Abstract: A method of measuring a pressure of a fluid adjacent a wall of a pipe or vessel. A transducer is attached to the wall of the pipe or vessel. A signal is transmitted by the transducer at a characteristic frequency via a plurality of guided wave modes. The characteristic frequency is a frequency at which the guided wave modes are separated in time from each other when received. The signal is received after the plurality of guided wave modes travel in or through the wall a predetermined number of times. The signal has a signal receipt time after the predetermined number of times. The pressure of the fluid is calculated using the signal receipt time.

Abstract: The methods disclosed herein are directed to an automated method for monitoring performance of a well in a hydrocarbon reservoir for continuous monitoring of well test production data for a plurality of well system performance parameters, trending actual performance parameter deviations from a well system model, and determining most probable root cause(s) of the performance parameter deviations based on the trend of the deviations of a plurality of parameters for an outflow component of a well performance model and a plurality of parameters inflow component of a well performance model. The method automatically notifies an operator of detected root causes of the performance degradation, and further may perform corrective action in the well system based on at least one root cause of the deviation determined by the well performance model.

Abstract: Hydrocarbon wells include a wellbore, a fracture that extends from the wellbore, and an electromagnetic contrast material positioned within the fracture. The hydrocarbon wells also include a downhole electromagnetic transmitter, which is configured to direct an electromagnetic probe signal incident upon the electromagnetic contrast material, and a downhole electromagnetic receiver, which is configured to receive an electromagnetic resultant signal from the electromagnetic contrast material. Methods for monitoring fracture morphology of a fracture that extends from a wellbore of a hydrocarbon well include flowing an electromagnetic contrast material into a fracture and generating an electromagnetic probe signal. The methods also include modifying the electromagnetic probe signal with the electromagnetic contrast material to generate an electromagnetic resultant signal. The methods further include receiving the electromagnetic resultant signal and determining the morphology of the fracture.

Abstract: A method and apparatus are provided for determining movement of a fluid into or out of a subsurface wellbore, to thereby enable accurate allocation of fluids being produced by or injected into each of several zones of the wellbore. A temperature change is effected in the fluid in a semi-continuous or pulsed manner at one or more locations in the wellbore. A temperature of the fluid is measured at one or more sensing locations downstream of the location of the temperature change. A time of flight model is used to determine, for a plurality of points of interest, a fluid flow direction, bulk flow rate and/or a cumulative flow rate contribution.

Abstract: A method of detecting and mitigating flow instabilities, such as slugging, in hydrocarbon production wells. Real-time production data pertaining to each well is are retrieved. Using the production data, patterns of flow instability are identified therein. A numerical model of transient and thermal multiphase flow in each well is generated. Well test data is are retrieved from a database. The numerical model is calibrated using the well test data. Using the calibrated numerical model, a parametric study is performed to determine how input parameters affect at least one of stability and performance of the wells. Results of the parametric study are queried to determine a type of flow instability and to determine operating conditions to improve performance of the wells. An advisory is provided to a user to change operating conditions of one or more of the wells, to improve stability and/or performance of one or more of the wells.

Abstract: Cable guides that support a fiber optic cable relative to a tube, hydrocarbon conveyance systems including the cable guides, and methods of acoustically probing an elongate region. The cable guides include a cable retention structure with a first retention region configured to align a first diffraction grating along a first sensing axis and a second retention region configured to align a second diffraction grating along a second sensing axis that is nonparallel to the first sensing axis. The tube defines a tubular conduit configured to convey a hydrocarbon. The hydrocarbon conveyance systems include a tube, a distributed acoustic sensor, and a cable guide. The methods include transmitting an initiated optical signal and receiving a reflected optical signal that includes reflected portions that are reflected by a first diffraction grating and a second diffraction grating. The methods further include analyzing the reflected optical signal to detect an applied mechanical strain.

Abstract: Drill strings with probe deployment structures, hydrocarbon wells that include the drill strings, and methods of utilizing the drill strings are disclosed herein. The drill strings include a pipe string and a drill bit attached to the pipe string. The drill strings also include a probe deployment structure attached to the pipe string and a downhole communication device attached to the pipe string. The probe deployment structure includes a probe and is configured to selectively insert the probe into a subterranean formation via a wellbore of the hydrocarbon well. The probe is configured to measure at least one property of the subterranean formation. The downhole communication device is configured to communicate with the probe. The hydrocarbon wells include a drill string support structure, which supports the drill string, a wellbore extending within a subsurface region, and the drill string extending within the wellbore.

