US Pat. No. 10,920,610

CASTING PLUG WITH FLOW CONTROL FEATURES

Raytheon Technologies Cor...

1. A casting plug for a component of gas turbine engine, comprising:a plug body that seals a core support aperture of a component;
a flow control feature that extends into a flow path within an airfoil of the component; and
a support that extends between the plug body and the flow control feature, the support transverse to the flow control feature to operates as a flow splitter.

US Pat. No. 10,920,609

TURBINE ENGINE TURBINE ASSEMBLY

SAFRAN AIRCRAFT ENGINES, ...

1. A turbine assembly for a turbine engine, the turbine assembly comprising:a rotor disk having a plurality of blades made of ceramic matrix composite material;
a stationary nozzle made of ceramic matrix composite material arranged downstream from the rotor disk and comprising a plurality of nozzle vanes, each nozzle vane having an outer platform at an outer end, the outer platforms of the nozzle vanes together forming a nozzle ring around the nozzle vanes;
a turbine ring made as a single piece of ceramic matrix composite material having an inside face facing the outer ends of the blades of the rotor disk, the turbine ring being fastened to the nozzle ring in such a manner that the turbine ring and the nozzle ring together define an annular wall corresponding to the outer wall of a gas flow passage through the turbine; and
a casing comprising an outer casing and a support structure including a plurality of cylindrical rings, the casing made of material presenting a coefficient of thermal expansion that is strictly greater than the coefficient of thermal expansion of the ceramic matrix composite material forming the blades of the rotor disk, the stationary nozzle, and the turbine ring, the casing extending around the nozzle ring and the turbine ring, at least one of the nozzle ring and the turbine ring being connected to the outer casing and one of the cylindrical rings of the casing via at least one sliding connection having a degree of freedom to move radially such that the casing is movable relative to said at least one of the nozzle ring and the turbine ring solely in a radial direction that is perpendicular to a longitudinal axis of the turbine assembly without stressing said at least one of the nozzle ring and the turbine ring to which the casing is connected,
wherein the turbine ring connects at an upstream end of the turbine assembly to the outer casing and said one of the cylindrical rings via said at least one sliding connection.

US Pat. No. 10,920,608

DEAD LEG DEBRIS EXTRACTOR FOR CONTINUOUS ON-LINE OPERATION

SIEMENS ENERGY, INC., Or...

1. A system for removing debris from a flow path of a cooling flow, comprising:a turbine including at least one airfoil to which a cooling flow is communicated, the cooling flow flowing through a plurality of cooling holes in the airfoil to cool the airfoil, wherein the cooling flow is communicated to the plurality of cooling holes via piping that includes a dead leg debris extractor,
wherein the dead leg debris extractor includes a means to capture and retain debris from the cooling flow continuously during online operation of the turbine,
wherein the dead leg debris extractor comprises a dead leg and a cone within the dead leg so that the cone is enclosed by a piping of the dead leg, and
wherein the dead leg extractor includes a cutback at a junction between an inlet pipe, an outlet pipe, and the dead leg, and
wherein the cutback includes an angled portion in the piping at the junction between the inlet pipe and the outlet pipe so that debris is drawn down into the dead leg.

US Pat. No. 10,920,607

METALLIC COMPLIANT TIP FAN BLADE

General Electric Company,...

1. A blade for a propulsion apparatus, comprising:a body formed of a first material having opposed pressure and suction sides, and extending in span between a root and a tip, and extending in chord between a leading edge and a trailing edge;
a fracture structure defined within the body and positioned near the tip; and
wherein the fracture structure includes a plurality of chambers defining a region of intentional porosity in the fracture structure, each of the chambers configured to reduce stiffness of the tip to allow the tip to fold across the body of the blade during failure of the fracture structure;
wherein the fracture structure includes a first fracture wall disposed between at least one chamber and the pressure side, and a second fracture wall disposed between the at least one chamber and the suction side; and
wherein the fracture structure is configured to fail when a predetermined force is applied to the tip such that the tip separates from a remainder of the body.

US Pat. No. 10,920,606

METHOD AND SYSTEM FOR DIAGNOSING A CONDITION OF AN ENGINE USING LUBRICATING FLUID ANALYSIS

1. A method for diagnosing a condition of an engine, the method comprising:receiving a plurality of particles from lubricating fluid of the engine;
obtaining, using data acquisition equipment, input data associated with the plurality particles, the input data representative of a respective volume of and a respective chemical composition category for each of the plurality of particles;
using one or more data processors:
from the input data, generating data representative of a mass of material of a selected one of the chemical composition categories in the plurality of particles by using the respective volumes of the particles in the selected chemical composition category and a density of the selected chemical composition category;
comparing the mass of material of the selected chemical composition category in the plurality of particles with reference data; and
based on the comparison, generating output data representative of a diagnosis of the condition of the engine.

US Pat. No. 10,920,605

SYSTEM AND METHOD FOR MEASURING ECCENTRICITY OF TURBINE SHELL RELATIVE TO TURBINE ROTOR

General Electric Company,...

1. A system for determining eccentricity of a turbine shell relative to a turbine rotor of a gas turbine, the system comprising:a first laser module comprising a housing and contained within the housing a microprocessor having coupled thereto a wireless network chip, a laser sensor, an inclination sensor, and a power supply, wherein the laser sensor is configured to transmit a laser beam toward the turbine shell as the turbine rotor spins at a slow speed and to receive a reflected laser beam from the turbine shell, thereby defining a path length indicative of a distance between the laser module and the turbine shell for each of a first series of points disposed circumferentially around the turbine shell;
an early-stage mounting bracket configured to hold the laser module proximate to an early-stage turbine blade connected to the turbine rotor, the early-stage turbine blade being disposed in a first turbine stage or a second turbine stage;
a base station configured to produce a wireless local area network near the turbine shell and to receive a plurality of distance measurement data each corresponding to the distance between the laser module and the turbine shell measured by the laser module for each of the first series of points; and
a server for processing the distance measurements into an eccentricity plot of the first turbine stage or the second turbine stage, wherein the eccentricity plot comprises: the plurality of distance data measured by the laser module plotted as a plot line, a circle fitted to the plot line, a circular grid having a center that represents a centerline of the turbine rotor, and a calculated center for the circle that is calculated based on the plurality of distance data measured by the laser module, wherein the calculated center represents a centerline of the turbine shell.

US Pat. No. 10,920,604

DEVICE FORMING A SEAL FOR A RELIEF VALVE IN A TURBINE ENGINE

Trelleborg Sealing Soluti...

1. A device forming a seal for a relief valve in a turbine engine, the device comprising:the seal comprising:
a deformable main body; and
an attachment projection extending from a first side portion of the main body;
wherein the main body forms a hollow dome having a base that is the first side portion and an apex opposite to the base;
wherein the attachment projection is configured to be inserted into a corresponding notch made in a casing of the turbine engine and to attach the seal to the casing; and
wherein the base is configured to rest on rims of the notch of the casing.

US Pat. No. 10,920,603

GAS TURBINE ENGINE FORWARD BEARING COMPARTMENT ARCHITECTURE

RAYTHEON TECHNOLOGIES COR...

1. A turbofan engine comprising:a fan and an outer housing surrounding the fan to define a bypass duct;
a low spool including an inner shaft;
a high spool including an outer shaft, and wherein the inner shaft and the outer shaft are concentric and are rotatable about an engine central longitudinal axis;
a compressor section including a low pressure compressor and a high pressure compressor axially aft of the low pressure compressor;
a turbine section including a high pressure turbine and a fan drive turbine, the inner shaft driven by the fan drive turbine, and the outer shaft interconnecting the high pressure compressor and the high pressure turbine;
a front center body case structure defining a first core flow path for core airflow into the low pressure compressor;
an intermediate case structure defining a second core flow path for core airflow into the high pressure compressor, and the intermediate case structure mounted to an aft end of the front center body case structure;
a geared architecture at least partially supported by the front center body case structure, and wherein the fan drive turbine drives the geared architecture to drive the fan at a speed lower than a speed of the fan drive turbine;
a first bearing structure forward of the geared architecture, and said first bearing structure mounted to the front center body case structure to rotationally support a fan shaft that connects with the geared architecture to drive the fan;
a fan rotor bearing support structure extending radially inward from said front center body case structure and at least partially supporting the first bearing structure; and
a flex support that provides a flexible attachment of the geared architecture within the front center body case structure.

US Pat. No. 10,920,602

TIP CLEARANCE CONTROL SYSTEM

Rolls-Royce Corporation, ...

1. A turbo fan engine for an aircraft, the turbo fan engine comprising:an intake section;
a compressor section;
a combustion section;
a turbine section;
an exhaust section;
an engine case comprising an inner surface and an outer surface;
turbine blades, a tip of which rotating along the inner surface of the engine case, a tip clearance being defined between the turbine blades and the inner surface of the engine case; and
a tip clearance control system comprising:
a distribution manifold positioned along the engine case for a turbine of the turbo fan engine, wherein the distribution manifold includes a passageway for a thermal fluid, an inlet configured to direct the thermal fluid into the passageway, an inner surface extending along and facing the outer surface of the engine case, and a plurality of outlets configured to direct the thermal fluid onto the outer surface of the engine case, wherein the thermal fluid includes bypass air of the turbo fan engine of the aircraft; and
a variable blower that adds kinetic energy to the thermal fluid, the variable blower configured to blow the bypass air of the turbo fan engine thorough the inlet of the distribution manifold.

US Pat. No. 10,920,601

BLADE OUTER AIR SEAL FIN COOLING ASSEMBLY AND METHOD

RAYTHEON TECHNOLOGIES COR...

1. A sacrificial structure for forming internal cooling passages within a blade outer air seal, comprising:a refractory metal core to form an internal cooling passage within a fin of the blade outer air seal;
wherein the fin extends between an opposed pair of grooves in a body of the blade outer air seal, the fin extends radially from the body and terminates at a radially inner fin face having one or more cooling outlets;
wherein the internal cooling passage extends from a cooling cavity, through the fin, to at least one of the one or more cooling outlets; and
wherein the refractory metal core includes a first radially extending portion dimensioned to extend from the cooling cavity, a second radially extending portion dimensioned to extend from a respective one of the one or more cooling outlets, and a circumferentially extending portion connecting the first and second radially extending portions such that the first radially extending portion is circumferentially offset from the second radially extending portion.

US Pat. No. 10,920,600

INTEGRATED SEAL AND WEAR LINER

RAYTHEON TECHNOLOGIES COR...

1. A blade outer air seal assembly, comprising:a support structure;
a blade outer air seal extending circumferentially about an axis and mounted in the support structure, the blade outer air seal having a lip at an axial end engaged with the support structure;
a seal structure having a seal portion and a wear liner portion joined by a radially extending portion, wherein the seal portion is radially outward of the lip and the wear liner is radially inward of the lip, wherein the wear liner portion is flat in an axial direction and arranged between the support structure and the lip, and the wear liner portion is in contact with the support structure and the lip.

US Pat. No. 10,920,599

CONTOURED ENDWALL FOR A GAS TURBINE ENGINE

Raytheon Technologies Cor...

1. A vane for a gas turbine engine comprising:first and second endwalls each including a radially facing surface that bounds a gas path;
an airfoil section extending in a radial direction between the first and second endwalls, extending in an axial direction between an airfoil leading edge and an airfoil trailing edge, and extending in a circumferential direction between pressure and suction sides;
wherein the radially facing surface of each of the first and second endwalls is axially sloped such that the gas path converges in the axial direction between the airfoil leading and trailing edges;
wherein the first endwall includes an axisymmetric contour at least partially swept in the circumferential direction from each of the pressure and suction sides; and
wherein the first endwall extends in the circumferential direction between opposed mate faces of the outer endwall, and the axisymmetric contour is swept in the circumferential direction from the pressure and suction sides to respective ones of the opposed mate faces.

US Pat. No. 10,920,598

ROTOR ASSEMBLY COVER PLATE

Rolls-Royce Corporation, ...

1. A rotor assembly comprising:a rotor disk concentric with an axis of rotation having a plurality of axially-extending keyways arranged around the outer circumference of the disk, wherein each of the axially-extending fir tree keyways defines a plurality of axially extending recesses;
a plurality of blade assemblies, each of the plurality of blade assemblies comprising a blade, a blade skirt, and a fir tree blade key; the blade skirt positioned between the blade and the fir tree blade key; each fir tree blade key having a shape including a plurality of axially extending, circumferentially oriented blade key ridges, the shape being complimentary to a respective fir tree keyway of the plurality of fir tree keyways of the rotor disk and received in the respective fir tree keyway such that each of the respective blade assemblies of the plurality of blade assemblies are restrained from relative movement in the radial and circumferential directions, wherein each fir tree blade key defines an axial notch extending a full circumferential width of the fir tree blade key and part of a radial height of the fir tree blade key; and,
a plurality of cover plate segments; each of the plurality of cover plate segments forming a respective portion of an annular cover plate ring concentric with the axis of rotation, each of the plurality of cover plate segments having a front plate face and a back plate face each normal to the axis and having a thickness in the axial direction less than the radial width of each segment, the front and back plate face having a radially outer portion, radially inner portion, and a plate key extending from the front plate face of the cover plate segment that is received in a portion of the respective fir tree keyway at the axial notch of the respective fir tree blade key, wherein the plate key comprises a shape including a plurality of axially extending, circumferentially oriented plate key ridges, the shape being complimentary to a portion of a respective fir tree keyway of the plurality of fir tree keyways of the rotor disk corresponding to the axial notch in the respective fir tree blade key, wherein the plate key ridges axially align with the axially extending, circumferentially oriented blade key ridges and engage with corresponding axially extending recesses of the respective fir tree keyway, and wherein the plate key extends less than a full radial length of the respective fir tree keyway;
wherein, each front plate face of the plurality of cover plate segments engage one or more of the respective blade keys and the radially outer portions engage a blade groove defined by the blade skirt and the radially inner portions engage a disk groove in the disk restricting relative axial movement of the blade assembly with respect to the rotor disk; and the plate key engages the portion of the fir tree keyway restricting radial movement of the cover plate segment.

US Pat. No. 10,920,597

TURBINE BLADE COOLING SYSTEM WITH CHANNEL TRANSITION

Solar Turbines Incorporat...

1. A turbine blade for use in a gas turbine engine, the turbine blade comprising:a base including
a root end,
a forward face,
an aft face distal from the forward face,
a first inner channel cooling air inlet disposed proximate the root end,
a second inner channel cooling air inlet disposed proximate the root end in series with the first inner channel cooling air inlet from the forward face to the aft face,
a first inner channel transition section disposed within the base, and
a second inner channel transition section disposed within the base;
an airfoil comprising a skin extending from the base and defining a leading edge, a trailing edge, a pressure side, and a lift side, including
a tip end distal from the base, and
a multi bend heat exchange path, having
a pressure side portion of the multi-path heat exchange disposed adjacent the pressure side of the skin, and
a lift side portion of the multi-path heat exchange disposed adjacent the pressure side of the skin;
a first inner channel terminal end disposed between the first inner channel transition section and the tip end;
a second inner channel terminal end disposed between the second inner channel transition section and the tip end;
a first inner channel extending from the first inner channel cooling air inlet towards the tip end, having a portion that curves within the first inner channel transition section towards the pressure side of the skin as the first inner channel extends upwardly towards the first inner channel terminal end, and is in flow communication with the pressure side portion of the multi bend heat exchange path;
a second inner channel extending from the second inner channel cooling air inlet towards the tip end, disposed between the first inner channel and aft face adjacent the second inner channel cooling air inlet, having a portion that curves within the second inner channel transition section towards the lift side of the skin as the second inner channel extends upwardly towards the second inner channel terminal end, the second inner channel disposed between the first inner channel and the lift side at the second inner channel terminal end, and is in flow communication with the lift side portion of the multi bend heat exchange path; and
wherein within the base the first inner channel and the second inner channel transition their relative positions from the series arrangement of the first inner channel cooling inlet and the second inner channel cooling inlet to a parallel arrangement such that one of the inner channels is adjacent the pressure side and the other of the inner channels is adjacent the lift side and the inner channels are adjacent each other.

US Pat. No. 10,920,596

RADIALLY COMPRESSIBLE AND EXPANDABLE ROTOR FOR A PUMP HAVING AN IMPELLER BLADE

ECP ENTWICKLUNGSGESELLSCH...

1. A radially compressible and expandable rotor for a pump having at least one impeller comprising an impeller blade, wherein the impeller blade has an impeller blade body made of material that is elastically deformable and the rotor further comprising at least one stiffening strut, wherein the stiffening strut is at least partially embedded in the material of the impeller blade body, wherein the stiffening strut has a stiffening curvature.

US Pat. No. 10,920,595

TURBINE COMPONENT HAVING MULTIPLE CONTROLLED METALLIC GRAIN ORIENTATIONS, APPARATUS AND MANUFACTURING METHOD THEREOF

GENERAL ELECTRIC COMPANY,...

1. A turbine engine component, comprising:a longitudinal axis;
a first region with a first metallic grain orientation that is substantially perpendicular to the longitudinal axis;
one or more second regions with a second metallic grain orientation that is different from the first metallic grain orientation; and
one or more graded transition regions disposed between the first and one or more second regions, wherein the component is a stator vane and the stator vane comprises an airfoil as the first region, and an inner trunnion pin and an outer trunnion pin as the second regions.

US Pat. No. 10,920,594

MODAL RESPONSE TUNED TURBINE BLADE

Solar Turbines Incorporat...

1. A turbine blade for use in a gas turbine engine having an operating speed range, the turbine blade comprising:a base
an airfoil comprising
a skin extending from the base and defining a leading edge and a trailing edge opposite the leading edge, the trailing edge having
an inner edge disposed proximate to the base,
an outer edge disposed distal the inner edge, and
a tuning region edge disposed between the inner edge and the outer edge, and having
an upper transition edge extending from the outer edge towards the inner edge,
a middle transition edge disposed between the upper transition edge and the inner edge,
a lower transition edge disposed between the middle transition edge and the inner edge,
an upper tuning edge means for moving a first modal response of the turbine blade outside of the operating speed range, and disposed between the upper transition edge and the middle transition edge, being at least partially closer to the leading edge than the middle transition edge, and
a middle tuning edge means for cooperating with the upper tuning edge means for moving the first modal response of the turbine blade outside of the operating speed range and for keeping at least a second modal response outside of the operating speed range, and disposed between the middle transition edge and the lower transition edge, being at least partially closer to the leading edge than the middle transition edge.

US Pat. No. 10,920,593

MOVABLE RING ASSEMBLY FOR A TURBINE ENGINE TURBINE

SAFRAN AIRCRAFT ENGINES, ...

1. A movable ring assembly which is mounted between an upstream rotor disk and a downstream rotor disk of a turbine engine turbine, the upstream rotor disk being fixed to the downstream rotor disk by bolts, the movable ring assembly comprising:a ferrule fixed between the upstream rotor disk and the downstream rotor disk by bolting the upstream rotor disk, the ferrule and the downstream rotor disk together, and
a part forming a movable ring and bearing radial sealing members, the movable ring being fixed between the upstream rotor disk and the ferrule without bolting the upstream rotor disk, the movable ring and the ferrule together.

US Pat. No. 10,920,592

SYSTEM AND METHOD FOR ASSEMBLING GAS TURBINE ROTOR USING LOCALIZED INDUCTIVE HEATING

General Electric Company,...

