Abstract: Wellbore equipment used in oil and gas operations can be negatively affected by corrosive fluids. Coatings can be applied to the equipment to help protect the equipment. A field test can be used at a wellsite to ensure the coating is effective. Due to the HSE risks of the corrosive fluids, a proxy fluid can be used instead. The proxy fluid can have similar chemical or physical properties and simulate the corrosive fluid that is anticipated to be present in the wellbore. The wellbore equipment that is coated can be sealed to create a containment area where an initial concentration of the proxy fluid is introduced into the containment area for a period of time. A final concentration of the proxy fluid can be measured after the period of time has elapsed. By calculating the percent change of the proxy fluid, the effectiveness of the coating can be determined.

Abstract: A device for monitoring deposition of a coating comprising a dielectric material during deposition of the coating. The device includes a parallel-plate capacitor having a first plate, and a second plate; a first lead electrically connected to the first plate; a second lead electrically connected to the second plate; and a power supply. The first plate and the second plate are parallel and separated by a spacing with a known spacing thickness. The first lead and the second lead can be electrically connected to positive and negative terminals of the power supply. The device is configured to register a capacitance when the first lead and the second lead are respectively connected to the positive and the negative terminals of the power supply and a dielectric material fills the spacing, and is configured to register no capacitance until the dielectric material fills the spacing.

Abstract: In general, in one aspect, embodiments relate to a method that includes assembling a downhole tool from a plurality of subassemblies with a robotic tool assembly disposed on a subsea tree at a sea-floor in a subsea environment. The method may also include introducing the downhole tool into a wellbore, traversing the wellbore with the downhole tool to reach one or more target depths, performing at least a wellbore operation with the downhole tool at the one or more target depths, and retrieving the downhole tool from the wellbore after performing the wellbore operation.

Abstract: The disclosure presents processes to determine a first formation fluid-second formation fluid boundary from one side of the boundary utilizing a formation tester tool. For example, the formation tester can be utilized in a borehole to determine an engagement point with a subterranean formation and determine one or more, or a combination of, injectable fluids to inject into the subterranean formation. Sensors coupled to the formation tester can measure the rebound pressure of the injected fluids. In some aspects, the fluid density of the collected fluid can be measured. The measured pressure changes and other collected data, can be utilized to determine a first formation fluid-second formation fluid boundary parameter. Other characteristic parameters can also be determined such as wettability parameters, porosity parameters, and capillary effects parameters. The formation tester can collect a core sample and an analyzation of the core sample can be utilized to determine the characteristic parameters.

Abstract: Downhole tool is provided that includes a body, an intake port for receiving fluid from external the body, a pump, a filtration device, and an exit port. The pump is in fluid communication with the intake port for withdrawing fluid through the intake port. The filtration device has a particulate removing filter, and a flow line extending from the intake port to the filtration device. The filtration device is contained within the body and is in fluid communication with the intake port. The exit port is in fluid communication with the filtration device for ejecting the fluid to external the body.

Abstract: A downhole sample extractor includes a sample container chamber that holds a sample container containing a downhole sample. The downhole sample extractor also includes a sample extraction chamber having an internal chamber that is partially filled with a carrier solution, wherein the downhole sample is mixed with the carrier solution in the internal chamber of the extraction container. The downhole sample extractor further includes a first piston that, when actuated, inserts the sample container into the internal chamber of the sample extraction chamber.

Abstract: A system for detecting an anomaly in a video of a factory automation scene is disclosed. The system may accept the video; accept a set of training feature vectors derived from spatio-temporal regions of a training video, where a spatio-temporal region is associated with one or multiple training feature vectors; partition the video into multiple sequences of video volumes; produce a sequence of binary difference images for each of the video volumes; count occurrences of each of predetermined patterns of pixels in each binary difference image for each of the video volumes to produce an input feature vector including an input motion feature vector defining a temporal variation of counts of the predetermined patterns for each of the video volumes; produce a set of distances based on the produced input feature vectors and the set of training feature vectors; and detect the anomaly based on the produced set of distances.

Abstract: Surface tracking systems and methods for tracking a first wellbore relative to a non-geological target in a subterranean formation by determining characteristics of gravity anomalies related to the first wellbore and the non-geological target. The system includes a gravity sensor located at the Earth's surface and an information handling system operable to analyze the first and second gravity anomalies to determine a position and the trajectory of the first wellbore relative to the non-geological target. The systems and methods may also include the ability steer a trajectory of the first wellbore relative to the non-geological target.

Abstract: Improved systematic inversion methodology applied to formation testing data interpretation with spherical, radial and/or cylindrical flow models is disclosed. A method of determining a flow line parameter includes determining a diverse set of flow models and selecting at least one flow model from the diverse set of flow models representative, at least in part, of a formation tester tool, at least one formation, at least one fluid, and at least one flow of the at least one fluid. The method further includes lowering the formation testing tool into the at least one formation to intersect with the formation at least one formation and sealing a probe of the formation tester placed in fluid communication with the at least one formation. The method further includes initiating flow from the at least one formation and utilizing the at least one selected flow model to predict the flow line parameter.