Abstract: Hydrocarbon wells that include interrogation devices positioned within a fracture and methods of monitoring at least one property of a fracture. The hydrocarbon wells include a wellbore that extends within a subsurface region and a fracture that extends from the wellbore. The hydrocarbon wells also include a plurality of interrogation devices entrained within a carrier fluid and positioned within the fracture and a downhole communication device positioned within the wellbore and proximal the fracture. The methods include flowing the interrogation devices into the fracture and conveying the excitation signal into the fracture. The methods also include receiving the excitation signal with the interrogation devices and generating a plurality of corresponding resultant signals with the interrogation devices.

Abstract: Methods and systems for determining a liquid level in a formation between a horizontal segment of an injection wellbore and a horizontal segment of a production wellbore are disclosed. Under shut-in conditions, local temperatures and pressures are determined for each of a plurality of inflow zones along the production wellbore segment. Local profile values are determined based on local shut-in subcool values and local shut-in liquid levels. After flow has resumed, a local liquid level is determined based on the local operating subcool value and the local profile value for that inflow zone. The local profile values may be updated during subsequent shut-ins.

Abstract: Hydrocarbon wells and methods of interrogating fluid flow within hydrocarbon wells. The hydrocarbon wells include a wellbore and downhole tubing that defines a tubing conduit and extends within the wellbore. The hydrocarbon wells also include an interrogation device. The interrogation device is configured to indicate at least one property of fluid flow within the hydrocarbon wells. The hydrocarbon wells also include a downhole location at which the interrogation device is released into the tubing conduit and a detection structure configured to query the interrogation device to determine the at least one property of fluid flow within the hydrocarbon wells. The methods include releasing an interrogation device at a downhole location within a hydrocarbon well and flowing the interrogation device from the downhole location to a surface region. The methods also include querying the interrogation device to determine at least one property of fluid flow within the hydrocarbon well.

Abstract: A method of measuring a pressure of a fluid adjacent a wall of a pipe or vessel. A transducer is attached to the wall of the pipe or vessel. A signal is transmitted by the transducer at a characteristic frequency via a plurality of guided wave modes. The characteristic frequency is a frequency at which the guided wave modes are separated in time from each other when received. The signal is received after the plurality of guided wave modes travel in or through the wall a predetermined number of times. The signal has a signal receipt time after the predetermined number of times. The pressure of the fluid is calculated using the signal receipt time.

Abstract: Methods and systems for determining a liquid level above a horizontal segment of a wellbore in a formation are disclosed. Local temperatures and pressures are determined for each of a plurality of zones along the wellbore segment. For each zone, a local inflow rate is determined for fluids entering the wellbore from the formation. Based on the local inflow rate, local temperature, and local pressure, a local reservoir pressure is determined, and a local liquid level is determined based on the local reservoir pressure and a pressure associated with an injector wellbore positioned above the horizontal segment.

Abstract: A method and apparatus are provided for determining movement of a fluid into or out of a subsurface wellbore, to thereby enable accurate allocation of fluids being produced by or injected into each of several zones of the wellbore. A temperature change is effected in the fluid at a first location in the wellbore. A temperature of the fluid is measured at one or more sensing locations downstream of the location of the temperature change. A simulated heat flow profile is generated from a wellbore model. The simulated heat flow profile is compared to the measured temperature of the fluid at the one or more sensing locations. An inversion model is used to determine, for a plurality of points of interest, a fluid flow direction and/or a cumulative flow rate contribution.

Abstract: Hydrocarbon wells including electrically actuated gas lift valve assemblies and methods of providing gas lift in a hydrocarbon well. The hydrocarbon wells include a wellbore that extends within a subterranean formation and downhole tubing that extends within the wellbore. The hydrocarbon wells also include a lift gas supply system configured to provide a lift gas stream to a lift gas supply conduit of the wellbore, a plurality of electrically actuated gas lift valve assemblies, a valve power supply system, and a controller. The methods include measuring a respective pressure differential between a lift gas supply conduit and a production conduit of the hydrocarbon well at each electrically actuated gas lift valve assembly in a plurality of electrically actuated gas lift valve assemblies of the hydrocarbon well. The methods also include selectively opening a selected electrically actuated gas lift valve assembly based on the respective pressure differential.