1. A method of assembling a rotor comprising a plurality of rotor disks, each rotor disk of the plurality of rotor disks comprising a connecting element, the method comprising:(a) applying heat to a localized region of a first rotor disk of the plurality of rotor disks to selectively deflect a first connecting element of the first rotor disk, wherein the first rotor disk is stationary during the applying of heat; wherein the applying heat to a localized region includes inductive heating using an inductive heating fixture temporarily attached in a stationary position to the rotor disk during the step of applying heat, and wherein the localized region of the rotor disk varies among the plurality of rotor disks;
(b) installing the first rotor disk;
(c) repeating steps (a) and (b) for each rotor disk of the plurality of rotor disks to form a stacked rotor assembly; and
allowing the stacked rotor assembly to cool, wherein the respective connecting element of each rotor disk that has been selectively deflected contracts into an interference fit with an adjacent rotor disk, wherein the rotor disk defines a central rotor bore and the connecting element is disposed radially outboard of the central rotor bore; wherein the localized region is adjacent the central rotor bore; and wherein the method further comprises forming the inductive heating fixture for installation within the central rotor bore.

US Pat. No. 10,920,591

TURBINE DISK

Raytheon Technologies Cor...

1. A turbine rotor, comprising:a disk rotationally disposed about a central axis, the disk including
a bore disposed about the central axis, the bore having
a fore surface including a fore web transition portion, a fore ramp portion radially inward of the fore web transition portion and a fore base transition portion radially inward of the fore ramp portion,
an aft surface including an aft web transition portion, an aft ramp portion radially inward of the aft web transition portion and an aft base transition portion radially inward of the aft ramp portion and
a base portion;
a rim having a first rim portion and a second rim portion, the second rim portion disposed radially inward of the first rim portion;
a first blade post disposed proximate the first rim portion;
a first tab disposed proximate the second rim portion, the first tab positioned radially inward of the first blade post and having a first axial profile;
a slot disposed circumferentially adjacent the first tab, the slot having a roof portion that defines a roof angle extending radially outward with respect to the central axis, the roof angle ranging from 35 degrees to 45 degrees,
wherein the first axial profile of the first tab provides a forward facing surface that includes a blade post transition portion, disposed circumferentially adjacent a radially inward most branch of a plurality of branches spaced radially between a base and a tip of the first blade post and at a radial distance from the central axis equal to that of the radially inward most branch, a slope portion radially inward of the blade post transition portion and a face portion radially inward of the slope portion, the blade post transition portion defining a radius of curvature that transitions a first portion of the first blade post to the slope portion; and
a web disposed radially between the bore and the rim, the web having a fore surface and an aft surface,
wherein the base portion of the bore includes a spool engagement surface, a first arm extending in an aft direction and a second arm extending in a fore direction and
wherein the base portion further includes a radially extending first transition portion connecting an aft end of the spool engagement surface to a radially inward portion of the first arm and a radially extending second transition portion connecting a fore end of the spool engagement surface to a radially inward portion of the second arm.

US Pat. No. 10,920,590

TURBINE ASSEMBLY MAINTENANCE METHODS

GENERAL ELECTRIC COMPANY,...

1. A method for maintenance of a turbine assembly, the turbine assembly comprising a rotor and a stator, the stator comprising a damaged region, the method comprising:anchoring a remotely controllable maintenance apparatus on the rotor;
rotating the rotor to position the maintenance apparatus proximate to the damaged region; and
thereafter, operating and moving a repair tool along the maintenance apparatus and relative to the damaged region so as to repair the damaged region, wherein operating the repair tool comprises disposing a repair material on the damaged region.

US Pat. No. 10,920,589

SIX-STROKE ROTARY-VANE INTERNAL COMBUSTION ENGINE

1. A six-stroke rotary-vane internal combustion engine comprising:a stator having inlet ports and outlet ports, holes for spark plugs and working chambers for intake and compression of an air-fuel mixture alternating with working chambers for expansion and removal of combustion products;
a cylindrical rotor rigidly fixed on a shaft and having side walls, the cylindrical rotor comprising longitudinal grooves housing blades, combustion chambers being formed on a cylindrical surface of the rotor between the grooves;
front and rear end shields,
side walls of all the working chambers of the engine are formed by rotating parts of the rotor,
wherein the combustion chambers are formed as hemispherical recesses on the cylindrical surface of the rotor between the longitudinal grooves of the rotor, and
the working chambers of the stator are formed as cylindrical borings with axes parallel to a stator axis, the borings being evenly spaced along an inner surface of the stator,
each blade consists of separate plates freely displaceable relative to each other, each plate of the blade being made of two parts movable apart in an axial direction by a spring,
wherein the number of blades is a multiple of the number of the chambers for intake of the air-fuel mixture.

US Pat. No. 10,920,588

ADAPTIVE PITCH STEERING IN A LONGWALL SHEARING SYSTEM

Joy Global Underground Mi...

1. A method of controlling a pitch angle of a shearer, the method comprising:storing in a memory, as historical corrective actions, for one or more previous shearer passes, a previous pitch correction height, a previous pitch difference, and a previous achieved change in pitch angle resulting from changing a height of a floor cutter of the shearer based on the previous pitch correction height;
receiving a sensor signal indicative of the pitch angle of the shearer;receiving a target pitch profile defining a plurality of target pitch angles for different sections of a mineral face;determining, with an electronic processor, a pitch difference between the pitch angle and a target pitch angle of the plurality of target pitch angles of the target pitch profile;
determining a pitch compensation value based on the historical corrective actions;
determining, with the electronic processor, a pitch correction height corresponding to a new height for the floor cutter based on the pitch difference and pitch compensation value; and
changing, with the electronic processor, a height of the floor cutter based on the pitch correction height.

US Pat. No. 10,920,587

FORMATION EVALUATION PUMPING SYSTEM AND METHOD

Fiorentini USA Inc, Whee...

1. A fluid pumping system, comprising:a housing having a first cylinder and a second cylinder in axial alignment positioned therein;
a working piston slidably positioned in the first cylinder and a pumping piston slidably positioned in the second cylinder;
a connecting rod axially connecting the working piston to the pumping piston and sealably isolating the first cylinder from the second cylinder;
wherein the working piston forms a first working chamber and a second working chamber in the first cylinder;
wherein the pumping piston forms a first pumping chamber and a second pumping chamber in the second cylinder;
a motor driven pump adapted to forcibly pump a working fluid into and out of the first working chamber and into and out of the second working chamber to produce an axial force on the connecting rod;wherein the first working chamber and the second working chamber are configured to be in fluid communication with the working fluid and the first pumping chamber and the second pumping chamber are configured to be in fluid communication with a process fluid;a first working port positioned in the first working chamber configured to be in fluid communication with the working fluid;
a second working port positioned in the second working chamber configured to be in fluid communication with the working fluid;
a first pumping port positioned in the first pumping chamber configured to be in fluid communication with the process fluid; and
a second pumping port positioned in the second pumping chamber configured to be in fluid communication with the process fluid;
a first working valve positioned in the first working port, a second working valve positioned in the second working port, a first pumping valve positioned in the first pumping port and a second pumping valve positioned in the second pumping port;
a working piston seal positioned on an outer diameter of the working piston to fluidically seal the first working chamber from the second working chamber;
a pumping piston seal positioned on an outer diameter of the pumping piston to fluidically seal the first pumping chamber from the second pumping chamber;
a hydraulic pumping module including the motor driven pump coupled to the first working valve and configured to selectively pump the working fluid into and out the first working chamber and coupled to the second working valve and configured to selectively pump the working fluid into and out of the second working chamber;
a first valve module coupled to the first pumping valve and configured to selectively allow the process fluid into and out of the first pumping valve;
a second valve module coupled to the second pumping valve and configured to selectively allow the process fluid into and out of the second pumping valve;
wherein the hydraulic pumping module further comprises:
a working fluid tank;
the motor driven pump in fluid communication with the working fluid tank; and
a hydraulic pumping module shuttle valve selectively fluidically coupled to the working fluid tank, the pump, the first working valve and the second working valve.

US Pat. No. 10,920,586

SYSTEMS AND METHODS FOR LOGGING WHILE TREATING

SAUDI ARABIAN OIL COMPANY...

13. A method for measuring properties within a subterranean well, the method including:supporting a measuring tool within the subterranean well with a delivery line, the measuring tool having:
a tool body with a central axis and a tool attachment located at an axial end of the tool body;
a delivery line attachment attaching the measuring tool to the delivery line; and
a primary treatment platform in mechanical communication with the tool body, the primary treatment platform having a platform attachment sized to mate with the tool attachment and also having at least one treatment system;
alternately selectively releasing the primary treatment platform from direct attachment with the tool body, and selectively directly securing the primary treatment platform to the tool body with the tool attachment, with the platform attachment;
a secondary treatment platform which is detachable from tool body while in the well, where the primary treatment platform is located downhole of the tool body and the secondary treatment platform is located uphole of the tool body and wherein the primary treatment platform and secondary treatment platform are configured to treat obstructions in the well; and
performing a treatment function within the subterranean well with the at least one treatment system during delivery of the measuring tool into the subterranean well.

US Pat. No. 10,920,585

DETERMINING SAND-DUNE VELOCITY VARIATIONS

Saudi Arabian Oil Company...

1. A method, comprising:receiving airborne electromagnetic (AEM) data and seismic data for a geographic region including sand dunes, wherein the AEM data identifies apparent resistivity as a function of depth within the sand dunes;
separately calculating an inversion of the AEM data to generate a resistivity model;
determining a base of sand (BOS) of the geographic region using the resistivity model;
calculating an inversion with cross-domain regularization of the AEM data and the seismic data, wherein the cross-domain regularization comprises a cross-domain regularizer calculated from the resistivity model derived from the AEM data inversion and the velocity model derived from the seismic data inversion; using the determination of the BOS;
generating a velocity-depth model based on the inversion with the cross-domain regularization between the resistivity and the velocity models, wherein the AEM data and the seismic data cover a common geographic region of the resistivity and the velocity models, wherein the velocity depth model identifies velocity variations within the sand dunes; and
generating a seismic image using the velocity-depth model.

US Pat. No. 10,920,584

DETECTION OF INFLUX AND LOSS OF CIRCULATION

SCHLUMBERGER TECHNOLOGY C...

1. A method for detecting an influx and/or loss of circulation in a wellbore, comprising:measuring a condition in the wellbore using one or more of a stroke counter, a flow meter, or a pressure transducer prior to a positive displacement pump being shut off;
determining that the positive displacement pump is shut off;
predicting pit volume and/or gas concentration at a plurality of time points after the positive displacement pump is shut off using the measured condition prior to the positive displacement pump being shut off, wherein the measured condition prior to the positive displacement pump being shut off correlates with the pit volume and/or gas concentration after the positive displacement pump is shut off;
measuring pit volume using a fluid level sensor and/or gas concentration using a gas level sensor at the plurality of time points after the positive displacement pump is shut off, the measured pit volume including a total active volume (TAV) and a flowback curve, the flowback curve being a normalized TAV which is reset to zero when the positive displacement pump is shut off;
comparing the predicted pit volume and/or gas concentration with the measured pit volume and/or gas concentration at the plurality of time points after the positive displacement pump is shut off using a computer; and
producing a warning signal when the difference between the predicted pit volume and/or gas concentration and the measured pit volume and/or gas concentration is greater than a predetermined value.

US Pat. No. 10,920,583

MONITORING WATER FLOOD LOCATION USING POTENTIALS BETWEEN CASING AND CASING-MOUNTED ELECTRODES

Halliburton Energy Servic...

1. A system for locating water floods, comprising:at least one current source coupled to a borehole casing to inject current into a formation within which the casing is disposed; and
multiple electrodes coupled to the casing, each of the electrodes coupled to a different one of multiple transducers,
wherein each of the multiple transducers is used to determine a potential between the casing and a corresponding one of the multiple electrodes to which the transducer is coupled,
wherein the potentials from the multiple transducers are used to determine a water flood location.

US Pat. No. 10,920,582

SYSTEMS AND METHODS TO USE TRIANGULATION THROUGH ONE SENSOR BEAMFORMING IN DOWNHOLE LEAK DETECTION

Halliburton Energy Servic...

1. A method of downhole leak detection, comprising:obtaining physical signals detected by a single physical sensor moving along a wellbore;
performing a first frame decomposition operation on a first set of physical signals of the physical signals detected by the single physical sensor at a first location to obtain a first plurality of virtual signals associated with a first array of virtual sensors, each virtual sensor of the first array of virtual sensors being located at a virtual distance relative to the first location, the virtual distance corresponding to a physical distance;
performing a second frame decomposition operation on a second set of physical signals of the physical signals detected by the single physical sensor at a second location to obtain a second plurality of virtual signals associated with a second array of virtual sensors, each virtual sensor of the second array of virtual sensors being located at a virtual distance relative to the second location, the virtual distance corresponding to a physical distance;
computing a first direction of arrival estimate of the first location of the single physical sensor relative to a location of a downhole leak and a second direction of arrival estimate of the second location of the single physical sensor relative to the location of the downhole leak;
determining a temporal correction factor for the first plurality of virtual signals corresponding to the first array of virtual sensors and the second plurality of virtual signals corresponding to the second array of virtual sensors;
determining a modeled transfer function of the first plurality of virtual signals and the second plurality of virtual signals corresponding to the first array of virtual sensors and the second array of virtual sensors;
calculating a virtual steering weight of the virtual sensors relative to the single physical sensor based on the temporal correction factor and the modeled transfer function;
applying the virtual steering weight to one or more covariance matrices that represent the first plurality of virtual signals and the second plurality of virtual signals corresponding to the first array of virtual sensors and the second array of virtual sensors; and
triangulating the first direction of arrival estimate and the second direction of arrival estimate to estimate the location of the downhole leak.

US Pat. No. 10,920,581

FLOW VELOCITY METER AND METHOD OF MEASURING FLOW VELOCITY OF A FLUID

SHELL OIL COMPANY, Houst...

1. A flow velocity meter for measuring flow of a fluid, comprising:a distributed fluid-contact surface; and
a distributed acoustic sensor along a longitudinal direction, which distributed acoustic sensor comprises a distributed sensing element that is acoustically coupled to the distributed fluid-contact surface via a distributed acoustic path,wherein the distributed acoustic path (1) extends between the distributed fluid-contact surface and the distributed sensing element, and (2) bypasses the fluid;
wherein at least a part of the fluid-contact surface is provided with a flow-disturbing surface texture having a surface relief with a pre-determined pattern in said longitudinal direction, wherein said flow-disturbing surface texture is a knurled surface.

US Pat. No. 10,920,580

REAL-TIME BOTTOM-HOLE FLOW MEASUREMENTS FOR HYDRAULIC FRACTURING WITH A DOPPLER SENSOR IN BRIDGE PLUG USING DAS COMMUNICATION

Halliburton Energy Servic...

1. A system for obtaining downhole flow rates and proppant concentrations between perforations during hydraulic fracturing comprising:at least one bridge plug deployed down hole in a casing with one or more perforations in the casing above the at least one bridge plug;
a Doppler based flow meter sensor installed in the at least one bridge plug, wherein the Doppler based flow meter sensor is configured to emit a Doppler signal uphole and to detect reflections of the Doppler signal off fluid used for hydraulic fracturing;
an electro acoustic technology acoustic signal generator installed in the at least one bridge plug; and
a fiber optic cable installed on the outside of the casing that is part of a distributed acoustic sensing (DAS) system connected to a surface distributed acoustic sensing interrogator.

US Pat. No. 10,920,579

METHOD AND APPARATUS FOR EARLY DETECTION OF KICKS

Board of Regents, The Uni...

1. A well monitoring system, comprising:a well;
a well system, the well system including at least one sensor measuring at least one well condition; and
a computing apparatus, including:
a processor;
a storage;
a bus system over which the processor communicates with the storage;
a data structure residing in the storage in which a set of real-time data acquired by the at least one sensor is stored;
a well monitoring software component residing on the storage that, when executed by the processor over the bus system, performs a method to detect a kick in a well, the method comprising:
storing the set of real-time data from a plurality of measurements of the at least one well condition by the at least one sensor into the data structure in the storage, the at least one well condition being correlative to an unplanned fluid influx into the well;
modeling an operation of the well with a physics-based, state space model of the well system to obtain an estimate of the at least one well condition;
accessing the set of real-time data from the storage; and
applying the set of real-time data accessed from the storage and the estimate of the well condition to a probabilistic estimator to yield a probability of an occurrence of a kick and a confidence measure for the probability.

US Pat. No. 10,920,578

METHOD FOR FINDING POSITION OF COLLARS

Halliburton Energy Servic...

1. A method for determining location of a collar in a wellbore, comprising:taking an electromagnetic measurement;
producing an electromagnetic log from the electromagnetic measurement, wherein the electromagnetic log comprises a plurality of channels, wherein each of the plurality of channels is a distance between a receiver and a transmitter; and
locating a position of the collar in a first casing and a second casing in the electromagnetic log based on a collar signature in the electromagnetic log, wherein the collar signature comprises at least one channel from the plurality of channels.

US Pat. No. 10,920,577

POSITION SENSING FOR DOWNHOLE TOOLS

Halliburton Energy Servic...

11. A method for determining a position of a downhole tool comprising:positioning a plurality of downhole tools in a wellbore, wherein at least one position sensor of a plurality of position sensors is attached to teach of the plurality of downhole tools;
attaching the plurality of position sensors in series along a first conductor;
taking a first measurement of a line resistance between a first conductor and, a second conductor;
moving at least one of the downhole tools, wherein moving the at least one of the downhole tools increases or decreases the line resistance; and
taking a second measurement of the line resistance between the first conductor and the second conductor, wherein the second measurement provides an indication of the position of the at least one of the downhole tools.

US Pat. No. 10,920,576

SYSTEM AND METHOD FOR DETERMINING BHA POSITION DURING LATERAL DRILLING

MOTIVE DRILLING TECHNOLOG...

1. A control system for drilling, the control system comprising:a processor having access to a memory media;
the memory media storing instructions executable by the processor for controlling drilling direction of a bore hole assembly (BHA) during lateral drilling by a drilling rig of a wellbore through a formation, the instructions further comprising instructions for:
accessing first logging data comprising logging data collected by the BHA over an evaluation length of the wellbore and corrected for true vertical depth (TVD) using a spatial path of the wellbore, wherein TVD represents a location with respect to both a vertical and horizontal axis;
determining a first bed dip of the formation by iteratively applying different values of bed dip to the first logging data to determine the first bed dip as a value of bed dip best matching with the first logging data;
determining a second bed dip by modifying the first bed dip based on drilling information collected during the lateral drilling, wherein the drilling information comprises at least one of: second logging data different from the first logging data, mud analysis data, and drilling equipment data;
estimating a subterranean location of the BHA based on the first logging data, the second bed dip, and the drilling information, wherein the subterranean location is the location of the BHA with respect to both a vertical and horizontal axis; and
using the subterranean location to modify steering of the lateral drilling of the wellbore.

US Pat. No. 10,920,575

METHODS AND SYSTEMS EMPLOYING A ROTATING MAGNET AND FIBER OPTIC SENSORS FOR RANGING

Halliburton Energy Servic...

1. A system comprising:a drillstring in a first borehole, the drillstring comprising a magnet rotatable about an axis of the drillstring;
at least one fiber optic sensor deployed in a second borehole for generating electromagnetic (EM) field measurements in response to a magnetic field produced by rotation of the magnet about the axis of the drillstring; and
a processor in electronic communication with the at least one fiber optic sensor to determine a distance or direction of the magnet relative to the at least one fiber optic sensor based on the EM field measurements.

