Abstract: The invention is directed to a method for diagnosing and treating fibrosis, especially pulmonary fibrosis, associated with mutation of the S100A13 and S100A3 genes. Methods for detecting and distinguishing the mutant forms of these genes are disclosed and ways to compensate for loss of function or aberrant function of the mutated S100A13 or S100A3 proteins are disclosed.

Abstract: A method of controlling an aeronautical gas turbine engine may be performed with an electronic controller. The method may include determining an airfoil pitch control command for at least one of a plurality of airfoils of the aeronautical gas turbine engine based at least in part on an excitation load acting upon the aeronautical gas turbine engine, and outputting the airfoil pitch control command to one or more actuators actuatable to change a pitch angle of the at least one of the plurality of airfoils. The airfoil pitch control command may be configured to augment and/or compensate for the excitation load acting upon the aeronautical gas turbine engine. The method may be embodied by a non-transitory computer-readable medium that includes computer-executable instructions, which when executed by a processor associated with the electronic controller, cause the electronic controller to perform the method.

Abstract: An open rotor aeronautical engine may include a core engine, a plurality of unducted airfoils, and a pitch change assembly. The pitch change assembly may include an ensemble actuator assembly and a unitary actuator assembly. The ensemble actuator assembly may have one or more ensemble actuators and a unison ring that is movable by actuation of the one or more ensemble actuators to collectively change a pitch angle of the plurality of unducted airfoils. The unitary actuator assembly comprising a plurality of unitary actuators respectively coupled to a corresponding one of the plurality of unducted airfoils, the plurality of unitary actuators respectively movable to change the pitch angle of the corresponding one of the plurality of unducted airfoils.

Abstract: An open rotor engine includes a core engine, a plurality of guide vanes positioned within or extending from the core engine; and a pitch change assembly operably coupled to the plurality of guide vanes. The pitch change assembly includes one or more actuators configured to change a pitch angle of respective ones of the plurality of guide vanes, and a plurality of linkage arms that are respectively movable by actuation of at least one of the one or more actuators. The plurality of linkage arms are directly or indirectly coupled to a corresponding one of the plurality of guide vanes. The plurality of linkage arms may have a length that differs from one another, and such length may orient a displacement or a range of motion of the respective linkage arm to an envelope of rotation about a guide vane axis that differs as between the plurality of guide vanes.

Abstract: Pursuant to various embodiments, systems, apparatuses and methods are provided herein useful to monitoring one or more components coupled to shaft-driven gearbox of an engine or motor. In some approaches, the systems include a sensor, such as a vibration sensor, mechanically linked or mounted to the shaft-driven gearbox. The vibration sensor may be used to monitor a vibration response of one or more components coupled to the shaft-driven gearbox. It is contemplated, by monitoring a component coupled to the shaft-driven gearbox using the systems and methods described herein, is possible to proactively detect one or more faults in the component and/or to identify one or more maintenance actions.

Abstract: Pursuant to various embodiments, systems, apparatuses and methods are provided herein useful to monitoring one or more components coupled to shaft-driven gearbox of an engine or motor. In some approaches, the systems include a sensor, such as a vibration sensor, mechanically linked or mounted to the shaft-driven gearbox. The vibration sensor may be used to monitor a vibration response of one or more components coupled to the shaft-driven gearbox. It is contemplated, by monitoring a component coupled to the shaft-driven gearbox using the systems and methods described herein, is possible to proactively detect one or more faults in the component and/or to identify one or more maintenance actions.

Abstract: Systems, processes, and computer-readable media for determining lithology porosity of a formation rock from surface drilling parameters using a lithology porosity machine learning model without the use of wireline logging. Lithology porosity at different depths in existing may be determined from the wireline logs. The lithology porosity may be shaly sand, tight sand, porous gas, or porous wet. The lithology porosity machine-learning model may be trained and calibrated using the data from a structured data set having surface drilling parameters from the existing wells and lithology porosity classifications from the wells. The lithology porosity machine learning model may then be used to determine a lithology porosity classification for a new well without the use of wireline logging.

Abstract: According to one or more embodiments of the present disclosure, water-based drilling fluids may include an aqueous base fluid and one or more additives. In embodiments, water-based drilling fluids may include a lubricant blend including at least oleic acid and palmitoleic acid. The sum of the volume percent of the oleic acid and palmitoleic acid may be from 0.1 vol. % to 10 vol. % of the total volume of the water-based drilling fluid. In embodiments, water-based drilling fluids may include a lesser melting point fraction of jojoba oil in an amount of from 0.1 vol. % to 10 vol. % relative to the total volume of the water-based drilling fluid. At least 90% of the lesser melting point fraction of jojoba oil may have a melting point less than or equal to 15° C. Methods for drilling subterranean wells with the water-based drilling fluids are also disclosed.

Abstract: According to one or more embodiments of the present disclosure, water-based drilling fluids may include an aqueous base fluid and one or more additives. In embodiments, water-based drilling fluids may include a lubricant blend including at least oleic acid and palmitoleic acid. The sum of the volume percent of the oleic acid and palmitoleic acid may be from 0.1 vol. % to 10 vol. % of the total volume of the water-based drilling fluid. In embodiments, water-based drilling fluids may include a lesser melting point fraction of jojoba oil in an amount of from 0.1 vol. % to 10 vol. % relative to the total volume of the water-based drilling fluid. At least 90% of the lesser melting point fraction of jojoba oil may have a melting point less than or equal to 15° C. Methods for drilling subterranean wells with the water-based drilling fluids are also disclosed.

