Abstract: A system and method for monitoring oil flow rates at multiple points in production wells using a flow sensing fiber optic cable. An illustrative system embodiment includes: a fiber optic sensing system housed within a tube suitable for a downhole environment; and a flow to signal conversion device attached to the tube and deployed in the oil flow.

Abstract: A system for continuous determination of annulus pressure in subsurface wells comprises one or more electro acoustic technology sensor assemblies permanently installed in each annulus surrounding a subsurface well; and a fiber optic cable in close proximity to the electro acoustic technology sensor assemblies and in communication with a surface distributed acoustic fiber optic interrogator.

Abstract: The present invention relates to a system for vortex energy harvesting for downhole applications and a method thereof, the system comprising: one or more electro acoustic technology assemblies mounted downhole in close proximity to a fiber optic cable that is part of a fiber optic distributed acoustic sensing system connected back to a surface distributed acoustic sensing interrogator; and one or more vortex energy harvesters attached to each of the electro acoustic technology assemblies and exposed to a fluid flow in the downhole application.

Abstract: Methods are proposed for compensation of distortion in fiber Fabry-Perot interferometric (FFPI) sensors induced by dynamic wavelength dependent attenuation in subsurface wells. The methods involve measurement techniques that correct the reflective spectrum from one or more FFPI sensors utilizing a background low frequency spectrum for normalization.

Abstract: A system and method for enabling inductive charging through downhole casings for electro acoustic technology devices.

Abstract: A system and method for obtaining real time down hole flow measurements and proppant concentrations between perforations and/or perforation clusters during hydraulic fracturing in multistage stimulated wells.

Abstract: A method may include coiling a fiber line around an exterior side of a casing section. A mold may be temporarily secured to at least a portion of the exterior side of the casing section. An epoxy material may be injected into the mold to form a cover. The cover may extend over the fiber line and the exterior of the casing section. The cover may have a substantially equal thickness for centralizing the casing section when the casing section is positioned downhole. The mold may be removed from the exterior side of the casing section after the epoxy material has cured.

Abstract: A device is described for measuring downhole flow rate, density and fluid fractions of oil-gas-water mixtures in a production string.

Abstract: Aspects of the disclosure include an optical fiber sensing system and apparatus that provide for free rotation of fiber optic cables containing multiple cores. For example, the disclosure presents a fiber optic rotary joint, comprising a stator housing a non-rotating portion of a dual-core fiber optic cable and a rotor housing a rotating portion of the dual-core fiber optic cable. In such an example, the rotor is mounted to the stator to allow rotation of at least a portion of the rotor about at least a portion of the stator. Further provided is an optical fiber sensing system, comprising one or more multiplexor/demultiplexors configured to multiplex and demultiplex one or more signals, a dual-core fiber optic cable communicatively coupled to the multiplexor/demultiplexor and configured to carry one or more signals on an inner core and an outer core disposed about the inner core, and a dual-core fiber optic rotary joint.

Abstract: A subsurface electric field monitoring system includes one or more electric field sensors deployed external to a casing in a borehole formed in a downhole formation. The system also includes a multi-layer cement arrangement external to the casing, where the multi-layer cement arrangement focuses emitted current to a target region of the downhole formation. The system also includes a data processing system that receives measurements collected by the one or more electric field sensors in response to the focused emitted current, wherein the data processing system models the subsurface electric field based on the received measurements.

Abstract: A method for utilizing multi-parameter fiber optic sensing cables in conjunction with a reservoir compaction and subsidence model of a multi-well hydrocarbon field to continuously update the reservoir model to optimize production efficiency while ensuring well integrity on a field level.

Abstract: A method and system for operating fiber optic monitoring systems utilizing solar panels, batteries, and an interrogator system with associated electronics for operating in cold climates.