US Pat. No. 10,920,574

ACOUSTIC TESTING OF CORE SAMPLES

Saudi Arabian Oil Company...

1. A system comprising:a central member defining a sample chamber, wherein the central member is configured to enclose at least a portion of a sample within the sample chamber, and wherein the central member comprises a plurality of acoustic sensors configured to detect sound waves in the sample chamber and a plurality of acoustic emitters configured to emit sounds waves in the sample chamber;
a pulser and receiver circuit;
a switch coupled to the pulse and receiver circuit and to each of the acoustic emitters, wherein the switch is configured to connect or disconnect the pulser and receiver circuit to a specified one of the acoustic emitters;
a data acquisition unit coupled to the pulser and receiver circuit and to each of the acoustic sensors, wherein the data acquisition unit is configured to receive a respective signal from each of the acoustic sensors; and
wherein the pulser and receiver circuit is configured to transmit an electric pulse to the specified one of the plurality of acoustic emitters through the switch and to transmit a first control signal to the data acquisition unit.

US Pat. No. 10,920,573

LOCKING LID FOR DOWNHOLE TOOLS

Hunting Energy Services, ...

8. A method for assembling a sonde housing used in directional drilling, the method comprising the steps of:providing a cylindrical housing body with walls defining a longitudinal cavity;
providing a cover for the cavity, the cover having a top surface, a bottom surface, opposing end surfaces and opposing longitudinal side surfaces, the cover being provided with a plurality of tabs extending from the longitudinal side surfaces of the cover which are engageable within mating grooves provided in the sonde housing body for slidably engaging the tabs;
wherein the cover is engageable within the cavity in the housing body by vertically positioning and partially engaging the cover therein, the cavity also beings sized to allow longitudinal sliding movement of the cover within the cavity, thereby allowing the cover to move from a partially engaged position to a fully engaged position;
positioning the cover within the cavity and fully engaging the cover within the cavity by sliding longitudinal movement;
wherein the tabs which are provided on the longitudinal side surfaces of the cover are cut on an inclined angle which forms a ramp surface with respect to the mating grooves provided in the sonde housing body so that when the tabs engage the mating grooves during the longitudinal sliding movement of the cover within the cavity pressure is created against the mating surfaces of the sonde housing body and the cover;
further securing the cover within the cavity by engaging a roll pin between the sonde housing body and the cover when the cover is in place in the fully engaged position; and
wherein the tabs which are provided on the longitudinal surfaces of the cover are cut at an angle in the range from about 5 to 20 degrees with respect to a longitudinal center line of the sonde housing body.

US Pat. No. 10,920,572

SENSOR DEPLOYMENT SYSTEM AND METHOD USING A MOVABLE ARM WITH A TELESCOPING SECTION

Sondex Wireline Limited, ...

1. A sensor deployment system, comprising:a pair of bulkheads arranged along a tool string axis;
a pair of pivot blocks arranged along the tool string axis, a respective pivot block of the pair of pivot blocks being positioned proximate a respective bulkhead of the pair of bulkheads, the pivot blocks being axially fixed relative to the pair of bulkheads; and
an arm coupled to the pair of pivot blocks at opposite ends, the arm comprising:
a first segment rotationally coupled to a first pivot block of the pair of pivot blocks;
a second segment rotationally coupled to a second pivot block of the pair of pivot blocks;
a first link arm coupled to the first pivot block and the first segment;
a second link arm coupled to the second pivot block and the second segment; and
a telescoping section extending between the first segment and the second segment, wherein the telescoping section moves radially outward from the tool string axis as the first and second segments rotate about the respective pivot blocks, an axis extending along a length of the telescoping section being maintained substantially parallel to the tool string axis.

US Pat. No. 10,920,571

MEASUREMENT OF TORQUE WITH SHEAR STRESS SENSORS

Halliburton Energy Servic...

1. A downhole torque measurement tool, comprising:a lower cylindrical sub having a box end and a pin end;
an upper cylindrical sub having a box end, a pin end and an inner bore with an inner surface extending between the box end and the pin end,
wherein the box end of the upper cylindrical sub is connected to the pin end of the lower cylindrical sub;
wherein the lower cylindrical sub comprises an outer cylindrical shaft having a hollow cavity extending parallel to a longitudinal axis of the outer cylindrical shaft and an inner cylindrical shaft positioned within the hollow cavity and extending parallel to the longitudinal axis of the outer cylindrical shaft, the outer and inner cylindrical shafts each having a common end coupled together and forming a unitary structure at the box end of the lower cylindrical sub; and
wherein the inner cylindrical shaft has an extended end that extends a length greater than a length of the outer cylindrical shaft at the pin end of the lower cylindrical sub such that the extended end of the inner cylindrical shaft extends into the bore of the upper cylindrical sub and forms an annular space;
a flexible coupling positioned within the annular space and at least partially encircling the extended end of the inner cylindrical shaft, the flexible coupling coupled to the extended end of the inner cylindrical shafts; and
a micro-electro-mechanical-system (MEMS) shear stress sensor positioned within the annular space on the inner surface of the upper cylindrical sub and in contact with the flexible coupling, wherein relative positional displacement between the inner and outer shafts produces shear stress in the flexible coupling that is measured by the MEMS shear stress sensor.

US Pat. No. 10,920,570

MEASUREMENT OF TORQUE WITH SHEAR STRESS SENSORS

Halliburton Energy Servic...

1. A torque measurement tool, comprising:an outer cylindrical shaft extending along a longitudinal axis and having an inner bore with an inner surface;
an inner cylindrical shaft positioned within the inner bore of the outer cylindrical shaft and extending along the longitudinal axis, the inner cylindrical shaft having an outer surface;
a flexible coupling positioned within an annular space between the inner surface of the outer cylindrical shaft and the outer surface of the inner cylindrical shaft, the flexible coupling directly coupled to the inner-surface of the outer cylindrical shaft and to the outer surface of the inner cylindrical shaft such that the flexible coupling couples the outer surface of the inner cylindrical shaft with the inner surface of the outer cylindrical shaft; and
a micro-electro-mechanical-system (MEMS) shear stress sensor positioned within a recess located on the outer surface of the inner cylindrical shaft, the shear stress sensor having a contact surface positioned about flush to the outer surface of the inner cylindrical shaft and in contact with the flexible coupling.

US Pat. No. 10,920,569

ACOUSTIC METHOD AND APPARATUS FOR CEMENT BOND EVALUATION THROUGH TUBING

Halliburton Energy Servic...

1. A method for determining cement bonding, comprising:disposing an acoustic logging tool in a wellbore and inside a pipe string at a first location, wherein the acoustic logging tool comprises a transmitter and a receiver disposed on the acoustic logging tool;
broadcasting a shaped signal by the transmitter through the pipe string and through at least a first casing of one or more concentric pipes disposed around the pipe string;
receiving a reverberating signal by the receiver;
processing the reverberating signal by an information handling system;
determining presence of a material outside an outermost of the one or more concentric pipes; and
moving the acoustic logging tool to a second location inside the pipe string.

US Pat. No. 10,920,568

EVALUATING CEMENT INTEGRITY IN A WELLBORE WITH MULTIPLE CASING STRINGS

Halliburton Energy Servic...

1. A logging tool for evaluating an integrity of cement in a wellbore with multiple casing strings, the tool comprising:a first body; and
a first detector/source set contained in the first body, the first set comprising:
at least a first collimated photon source that produces a field of photons emitted from the first source, and
at least a first non-azimuthally collimated photon detector spaced away from the first source by a first distance that sets a first radial depth of investigation (DOI) of the first detector, with photon count rates produced by the first detector that are based on energy levels of scattered photons received by the first detector from materials surrounding the wellbore.

US Pat. No. 10,920,567

HEALTH MONITORING OF POWER GENERATION ASSEMBLY FOR DOWNHOLE APPLICATIONS

HALLIBURTON ENERGY SERVIC...

1. A system for health monitoring of a downhole assembly, the system comprising:a functional test system comprised of an enclosure with an inlet and an outlet;
a source of a fluid coupled to the inlet of the functional test system;
a downhole tool within the enclosure of the functional test system, wherein the downhole tool includes at least one internal component and a housing with at least one access port for providing access to an interior of the downhole tool for investigative equipment located exterior to the housing, and the functional test system is used to actuate the at least one internal component of the downhole tool as fluid flows from the source into the enclosure via the inlet; and
a diagnostic system communicatively coupled to the investigative equipment to determine an operating efficiency of the downhole tool based on data collected by the investigative equipment via the at least one access port of the housing when the at least one internal component of the downhole tool is actuated by the functional test system.

US Pat. No. 10,920,566

RATE OF PENETRATION DRILLING OPERATION CONTROLLER

Schlumberger Technology C...

1. A method comprising:receiving a maximum depth of cut value of a bit that accounts for bit body formation engagement;
receiving a total revolution rate value for the bit that is based at least in part on a differential pressure value of a mud motor;
generating a rate of penetration value for the bit as operatively coupled to the mud motor by multiplying the maximum depth of cut value and the total revolution rate value; and
operating a rigsite system according to the rate of penetration value for drilling a portion of a borehole using the bit as operatively coupled to the mud motor.

US Pat. No. 10,920,565

WELL CONSTRUCTION MANAGEMENT AND DECISION SUPPORT SYSTEM

Schlumberger Technology C...

1. A well construction control system, comprising:drilling operating parameters of a wellbore being drilled through subsurface formations;
a computer system configured to accept an input signal from survey instruments of a drill string measuring at least one of the drilling operating parameters, wherein the survey instruments have limited accuracy in determining a geodetic position of the wellbore;
the computer system configured to accept as input a predetermined configuration of the wellbore when completed that comprises a geodetic trajectory for the wellbore,
the computer system configured to calculate at least one wellbore state parameter from the at least one of the drilling operating parameters and predetermined wellbore state parameters from the predetermined configuration, wherein the wellbore state parameters comprise a geodetic wellbore parameter;
wherein the computer system is configured to:
calculate, using the calculated at least one wellbore state parameter and the limited accuracy of the survey instruments, a modified well plan that comprises at least one task for a corrective action, wherein the at least one task comprises an adjustment to an interval for a directional survey that uses the survey instruments and that is performed while drilling of the wellbore is stopped, wherein the interval depends on the limited accuracy of the survey instruments, decreases with increased risk, and increases with decreased risk, and
to generate at least one command to operate at least one automatic drilling unit control according to at least one of the drilling operating parameters for the at least one task of the modified well plan.

US Pat. No. 10,920,564

DOWNHOLE CLUTCH JOINT FOR MULTI-DIRECTIONALLY ROTATING DOWNHOLE DRILLING ASSEMBLY

1. A downhole clutch joint assembly comprising:a first component;
a second component;
a ratchet sleeve assembly; and
a biasing member;
wherein:
said ratchet sleeve assembly comprises:
a substantially tubular first ratchet sleeve comprising a plurality of saw teeth proximate a first end thereof; and
a substantially tubular second ratchet sleeve comprising a plurality of saw teeth proximate an end thereof;
said first ratchet sleeve is positioned around, and engaged with, a portion of said first component;
said second ratchet sleeve is positioned within, and engaged with, a portion of said second component;
said first ratchet sleeve saw teeth are disposed in engaging abutment with said second ratchet sleeve saw teeth;
said first ratchet sleeve is positioned longitudinally between said biasing member and said second ratchet sleeve;
said biasing member biases said first ratchet sleeve against said second ratchet sleeve;
upon rotation of said first component in a first direction, said first ratchet sleeve saw teeth engage said second ratchet sleeve saw teeth to induce rotation of said second ratchet sleeve, and thereby said second component, in said first direction; and
upon rotation of said first component in a second direction, said first ratchet sleeve saw teeth slidingly disengage from said second ratchet sleeve saw teeth and said second component substantially ceases rotation.

US Pat. No. 10,920,563

HORIZONTAL DRILLING DEVICE AND METHOD OF USING THE SAME

19. An apparatus for horizontal drilling under an obstacle impassable by foot, comprising:a locator box;
a horizontal drill rig with a drill head;
a transmitter operably coupled to the drill head;
a suspension assembly extending over the obstacle above a bore hole line;
a remote control device paired with the locator box capable of wirelessly sending instructions and wirelessly receiving data from the locator box,
wherein the locator box is operably coupled to the suspension assembly, and
wherein the suspension assembly allows the locator box to be positioned at any point along the suspension assembly.

US Pat. No. 10,920,562

REMOTE CONTROL AND MONITORING OF ENGINE CONTROL SYSTEM

Schlumberger Technology C...

1. A system for operating a genset for a drilling rig, the system comprising:a remote (HMI) component;
a genset configured to run to provide power to the drilling rig; and
an idle control component configured to operate the genset in:
an automatic idle mode in which the genset shuts off after a predetermined criteria is met; and
a constant idle mode in which the genset continues to idle until instructed to stop;
wherein the remote (HMI) component is configured:
to receive instructions to operate the genset and to deliver the instructions to the genset to operate the genset without the intervention of a motor operator; and
to permit selection between the automatic idle mode and the constant idle mode.

US Pat. No. 10,920,561

DRILLING ASSESSMENT SYSTEM

Schlumberger Technology C...

1. A method comprising:performing a pre-run simulation of a drillstring using a component-based model of the drillstring, borehole trajectory information and formation information to determine respective different axial positions of a first component and a second component that increase measurement accuracy and sensitivity of a first sensor of the first component and a second sensor of the second component to dynamic mechanical behavior of the drillstring wherein the pre-run simulation predicts a statistical, axial distribution of one or more dynamic mechanical drilling parameters of the drillstring in a borehole of a formation measurable by at least one of the first sensor and the second sensor to determine at least one of the different axial positions using a maximum statistical variation at each of one or more axial positions along the drillstring;
receiving data acquired during drilling of the borehole, wherein the data comprise rate of penetration data and downhole sensor data acquired via at least the first sensor of the first component and the second sensor of the second component of a plurality of components arranged in an order at respective axial positions of the drillstring, wherein the first sensor and the second sensor comprise the respective different axial positions;
using at least a portion of the data, validating a simulated rate of penetration of the component-based model of the drillstring and validating simulated dynamic mechanical drilling parameter values of the component-based model of the drillstring with respect to time for axial positions along the drillstring as disposed in the borehole of the formation during the drilling of the borehole;
analyzing the validated simulated dynamic mechanical drilling parameter values to generate results; and
controlling the drillstring based at least in part on the results.

US Pat. No. 10,920,560

HORIZONTAL GAS AND LIQUID BYPASS SEPARATOR

WellWorx Energy Solutions...

1. A separator for use in a well bore, wherein the separator comprises at least one valve, wherein the at least one valve comprises:a body extending along a longitudinal axis from a first end to a second end of the body;
a conduit extending longitudinally through the body from the first end to the second end of the body;
an elongated channel extending laterally through the body from an outer surface of the body to the conduit and longitudinally along the length of the body;
a pair of inner stops positioned at each end of the elongated channel adjacent to the conduit;
a pair or outer stops positioned at each end of the elongated channel adjacent to the exterior surface of the body; and
a cylindrical plunger positioned within the elongated channel such that the plunger is translatable inwardly and outwardly within the elongated channel to selectively seal the conduit relative to the elongated channel, wherein the cylindrical plunger is longer then the length of the elongated channel such that the pair of inner stops engages ends of the cylindrical plunger;
wherein the plunger is translatable inward within the elongated channel towards the longitudinal axis to a closed position such that the plunger substantially seals the conduit relative to the elongated channel to thereby inhibit gas from entering the conduit, wherein the plunger is translatable outward within the elongated channel away from the longitudinal axis to an open position such that the plunger substantially opens the conduit relative to the elongated channel to thereby allow liquid to enter the conduit.

US Pat. No. 10,920,558

METHOD OF ENHANCING PROPPANT DISTRIBUTION AND WELL PRODUCTION

HALLIBURTON ENERGY SERVIC...

1. A method for treating a subterranean formation, the method comprising:injecting a pad fluid into the subterranean formation at a pressure sufficient to create at least one fracture in the subterranean formation;
injecting a first treatment fluid into the at least one fracture, wherein the first treatment fluid comprises:
an aqueous base fluid comprising a viscosity of about 0.25 cP to about 20 cP, and
a first proppant particulate;
allowing the first proppant particulate to gravitationally migrate into a bottom portion of the at least one fracture,
wherein about 5% to about 30% by weight of total first proppant particulate in the bottom portion of the at least one fracture comprises a density of about 2.7 g/cc to about 4.0 g/cc and a crush strength of about 2,000 psi to about 20,000 psi,
wherein a portion of the first proppant forms dunes after gravitationally migrating into the bottom portion of the at least one fracture;
injecting a post flush fluid capable of redistributing the formed dunes throughout the bottom portion of the at least one fracture;
injecting a second treatment fluid into the at least one fracture, wherein the second treatment fluid comprises:
a suspension base fluid comprising a viscosity of about 50 cP to about 10,000 cP, and
a second proppant particulate, wherein the second proppant particulate comprises a crush strength of about 2,000 psi to about 20,000 psi; and
allowing the fracture to close, thereby forming a full proppant pack in the bottom portion of the at least one fracture and a partial proppant pack in a top portion of the at least one fracture.

US Pat. No. 10,920,557

UTILIZING ELECTRICALLY ACTUATED EXPLOSIVES DOWNHOLE

Halliburton Energy Servic...

1. A method for creating a perforation in a subterranean formation using electrically ignitable and electrically controllable explosive material (EIECEM), comprising:positioning a charge carrier in a wellbore of the formation, wherein the charge carrier comprises a plurality of shaped charges, wherein each of the plurality of shaped charges comprises the EIECEM, wherein the EIECEM is disposed about a cone, wherein an insulator is disposed about a portion of the cone to insulate the cone from the EIECEM, wherein a remaining portion of the cone is not lined with the insulator;
exciting an electrical current at the charge carrier, wherein exciting the electrical current comprises inducing an electrical current at the EIECEM;
igniting the EIECEM by the electrical current, wherein igniting the EIECEM creates an explosion for a duration of the electrical current; and
creating a perforation in the formation based, at least in part, on the explosion.

US Pat. No. 10,920,556

USING RADIO WAVES TO FRACTURE ROCKS IN A HYDROCARBON RESERVOIR

Saudi Arabian Oil Comoanv...

1. A method, comprising:forming a borehole in a hydrocarbon reservoir from a surface of the hydrocarbon reservoir extending downward into the hydrocarbon reservoir;
transmitting an electromagnetic (EM) wave through the borehole:
directing at least a portion of the EM wave to rocks at a location below the surface in the hydrocarbon reservoir; and
fracturing the rocks at the location below the surface in the hydrocarbon reservoir by irradiating the rocks around the borehole using at least the portion of the EM wave, wherein irradiating the rocks elevates pore-water pressure in the rocks causing fracturing of the rocks, and wherein the irradiating is performed using the following procedures:
irradiating a first portion of the rocks by using the EM wave for a first duration;
after irradiating the first portion of the rocks for the first duration, refraining from irradiating the first portion of the rocks for a second duration, wherein a length of the second duration is determined based on a thermal diffusivity of the rocks; and
repeating the irradiating step and the refraining step for multiple iterations.

US Pat. No. 10,920,555

FLUID EXCHANGE DEVICES AND RELATED CONTROLS, SYSTEMS, AND METHODS

Flowserve Management Comp...

