Abstract: An approach is provided in which an information handling system matches packet properties of an egress data packet to a classification rule corresponding to differentiated services (DiffServ) parameters. The information handling system encapsulates the egress data packet with a network virtualization overlay header that includes a DiffServ classification identifier corresponding to the DiffServ classification rule. In turn, the information handling system sends the encapsulated egress data packet to a downstream network component.

Abstract: Described herein are devices, systems, and methods for analyzing multi-phase fluid flow profile and flow field distribution by utilizing heating wires and thermal sensing arrays to detect transient thermal response and generate a dynamic temperature profile. The thermal sensing arrays include a plurality of thermal sensors disposed linearly along the length of the array. The multi-point dynamic temperature profile is used to determine fluid rate, velocity, flow patterns, and flow field distribution.

Abstract: A multiple parameter sensing leak detection system may include one or more multi-parameter sensing modules capable of simultaneously measuring downhole temperature, pressure, and acoustic signals. The temperature and pressure detectors may include quartz based sensing elements, and the acoustic detector may include piezoelectric based sensing elements. In one or more embodiments, a plurality of sensing modules may be carried on a caliper for allowing radial identification of leak location. In one or more embodiments, multiple calipers, each carrying a circumferential arrangement of sensing modules may be used to identify annular or inter-annular leakage beyond production tubing using triangulation techniques. A leak analysis method identifies if relative pressure and temperature variation amplitudes fall outside leak thresholds and if power spectral density from noise has anomalous frequency signatures.

Abstract: Downhole slickline cable including a polymer matrix having reinforcing fibers embedded therein. A plurality of integrity-sensing optical fibers are embedded within the polymer composite and extend along an axial length of the downhole slickline cable that enables slickline cable structural and mechanical integrity self-diagnosis. The cable may include energy transmission lines that include one or more integrity-sensing optical fibers.

Abstract: A downhole well fluid sensing device is disclosed for determining thermal conductivity of a formation fluid produced by a sampled subterranean well, the sensor package having an annulus shaped, elongate body defining a cylindrical fluid sampling space, the elongate body and the sampling space having a common longitudinal center axis. The elongate body has a fluid entrance port that provides well fluid ingress into the fluid sampling space and a fluid exit port that provides well fluid egress out of the fluid sampling space. A heat source is coupled to the elongate body and located along a portion of the fluid path, and the heat source inputs heat into sampled well fluid. Finally, temperature sensing devices located between the fluid entrance port and fluid exit port measure heat conducted to the sampled well fluid, wherein each of the temperature sensing devices is radially spaced from the heat source.

Abstract: A polymer composite wireline cable comprising: a polymeric matrix material; at least one reinforced fiber embedded in the polymeric matrix material; and at least one optical fiber disposed in the polymeric matrix material, the at least one optical fiber having at least one pair of Bragg grating sensors, wherein one of the pair of Bragg grating sensors is configured to experience loading strain and the other of the pair of Bragg grating sensors is configured not to experience loading strain.

Abstract: Downhole fluid sensing device is disclosed for determining heat capacity of a formation fluid produced by a sampled subterranean well, the sensor package having an annulus shaped, elongate body defining a cylindrical fluid sampling space, the sensor package and the sampling space having a common longitudinal center axis. The elongate sensor package body has a fluid entrance port that provides well fluid ingress into the fluid sampling space and a fluid exit port that provides well fluid egress out of the fluid sampling space. A heat source is coupled to the elongate sensor package body and located along a portion of the fluid path, and the heat source inputs heat into sampled well fluid. Finally, temperature sensing devices (located between the fluid entrance port and fluid exit port measure heat conducted to the sampled well fluid, wherein each of the temperature sensing devices is radially spaced from the heat source.

Abstract: A distributed acoustic sensing cable package having a polymer composite extruded over an optical waveguide to encase the waveguide and to form a crystalline matrix layer acoustically coupled to the waveguide. The crystalline matrix includes reinforcement fibers to further enhance transmission of a cable strain to the optical waveguide. During manufacture of the cable, the polymer composite may be extruded over the optical waveguide and subsequently subjected to heat treatment to increase the crystallinity of the polymer composite and increase the elastic modulus. Both axial and radial strain fields are effectively interact with cased fiber waveguide for producing measurable phase shift signal for distributed acoustic noise detection.

Abstract: A distributed acoustic sensing cable package having a polymer composite extruded over an optical waveguide to encase the waveguide and to form a crystalline matrix layer acoustically coupled to the waveguide. The crystalline matrix includes reinforcement fibers to further enhance transmission of a cable strain to the optical waveguide. During manufacture of the cable, the polymer composite may be extruded over the optical waveguide and subsequently subjected to heat treatment to increase the crystallinity of the polymer composite and increase the elastic modulus. Both axial and radial strain fields are effectively interact with cased fiber waveguide for producing measurable phase shift signal for distributed acoustic noise detection.

Abstract: A distributed acoustic sensing cable package having a polymer composite extruded over an optical waveguide to encase the waveguide and to form a crystalline matrix layer acoustically coupled to the waveguide. The crystalline matrix includes reinforcement fibers to further enhance transmission of a cable strain to the optical waveguide. During manufacture of the cable, the polymer composite may be extruded over the optical waveguide and subsequently subjected to heat treatment to increase the crystallinity of the polymer composite and increase the elastic modulus. Both axial and radial strain fields are effectively interact with cased fiber waveguide for producing measurable phase shift signal for distributed acoustic noise detection.