Abstract: Hydrocarbon wells and methods for monitoring fracture morphology of a fracture that extends from a wellbore of the hydrocarbon wells are disclosed herein. The hydrocarbon wells include a wellbore, a fracture that extends from the wellbore, and an electromagnetic contrast material positioned within the fracture. The hydrocarbon wells also include a downhole electromagnetic transmitter, which is configured to direct an electromagnetic probe signal incident upon the electromagnetic contrast material, and a downhole electromagnetic receiver, which is configured to receive an electromagnetic resultant signal from the electromagnetic contrast material. The methods include flowing an electromagnetic contrast material into a fracture and generating an electromagnetic probe signal. The methods also include modifying the electromagnetic probe signal with the electromagnetic contrast material to generate an electromagnetic resultant signal.

Abstract: Drill strings with probe deployment structures, hydrocarbon wells that include the drill strings, and methods of utilizing the drill strings are disclosed herein. The drill strings include a pipe string and a drill bit attached to the pipe string. The drill strings also include a probe deployment structure attached to the pipe string and a downhole communication device attached to the pipe string. The probe deployment structure includes a probe and is configured to selectively insert the probe into a subterranean formation via a wellbore of the hydrocarbon well. The probe is configured to measure at least one property of the subterranean formation. The downhole communication device is configured to communicate with the probe. The hydrocarbon wells include a drill string support structure, which supports the drill string, a wellbore extending within a subsurface region, and the drill string extending within the wellbore.

Abstract: Hydrocarbon wells that include interrogation devices positioned within a fracture and methods of monitoring at least one property of a fracture. The hydrocarbon wells include a wellbore that extends within a subsurface region and a fracture that extends from the wellbore. The hydrocarbon wells also include a plurality of interrogation devices entrained within a carrier fluid and positioned within the fracture and a downhole communication device positioned within the wellbore and proximal the fracture. The methods include flowing the interrogation devices into the fracture and conveying the excitation signal into the fracture. The methods also include receiving the excitation signal with the interrogation devices and generating a plurality of corresponding resultant signals with the interrogation devices.

Abstract: Hydrocarbon wells and methods of interrogating fluid flow within hydrocarbon wells. The hydrocarbon wells include a wellbore and downhole tubing that defines a tubing conduit and extends within the wellbore. The hydrocarbon wells also include an interrogation device. The interrogation device is configured to indicate at least one property of fluid flow within the hydrocarbon wells. The hydrocarbon wells also include a downhole location at which the interrogation device is released into the tubing conduit and a detection structure configured to query the interrogation device to determine the at least one property of fluid flow within the hydrocarbon wells. The methods include releasing an interrogation device at a downhole location within a hydrocarbon well and flowing the interrogation device from the downhole location to a surface region. The methods also include querying the interrogation device to determine at least one property of fluid flow within the hydrocarbon well.

Abstract: The methods disclosed herein are directed to an automated method for monitoring performance of a well in a hydrocarbon reservoir for continuous monitoring of well test production data for a plurality of well system performance parameters, trending actual performance parameter deviations from a well system model, and determining most probable root cause(s) of the performance parameter deviations based on the trend of the deviations of a plurality of parameters for an outflow component of a well performance model and a plurality of parameters inflow component of a well performance model. The method automatically notifies an operator of detected root causes of the performance degradation, and further may perform corrective action in the well system based on at least one root cause of the deviation determined by the well performance model.

Abstract: A method and apparatus are provided for determining movement of a fluid into or out of a subsurface wellbore, to thereby enable accurate allocation of fluids being produced by or injected into each of several zones of the wellbore. A temperature change is effected in the fluid in a semi-continuous or pulsed manner at one or more locations in the wellbore. A temperature of the fluid is measured at one or more sensing locations downstream of the location of the temperature change. A time of flight model is used to determine, for a plurality of points of interest, a fluid flow direction, bulk flow rate and/or a cumulative flow rate contribution.