1. A system for exchanging pressure between at least two fluid streams, the system comprising:a pressure exchange device comprising:
at least one tank;
at least one high pressure inlet in communication with the at least one tank and for receiving a fluid at a first higher pressure into the at least one tank;
at least one low pressure inlet in communication with the at least one tank and for receiving a downhole fluid at a first lower pressure into the at least one tank;
at least one high pressure outlet in communication with the at least one tank and for outputting the downhole fluid from the at least one tank at a second higher pressure that is greater than the first lower pressure;
at least one low pressure outlet in communication with the at least one tank and for outputting the fluid from the at least one tank at a second lower pressure that is less than the first higher pressure;
a valve device comprising a linear valve actuator, wherein the valve actuator is configured to move one or more valve members at variable rates along a stroke of the linear valve actuator in order to selectively fill and empty the at least one tank in communication with the at least one low pressure outlet and the at least one high pressure inlet, the system and the valve device configured to:
move the valve actuator at a first higher rate of speed when in communication with a low pressure outlet;
move the valve actuator at a second lower rate of speed that is less than the first higher rate of speed when transitioning into communication with the high pressure inlet;
selectively place the fluid at the first higher pressure in communication with the downhole fluid at the first lower pressure in order to pressurize the downhole fluid to the second higher pressure; and
selectively output the fluid at the second lower pressure from the pressure exchange device through the at least one low pressure outlet; and
at least one pump for supplying the fluid at the first higher pressure to the at least one high pressure inlet of the pressure device.

US Pat. No. 10,920,554

STIMULATING U-SHAPE WELLBORES

Saudi Arabian Oil Company...

1. A wellbore notching system comprising:a fluid conduit extending from a topside facility into a wellbore;
a well-notching tool fluidically connected to and positioned at a downhole end of the fluid conduit within a wellbore, the well-notching tool comprising:
a cylindrical drum with a fluid inlet fluidically connected to the downhole end of a fluid conduit, the cylindrical drum having an outer surface along which is the fluid inlet, the cylindrical drum having an inner surface and a center;
a plurality of fluid nozzles fluidically connected to an interior of the cylindrical drum and positioned around an outer circumference of the cylindrical drum, the plurality of fluid nozzles positioned to direct fluid away from the cylindrical drum;
a rotatable collar positioned in the center of the cylindrical drum, the rotatable collar having an outer surface parallel to the inner surface of the cylindrical drum; and
a plurality of sleeve plates positioned between the inner surface of the cylindrical drum and the outer surface of the rotatable collar, each of the plurality of sleeve plates defining a hole with a diameter smaller than a diameter of a corresponding dropped ball, wherein a first sleeve plate of the plurality of sleeve plates has a first hole sized to receive a first dropped ball of a first size, and a second sleeve plate of the plurality of sleeve plates has a second hole sized to receive a second dropped ball of a second size; and
an isolation packer positioned uphole of the well-notching tool, the isolation packer fluidically isolating a section of the wellbore to be notched from a remainder of the wellbore.

US Pat. No. 10,920,553

APPARATUS AND METHOD FOR SERVICING A WELL

Schlumberger Technology C...

1. A blending system, comprising:a chassis;
a blender apparatus comprising:
a mixer positioned on the chassis, the mixer having a mixer housing defining a first mixer inlet, a second mixer inlet and a mixer outlet, the first mixer inlet configured to receive a liquid component, and the second mixer inlet configured to receive a dry component, the mixer configured to pressurize at least the liquid component within the mixer housing and discharge the liquid component through the mixer outlet at a first pressure above hydrostatic pressure;
a transfer pump positioned on the chassis, the transfer pump having a pump housing defining a pump inlet to receive a liquid component and a pump outlet to discharge the liquid component, the transfer pump configured to receive the liquid component, pressurize the liquid component within the pump housing, and discharge the liquid component through the pump outlet at a second pressure above hydrostatic pressure;
at least two fluid intake ports including a first fluid intake port in fluid communication with the first mixer inlet and a second fluid intake port in fluid communication with the pump inlet;
at least two discharge ports including a first discharge port in fluid communication with the mixer outlet and a second discharge port in fluid communication with the pump outlet; and
a valve having an open position and a closed position, wherein the open position places the first fluid intake port in fluid communication with the second fluid intake port.

US Pat. No. 10,920,552

METHOD OF INTEGRATING FRACTURE, PRODUCTION, AND RESERVOIR OPERATIONS INTO GEOMECHANICAL OPERATIONS OF A WELLSITE

Schlumberger Technology C...

1. A method of performing oilfield operations at a wellsite, the wellsite positioned about a subterranean formation having a wellbore therethrough and a fracture network therein, the fracture network comprising natural fractures, the method comprising:generating fracture parameters comprising a hydraulic fracture network based on wellsite data comprising a mechanical earth model;
generating reservoir parameters comprising a reservoir grid based on the wellsite data and the generated fracture parameters;
generating production parameters comprising production rate over time based on the wellsite data and the hydraulic fracture network;
forming a finite element grid from the fracture parameters, the production parameters, and the reservoir parameters by coupling the hydraulic fracture network to the reservoir grid;
generating integrated geomechanical parameters comprising estimated microseismic events based on the finite element grid; and
performing fracture operations and production operations based on the integrated geomechanical parameters.

US Pat. No. 10,920,551

GEOMECHANICAL MODEL OF STRESSES ON AN ORTHORHOMBIC MEDIA

Halliburton Energy Servic...

1. A method for generating a geomechanical model of a formation for use during a subterranean operation, comprising:retrieving a stiffness coefficient matrix for a formation to be fractured;
generating a geomechanical model of the formation based on a set of natural fractures and an anisotropic behavior of the formation;
calculating a maximum horizontal stress of the formation based on the geomechanical model and the stiffness coefficient matrix;
determining a fracture closure pressure of the formation based on the maximum horizontal stress;
drilling a wellbore horizontally through the formation in a direction perpendicular to the maximum horizontal stress of the formation; and
fracturing the formation inside the wellbore with a fracturing fluid, a pressure of the fracturing fluid based on the fracture closure pressure.

US Pat. No. 10,920,550

MICROBIALLY ENHANCED THERMAL OIL RECOVERY

9668241 Canada Inc., Ott...

1. A method for oil recovery in a subsurface of an oil reservoir, the method comprising steps of:(a) utilizing at least one injection well within the subsurface;
(b) utilizing a heat source to heat the subsurface to a temperature that is between above an in situ temperature and an upper limit for microbial life, and stimulate activity of at least one in situ dormant microorganism from a microbial seed bank located in the subsurface to produce a gas pressure within the subsurface; and
(c) utilizing the gas pressure in recovery of subsurface oil through a production recovery well.

US Pat. No. 10,920,549

CREATING FRACTURES IN A FORMATION USING ELECTROMAGNETIC SIGNALS

Saudi Arabian Oil Company...

21. A method of creating fractures in a formation, the method comprising:generating electromagnetic (EM) signals;
directing, via an antenna, the EM signals through an enabler, which is susceptible to heating by the EM signals, to cause a temperature of a formation to increase from a first temperature to a second temperature, the antenna being on a first side of multiple sides of a rotational device;
applying, via a purging system, a cooling agent to the formation to cause the temperature of the formation to decrease from the second temperature to a third temperature, thereby stimulating thermal shock and creating fractures in the formation, the purging system being on a second side of multiple sides of the rotational device, the second side being different than the first side;
heating and cooling the formation, via the antenna and the purging system, multiple times in succession,
removing debris from the wellbore via at least one cleaning nozzle disposed on the rotational device longitudinally above the purging system, and
rotating the rotational device after causing the temperature of the formation to increase and before causing the temperature of the formation to decrease.

US Pat. No. 10,920,548

METHOD AND APPARATUS FOR RIG-LESS DEPLOYMENT OF ELECTRICAL SUBMERSIBLE PUMP SYSTEMS

SAUDI ARABIAN OIL COMPANY...

8. A method for producing hydrocarbons from a subterranean well, the method including:providing a first electrical submersible pump section having an outer motor body, a motor stator, and a central bore, the central bore extending through the outer motor body and sized to accommodate a motor rotor assembly, where the first electrical submersible pump section includes an uphole facing landing shoulder;
securing the first electrical submersible pump section to a downhole production tubing with a downhole ring of the first electrical submersible pump section;
securing the first electrical submersible pump section to an uphole production tubing with an uphole ring of the first electrical submersible pump section;
providing a second electrical submersible pump section having the motor rotor assembly, a seal section, a pump assembly, and a downhole facing mating shoulder, the second electrical pump section being separable from the first electrical submersible pump section;
connecting an installation line to a deployment connector of the second electrical submersible pump section for rig-less installation and removal of the second electrical submersible pump section with the second electrical submersible pump section separated from the first electrical submersible pump section; and
supporting the downward facing mating shoulder with the uphole facing landing shoulder, the uphole facing landing shoulder shaped to allow for relative axial movement of the second electrical submersible pump section relative to the first electrical submersible pump section,
engaging the uphole production tubing with an anchor of the second electrical submersible pump section, preventing relative movement between the second electrical submersible pump section and the uphole production lubing and isolating between input ports and discharge of the pump assembly.

US Pat. No. 10,920,547

SYSTEMS AND METHODS FOR KILLING WELLS EQUIPPED WITH JET PUMPS

HANSEN DOWNHOLE PUMP SOLU...

1. A wellbore pump system, comprising:at least one jet pump disposed in a tubular string inserted into a subsurface wellbore, an inlet of the at least one jet pump in fluid communication with a subsurface reservoir, a discharge of the at least one jet pump in fluid communication with an interior of the tubular string; and
a first fluid bypass fluidly connecting the inlet and discharge of the at least one jet pump, the fluid bypass operable to enable fluid flow when a differential pressure of fluid pumped into the tubular string from the surface exceeds a predetermined pressure, the first fluid bypass comprising a control valve operable to close fluid flow in a first direction and to open fluid flow in a direction opposed to the first direction when a pressure differential exceeds the predetermined pressure.

US Pat. No. 10,920,546

APPARATUS AND METHODS FOR OPERATING GAS LIFT WELLS

Weatherford Technology Ho...

1. A method of operating an intermittent gas lift system operable to inject lift gas into a wellbore for hydrocarbon production, comprising:causing, by a processing system proximate to the wellbore, injection of the lift gas into the wellbore at a first gas injection rate;
obtaining, by the processing system, a first indication of a first casing pressure associated with the wellbore;
determining, by the processing system, a first period to inject the lift gas with the intermittent gas lift system based on the first gas injection rate, a depth of the wellbore, and the first casing pressure; and
operating, by the processing system, the intermittent gas lift system according to the determination, wherein the operating comprises causing stopping of the injection of the lift gas at the end of the first period.

US Pat. No. 10,920,544

SETTING TOOL IGNITER SYSTEM AND METHOD

GEODYNAMICS, INC., Mills...

17. A method for assembling a downhole system comprising:placing an igniter system into an adapter;
placing an igniter switch into the adapter;
electrically connecting the igniter system to the igniter switch through a wall opening formed in the adapter;
placing a pressure sealing bulkhead element into a switch sub;
electrically connecting the pressure sealing bulkhead element to the igniter switch;
placing a gun detonator and a gun switch inside the switch sub;
electrically connecting the gun switch to the gun detonator and the pressure sealing bulkhead element; and
attaching the adapter to the switch sub,
wherein wires from the gun detonator do not extend past the switch sub and wires from the igniter system do not extend past the adapter.

US Pat. No. 10,920,543

SINGLE CHARGE PERFORATING GUN

DynaEnergetics Europe Gmb...

1. A perforating gun assembly, comprising:a single-charge positioning device, comprising:
a detonator holder portion; and
a shaped charge holder portion positioned adjacent to the detonator holder portion, wherein the shaped charge holder portion comprises
a shaped charge receptacle including a plurality of retention mechanisms extending from a portion of the shaped charge receptacle and engaged with a surface of a shaped charge, and
a frame including arms extending around the shaped charge and under a base of the shaped charge;
a detonator positioned within the detonator holder portion, the detonator comprising an electrically conductive portion;
a shaped charge positioned in the shaped charge holder portion, the shaped charge comprising an electrically conductive casing; and
a spring positioned between the electrically conductive portion of the detonator and the electrically conductive shaped charge casing, such that the spring electrically connects the detonator to the shaped charge casing.

US Pat. No. 10,920,542

PERFORATOR HAVING MOVABLE CLUSTERS OF PERFORATOR GUNS

Halliburton Energy Servic...

17. A method comprising:lowering a perforator tool down a wellbore to a perforating position, wherein the perforator tool comprises a first cluster of perforator guns in a closed position at a first axial position and a second cluster of perforator guns in the closed position at a second axial position; and
in response to the perforator tool being lowered to a perforator position in the wellbore,
moving the first cluster of perforator guns from the closed position to an expanded position;
moving the second cluster of perforator guns from the closed position to the expanded position;
moving the first cluster axially such that the first cluster and the second cluster at least partially overlap; and
perforating the wellbore based on detonation of the first and second cluster of perforator guns.

US Pat. No. 10,920,541

PERFORATING DEVICE

Halliburton Energy Servic...

7. A method of perforating a wellbore target, the method comprising:connecting a conveyance mechanism with a service rig positioned over a well;
connecting at least one perforating device to the conveyance mechanism, the perforating device comprising:
a center member having a length;
an expansion tool positioned about the center member along at least a portion of the length; and
a plurality of perforating guns positioned about the expansion tool, each of the plurality of perforating guns carrying one or more explosive shaped charges;
wherein the expansion tool is configured to move the plurality of perforating guns radially outward toward the wellbore target of a wellbore it is configured to be positioned within; and
wherein the expansion tool includes a plurality of substantially parallel fingers having the plurality of perforating guns positioned at distal ends thereof, the plurality of substantially parallel fingers configured to expand outward to move the plurality of perforating guns radially outward toward the wellbore target
conveying the at least one perforating device into the well;
moving the plurality of guns radially outward toward the wellbore target; and
detonating the explosive shaped charges of the plurality of perforating guns.

US Pat. No. 10,920,540

REDUCING NOISE PRODUCED BY WELL OPERATIONS

Halliburton Energy Servic...

1. A method for reducing noise produced by a well operation, the method comprising:obtaining a list of equipment for the well operation;
for engines of a combination of equipment indicated in the list of equipment, obtaining mappings between engine speeds, loads;
and noise;
selecting engine speeds for the engines of the combination of equipment to minimize the noise produced by the combination of equipment based, in part, on the mappings; and
adjusting the engines to operate at the selected engine speeds.

US Pat. No. 10,920,538

METHOD INTEGRATING FRACTURE AND RESERVOIR OPERATIONS INTO GEOMECHANICAL OPERATIONS OF A WELLSITE

Schlumberger Technology C...

1. A method of performing oilfield operations at a wellsite, the wellsite positioned about a subterranean formation having a wellbore therethrough and a fracture network therein, the fracture network comprising natural fractures, the method comprising:generating fracture parameters comprising a hydraulic fracture network based on wellsite data comprising a mechanical earth model;
generating reservoir parameters comprising a reservoir grid based on the wellsite data and the generated fracture parameters;
forming a finite element grid from the fracture parameters and the reservoir parameters by coupling the hydraulic fracture network to the reservoir grid;
generating integrated geomechanical parameters comprising estimated microseismic events based on the finite element grid; and
performing fracture operations and production operations based on the integrated geomechanical parameters.

US Pat. No. 10,920,537

SHROUD ASSEMBLY

Weatherford Technology Ho...

1. A shroud assembly, comprising:two semi-cylindrical covers having a connector at each end;
a plurality of receiver rings for supporting the covers and engaging the connector; and
an extender ring coupled to a base ring, and configured to move a first receiver ring of the plurality of receiver rings axially relative to the base ring toward a second receiver ring of the plurality of receiver rings.

US Pat. No. 10,920,536

METHODS AND SYSTEMS FOR DESIGNING DRILLING SYSTEMS

Schlumberger Technology C...

1. A method for designing a physical component of a drilling system, the method comprising:defining, using a computer processor, input parameters of a first primitive in the drilling system, the input parameters comprising at least one control relationship between a first control point on the first primitive and a second control point on a second primitive,
wherein the control relationship includes both of status and dynamic relationships and define the degrees of freedom between the first control point on the first primitive and the second control point on the second primitive,
wherein each of the first primitive and the second primitive:
has a general shape of a drilling component for a drilling system;
is defined by the control relationships between elements of the general shape of the primitive and;
lacks a design specification, including at least a material selection for the primitive;
providing a drilling design tool to define the control relationships for the first primitive and the second primitive;
simulating, by the computer processor, the drilling system with the first primitive to obtain a performance parameter of the first primitive without simulating any design in any design specification, wherein simulating the drilling system is a transient time simulation comprising modeling performance of drilling operations of the first primitive based on at least one of time and incremental rotation of the drilling system;
wherein the first primitive and the second primitive are retrieved from a primitive library that stores a plurality of stored primitives,
designing, based on the performance parameter and after simulating the first primitive, the physical component for the drilling system to obtain a physical component design, the physical component having the input parameters of the first primitive and the design specification;
simulating the physical component of the drilling system using the physical component design; and
storing the physical component design.

US Pat. No. 10,920,535

INJECTION METHOD FOR HIGH VISCOSITY DRY FRICTION REDUCER TO INCREASE VISCOSITY AND PUMP EFFICIENCY

Halliburton Energy Servic...

1. A method of placing a slurry stream comprising dry friction reducer (DFR) into a subterranean formation penetrated by a wellbore, the method comprising:forming a slurry comprising an aqueous-based fluid and a proppant, wherein forming the slurry comprises introducing a dry material comprising the proppant and the aqueous-based fluid into a slurry blender;
forming a slurry stream comprising DFR by:
(a) forming a DFR concentrate by combining DFR with an amount of water; adding the DFR concentrate into the slurry in the slurry blender, whereby the DFR concentrate is introduced into a location within the slurry blender distant a location at which the dry material is added thereto, wherein adding the DFR concentrate into the slurry in the slurry blender at the distant location comprises adding the DFR into the slurry blender via a line at or near a bottom thereof; and removing the slurry stream comprising DFR from the slurry blender;
(b) forming a DFR concentrate by combining DFR with an amount of water; removing a slurry stream from the slurry blender; and adding the DFR concentrate into the slurry stream to provide the slurry stream comprising DFR;
(c) introducing DFR, in dry powder form, into the slurry blender and removing the slurry stream comprising DFR from the slurry blender; or
(d) a combination of (a), (b), and/or (c); and
introducing the slurry stream comprising DFR into the formation via the wellbore.

US Pat. No. 10,920,534

METHOD FOR ADJUSTING THE LEVEL OF INHIBITORS IN AN OIL OR GAS WELL

TOTAL SA, Courbevoie (FR...