Abstract: A downhole formation fluid viscometer sensor and method therefor include a viscometer sensing package, a flexible diaphragm, a magnet and electric coil, and a signal pickup assembly. The viscometer sensor may also include a first cavity and a second cavity for mechanical and electric energy transfer. The magnet and electric coil may be driven by external alternating current to generate an electromagnetic force. Silicon oil may be used to fill the first cavity and/or a pressure balance hole may connect the first cavity to an external area. The diaphragm may be a titanium alloy and a ferromagnetic magnet may be attached to the diaphragm. The diaphragm preferably has a thickness from about 0.030 to about 0.040 inches and the magnet and electric coil can propel the diaphragm to vibrate at a frequency from 0 to 100 kHz. Formation fluid viscosity is determined using resonant frequency linewidth, with contributions from the sensor package intrinsic properties removed.

Abstract: A distributed acoustic sensing cable including an optical fiber waveguide configured to provide light signal transmission and an acoustic device coupled to the optical fiber waveguide and configured to provide acoustic signal transmission. The acoustic device includes a polymer composite having reinforced fibers embedded therein. The polymer composite having acoustic waveguides for attenuating undesirable acoustic waves propagating along the distributed acoustic sensing cable and optical fibers embedded within the polymer composite that extend along an axial length of the acoustic device that facilitate the light signal transmission.

Abstract: Disclosed embodiments include a distributed nondestructive inspection method and system for slickline cable structural defect and mechanical strength degradation inspection. One method may include transmitting a light pulse along an optical fiber embedded in a slickline cable. A reflected light signal is received from the optical fiber in response to the local strain induced refractive index variation. Defects and mechanical strength degradation may be determined by time-dependent time-domain and frequency-domain data analyses of the dynamic strain signals and power spectral density variation as a function of time and cable location.

Abstract: A measurement assembly for determining an electrical resistance of a fluid in a wellbore is provided. The measurement assembly can include a non-conductive frame, comprising an excitation electrode and a monitoring electrode coupled to the non-conductive frame. The measurement assembly can also include a central electrode in a flow path for the fluid, wherein the flow path is defined by the non-conductive frame. The central electrode can be positioned for conductively coupling the excitation electrode and the monitoring electrode through a conductive path defined by the fluid. Further, the measurement assembly can include a power source for transmitting power to the excitation electrode for determining the electrical resistance of the fluid. The electrical resistance of the fluid can be used to determine whether the fluid includes oil, water, or gas.

Abstract: A downhole formation fluid identification sensing module for measuring averaged gas molecular weight of wellbore formation fluid acquires simultaneous temperature, pressure, and density measurements. The sensing module includes two venturi-type gas sensors that both contain vibrating tubes. During operation, formation fluid flows through the vibrating tubes whereby resonant frequency measurements are acquired simultaneously with temperature and pressure measurements. Each measurement is then utilized to determine the gas molecular weight of the dry, wet or saturated formation fluid.

Abstract: A system is provided that can include a first tube for communicating a fluid through a wellbore. The system can also include a gap between the first tube and a first electromagnetic acoustic transducer (EMAT). The first EMAT can be positioned to magnetically couple with the first tube. The first EMAT can include a magnet and a wire coil positioned around the magnet. The first EMAT can coupled to a power source and positioned to, responsive to receiving a power from the power source, apply a first magnetic force to the first tube for determining a density or viscosity of the fluid.

Abstract: Systems and methods for determining whether mechanical fatigue exists in a downhole cable using thermally-induced acoustic waves are disclosed herein. A cable fatigue monitoring system includes a thermal source, one or more light sources, one or more photodetector arrays, and a computing system comprising a processor, a memory, and a cable distortion module. The cable distortion module is operable to generate acoustic waves in a cable using the thermal source, direct light from the one or more light sources toward the cable, detect light from the one or more light sources transmitted past the cable at the one or more photodetector arrays, and determine, based on the detected light transmitted past the cable, whether a change in velocity of the acoustic waves has occurred in the cable.

Abstract: In accordance with embodiments of the present disclosure, systems and methods for determining a dynamic effective elastic modulus of a composite slickline or wireline cable are provided. A system for estimating the effective elastic modulus (or change thereof) may include a sensing head assembly, a vibration generator, a pair of pulleys, and an optical-based signal processing assembly. The system may detect a resonant frequency of a section of the composite cable held between the two pulleys and estimate the effective elastic modulus based on the detected resonant frequency variation. Adjustments for weight and length of the cable extending into the wellbore may be made as well to determine the dynamic elastic modulus of the cable. The opto-mechanical integrated system described below may enable real-time elastic modulus determination.

Abstract: In some embodiments, a distributed nondestructive inspection method for slickline cable structural defect detection transmits a light pulse along an optical waveguide in the slickline cable. A reflected light signal is 5 received from the optical waveguide in response to the light pulse. Defects can then be determined in the slickline cable based on variations in scattering intensity, phase shift, specific spectral signature, power spectral density, strain amplitude, and/or transmission loss of the reflected light signal as compared to the light pulse.

Abstract: A polymer composite wireline cable comprising: a polymeric matrix material; at least one reinforced fiber embedded in the polymeric matrix material; and at least one optical fiber disposed in the polymeric matrix material, the at least one optical fiber having at least one pair of Bragg grating sensors, wherein one of the pair of Bragg grating sensors is configured to experience loading strain and the other of the pair of Bragg grating sensors is configured not to experience loading strain.