Abstract: A terminal assembly for a heater system includes a plurality of resistive heating elements arranged in multiple power phases includes a plurality of power busbars, a neutral busbar, a phase barrier disposed between each of the plurality of power busbars, and a plurality of interchangeable couplers. Each power busbar corresponds to a power phase of the multiple power phases and is configured to connect a power lead from one of the multiple power phases and a first end of a plurality of resistive heating elements. The resistive heating elements are in electrical communication with the power lead. The neutral busbar is offset longitudinally from the power busbars and configured to receive a second end of the resistive heating elements. The interchangeable couplers are configured to connect at least a subset of the resistive heating elements to at least one power busbar or at least one neutral busbar.

Abstract: The long strand fiberglass-impregnated waterproofing compound may provide a pre-mixed waterproofing compound that eliminates the need for a worker to combine the various elements prior to application. The compound may benefit from the use of long strand fiberglass so as to provide additional strength and resiliency to the compound and may be provided in a container suitable for preventing the compound from drying out before it is applied. The advantages of such a compound include creating a seamless waterproof seal on a surface, as well as adding structural rigidity and strength to the surface, while reducing the amount of time needed to apply the compound. The compound comprises, generally, a waterproofing material combined with a structural lattice in a portable container.

Abstract: Systems and techniques are described for modeling borehole fluid flow using a dynamic pressure boundary. An example method can include calculating a radius of fluids and a radius of pressure associated with a borehole, the radius of pressure relating to a fluid flow; generating a first model, wherein a size of the first model is larger than the calculated radius of pressure; determining a dynamic pressure based on the first model; generating a second model, wherein a size of the second model is larger than the calculated radius of fluids; and modelling the borehole fluid flow based on the second model, wherein the dynamic pressure is used as a boundary condition of the second model.

Abstract: The subject disclosure relates to techniques for correcting logging depth of a well bore. A process of the disclosed technology can include receiving a first sensor measurement from a first sensor disposed in a wellbore, receiving a second sensor measurement from a second sensor disposed in the wellbore, wherein the first sensor and the second sensor are disposed on a wireline with a predetermined distance between the first sensor and the second sensor, generating a correlation function based on the first sensor measurement and the second measurement, and determining, based on the correlation function, whether the measurements indicate a perceived distance between the first sensor and the second sensor deviating from the predetermined distance.

Abstract: A method and system for performing a pressure test. The method may include inserting a formation testing tool into a wellbore to a first location within the wellbore based at least in part on a figure of merit. The formation testing tool may include at least one probe, a pump disposed within the formation testing tool and connect to the at least one probe by at least one probe channel and at least one fluid passageway, and at least one stabilizer disposed on the formation testing tool. The method may further include activating the at least one stabilizer, wherein the at least one stabilizer is activated into a surface of the wellbore and performing the pressure test and determining at least one formation property from the pressure test.

Abstract: A method includes receiving first material property data for a first material in one or more second materials, detecting material sensor data from at least one sensor, and applying an inverse model and a forward model to the first material property data to provide, at least in part, synthetic sensor measurement data for the one or more second materials.

Abstract: An optical element may be fabricated by applying foreign or attenuating material, for example, a copper material or a material that includes copper, to a silicon dioxide thin film to form a layer that exhibits extraordinary optical absorption in the infrared wavelength region of at or about 2500-4700 nanometers. The foreign material may comprise or include a transition metal. The optical element exhibits increased accuracy and sensitivity in the infrared wavelength region of at or about 2500-4700 nanometers. The at or about 2500-4700 nanometers absorption property of the optical element can be selectively tuned to any region within this at or about 2500-4700 nanometers wavelength region. The optical element may comprise multiple layers of varying thicknesses to further tune the optical element to one or more spectral bands. Such an optical element may be utilized in a formation fluid analysis tool or an eye protection device.

Abstract: Systems, methods, and devices are disclosed for holding devices for securing a surgical robotic device and a patient anatomy positioner to a support (e.g., in an operating room). A holding device comprises a carriage, an anchor component fixed to the carriage for attaching to the support, a patient stabilization connector extending from the anchor component for attaching to the patient positioner, and an elongate holder slidably mounted on the carriage for attaching to the robotic device, wherein, when the anchor component is attached to the support, the carriage and the patient stabilization connector are immobilized. The holding devices may also include a hydraulic cylinder interposed between the elongate holder and carriage and/or a horizontal linkage interposed between the elongate holder and the robotic device.

Abstract: A fluid sampling tool may include a fluid characterization device consisting of a densitometer, a viscometer, or a vibrating element, or a combination thereof and a polymer disposed in or around the fluid characterization device, wherein the polymer volume, density, or viscosity changes with an ionic stimulus. The fluid characterization device may be located within a bypass flow line of the sampling tool. A method of measuring pH and a method of monitoring at least two analytes at the same time using the fluid characterization devices are also discussed.