1. A method for adjusting to a predetermined value an amount of an inhibitor selected from the group consisting of a mineral deposition inhibitor and a corrosion inhibitor injected into a gas or oil well, comprising the following successive steps:tagging the inhibitor with a lanthanide, said tagging of the inhibitor being carried out (i) by grafting, on a skeleton of the inhibitor, a molecule complexing the lanthanide; or (ii) via complexation of the lanthanide with the inhibitor;
extracting a fluid from a production well;
detecting and quantifying the tagged inhibitor, via time-resolved fluorescence, in the fluid extracted from the production well, wherein the time-resolved fluorescence is performed by applying a delay, referred to as integration delay, between the excitation of the sample to be analysed and the measurement of the signal emitted, said integration delay being between 0.001 and 10 ms; and
if the amount of the tagged inhibitor does not meet the predetermined value, injecting into the well an additional quantity of the inhibitor to reach said predetermined value,
wherein the mineral deposition inhibitor is selected from the group consisting of polyphosphates, organophosphonates, carboxylic polyacides, polymers with a sulphonic acid function, polyphosphinocarboxylic acid (PPCA), sulphonated polyphosphinocarboxylic acid (PPCA), polyethyleneimine, silicone polymers functionalised by amine groups, and copolymers made from quaternary ammonium,
or wherein the corrosion inhibitor is selected from the group consisting of cyclohexylamine, hexylamine, morpholine, octadecylamine, diethylaminoethanol and betaines.

US Pat. No. 10,920,533

METHOD AND APPARATUS FOR WASHING AN UPPER COMPLETION

CONOCOPHILLIPS COMPANY, ...

1. A process for washing a wellbore, the process comprising:a) passing a drill string, including a reservoir liner hanger running tool, down a wellbore having a casing, to install a reservoir liner in an uncased distal portion of the wellbore;
b) displacing cement into an annulus around the reservoir liner by passing completion fluid through the drill string and reservoir liner;
c) without first removing the drill string from the wellbore, performing an inflow test on the reservoir liner; and
d) washing an interior of the casing by passing wash fluid through the drill string and into the casing, while rotating the drill string.

US Pat. No. 10,920,532

SQUEEZE PACKER AND METHOD OF SETTING A SQUEEZE PACKER

Coretrax Technology Limit...

17. A method of injecting a fluid into a wellbore of an oil, gas or water well through an elongate member, the method comprising:deploying a squeeze packer into the wellbore, the squeeze packer comprising:
a body with a bore, at least one anchoring member actuable between active and inactive configurations in response to changes in fluid pressure, and wherein in the active configuration, the anchoring member is adapted to anchor the body in the wellbore to resist axial movement of the body in the wellbore, and a sealing member adapted to seal an annulus between the body and an inner surface of the wellbore;
a stinger adapted for connection to the elongate member for injection of a fluid through the packer, the stinger being releasably latched onto the body; and
a valve selectively actuable to open and close the bore to allow and prevent fluid passage through the body, wherein the valve controls passage of pressurised fluid to the anchoring member to actuate the anchoring member between inactive and active configurations;
the method including:
anchoring the squeeze packer in the wellbore and sealing the annulus between the body and the inner surface of the wellbore;
releasing the stinger from the packer by rotation of the elongate member in a direction opposite to the direction of rotation used to disconnect the threaded couplings making up the elongate member, and
moving the stinger axially within the body to actuate the valve between different actuation configurations;
wherein the anchoring member comprises first and second sets of slips and wherein the first set of slips is set by hydraulic pressure before the second set is set mechanically by exerting an axial force on the elongate member.

US Pat. No. 10,920,531

WELLBORE ISOLATION WHILE PLACING VALVES ON PRODUCTION

SCHLUMBERGER TECHNOLOGY C...

1. An apparatus, comprising:a production liner installed within a wellbore extending from the Earth's surface into a subterranean formation, wherein the production liner comprises a plurality of casing valves each comprising a port and a closure member slidingly engaged within the casing valve and moveable between a closed-port position, in which the closure member interrupts fluid communication between the production liner and the subterranean formation proximate the port, and an open-port position, in which fluid communication is permitted between the production liner and the subterranean formation proximate the port; and
an internal completion string installed within the production liner and comprising:
at least one packer extendable from the internal completion string into sealing engagement with the production liner; and
a plurality of shifting tools, each shifting tool comprising:
an interface member operable to impart linear motion to the closure member;
an actuator operable to impart linear motion to the interface member; and
at least one anchor extendable from the internal completion string into sealing engagement with the production liner, the at least one anchor expandable to stabilize the internal completion string relative to the production liner,
wherein the plurality of shifting tools are configured to be remotely operated to selectively open or close each casing valve without mechanically moving the internal completion string to a different location in the production liner.

US Pat. No. 10,920,530

SYSTEM AND METHOD FOR COMPLETING AND STIMULATING A RESERVOIR

SCHLUMBERGER TECHNOLOGY C...

1. A system for efficiently frac packing a tight reservoir formation, comprising:a zonal fracture and flow system comprising:
a zonal frac and flow valve;
a polished bore receptacle;
a first casing joint located between the zonal frac and flow valve and the polished bore receptacle;
a tip valve assembly;
a tip locating assembly,
wherein the tip valve assembly and the tip locating assembly are disposed within the polished bore receptacle;
a second casing joint positioned above the polished bore receptacle; and
a resettable shifting assembly,
wherein the resettable shifting assembly is disposed within the second casing joint,
wherein the zonal frac and flow valve comprises a combined screen and sleeve, the combined screen and sleeve comprising a screen carried on an outer surface of a sleeve,
wherein the combined screen and sleeve serves as a valve through which fracturing fluid flows outwardly during a stimulation procedure,
wherein, during a production procedure, production fluid flows from the formation, through the screen and across the outer surface of the sleeve of the combined screen and sleeve, and upward through the zonal frac and flow valve,
wherein the tip valve assembly controls a change in flow path from a frac port to a reverse port by manipulating a tip valve closing sleeve,
wherein the tip locating assembly controls a position of a stimulation tip by using weight indications to track the position of the stimulation tip,
wherein the tip locating assembly allows for a weight down mode to maintain the position and configuration of the tip valve assembly with respect to frac and reverse positions,
wherein the resettable shifting assembly is configured to shift sleeves having a mating profile.

US Pat. No. 10,920,529

SURFACE CONTROLLED WIRELINE RETRIEVABLE SAFETY VALVE

1. A surface-controlled wireline-retrievable safety valve comprising:a seat housing comprising a plurality of flow ports and configured to house a hard-seat;
a closure device comprising a plurality of equalization ports, wherein the closure device is disposed within the seat housing and is configured to controllably move off the hard seat and expose the plurality of flow ports to a central lumen of the safety valve under hydraulic actuation;
a power piston comprising a shoulder portion, wherein the power piston is attached to the closure device and the shoulder portion is disposed within a hydraulic chamber housing forming a differential area;
a hydraulic actuation port configured to receive hydraulic actuation fluid from a surface pump; and
a hydraulic passage configured to convey the hydraulic actuation fluid from the hydraulic actuation port to the differential area via a hydraulic access port,
wherein, under hydraulic actuation, prior to the closure device moving off the hard seat, production fluids entering the plurality of flow ports cause a metal-to-metal seal of the closure device to open allowing at least one of the plurality of equalization ports of the closure device to equalize hydraulic pressure across the closure device while the closure device is still on the hard seat, and
wherein, under hydraulic actuation, hydraulic fluid in the differential area causes the power piston to compress a power spring and move the closure device off the hard seat exposing the plurality of flow ports to the central lumen of the safety valve.

US Pat. No. 10,920,528

PRESSURE RESPONSE FRACTURE PORT TOOL FOR USE IN HYDRAULIC FRACTURING APPLICATIONS

Watson Well Solutions, LL...

1. A method for detecting when a fracture zone of interest is opened and exposed to a wellbore, the method making use of a fracture port tool, the fracture port tool including a sliding sleeve residing within an outer housing and arranged to move in response to fluid pressure between a first, a second, and a third position relative to a first and a second set of flow ports, a first fluid medium affecting a rate of travel between the first and second positions and a second fluid medium different than the first fluid medium affecting a rate of travel between the second and third positions, the method comprising:creating a first well fluid pressure within the fracture port tool;
creating a second well fluid pressure within the fracture port tool by allowing a portion of the well fluid to exit the fracture port tool and become exposed to the well bore;
creating a third well fluid pressure within the fracture port tool by allowing an additional portion of the well fluid to exit the fracture port tool and become exposed to the well fluid;
wherein the second pressure is greater than the first and third pressures; and
detecting the second well fluid pressure as a pressure increase when the first set of flow ports is exposed to the well bore; and
detecting the third well fluid pressure as a pressure decrease when the second set of flow ports is exposed to the well bore.

US Pat. No. 10,920,527

DOWNHOLE ELECTRONIC TRIGGERING AND ACTUATION MECHANISM

1. A triggering mechanism for oilfield wellbore downhole equipment, comprising;a housing for inserting downhole in an oilfield wellbore and associating with a downhole tool in a predetermined and desired position within said oilfield wellbore;
said housing further for associating there within a computer processor, a clock, at least one sensor circuit, and an electrical power source;
said computer processor comprising computer processing circuitry for processing executable instructions associated with a plurality of physical parameters within said oilfield wellbore, said computer processor further comprising at least one computer memory circuit comprising a computer readable memory circuit for storing said executable instructions and data associated with said plurality of physical parameters;
said clock comprising circuitry for providing timing data to said computer processor;
said at least one sensor circuit for sensing said plurality of physical parameters within said oilfield wellbore and generating and communicating said data associated with said plurality of physical parameters, said plurality of physical parameters comprising at least a pressure parameter associated with the pressure within said oilfield wellbore downhole environment; and
said electrical power source comprising circuitry for powering said computer processor downhole within said oilfield wellbore;
a valve control circuit for receiving a plurality of valve control commands from said computer processor for controlling a valve, wherein said valve control commands control a valve associated with a flow path flowing a control fluid;
a valve operating in response to said valve control commands and in response thereto controlling flow of said control fluid from said flow path to an associated mechanical actuating device within said oilfield wellbore, said mechanical actuating device operating in association with said downhole tool within said oilfield wellbore;
wherein said valve control commands derive from real-time sampling of said downhole physical parameters; and further
wherein, in response to said real-time sampling of said downhole physical parameters said computer processor generates a plurality of ratio-based derivative values relating to physical parameter differences over a predetermined time span within said downhole wellbore environment; and
in response to said plurality of ratio-based derivative values relating to said physical parameter differences generating triggering commands to said valve for flowing said control fluid to said associated mechanical actuating device for actuating said associated mechanical actuating device from a first condition or status to a second condition or status.

US Pat. No. 10,920,526

DOWNHOLE INTERVENTIONLESS TOOLS, SYSTEMS, AND METHODS FOR SETTING PACKERS

Halliburton Energy Servic...

1. A hydraulic setting tool for setting a packer, comprising:a mandrel comprising a main flow path;
a piston housing surrounding at least a portion of the mandrel;
a piston disposed between the piston housing and the portion of the mandrel, wherein the piston, the piston housing, and the portion of the mandrel define a cavity disposed therebetween;
a port passing through the mandrel and configured to provide fluid communication between the main flow path and the cavity;
an isolation sleeve located within the mandrel and movable along the main flow path between a closed position and an opened position to control the fluid communication between the main flow path and the cavity via the port, wherein the hydraulic setting tool is configured to set the packer when the isolation sleeve shifted to the open position; and
a remotely activated valve located downstream from the isolation sleeve within the main flow path, the remotely activated valve adjustable, between an open position and a closed position and activated by a trigger based on temperature, pressure, flow rate, time, or combinations thereof, and the remotely activated valve actuable to reduce or cease flow through the remotely activated valve to increase pressure within the main flow path uphole of the remotely activated valve to shift the isolation sleeve from the closed position to the opened position.

US Pat. No. 10,920,525

SELF CALIBRATING TOE VALVE

TCO AS, Bergen (NO)

19. A method of opening a toe valve comprising;a housing having an interior and exterior,
a sliding sleeve,
a counter mechanism comprising:
a cylinder,
a ratchet piston with first and second ends, and
a ratchet shaft connected to the second end,
a trigger assembly comprising:
a trigger housing, and
a release piston, wherein
the trigger assembly is arranged between the counter mechanism and the sliding sleeve, and wherein the toe valve further comprises:
a closed chamber enclosing the ratchet shaft and defined at least partly by the cylinder comprising a chamber fluid with a chamber pressure,
an inlet pressure port configured to be in communication with a wellbore fluid with a wellbore pressure, and wherein the first end of the ratchet piston is in fluid communication with the inlet pressure port,
a retaining mechanism, and
a valve mechanism interconnecting the first and second ends of the ratchet piston, the method comprising the steps of;
activating the counter mechanism, wherein the activation of the counter mechanism comprising the steps of;
a) increasing wellbore pressure at the inlet pressure port to push the ratchet piston towards the trigger assembly whereby the ratchet piston compresses the fluid in the closed chamber, and to move the ratchet shaft is to a new position,
b) retaining the ratchet shaft in the new position by the retaining mechanism;
c) continue increasing wellbore pressure;
d) decreasing the wellbore pressure lower than chamber pressure;
e) open the valve mechanism to equalize pressure across the ratchet piston by releasing fluid from the closed chamber;
f) repeating steps a) to e) until the ratchet shaft engages with the activation pin and forces the activation pin from its position towards the release piston;
activating the trigger assembly, wherein the activation of the trigger assembly comprising the steps of;
pushing the release piston with the activation pin towards the first atmospheric chamber, thereby increasing the pressure in the atmospheric chamber; and
pushing the sliding sleeve away from the at least one frack port towards the second atmospheric chamber with the release piston.

US Pat. No. 10,920,524

OPTIMIZED COMPOSITE DOWNHOLE TOOL FOR WELL COMPLETION

CCDI Composites, Inc., S...

12. A method of manufacturing a sub-assembly for use with a frac plug or bridge plug system comprising the steps:forming a first structural component with a body from a first composite material;
forming a second component by molding a body from a second composite material;
wherein the first structural component has a tapered surface section adjacent a first open end with a first outer diameter;
wherein a second outer diameter at a second open end is larger than the first outer diameter; and
wherein the sub-assembly has a bore extending between a first end and a second end, and wherein the bore of the sub-assembly is formed by both the body of the first structural component and the body of the second component.

US Pat. No. 10,920,523

BALL DROP WIRELINE ADAPTER KIT

INNOVEX DOWNHOLE SOLUTION...

17. A method for actuating a plug in a wellbore, comprising:running a wireline adapter kit and the plug into the wellbore, wherein an inner sleeve of the wireline adapter kit is coupled to a mandrel of the plug as the wireline adapter kit and the plug are run into the wellbore, and wherein a first retainer is positioned at least partially within the inner sleeve and prevents an impediment in the inner sleeve from passing therethrough and into the plug when a force on the impediment is less than a predetermined amount;
setting the plug in the wellbore using the wireline adapter kit;
decoupling the inner sleeve from the mandrel after the plug is set, which allows a second retainer in the inner sleeve, the mandrel, or both to actuate from a first position that prevents the impediment from passing through the first retainer to a second position that allows the impediment to pass through the first retainer; and
increasing a pressure differential across the impediment after the wireline adapter kit is decoupled from the plug, thereby causing force on the impediment to exceed the predetermined amount such that the impediment passes through the first retainer and into the plug.

US Pat. No. 10,920,522

ROTATING AND RECIPROCATING SWIVEL APPARATUS AND METHOD

10. A method of creating a rotating and reciprocating swivel tool while located on a drilling rig or platform, comprising the steps of:(a) providing a swivel tool, the swivel tool comprising a mandrel and a sleeve surrounding the mandrel, the sleeve having a generally cylindrical portion with an exterior sealing surface, said sleeve having a cavity and upper and lower end portions, an interior volume between the mandrel and sleeve which is sealed by a pair of spaced apart sealing units, each end portion having a wiper cavity with a wiper, the mandrel being rotatable and reciprocable relative to the sleeve, the mandrel extending into the cavity and having a first stroke length relative to the sleeve;
(b) lowering the swivel tool in a riser and towards a blowout preventer and wellbore, and supporting an upright orientation swivel tool;
(c) repeating step “b” until the final stroking length of the mandrel relative to the sleeve is at least 100 feet; and
(d) detachably connecting the exterior sealing surface of the sleeve to a seal of the blowout preventer, wherein the seal of the blowout preventer can be selectively closed on the exterior sealing surface of the sleeve, and while the seal is closed and forms a seal against the exterior sealing surface of the sleeve and separates upper and lower volumetric sections of fluid, the upper volumetric section being located in the riser above the blowout preventer and the lower volumetric section being located in the wellbore below the blowout preventer, wiping the mandrel with one or both of the wipers to prevent debris from damaging the upper and/or lower sealing units.

US Pat. No. 10,920,521

SELF-CONTAINED WELL INTERVENTION SYSTEM AND METHOD

Saudi Arabian Oil Company...

1. An end cap for sealed attachment to a well tree that is coupled to a wellhead and is configured for a well intervention application comprising:a cap body having a first closed end and an opposite open end that is for sealingly being coupled to one end of the well tree for closing off the well tree and includes a hollow interior;
a rotatable winch that is disposed within the hollow interior and about which a first cable can be wound; and
the winch being coupled to an external part that is configured to rotate the winch and is located external to the cap body;
wherein the first closed end is defined by a top wall that includes a first through hole for receiving a second cable from within the hollow interior and permit routing of the second cable to a location exterior to the cap body;
wherein a load cell is disposed within the hollow interior and is configured to measure tension on the first cable, the second cable being operatively coupled to the load cell and being rotated through the through hole to the exterior of the cap body.

US Pat. No. 10,920,519

BLOW OUT PREVENTER BONNET HANDLING APPARATUS AND METHOD

1. A blow out preventer bonnet removal method for removing a bonnet from a body of a blow out preventer, comprising the steps of:a) attaching a rail system to the body that extends laterally away from the body;
b) mounting a carriage apparatus to the rail system;
c) connecting a saddle assembly to the bonnet;
d) detaching the bonnet from the body after step “c”;
e) moving the bonnet from a first position next to the body to a second position spaced away from the body wherein the carriage apparatus transports the bonnet upon the rail system; and
f) wherein step “e” includes ratcheting the carriage apparatus relative to the rail system.

US Pat. No. 10,920,518

METHOD AND ARRANGEMENT FOR REMOVING A LINER BELOW SURFACE

CALLIDUS CAPITAL B.V., H...

1. A method of removing a liner of a well, the liner comprising a liner material, the method comprising:Providing an oxidiser holding module in the well for defining a first boundary of a removal space, the space being delimited by at least the oxidiser holding module transverse of the liner and the liner;
Providing oxygen or an oxygen releasing compound in the space;
Providing an ignition module for igniting the liner material inside the space; and
Activating the ignition for igniting the liner material.

US Pat. No. 10,920,517

VIBRATION-INDUCED INSTALLATION OF WELLBORE CASING

Saudi Arabian Oil Company...

1. A method of installing a casing string into a wellbore, the method comprising:while running a casing string to a target depth within a wellbore, an annulus defined between the casing string and the wellbore, reducing a coefficient of friction between the casing string and the wellbore by inducing a vibration within the casing string by activating a vibration inducing device positioned within the casing string, a closed fluid bypass channel positioned within the vibration inducing device;
flowing a fluid through the casing string, the fluid passing through the vibration inducing device, the closed fluid bypass channel closed to flow of the fluid through the fluid bypass channel;
in response to an increase in a differential pressure of the fluid resulting from an increased flow of the fluid within the casing, opening the fluid bypass channel, wherein at least a portion of the fluid flows through the opened fluid bypass channel and a remainder of the fluid flows through the vibration inducing device causing a change in the vibration induced within the casing string; and
flowing the fluid through the annulus while the casing string vibrates at the changed vibration induced within the casing string.

US Pat. No. 10,920,516

DEVICE AND METHOD FOR COLLECTING DEBRIS OF DEPOSITS IN A WELLBORE

Blue Spark Energy Inc., ...