Abstract: A flexible sensor is provided. A further aspect employs a sensor apparatus including pressure or force sensing layers or sheets in addition to location sensing layers or sheets. In another aspect, an electrical sensing circuit and flexible films are used to sense pressure and/or location of a contacting object. In another aspect, a compressible polymer includes conductive particles therein such that the compressible polymer changes electrical resistance when compressed to indicate a force or location. Still another aspect has stacked sandwiches of pressure and/or location sensing films, layers or sheets.

Abstract: Provided are techniques that include determining a first set of operating parameters for a hydrocarbon well for a first period; determining, based on the first set of operating parameters, a skin factor (S1); determining, based on the skin factor (S1), a well model for the well; determining, a second set of operating parameters for the well for a second period; determining, based on the second set of operating parameters, well performance characteristics for the second period that include: a well pressure and a production flowrate for the second period of time; determining that the well performance characteristics for the second period are not consistent with the well model and, in response: determining, based on the second set of operating parameters, an updated skin factor; and determining, based on the updated skin factor (S2), an updated well model for the well.

Abstract: A water-based wellbore fluid may include an aqueous base fluid and a modified graphene shale inhibitor that comprises one or more substituents that are covalently bonded to graphene via a linking group. One of the one or more substituents may be a hydrocarbon group that has a number of carbon atoms in the range from 8 to 14.

Abstract: Provided are techniques that include determining a first set of operating parameters for a hydrocarbon well for a first period; determining, based on the first set of operating parameters, a skin factor (S1); determining, based on the skin factor (S1), a well model for the well; determining, a second set of operating parameters for the well for a second period; determining, based on the second set of operating parameters, well performance characteristics for the second period that include: a well pressure and a production flowrate for the second period of time; determining that the well performance characteristics for the second period are not consistent with the well model and, in response: determining, based on the second set of operating parameters, an updated skin factor; and determining, based on the updated skin factor (S2), an updated well model for the well.

Abstract: Systems, processes, and computer-readable media for determining lithology porosity of a formation rock from surface drilling parameters without the use of wireline logging. Lithology porosity at different depths in existing may be determined from the wireline logs. The lithology porosity may be shaly sand, tight sand, porous gas, or porous wet. A lithology porosity machine-learning model may be trained and calibrating using the data from a structured data set having surface drilling parameters from the existing wells and lithology porosity classifications from the wells. The lithology porosity machine learning model may then be used to determine a lithology porosity classification for a new well without the use of wireline logging.

Abstract: A water-based wellbore fluid may include an aqueous base fluid and a modified graphene shale inhibitor that comprises one or more substituents that are covalently bonded to graphene via a linking group. One of the one or more substituents may be a hydrocarbon group that has a number of carbon atoms in the range from 8 to 14.

Abstract: According to one or more embodiments of the present disclosure, water-based drilling fluids may include an aqueous base fluid and one or more additives. In embodiments, water-based drilling fluids may include a lubricant blend including at least oleic acid and palmitoleic acid. The sum of the volume percent of the oleic acid and palmitoleic acid may be from 0.1 vol. % to 10 vol. % of the total volume of the water-based drilling fluid. In embodiments, water-based drilling fluids may include a lesser melting point fraction of jojoba oil in an amount of from 0.1 vol. % to 10 vol. % relative to the total volume of the water-based drilling fluid. At least 90% of the lesser melting point fraction of jojoba oil may have a melting point less than or equal to 15° C. Methods for drilling subterranean wells with the water-based drilling fluids are also disclosed.

Abstract: According to one or more embodiments of the present disclosure, water-based drilling fluids may include an aqueous base fluid and one or more additives. In embodiments, water-based drilling fluids may include a lubricant blend including at least oleic acid and palmitoleic acid. The sum of the volume percent of the oleic acid and palmitoleic acid may be from 0.1 vol. % to 10 vol. % of the total volume of the water-based drilling fluid. In embodiments, water-based drilling fluids may include a lesser melting point fraction of jojoba oil in an amount of from 0.1 vol. % to 10 vol. % relative to the total volume of the water-based drilling fluid. At least 90% of the lesser melting point fraction of jojoba oil may have a melting point less than or equal to 15° C. Methods for drilling subterranean wells with the water-based drilling fluids are also disclosed.

Abstract: The invention is directed to a method for diagnosing and treating a pulmonary lung disease by detecting a mutant S100A3 protein associated with pulmonary lung disease and by treating a subject with a functional S100A3 protein.

Abstract: Systems and methods for indirect monitoring of combustor dynamics in a gas turbine engine include collecting vibration data acquired by a vibration sensor, which is mounted proximate to an operational component positioned relative to a combustor of a gas turbine engine. The vibration data can be transformed into a frequency domain representation at periodic intervals. The relative signal strength of the vibration data can be determined over the one or more identified frequency bands. The relative signal strength can be adjusted with hysteresis at each of the one or more identified frequency bands. Occurrence of a combustor dynamics event at one or more specific resonant frequencies can be determined based at least in part on evaluation of the adjusted relative signal strength relative to one or more event detection threshold levels.

Abstract: The invention is directed to a method for diagnosing and treating fibrosis, especially pulmonary fibrosis, associated with mutation of the S100A13 and S100A3 genes. Methods for detecting and distinguishing the mutant forms of these genes are disclosed and ways to compensate for loss of function or aberrant function of the mutated S100A13 or S100A3 proteins are disclosed.