Abstract: An apparatus for collecting energy in connection with a sheave system in a hoisting apparatus provided with a sheave system. The apparatus includes at least one generator including a rotor and at least one stator. The rotor is connected rigidly to a sheave of the sheave system, and the at least one stator is connected rigidly to the sheave system such that when the load of the hoisting apparatus is rising or lowering, said at least one sheave rotates, whereby the rotor rotates simultaneously but the stator does not rotate, whereby electric energy is induced in the stator. The apparatus further includes electric energy storage, a device for modifying induced electric energy and storing it in energy storage; and a device for supplying energy from the energy storage to at least one consumption device. The consumption device may be, for example, a working lamp, sensor, measuring device, communications device, signal device, charging plug or a combination of these mounted in connection with the sheave system.

Abstract: A method for using the depth derivative of distributed temperature sensing data to identify fluid levels, gas production intervals, water production intervals, and other fluid flow activities inside or near the well-bore during the production process comprises providing a fiber optic based distributed temperature sensing measurement system through a production region; gathering the temperatures through the production region as a function of the depth in the subsurface well and as a function of the elapsed time; calculating from the gathered data the depth derivative of the temperature changes as a function of depth in the subsurface well and of the elapsed time; and displaying the depth derivative data for analysis of the fluid levels by operators to identify fluid levels, gas production intervals, water production intervals, and other fluid flow activities inside or near the wellbore during the production process.

Abstract: A method for using the depth derivative of distributed temperature sensing data to identify fluid levels as a tool of downhole pressure control comprises providing a fiber optic based distributed temperature sensing measurement system through a production region; gathering the temperatures through the production region as a function of the depth in the subsurface well and as a function of the elapsed time; calculating from the gathered data the depth derivative of the temperature changes as a function of depth in the subsurface well and of the elapsed time; and displaying the depth derivative data for analysis of the fluid levels to identify fluid levels.

Abstract: A method for using the time derivative and depth derivative of distributed temperature sensing data to evaluate data quality and resolution of DTS data obtained from subsurface wells comprises providing a fiber optic based distributed temperature sensing measurement system through a production region; gathering the temperatures through the production region as a function of the depth in the subsurface well and as a function of the elapsed time; calculating from the gathered data the time derivative of the temperature changes as a function of depth in the subsurface well and of the elapsed time; calculating from the gathered data the depth derivative of the temperature changes as a function of depth in the subsurface well and of the elapsed time; displaying the time derivative data for analysis of the data quality of the DTS data by operators; and displaying the depth derivative data for analysis of the resolution of the DTS data by operators.

Abstract: A method for using the depth derivative of distributed temperature sensing data to identify initiation points near wellbores created by hydraulic fracturing comprises providing a fiber optic based distributed temperature sensing measurement system through a production region; gathering the temperatures through the production region as a function of the depth in the sub-surface well and as a function of the elapsed time; calculating from the gathered data the depth derivative of the temperature changes as a function of depth in the subsurface well and of the elapsed time; and displaying the depth derivative data for analysis of initiation points near wellbores created by hydraulic fracturing.

Abstract: A method is presented for using the time derivative of distributed temperature sensing data to monitor and analyze cement critical temperature Time derivative of DTS in depth and time scale changes during the cementing process in subsurface wells.

Abstract: A system and method for evaluating individual Fiber Bragg Grating (FBG) sensors in a multiplexed acoustic sensor system, the system comprising: a broadband pulsed source; a circulator that passes a laser pulse to a multiplexed series of N FBG sensors and one reference Fresnel reflector, wherein said circulator also receives a return N+1 reflection pulse train from the N FBG sensors and one reference Fresnel reflector; and an optical switch that receives the return N+1 reflection pulse train from the N FBG sensors and one reference Fresnel reflector.

Abstract: Systems and methods for distributed acoustic sensing based on coherent Rayleigh scattering are disclosed herein. A system comprises a pulse generator, an interferometer, a photo detector assembly, and an information handling system. The interferometer comprises a first and second optical switch each comprising a plurality of ports. The information handling system activates one port on each of the first and second optical switches so as to vary the optical path length of the interferometer. A method comprises splitting backscattered light from an optical pulse into a first portion and a second portion, activating one port of a first optical switch and one port of a second optical switch, sending the first portion into a first arm of an interferometer, sending the second portion into a second arm of the interferometer, combining the first and second portions to form an interferometric signal, and receiving the interferometric signal at a photodetector assembly.