1. An assembly for removing deposits from a wellbore wall or an equipment arranged in a wellbore of a subterranean formation and for collecting debris of said deposits, said assembly comprising:a cleaning device comprising an electrical discharge generating device configured for generating electrical discharges that propagate shock waves for removing deposits from said wellbore wall or said equipment, said electrical discharge generating device comprising a rod for mounting the collecting device;
a collecting device attached below said cleaning device via said rod in order to collect debris from deposits removed by the cleaning device;
said collecting device comprising:
a deflector configured for deflecting falling debris of deposits while said deposits are being removed from said wellbore wall or said wellbore equipment; and
a debris storing module connected to said deflector and configured for collecting and storing debris deflected by said deflector, said debris storing module comprising at least one tubular section, each tubular section comprising a plurality of slots;
said deflector comprising:
a tubular portion comprising a first end connected to the debris storing module and a second end configured for collecting debris, said tubular portion being adapted to convey debris from said second end into the debris storing module through said first end;
a connecting shaft mounted on the second end of the tubular portion and attaching the collecting device to the rod of the electrical discharge generating device;
a plurality of wings delimiting openings for reinforcing said deflector and for guiding debris into said openings into the tubular portion; and
an unloading plug connected to the debris storing module and being configured for switching between a first position in which the unloading plug prevents the debris stored in the debris storing module to leave said debris storing module and a second position in which the unloading plug allows the debris stored in the debris storing module to leave said debris storing module.

US Pat. No. 10,920,515

DEVICE AND METHOD FOR RETRIEVING A RESTRICTION ELEMENT FROM A WELL

GEODYNAMICS, INC., Mills...

1. A setting tool for setting a plug in a well, the setting tool comprising:a body extending along a longitudinal axis X;
a rod extending along the longitudinal axis of the body, from an upstream end to a downstream end of the body;
a chamber formed at the downstream end of the body; and
a ball located in the chamber and configured to move freely inside the chamber,
wherein the rod extends through the entire chamber and the ball is located between the rod and a wall of the chamber, and
wherein the rod has a first portion having a first diameter, a second portion having a second diameter, and a third portion having a third diameter, the second diameter is larger than the first diameter, and the third diameter is larger than the second diameter.

US Pat. No. 10,920,514

HYDRAULIC PACKER SETTING TOOL WITH ANTI-PRESET FEATURE

HALLIBURTON ENERGY SERVIC...

12. A method, comprising:conveying a completion assembly into a wellbore, the completion assembly being operatively coupled to a work string with a completion running tool and a wellbore packer, wherein the completion running tool includes:
a body coupled to the work string at a first end and coupled to the wellbore packer at a second end, the body defining a central flow passage in fluid communication with the work string and further defining one or more radial flow ports;
a piston coupled to the body at a releasable coupling and positioned for longitudinal movement within a piston chamber defined radially between the body and an outer shroud; and
a prop sleeve positioned in the central flow passage and defining one or more apertures, the prop sleeve being movable between a first position, where the prop sleeve radially supports the releasable coupling and thereby prevents disengagement of the piston, and a second position, where the piston is able to disengage from the releasable coupling and move within the piston chamber;
circulating a fluid through the central flow passage and into a piston setting chamber via the one or more apertures and the one or more radial flow ports while conveying the completion assembly into the wellbore;
landing a wellbore projectile on a seat provided on an expandable ring positioned within the prop sleeve;
increasing a fluid pressure of the fluid to a first pressure and thereby moving the prop sleeve to the second position;
increasing the fluid pressure of the fluid to a second pressure and thereby disengaging the piston from the releasable coupling and moving the piston within the piston chamber; and
actuating the wellbore packer as the piston moves within the piston chamber,
wherein a packer setting arm is positioned axially adjacent the piston and operatively coupled to the wellbore packer, and wherein actuating the wellbore packer as the piston moves within the piston chamber comprises engaging the packer setting arm with the piston and thereby moving the packer setting arm as the piston moves.

US Pat. No. 10,920,513

COMPOSITE PERMANENT PACKER SPACER SYSTEM

Halliburton Energy Servic...

9. A method of closing off perforations in a well comprising:lowering a downhole tool into the well, the downhole tool comprising:
a mandrel having a flow passage;
a first sealing assembly disposed about the mandrel and moveable from an unset to a set position in which the first sealing assembly engages the well;
a second sealing assembly disposed about the mandrel and longitudinally spaced from the first sealing assembly, the second sealing assembly being moveable from an unset to a set position in which the second sealing assembly engages the well; and
a settable material disposed in the mandrel flow passage, wherein the settable material comprises a two component settable material, the first and second components being positioned in the mandrel flow passage, and wherein both the first and second components are pumpable into the annulus and will set upon being mixed;
positioning the first sealing assembly above the perforations to be closed off;
positioning the second sealing assembly below the perforations to be closed off; and injecting the settable material into a space between the first and second sealing assemblies.

US Pat. No. 10,920,512

SUBMERSIBLE PUMP SUPPORT ROD STABILIZING DEVICE

1. A submersible pump support rod stabilizing device, comprising: a submersible pump, an upper support rod, a lower support rod, profiled gaskets, ordinary gaskets, screw caps, upper support rod bends, lower support rod bends, upper support rod ends, lower support rod ends, upper support rod end circular rings, lower support rod end circular rings, inclined edges, a rope, a pulley and pull cords, wherein on an upper portion of one side and on a lower portion of the other side of the submersible pump are respectively provided screw rods fixed to a pump body and the upper support rod and the lower support rod rotationally connected to the screw rods through middle holes thereof; at portions close to their two ends, the upper and lower support rods are respectively provided with bends which bend towards the side of the submersible pump, with center lines of the upper and lower support rods as references, till meeting planes which are parallel to straight middle portions of the upper and lower support rods and which pass through a center line of the submersible pump, and then bend outwards along the planes to form a small segment of rod end respectively, which segment has a circular ring welded and fixed thereon; at end portions, all the rod ends are provided with respective inclined edges in the vertical direction, wherein all the upper and lower support rod ends on one side of the submersible pump are lower, and the inclined edges thereon are inclined in an obliquely upward direction relative to the upper and lower support rod ends, while all the upper and lower support rod ends on the other side are higher, and the inclined edges thereon are inclined in an obliquely downward direction relative to the upper and lower support rod ends; two ends of the rope are respectively fixed to the circular rings on the rod ends of the upper and lower support rods on a side of the submersible pump where all the rod ends are lower; the rope is provided with the pulley and is arranged in a pulley rim on a pulley spindle; an end of one pull cord passes through a center hole of the pulley spindle and is self-tied upwards and fixed thereby, so that when the pull cord is pulled upwards via the pulley, and the other end of the pull cord is fixed at the mouth of a well, the inclined edges on the rod ends of the upper and lower support rods respectively push against a well wall, thus stabilizing the submersible pump; one end of the other pull cord is fixed to the circular ring on the rod end of the lower support rod on the other side of the submersible pump where all the inclined edges of the rod ends are higher, and the pull cord is again knotted and fixed on the ring on the end of the upper support rod, at a position slightly further than the distance from the circular ring on the rod end of the lower support rod to the circular ring on the rod end of the upper support rod, on the side of the submersible pump, so that when the pull cord is pulled upwards, the inclined edges on the rod ends of the upper and lower support rods are respectively disengaged from the well wall to release the submersible pump, and the pull rope is further pulled so that the submersible pump is lifted out of the well.

US Pat. No. 10,920,511

TOOL POSITIONING DEVICES FOR OIL AND GAS APPLICATIONS

Saudi Arabian Oil Company...

1. A positioning device for adjusting a vertical position of a tool within a wellbore, the positioning device comprising:an anchor configured for attachment to the wellbore at a fixed vertical location within the wellbore;
a shaft coupled to the anchor;
a coupling member to which the tool is attached, the coupling member configured to be translated along the shaft to adjust the vertical position of the tool with respect to the fixed vertical location of the anchor within the wellbore; and
a housing that carries the anchor,
wherein the housing defines a first fluid chamber located between the anchor and the coupling member, and wherein the coupling member defines an interior region that provides a second fluid chamber that is fluidically coupled to the first fluid chamber.

US Pat. No. 10,920,510

DOWNHOLE ANCHOR

WEATHERFORD U.K. LIMITED,...

1. An anchoring apparatus for use in an openhole wellbore having a wall, the anchoring apparatus comprising:a mandrel having an uphole end and a downhole end, the mandrel having external recesses defined on an outer surface of the mandrel;
at least one movable wall engaging member configured to engage the wall of the openhole wellbore;
at least one lower sleeve located downhole relative to the at least one moveable wall engaging member and configured to contact the at least one movable wall engaging member at or near an upper end of the at least one lower sleeve; and
at least one actuating member located uphole relative to the at least one moveable wall engaging member and configured to move downwardly downhole and longitudinally relative to the mandrel, for moving the at least one movable wall engaging member from a retracted position to an expanded position;
wherein the at least one movable wall engaging member is movable from the retracted position to the expanded position to engage the wall,
wherein the at least one lower sleeve is detachably connected to a connector disposed between the at least one lower sleeve and the mandrel, the connector having internal protrusions engaged with the external recesses of the mandrel,
wherein the at least one lower sleeve is held stationary by the connector relative to the mandrel during deployment of the at least one movable wall engaging member from the retracted position to the expanded position,
wherein the at least one lower sleeve is configured to detach from the connector and is configured to release the at least one movable wall engaging member from the expanded position to the retracted position to disengage the wall, and
wherein the anchoring apparatus comprises a unidirectional or—non return—mechanism adapted to allow the at least one actuating member to move towards a respective one of the at least one movable wall engaging member, and prevent movement of the at least one actuating member in an opposite direction.

US Pat. No. 10,920,509

SUBTERRANEAN WELL THRUST-PROPELLED TORPEDO DEPLOYMENT SYSTEM AND METHOD

Saudi Arabian Oil Company...

2. A method of deploying a fiber-optic payload in a subterranean well, the method comprising:advancing a torpedo in a first portion of a wellbore of a subterranean well, the torpedo comprising:
a body;
a fiber-optic (FO) umbilical that is physically coupled to a surface component, and configured to unspool from the torpedo as the torpedo advances in the wellbore; and
an engine configured to generate thrust to propel the torpedo, the engine comprising a solid propellant fuel; and
activating an igniter of the engine to cause combustion of the solid propellant fuel to generate thrust to propel advancement of the torpedo within a second portion of the wellbore such that the FO umbilical is disposed in the second portion of the wellbore.

US Pat. No. 10,920,508

DRILLING MOTOR HAVING SENSORS FOR PERFORMANCE MONITORING

1. An apparatus, comprising:a sensor assembly disposable in a drill string proximate a drilling motor, the sensor assembly comprising a first pressure transducer in fluid communication with an upstream side of a rotor in the drilling motor, a second pressure transducer in fluid communication with a downstream side of the rotor and a rotational speed sensor coupled to the rotor, the first pressure transducer, the second pressure transducer and the rotational speed sensor disposed in a housing coupled to the rotor and wherein a through bore in the rotor fluidly connects the downstream side of the rotor to the second pressure transducer; and
a processor in signal communication with the first pressure transducer, the second pressure transducer and the rotational speed sensor.

US Pat. No. 10,920,507

DRILLING SYSTEM AND METHOD

Future Well Control AS, ...

1. A method for managed pressure drilling, comprising the steps of:extending a drilling riser having a drill string therein from a floating installation to a location on a seafloor, the drilling riser being fluidly connected to a subsea blow-out preventer stack and equipped with:
a first fluid conduit extending from the floating installation to a lower region of the drilling riser proximate to but above the subsea blow-out preventer stack, the first fluid conduit being fluidly connected with a drilling riser annulus residing between the drill string and the surrounding drilling riser, and
a second fluid conduit extending from the floating installation and fluidly connected to the drilling riser annulus through the subsea blow-out preventer stack;
providing a first fluid in the drilling riser annulus via the first fluid conduit;
providing a second fluid in the second fluid conduit and inside the drilling riser annulus below the first fluid, with the second fluid extending below the subsea blow-out preventer stack, wherein the first fluid has a higher density than the second fluid;
circulating the second fluid through a control valve residing at the floating installation, which is fluidly connected to the second fluid conduit; and
using a controller, operating the control valve to apply a surface back-pressure so as to obtain a pre-determined, combined hydrostatic and frictional circulation pressure for the second fluid below the subsea blow-out preventer stack;
and wherein the first fluid conduit is a drilling riser booster line, and the second fluid conduit is a kill line and/or a choke line.

US Pat. No. 10,920,506

METHODS FOR WELLBORE MILLING OPERATIONS

STEP ENERGY SERVICES LTD....

19. A method for milling a wellbore structure comprising: pumping fluid through a mud motor and a milling tool while the milling tool and the mud motor are moved on a string to mill out a wellbore structure; conveying a diversion agent with the fluid through the string, mud motor and milling tool to introduce the diversion agent to the wellbore, the diversion agent mitigating fluid loss in a low pressure zone, wherein conveying includes pumping a slurry of the diversion agent in the fluid through coiled tubing; and, deferring the introduction of any further diversion agent slugs to the coiled tubing until the slurry has exited the milling tool.

US Pat. No. 10,920,505

DUAL DEVICE APPARATUS AND METHODS USABLE IN WELL DRILLING AND OTHER OPERATIONS

RAPTOR RIG LTD., Calgary...

1. A rig comprising:a. a plurality of tubular rotational devices, including at least a first tubular rotational device and at least a second tubular rotation device, wherein the first tubular rotation device and the second tubular rotation device each includes a drive shaft;
b. a derrick assembly for supporting the plurality of tubular rotational devices and a plurality of booms;
c. wherein the plurality of booms include at least a first boom and a second boom, wherein the first boom is operatively connected to at least the first tubular rotational device, wherein the second boom is operatively connected to at least the second tubular rotational device, wherein the first boom is capable of moving the first tubular rotational device vertically inline with a single wellbore while the second boom is capable of independently moving the second tubular rotational device vertically out of alignment with the wellbore,
wherein the plurality of booms are slidably disposed in a horizontal direction along a rail proximate an opening of the wellbore to move each of the plurality of tubular rotational devices and toward the wellbore and away from the wellbore, the wellbore having a wellbore axis;
d. an elevator assembly configured to engage a first tubular segment; and,
e. a clamp assembly configured to move the first tubular segment toward the drive shaft of the first tubular rotational device;
wherein the first tubular rotational device is capable of rotating and lifting the first tubular segment inline with the wellbore while the second tubular rotational device is lifting and rotating a second tubular segment out of alignment with the wellbore.

US Pat. No. 10,920,504

PIPE GRABBER

1. In combination, a pipe handler and pipe grabber, the pipe handler having a boom with a pipe supporting trough, the pipe grabber comprising:a pipe grabber housing affixed adjacent to a longitudinal end of said pipe handler boom, said pipe grabber housing having a pipe retaining trough that is axially aligned with and terminates said pipe supporting trough and said pipe grabber housing having side walls extending from said pipe retaining trough;
an upper cylinder pin;
a lower cylinder pin;
a pair of upper link arms pivotal about said upper cylinder pin;
a pair of lower link arms pivotal about said lower cylinder pin;
a pair of link pins coupling individual ones of said pair of upper link arms to individual ones of said pair of lower link arms; and
a hydraulic cylinder affixed between said upper cylinder pin and said lower cylinder pin;
said pipe grabber configured to capture a pipe within said pipe retaining trough when said hydraulic cylinder is extended; and
said upper link arms configured to retract within said pipe grabber housing when said hydraulic cylinder is retracted;
wherein said pipe retaining trough has a depression running longitudinally between first and second ridges, a first perforation passing through said first ridge, and a second perforation passing through said second ridge;
a first one of said pair of upper link arms pivotal between a first active position passing through said first perforation and a second retracted position not passing through said first perforation; and
a second one of said pair of upper link arms pivotal between a first active position passing through said second perforation and a second retracted position not passing through said second perforation.

US Pat. No. 10,920,503

OIL WELL CASING CENTRALIZING STANDOFF CONNECTOR AND ADAPTOR

Unique Machine, LLC, Anc...

14. A pipe string centralizer comprising:a cylindrical body having front and back ends and an outer surface; and
a plurality of helical blades arranged around the body, each blade extending radially outwards from the outer surface of the body, and having a front and a back, first and second sides, and a top surface;
each pair of adjacent blades having an intervening gap along a line on the outer surface from the front to the back of the body parallel to the central axis and that does not intersect either of the adjacent blades;
an axial surface profile of the gap between adjacent blades as viewed parallel to the central axis from the front end to the back end of the centralizer forming a continuous curve;
wherein when the centralizer is within the casing the gap provides a straight line fluid flow path between the outer surface of the centralizer and an inner surface of the casing.

US Pat. No. 10,920,502

CASING FRICTION REDUCTION METHODS AND TOOL

SAUDI ARABIAN OIL COMPANY...

9. A method for reducing friction between a casing string and a bore of a subterranean well when moving the casing string within the bore of the subterranean well, the method including:removably attaching a roller bearing assembly to an outer diameter of the casing string, where the roller bearing assembly includes:
a bearing body; and
a plurality of spherical bearings spaced around an outer diameter of the bearing body; where
the bearing body is a jointed member formed of segments with an attachment member operable to be tightened so that there is a gap between opposing ends of adjacent segments of the bearing body and an inner diameter surface of the bearing body grips an outer diameter surface of the casing string so that the bearing body is stationary relative to the casing string as the casing string is moved within the bore of the subterranean well.

US Pat. No. 10,920,501

EXPANSION CHAMBER

INNOVEX DOWNHOLE SOLUTION...

1. An expansion chamber for use on a tubular, the expansion chamber comprising:a shell that is configured to be attached to the tubular by a bonding material, the shell having a port configured to receive the bonding material therethrough and into a cavity of the shell; and
a tube unit configured to be placed in the cavity of the shell, the tube unit having a tube with a port that is in fluid communication with the port of the shell, wherein the tube unit is at least partially enveloped in the bonding material.

US Pat. No. 10,920,500

ADJUSTABLE DOWNHOLE NOZZLE

Halliburton Energy Servic...

1. A drill bit nozzle comprising:a nozzle body including,
a fixed diameter inlet orifice; and
a plurality of slats each having a first end, a second end, and a pair of lengthwise edges extending between the first end and the second end, each slat contoured to overlap with lengthwise edges of one or more adjacent slats, wherein each first end is rotationally attached at a respective position around the inlet orifice, and wherein the second ends form the variable diameter outlet orifice, wherein each slat comprises a radially outward facing surface that is ramped upwardly from the second end to the first end or upwardly from the first end to the second end;
a ring member disposed circumferentially around said plurality of slats; and
an actuator configured to linearly displace said ring member lengthwise along said plurality of slats.

US Pat. No. 10,920,499

POLYCRYSTALLINE DIAMOND COMPACT INCLUDING A NON-UNIFORMLY LEACHED POLYCRYSTALLINE DIAMOND TABLE AND APPLICATIONS THEREFOR

US SYNTHETIC CORPORATION,...

1. A polycrystalline diamond compact, comprising:a substrate; and
a polycrystalline diamond table bonded to the substrate, the polycrystalline diamond table defining a substantially planar upper surface, and at least one peripheral surface, the polycrystalline diamond table including a plurality of bonded diamond grains defining a plurality of interstitial regions, the polycrystalline diamond table further including:
a first region adjacent to the substrate that includes a metallic constituent disposed interstitially between the bonded diamond grains thereof; and
a leached second region extending inwardly from the substantially planar upper surface to the first region with the first region positioned between the leached second region and the substrate, and inwardly from the at least one peripheral surface, the leached second region depleted of the metallic constituent, the leached second region including:
a first leached portion that exhibits a first leach depth; and
a second leached portion that exhibits a second leach depth that is about 5 percent to about 60 percent less than the first leach depth.

