predetermined threshold. The system comprises the cable having the distributed fiber optic sensor, the downhole device and a surface monitoring system for determining the characteristic of the stimulation operation using detected backscattered optical signals on the distributed fiber optic sensor.

This disclosure describes a system and method for generating images and location data of a subsurface object using existing infrastructure as a source. Many infrastructure objects (e.g., pipes, cables, conduits, wells, foundation structures) are constructed of rigid materials and have a known shape and location. Additionally these infrastructure objects can have exposed portions that are above or near the surface and readily accessible. A signal generator can be affixed to the exposed portion of the infrastructure object, which induces acoustic energy, or vibrations in the object. The object with affixed signal generator can then be used as a source in performing a subsurface imaging of subsurface objects, which are not exposed.

This disclosure describes a system and method for generating images and location data of a subsurface object using existing infrastructure as a source. Many infrastructure objects (e.g., pipes, cables, conduits, wells, foundation structures) are constructed of rigid materials and have a known shape and location. Additionally these infrastructure objects can have exposed portions that are above or near the surface and readily accessible. A signal generator can be affixed to the exposed portion of the infrastructure object, which induces acoustic energy, or vibrations in the object. The object with affixed signal generator can then be used as a source in performing a subsurface imaging of subsurface objects, which are not exposed.

A method for verticalizing recorded seismic data, the method including recording first data with a particle motion sensor, wherein the particle motion sensor is located on a streamer, and the particle motion sensor is configured to be insensitive to a direct current, recording second data with a gravity motion sensor, wherein the gravity motion sensor is also located on the stream, and the gravity motion sensor is configured to be sensitive to the direct current and temporally synchronous to the particle motion sensor, selecting a cost function that associates corresponding values of the first data and the second data, determining a misalignment angle from maximizing the cost function, wherein the misalignment angle describes a misalignment between corresponding axes of the particle motion sensor and the gravity motion sensor, and correcting seismic data recorded by the particle motion sensor based on the misalignment angle so that the corrected seismic data is verticalized with regard to gravity.

A device may provide, to a user device, a first message instructing a technician to move fiber cables and may receive a first signal based on the technician moving the fiber cables and a rest signal based on the technician stopping movement of the fiber cables. The device may calculate a distance, an average peak signal, and a baseline signal based on the first signal and the rest signal and may calculate a data collection window based on the distance, the average peak signal, and the baseline signal. The device may provide, to the user device, a second message instructing the technician to move one fiber cable at a time and may receive second signals based on the technician moving one fiber cable at a time. The device may provide, for display to the user device, the data collection window and indications of the second signals.

A device may provide, to a user device, a first message instructing a technician to move fiber cables and may receive a first signal based on the technician moving the fiber cables and a rest signal based on the technician stopping movement of the fiber cables. The device may calculate a distance, an average peak signal, and a baseline signal based on the first signal and the rest signal and may calculate a data collection window based on the distance, the average peak signal, and the baseline signal. The device may provide, to the user device, a second message instructing the technician to move one fiber cable at a time and may receive second signals based on the technician moving one fiber cable at a time. The device may provide, for display to the user device, the data collection window and indications of the second signals.

A marine seismic acquisition system includes a frame that includes a central longitudinal axis and members that define orthogonal planes that intersect along the central longitudinal axis; a data interface operatively coupled to the frame; hydrophones operatively coupled to the frame; a buoyancy engine operatively coupled to the frame where the buoyancy engine includes at least one mechanism that controls buoyancy of at least the frame, the hydrophones and the buoyancy engine; and at least one inertial motion sensor operatively coupled to the frame that generates frame orientation data, where the hydrophones, the buoyancy engine and the at least one inertial motion sensor are operatively coupled to the data interface.

A system can receive seismic data that can correlate to a subterranean formation. The system can derive a set of seismic attributes from the seismic data. The seismic attributes can include discontinuity-along-dip. The system can determine parameterized results by analyzing the seismic data and the seismic attributes using a deep learning neural network. The deep learning neural network can include a dilation module. The system can determine one or more fault probabilities of the subterranean formation using the parameterized results. The system can output the fault probabilities for use in a hydrocarbon exploration operation.

A plurality of sensors and a controller are disposed in a marine seismic streamer. Each of the sensors comprises an enclosure having two opposing interior walls, first and second piezoelectric elements disposed on the opposing interior walls, a third piezoelectric element disposed on a flexible substrate within the enclosure between the opposing interior walls, a pressure signal output node and an acceleration signal output node disposed on the exterior surface of the enclosure. A combined pressure signal derived from the pressure signal output nodes of the plural sensors is coupled to a pressure signal input of the controller. A combined acceleration signal derived from the acceleration signal output nodes of the plural sensors is coupled to an acceleration signal input of the controller. The streamer may be towed, and the combined pressure and acceleration signals may be recorded in a computer-readable medium.