US Pat. No. 10,920,498

DIGGING AUGER

1. A digging auger, comprising:a shaft with a proximal end and a distal end;
a screw extending from said proximal end to said distal end of said shaft; and
a paddle attachment adapted to be removably attached at said proximal end of said shaft, said paddle attachment comprises two pieces of rubber strips arranged on opposing sides of said shaft and extending generally radially outwards therefrom, wherein said paddle attachment further comprises a collar adapted to be mounted onto said shaft to allow for removable attachment of said paddle attachment with said digging auger, wherein said paddle attachment further comprises four pieces of metal strips welded to said collar and are arranged such that two pairs of two said metal strips are disposed along two opposing sides of said collar with gaps therebetween.

US Pat. No. 10,920,497

NO BLADE BIT

ULTERRA DRILLING TECHNOLO...

7. A bladeless polycrystalline diamond compact (PDC) drill bit, comprising:a head having a plurality of cutters, wherein each of the plurality of cutters is positioned on a knot that protrudes outward from a drilling face of the head, wherein:
each of the cutters is arranged about a central axis of the head such that each cutter has a unique radial distance and a unique angular position relative to the central axis;
the angular position of each successive one of the plurality of cutters following an innermost one of the plurality of cutters is incremented approximately by a golden angle;
each successive one of the cutters is a cutter with a next smallest radial distance from the central axis as compared to a previous cutter; and
the head defines at least one fluid port extending through the drilling surface.

US Pat. No. 10,920,496

CUTTING STRUCTURE DESIGN WITH NEW BACKUP CUTTER METHODOLOGY

Halliburton Energy Servic...

1. A drill bit for subterranean drilling operations, comprising:a drill bit body with a plurality of blades comprising:
a first primary blade;
a first secondary blade directly preceding, in the direction of rotation during a drilling operation, the first primary blade;
a first plurality of primary cutters, each located on the first primary blade;
a first plurality of secondary cutters, each located on the first secondary blade;
a first primary cutter of the first plurality of primary cutters having a plurality of areas that experience different amounts of wear during the drilling operation, wherein a first area of the plurality of areas is offset from a centerline of the first primary cutter and experiences the max amount of wear on the first primary cutter; and
a first secondary cutter having a radial position that is offset from the centerline of the first primary cutter and aligns with the offset radial position of the first area that experiences the max amount of wear on the first primary cutter.

US Pat. No. 10,920,495

DRILL BIT

ULTERRA DRILLING TECHNOLO...

9. A method of forming a core bit for collecting a core sample, the method comprising:forming a bit body having an opening for the core sample, and one or more blades with receptacles for cutters, wherein a width and a thickness of a blade of the one or more blades extends from the opening around a shoulder of the bit body;
mounting cutters into the receptacles for a first blade of the one or more blades, the cutters including:
an inner cutter mounted on a leading edge of the first blade adjacent the opening to cut the core sample; and
a set of outer cutters spaced from the opening mounted to the leading edge of the first blade extending along a line away from the opening rotationally offset from the inner cutter, wherein:
the inner cutter is rotationally offset forward from the set of outer cutters;
additional blades of the one or more blades comprise a second inner cutter and a second set of outer cutters; and
the second inner cutter and second set of outer cutters are on discontinuous blades.

US Pat. No. 10,920,494

HYDRAULIC FRACTURE COMPOSITION AND METHOD

AQUASMART ENTERPRISES, LL...

1. A material formed as a proppant for hydraulic fracturing, the material comprising:a substrate, comprising discrete granules of an inorganic material;
a binder individually coated onto each of the granules of the substrate, wherein the binder comprises a first volume of a polyacrylamide wetted with a solvent and absent any surfactant;
a powder comprising a second volume of a hydrophilic, synthetic polymer and absent any surfactant and secured to the granules of the substrate by the binder; and
a second powder comprising an aluminosilicate in an amount of about 0.5 wt. % to about 2 wt. % and absent any surfactant and secured to the granules of the substrate by the binder to form proppant particles.

US Pat. No. 10,920,493

METHOD OF FORMING STATORS FOR DOWNHOLE MOTORS

BAKER HUGHES, A GE COMPAN...

1. A method of making a stator comprising:positioning an inner tubular member having an inner surface within an outer tubular member, both the inner tubular member and the outer tubular member being formed from metal;
installing a rigid mandrel within the inner tubular member; and
applying a compressive force to the inner tubular member and the outer tubular member, the compressive force causing the inner tubular member to be connected to the outer tubular member.

US Pat. No. 10,920,492

LADDER WITH SAFETY FEATURES

Intex Marketing Ltd., To...

1. A ladder assembly configured for placement on a ground, the ladder assembly comprising:a left upright having an upper end;
a right upright cooperating with the left upright to define a lateral gap, the right upright having an upper end;
a lower ladder step having an upper step surface, the lower ladder step coupled to the left upright and the right upright and spanning the lateral gap;
an upper ladder step having an upper step surface, the upper ladder step coupled to the left upright and the right upright, spanning the lateral gap, and cooperating with the lower ladder step to define a vertical gap;
a safety block disposed above the lower ladder step, the safety block being moveable in a movement relative to the left upright and the right upright between:
a safety configuration in which the safety block spans the lateral gap and the vertical gap and directly covers the upper step surface of the lower ladder step, and
a ladder configuration in which the upper step surface of the lower ladder step is exposed, extends generally parallel to the ground, and faces upward,
whereby a user cannot step on the upper step surface of the lower ladder step when the safety block is in the safety configuration and the user can step on the upward-facing upper step surface of the lower ladder step when the safety block is in the ladder configuration; and
a handle positioned above at least one of the upper end of the left upright and the upper end of the right upright, wherein the handle is configured to drive the movement of the safety block between the safety configuration and the ladder configuration.

US Pat. No. 10,920,491

SHADING AND LIGHTING CONTROL USING A CONTROL NETWORK

1. A system for controlling lights and shades, comprising:a room controller adapted to transmit controls signals to one or more devices, wherein said control signals represent a desired intensity level setting, and wherein
the one or more devices are adapted to receive the transmitted control signals; and
a power cable adapted to transfer power to a first set of said one or more devices from a transformer, and wherein
the one or more devices are further adapted to convert said control signals to effectuate said desired intensity level setting, and wherein
said one or more devices includes motorized roller shades and dimmable lighting devices, wherein each of said one or more motorized roller shades includes a respective electronic data unit for each of said at least one motorized roller shades, and wherein
each of said electronic drive units includes
an elongated motor, and a battery, and further wherein
said battery is configured to provide operating power to said elongated motor, and wherein said electronic drive unit further comprises
a relay switch network configured to cause electrical power to selectively by-pass said electrical drive unit, and wherein
said relay switch network is further configured to selectively allow one or more batteries in one or more different respective motorized roller shades to draw re-charging power from said battery in said motorized roller shade associated with said electrical drive unit.

US Pat. No. 10,920,490

PHOTOSENSITIVE ELEMENT ASSEMBLY

LUTRON TECHNOLOGY COMPANY...

1. A controller for use in a load control system for controlling an electrical load, the controller comprising:a processor configured to:
combine a first sensor signal and a second sensor signal from at least a first sensor assembly and a second sensor assembly, respectively, the first and second sensor signals representing light levels at a window, the first and second sensor assemblies oriented so that the first sensor assembly has a maximum response to light entering a housing of the first sensor assembly at a first angle with respect to a normal of a plane of the window and the second sensor assembly has a maximum response to light entering a housing of the second sensor assembly at a second angle with respect to the normal of the plane of the window; and
transmit a command to automatically control the electrical load based on the combined first and second sensor signals.

US Pat. No. 10,920,489

UPRIGHT FOR A SHADING SYSTEM, REMOVABLE FLANGE OF THE UPRIGHT AND CORRESPONDING COUPLING MEANS

PLASTEX SA, Madonna del ...

1. An upright, comprising:two flanks spaced to receive a profiled element for a shading system therebetween, a first flank of the two flanks is associated with a removable flange;
a base extending between the two flanks; and
at least one damping device arranged between the removable flange and the base of the upright, in order to retain the removable flange between the base and the first flank of the two flanks, wherein the at least one damping device includes:
a channel having a substantially C-shaped cross-section, wherein the channel is configured to be mounted on an edge of the removable flange before the removable flange is mounted to the first flank of the two flanks; and
a flexible plastic tongue having one end on the channel and an opposite end at a distance therefrom and making contact with the base of the upright when the removable flange is mounted to the first flank of the two flanks;
wherein the first flank of the two flanks includes a locking tooth and the removable flange includes an engagement tooth adapted to engage the locking tooth between the base and the locking tooth;
wherein the at least one damping device causes the removable flange to be wedged between the base and the locking tooth, pushing the engagement tooth against the locking tooth.

US Pat. No. 10,920,488

ROLL SCREEN DEVICE

SEIKI HANBAI CO., LTD., ...

1. A roll screen device, comprising:a screen frame including at least a pair of side frames facing each other and an upper horizontal frame that is disposed between upper ends of the side frames and that has a channel shape that is open downward;
one of the side frames structured as a roller box containing a roller shaft that rolls up one end of a screen;
the other side frame structured as a receiving frame that an operation stile, that is attached to the other end of the screen, contacts when the screen is spread;
a guide member that slidably holds an upper end of the screen along a longitudinal direction, the guide member contained in the upper horizontal frame, and
the guide member having a slit that is formed in a lower surface thereof, the slit allowing engagement pieces for guiding, which are attached along the upper end of the screen, to be slidably engaged therewith in a retained state; and
the operation stile being attached to a leading end portion of the screen unrolled from the roller box, the operation stile allowing the screen to slide along the upper horizontal frame,
wherein a pair of protruding walls are provided in the upper horizontal frame that has a channel shape that is open downward, the protruding walls being directly or indirectly supported by the upper horizontal frame and facing each other inwardly along a longitudinal direction of the upper horizontal frame,
wherein the guide member includes a pair of flange portions that protrude outwardly from side walls on both sides along a longitudinal direction, the side walls forming the slit,
wherein, in the upper horizontal frame, the pair of flange portions of the guide member are disposed so as to respectively face upper sides of the pair of protruding walls, and the side walls on both sides of the slit of the guide member are disposed between the pair of protruding walls; and both end portions of the guide member are fixed to the upper horizontal frame in a state in which a space is formed above the guide member in the upper horizontal frame, the space allowing the guide member to bend upward,
wherein an urging member that applies an upward urging force to the guide member is provided between a corresponding one of the flange portions of the guide member and one of the protruding walls facing the flange portion, and the urging force that the urging member applies to the screen in a spread state is set in a range that suppresses deformation of a suspended shape due to a weight of the screen,
wherein a pair of engagement hooks are provided at upper end portions of the operation stile so as to face each other, and engagement stepped portions are respectively formed on both side walls of the guide member, the engagement stepped portions allowing the engagement hooks to slide by being engaged therewith and suspended along a longitudinal direction of the side walls, and
wherein the operation stile is formed so as to be slidable along the engagement stepped portions of the guide member in an opening/closing area of the screen.

US Pat. No. 10,920,487

PHOTOVOLTAIC SUNSHADE WITH PHOTOVOLTAIC THIN FILM STRIPS

King Abdulaziz University...

1. A sunshade system having a plurality of photovoltaically active sunshades, comprising:at least two sunshades, each comprising a flat surface constructed of a plastic polymer fabric,
wherein each flat surface constructed of plastic polymer fabric Is covered at least partially by a thin film comprising four rows of photovoltaic cells, each row comprising a plurality of photovoltaic cells connected in series, wherein the rows are connected In parallel, and wherein the photovoltaic cells are adhered to the plastic polymer fabric,
wherein each flat surface constructed of the plastic polymer fabric has a first end, a second end, a left edge, a right edge and a first central axis, a length (UL) between the first and second end and a width (W) between the left edge and the right edge;
for each sunshade:
a frame having a first rod perpendicular to the first central axis, the first rod having a left end and a right end, wherein a distance between the left end and the right end equals the width (W) of the plastic polymer fabric;
a second rod perpendicular to the first central axis and parallel to the first rod, the second rod having a left end and a right end, wherein a distance between the left end and the right end equals the width (W) of the plastic polymer fabric;
a third rod placed parallel to the first central axis, the third rod having a first end and a second end and a length (L), wherein the first end of the third rod is attached to a center of the first rod and extends at least partially through the first rod and wherein the second end of the third rod is attached to a center of the second rod;
a first guy wire having a first wire end and a second wire end, wherein the first wire end is attached to the left end of the first rod, and the second wire end is attached to the left end of the second rod;
a second guy wire having a third wire end and a fourth wire end, wherein the third wire end is attached to the right end of the first rod, and the fourth wire end is attached to the right end of the second rod;
wherein, for each sunshade, the flat surface of the plastic polymer fabric is attached at the first end to the first rod, attached at the second end to the second rod, wherein the plastic polymer fabric is attached along the first central axis to the third rod, attached along the left edge to the first guy wire and attached along the right edge to the second guy wire;
a first metal bar proximate to and parallel to each first rod;
a second metal bar proximate to and parallel to each second rod; further for each sunshade:
an electric motor having a body and a shaft extending perpendicularly to the body, wherein the electric motor is attached to the first metal bar and the shaft is parallel to the first central axis,
wherein the third rod is connected at the first end to the electric motor shaft;
a hinge connected to the second metal bar, wherein the third rod is connected at the second end to the hinge; and
a first controller operatively connected to the electric motors, the first controller including circuitry configured to actuate the electric motors to rotate the shaft bi-directionally through an angle of 180 degrees.

US Pat. No. 10,920,486

BEAD CHAIN SAFETY SYSTEM FOR ROLLER BLIND

Lin Gwo Tsair Enterprise ...

1. A bead chain safety system for roller blinds comprising:a fixing base having a first side, and a second side that is opposite to the first side, the second side having a recess formed therein;
an assembly base provided with a first end and a second end opposite to each other, the first end of the assembly base being connected to the second side of the fixing base and defining a rotary-disc mounting space therebetween, the assembly base having a first cavity formed in the second end thereof, and a through hole formed centrally in a bottom of the first cavity and extending through the second end of the assembly base to provide open communication between the first cavity and the rotary-disc mounting space;
a rotary disc having opposing closed and open ends being mounted in the rotary-disc mounting space, the closed end having a projection at a center thereof and the open end having a second cavity formed centrally therein; the projection is being disposed in the recess of the second side of the fixing base and supported thereby;
a first transmission member mounted in the second cavity of the rotary disc; the first transmission member having a conical head protruding from the second cavity of the rotary disc and an opposing open end disposed in the second cavity, the conical head having a plurality of first ribs disposed thereon;
a spring mounted in the second cavity of the rotary disc and having two ends respectively abutting against a bottom of the second cavity of the rotary disc and the open end of the first transmission member for positioning; and
a second transmission member mounted in the first cavity of the assembly base and including a tapered slot arranged on one side thereof and a plurality of second ribs spaced around a wall of the tapered slot; the tapered slot being disposed in correspondence with the through hole of the assembly base and the conical head of the first transmission member being mounted in the tapered slot of the second transmission member and the first ribs on the conical head are locked with and positioned by the second ribs.

US Pat. No. 10,920,484

METHODS AND APPARATUS FOR PET DOORS

Smartec Products LLC, Ph...

1. A door unit configured to connect to a pet doer security panel holder and respond to a signal from an authorized tag associated with a pet, comprising:a frame having a hole defined therethrough;
a door disposed over the hole and mounted on the frame, wherein the door opens only away from the security panel holder;
a motor, wherein the motor drives movement of the door;
a security panel interface on the frame, wherein the security panel interface comprises a selectable modular connector adapted to hang the frame on the security panel holder;
a tag sensor disposed on a central part of the door, wherein the tag sensor comprises a directional wireless Bluetooth sensor, comprising:
an interior sensor disposed on a first side of the door;
an exterior sensor disposed on a second side of the door; and
a shield housing, wherein the shield housing shields the interior sensor from signals from a first direction and shields the exterior sensor from signals from a second direction;
a control system responsive to signals from the tag sensor, wherein:
the motor is responsive to signals from the control system; and
the control system causes the motor to open the door when the tag sensor receives the signal from the authorized tag.

US Pat. No. 10,920,483

WINDOW SEAL FOR PREVENTING WATER PENETRATION

Mark Mutchnik, Miami Bea...

1. A water penetration prevention system for a window, comprising:an insert for being positioned along a track for a window, the insert having a first engaging portion disposed on a first side of the insert and a second engaging portion disposed on a second side of the insert opposite the first side;
at least one seal engaging member disposed between the first engaging portion of the insert and the second engaging portion of the insert, the at least one seal engaging member being selectively positionable between a first position and a second position,
wherein the at least one seal engaging member, in the second position, applies a force on at least one of the first side of the insert and the second side of the insert that causes the at least one of the first side of the insert and the second side of the insert to sealingly engage a corresponding one of the window and a vertical wall of the track;
wherein the at least one seal engaging member includes a toggle latch spreader that includes a biasing member that biases the toggle latch spreader toward the first position.

US Pat. No. 10,920,482

GLASS BUILDING MATERIAL

KANEKA CORPORATION, Osak...

1. A glass building material, comprising:a first photovoltaic string of a bifacial light-receiving type which has a shape extending in one direction;
a second photovoltaic string of a bifacial light-receiving type which is arranged next to the first photovoltaic string in a width direction, and which has a shape extending in the one direction;
a first glass substrate which is configured to cover one surface side of the first photovoltaic string and one surface side of the second photovoltaic string;
a reflective layer including a reflective film, a first white reflective plate, and a second white reflective plate,
wherein the reflective film is arranged on at least part of another surface side of the first photovoltaic string and another surface side of the second photovoltaic string, which has a transmittance higher than a reflectance in a visible light region, and which has a reflectance higher than a transmittance in a near-infrared region,
wherein the first white reflective plate has a shape extending in the one direction and a width larger than the first photovoltaic string and is disposed at a position opposed to the another surface side of the first photovoltaic string so as to contact with the reflective film, and
wherein the second white reflective plate has a shape extending in the one direction and a width larger than the second photovoltaic string and is disposed at a position opposed to the another surface side of the second photovoltaic string so as to contact with the reflective film.

US Pat. No. 10,920,480

THERMALLY EFFICIENT WINDOW FRAME

GED Integrated Solutions,...

1. A multi-sided channel shaped composite spacer frame for arranging first and second glass lites in a spaced apart, generally parallel relation to each other, said spacer frame comprising:an elongated thermal interruption strip comprising at least a portion of a peripheral wall, the elongated thermal interruption strip forms a portion of said composite spacer frame and extends around a periphery of the spacer frame;
a first elongated frame stock comprising at least a portion of the peripheral wall and comprising a first lateral wall, wherein an edge portion of the first elongated frame stock is secured to the thermal interruption strip;
a second elongated frame stock comprising at least a portion of the peripheral wall and comprising a second lateral wall, wherein an edge portion of the second elongated frame stock is secured to the thermal interruption strip, the first and second lateral walls and the peripheral wall forming an u-shaped channel defining an interior region; and
a vapor barrier overlying the thermal interruption strip and at least a portion of the peripheral wall to impede contaminants from reaching the interior region bounded by the first and second elongated frame stocks and prevent loss of fluids from the interior region, the vapor barrier comprising an airtight film.

US Pat. No. 10,920,479

STORAGE SYSTEM

VAPENSYSTEMS, INC, Lawre...

1. A storage system for securing a weapon or valuable item comprising:an outer housing assembly comprising
an elongated housing having a non-rotatable curved inner structure;
an arcuate housing door; and
a handle assembly that rotates the arcuate housing door concentrically about a longitudinal axis and partially within and adjacent to the non-rotatable curved inner structure, wherein a rotational pivot of the handle assembly is aligned with the longitudinal axis and rotates the arcuate housing door about the longitudinal axis between:
a closed position that prevents access to an internal compartment within the elongated housing, and
an open position that provides an access opening of approximately 180 degrees about the longitudinal axis into the internal compartment within the elongated housing
wherein the handle assembly is connected to at least one of a first curved end or a second curved end of the arcuate housing door and adapted to rotate the arcuate housing door between the closed position and the open position adjacent to the non-rotatable curved inner structure of the elongated housing.

US Pat. No. 10,920,478

VEHICLE SYSTEM WITH SELF-ADJUSTING VARIABLE SPEED CLOSURE

FORD GLOBAL TECHNOLOGIES,...

1. A vehicle system comprising:a closure panel;
at least one panel actuator operable to move the closure panel during opening and closing, and to move the closure panel at a closing speed during closing;
a latch operable to lock the closure panel; and
a controller electrically connected with the panel actuator, the controller configured to selectively adjust the closing speed of a next closing based on past opening and closing of the closure panel,
wherein the latch further comprises a latch actuator electrically connected with the controller and operable to move the latch during latching and unlatching, and to move the latch at a latching ratchet speed during the latching, and the controller is configured to selectively adjust the latching ratchet speed of a next latching based on past latching and unlatching of the latch.

US Pat. No. 10,920,477

SLIDING DOOR WITH WIRELESS-CONTROLLED MOTOR HOUSED IN JAMB

Naci Gul, Izmir (TR) Mus...

1. A sliding door assembly comprising:a frame that supports and interfaces directly to a fixed door panel and a moving door panel, wherein the frame includes opposed side jamb portions, a sill portion, and head jamb portion opposite the sill portion;
an electric motor;
a wireless motor controller; and
a drive belt that is operably coupled to the moving door panel, wherein the drive belt is driven by the electric motor under control of the wireless motor controller;
wherein the head jamb portion includes at least one internal channel that accommodates the drive belt;
wherein one of the side jamb portions includes a top part opposite a bottom part, wherein the top part of the one side jamb portion is disposed adjacent the head jamb portion, wherein the top part of the one side jamb portion has a first internal compartment that houses the electric motor and the wireless motor controller, wherein a bracket is disposed inside the first internal compartment and configured to mount the electric motor to the top part of the one side jamb portion inside the first internal compartment, wherein the bracket is secured to the top part of the one side jamb portion by a plurality of fasteners accessed within the first internal compartment, wherein the top part of the one side jamb portion further includes a first opening and a second opening, wherein the first opening allows for passage of the drive belt between the first internal compartment and the internal channel that accommodates the drive belt, and wherein the second opening is oriented parallel to the fixed door panel and the moving door panel and exposes the first internal compartment and receives a removable access panel; and
wherein the removable access panel is removably fixed to the one side jamb portion and has first and second configurations, wherein in the first configuration the access panel is fixed to the one side jamb portion and covers the second opening, and wherein in the second configuration the access panel is disconnected from the one side jamb portion to allow access to the internal compartment through the second opening and to the electric motor and the plurality of fasteners and the wireless motor controller disposed therein.

US Pat. No. 10,920,476

HINGE DEVICE FOR ROTATING DOOR

PARTSTEC CONSTRUCTION CO....

1. A hinge device for a rotating door, the hinge device comprising:a hollow housing having one end and an opposite end, the housing provided therein with a first inner chamber and a second inner chamber communicated with each other, in which the first inner chamber is filled with oil;
a shaft rotatably mounted to the housing while passing through the first inner chamber, in which one end of the shaft is exposed to an outside through the one end of the housing, an opposite end of the shaft is inserted into the first inner chamber, an outer circumferential surface of the shaft is spaced apart from the first inner chamber such that oil is filled therebetween, and a first seating groove is formed at an outer circumferential surface of the opposite end of the shaft;
a damper unit installed in the first inner chamber to adjust an amount of flow of the oil filled in the first inner chamber during relative rotation of the housing and the shaft;
a clutch roll inserted into the first seating groove in the second inner chamber;
a clutch member having one end surrounding the opposite end of the shaft in the second inner chamber, in which a first coupling protrusion protrudes from an opposite end of the clutch member, a through hole is formed at the one end of the clutch member surrounding the shaft, and the clutch roll is inserted into the through hole;
a support member mounted to the opposite end of the housing and having a second coupling protrusion protruding toward an inside of the housing; and
a torsion spring installed inside the housing and having one end coupled to the first coupling protrusion and an opposite end coupled to the second coupling protrusion,
wherein a second seating groove is formed at an inner peripheral surface of the housing such that the clutch roll inserted into the through hole is seated in the second seating groove,
a rotational force of the shaft is transferred to the clutch member through the clutch roll when the shaft rotates in a state where the clutch roll is inserted into both the first seating groove and the through hole, thereby rotating the clutch member together with the shaft, and
only the shaft independently rotates without rotation of the clutch roll and the clutch member when the shaft rotates in a state where the clutch roll is inserted into both the through hole and the second seating groove.

US Pat. No. 10,920,475

SLIDING-DOOR CLOSER SET

SUGATSUNE KOGYO CO., LTD....

1. A sliding door closer set comprising:a rail arranged partially inside a door pocket;
a closer hanging a sliding door and being capable of moving along the rail; and
a trigger arranged inside the door pocket;
wherein the sliding door is pulled into the door pocket with a pulling force of a coil spring provided in the closer as a result of engagement between the trigger and the closer, which has moved to a predetermined position on the rail; and
the sliding door closer set further comprises a trigger integrated plate mounted to the rail outside the door pocket and integrally connected to the trigger arranged inside the door pocket,
the trigger integrated plate is provided with a mounting part for mounting to the rail outside the door pocket, and
when the sliding door is stored inside the door pocket, the trigger is located between traveling bodies, and
a length of the trigger integrated plate from an edge outside the door pocket to the trigger is shorter than a length of the rail outside of the door pocket;
wherein when a trigger catcher captures the trigger arranged inside the door pocket in a state that the trigger integrated plate is mounted to the rail by a fastening member, the pulling force of the coil spring in the closer causes the sliding door to slide relative to the trigger catcher while the trigger catcher is capturing the trigger, so that the sliding door is pulled into the door pocket;
wherein after the sliding door is pulled into the door pocket by the coil spring of the closer, the fastening member is configured to be disconnected from the rail such that the trigger integrated plate is not mounted to the rail;
in a state that the trigger integrated plate is not mounted to the rail and the trigger is captured in the trigger catcher, movement of the sliding door from outside of the door pocket causes the predetermined position of the trigger to be adjusted;
after the predetermined position of the trigger is adjusted, the fastening member is configured to be reconnected to the rail such that the trigger integrated plate is again mounted to the rail.

US Pat. No. 10,920,474

HINGE DEVICE

SUGATSUNE KOGYO CO., LTD....

1. A hinge device, comprising:a case having a first contact portion, a second contact portion and a cylindrical portion;
a coil spring fitted in the cylindrical portion of the case;
a shaft member having a shaft inserted inside the coil spring, and a first engaging portion and a second engaging portion fixed to the shaft in anti-rotatable; wherein
when the case is rotated relatively from a neutral position in one direction with respect to the shaft member, one end of the coil spring in contact with the first contact portion of the case is rotated relatively in the one direction with respect to the shaft member, while another end of the coil spring comes into contact with the second engaging portion of the shaft member, thereby twisting the coil spring;
when the case is rotated relatively from the neutral position in the other direction with respect to the shaft member, the other end of the coil spring in contact with the second contact portion of the case is rotated relatively in the other direction with respect to the shaft member, while the one end of the coil spring comes into contact with the first engaging portion of the shaft member, thereby twisting the coil spring; and
the first and second contact portions are formed integral with the cylindrical portion;
wherein the one end of the coil spring is provided with a first spring holder that comes into contact with the first contact portion of the case;wherein the first spring holder has an arm extending in an axial direction of the shaft, andthe cylindrical portion has an end wall provided with a groove into which the arm of the first spring holder enters.

US Pat. No. 10,920,473

VEHICLE DOOR OPENING/CLOSING APPARATUS

U-SHIN LTD., Tokyo (JP)

1. A vehicle door opening/closing apparatus comprising:a tube shaped first housing for housing an electric motor drive mechanism inside, the electric motor drive mechanism including an electric motor;
a second housing that is disposed coaxially with the first housing, and that is moved in an axial direction relative to the first housing by a spindle drive mechanism connected to the electric motor drive mechanism;
a ball socket that includes a cap including a bottomed-tube shape for insertion into an opening on one end side of the first housing to block off the opening, and the ball socket also including a harness insertion hole formed in a bottom portion of the cap to allow a harness connected to the electric motor to be led out; and
a grommet that includes a cover portion extending outside the cap and covering the harness where the harness has been led out of the cap, wherein the grommet includes
a boot portion formed in a bottomed-tube shape opening toward the electric motor side and covering the harness inside the cap,
a coupling tube portion disposed inside the harness insertion hole so as to couple the boot portion and the cover portion together, with the harness inserted through an inside of the coupling tube portion, and
a detachment prevention section formed on the boot portion for engaging with the cap to limit movement of the boot portion toward the harness insertion hole.

US Pat. No. 10,920,472

HINGE FOR A REMOVABLE TAILGATE

FORD GLOBAL TECHNOLOGIES,...

1. A hinge to connect a tailgate to a box of a truck, comprising:a tailgate leaf;
a body leaf having a first chamber;
a hinge pivot pivotally connecting the tailgate leaf to the body leaf;
a slider movably positioned in the first chamber; and
a locking mechanism coupled to the body leaf and configurable in a first position to lock the slider in the first chamber and configurable in a second position to unlock the slider in the first chamber.

US Pat. No. 10,920,471

SELECTIVE TWO-WAY HINGE ASSEMBLY

Kingsway Enterprises (UK)...

1. A door mounting system, comprising:a hinge assembly and a door frame, wherein a length of the hinge assembly is approximately equal to a height of a door leaf, the hinge assembly comprising:
a first hinge member coupled to the door frame;
an intermediate hinge member, wherein the first hinge member and the intermediate hinge member are rotatably coupled to each other and are pivotable relative to each other about a first hinge axis;
a second hinge member for attachment to the door leaf, wherein the second hinge member and the intermediate hinge member are rotatably coupled to each other via a first outer hinge pin and a second outer hinge pin and are pivotable relative to each other about a second hinge axis, the first outer hinge pin and the second outer hinge pin being vertically spaced apart to define a gap therebetween; and
an engageable and disengageable locking mechanism adapted to be mounted in the door leaf, the locking mechanism including a locking element slidably mounted with respect to the second hinge member and the intermediate hinge member such that the locking element is movable between a first engaged position and a second disengaged position,
wherein when in the first engaged position, the locking element extends through the gap into the intermediate hinge member to inhibit rotation of the intermediate hinge member relative to the second hinge member, and
wherein when the locking element is in the second disengaged position, the locking element is retracted from the intermediate hinge member and allows the rotation of the intermediate hinge member relative to the second hinge member.

US Pat. No. 10,920,470

LOCK MECHANISM FOR SECURING A LOCKABLE VOLUME

United States Postal Serv...

1. A lock mechanism comprising:a frame;
an actuator mounted on the frame, the actuator having a moveable portion movable between a retracted position and an extended position;
a first linkage member connected to the moveable portion of the actuator;
a second linkage member connected to the frame at a fixed position, the second linkage member being rotatably connected to the first linkage member, the second linkage member comprising a bumper that contacts a section of the first linkage member when the moveable portion of the actuator is in the extended position and will move out of contact with the section when the moveable portion of the actuator is in the retracted position;
a third linkage member rotatably connected to the second linkage member and to a rotating plate; and
a rotatable cam rotatably connected to the rotating plate, the rotatable cam having a receiving portion configured to receive and secure a member of a lock structure in a locked position.

US Pat. No. 10,920,469

DOUBLE-ACTION, ADJUSTABLE, AFTER-MARKET SASH STOP

Vision Industries Group, ...

1. A stop, for use on a window to limit sliding of a sash member with respect to a master frame of the window, between a closed position and a partially opened position, the partially opened position being between the closed position and a fully opened position of the sash member, said stop comprising;a housing configured to mount said stop to the window, said housing comprising an interior surface defining a housing cavity, said interior surface comprising a contoured feature;
a tumbler, said tumbler comprising a first end and a second end; said tumbler being pivotally mounted to said housing; said second end of said tumbler comprising a bearing surface;
a biasing member, said biasing member configured to bias said second end of said tumbler to pivot outward from said housing cavity; a portion of said biasing member configured to contact and move with respect to said contoured feature to selectively limit outward pivotal travel of said tumbler, said tumbler thereby configured for toggling between a first tumbler position and a second tumbler position by a force applied proximate to said first end of said tumbler; when in said first tumbler position, said bearing surface of said tumbler is positioned to limit opening of the sash member to the partially opened position; when in said second tumbler position, at least a portion of said second end of said tumbler protrudes out from said housing cavity, such that said bearing surface is positioned to permit the sash member to open beyond the partially opened position;
wherein the force applied proximate to said first end of said tumbler causes said tumbler to toggle from said first tumbler position to a retracted tumbler position, in which said at least a portion of said second end of said tumbler is positioned within said housing cavity; and
wherein upon removal of the force, said tumbler is biased to pivot away from said retracted tumbler position, with said biased pivoting away from said retracted tumbler position limited by contact of said portion of said biasing member with said contoured feature, such that said tumbler is biased to pivot to said second tumbler position.

US Pat. No. 10,920,468

WINDOW LOCK

1. A lock assembly for a window having a first sash and a second sash, the lock assembly comprising:an elongate strip configured to be coupled to the first sash, the elongate strip having a plurality of recesses defined along a length of the elongate strip; and
a lock member configured to be coupled to and move with the second sash, such that the lock member is operable to move along the length of the elongate strip with the second sash, the lock member including a biasing member and a coupler biased in a direction of the elongate strip by the biasing member, the coupler configured to enter each of the plurality of recesses to selectively lock the lock member to the elongate strip,
wherein when the elongate strip is coupled to the first sash, the lock member is coupled to the second sash, and the coupler moves out of one of the plurality of recesses, the lock member is able to move along the length of the elongate strip with the second sash, such that the second sash is able to change position with respect to the first sash,
wherein when the elongate strip is coupled to the first sash, the lock member is coupled to the second sash, and the coupler is within one of the plurality of recesses, the lock member is prevented from moving in a first direction along the length of the elongate strip, and the lock member is prevented from moving in a second direction that is opposite the first direction along the length of the elongate strip, such that the second sash is prevented from moving in the first and second directions with respect to the first sash, and
wherein the lock member includes a button coupled to the coupler, such that when a force is applied to the button, the coupler moves in a direction away from the elongate strip.

US Pat. No. 10,920,467

SELECTIVELY LOCKABLE BOX AND METHOD OF USE

Adrian Steel Company, Ad...

1. A locking structure of a box, the box comprising a first compartment and a second compartment, the locking structure comprising:a horizontally oriented locking bar having a first end portion and a body portion, wherein the first end portion has an aperture therethrough and the body portion has a plurality of locking teeth extending therefrom configured to selectively interlock with slots on said first compartment;
a vertically oriented locking bar having a first end portion and a body portion configured to selectively prevent movement of said second compartment, wherein the first end portion has an aperture therethrough;
a lock housing having a lock behind fixed first and second bars defining a passage between them;
wherein said first end portion of said vertically oriented locking bar is selectively located between said fixed first and second bars and said lock;
wherein said first end portion of said horizontally oriented bar is selectively located through said passage between said fixed first and second bars, through said aperture of said vertically oriented bar and into said lock.

US Pat. No. 10,920,466

AIRCRAFT LAVATORY DOOR LATCH

SAFRAN CABIN INC., Hunti...

1. A door latch assembly comprising:a housing that includes a housing interior,
a switch member operatively associated with the housing that is rotatable between a first position and a second position,
a locking bolt that is movable linearly between an unlocked position and a locked position,
a gear train operatively connected between the switch member and the locking bolt,
wherein rotational motion of the switch member is converted to linear motion of the locking bolt, such that rotation of the switch member from the first position to the second position moves the locking bolt from the unlocked position to the locked position, and
an override assembly that includes a main body portion and a finger lid hingedly connected to the main body portion, wherein the finger lid is pivotable between a stowed position and a deployed position, wherein rotational motion of the finger lid is converted to linear motion of the locking bolt by the gear train, such that rotation of the finger lid from a first position to a second position moves the locking bolt from the unlocked position to the locked position.

US Pat. No. 10,920,465

INTERIOR DOOR LOCK OPERATOR INTEGRATED INTO PULL DOOR HANDLE

Illinois Tool Works Inc.,...

1. A side door of a motor vehicle, comprising:a door lock having a mechanical actuating means;
a door lock actuator connected to the door lock, the door lock actuator being an interior door actuator and having a pivoting lever pivotably mounted about a rotational axis of a joint, the pivoting lever having a coupling section connected to the mechanical actuating means;
an electric switch disposed in the pivoting lever and connected to the door lock via a signal line; and
an interior door handle having
one or more fastening regions, and
at least one handle region, the handle region defining an opening to receive a hand and having an axial extent, wherein:
the pivoting lever is integrated into the handle region of the interior door handle, and
the rotational axis is oriented substantially transversely with respect to the axial extent.

US Pat. No. 10,920,464

TAILGATE OPENING AND CLOSING DEVICE FOR VEHICLE

Hyundai Motor Company, S...

1. A tailgate opening and closing device for a vehicle, the tailgate opening and closing device including:a base formed, at a first side thereof, with a first insertion hole into or from which a striker is configured to be inserted or withdrawn;
a main gear disposed at a second side of the base so as to be rotatable about a first rotation shaft by a drive motor;
a claw rotatably disposed at a side of the first insertion hole of the base, the claw including a second insertion hole configured for receiving the striker, to lock the striker when the striker is inserted into the first insertion hole and the second insertion hole; and
a lever assembly including an error lever disposed adjacent to the main gear and the claw while extending across the base between the main gear and the claw, a pawl lever coupled to the base and configured for locking and unlocking the claw such that the claw locks and unlocks the striker, a release lever connected to the error lever and the pawl lever while being pivotable about a second rotation shaft coupled to the base, and a cinching member connected, at a first side thereof, to the release lever while being connected, at a second side thereof, to the error lever such that the cinching member is pivotable, causing the claw to lock the striker,
wherein the pawl lever is pivotably coupled to the base by the second rotation shaft, together with the release lever and the error lever;
wherein the pawl lever is formed, at a first side thereof, with an engagement protrusion extending toward the claw to prevent and allow rotation of the claw, thereby locking and unlocking the claw; and
wherein the pawl lever is formed, at a second side thereof, with a first stopper to limit a pivotal angle of the release lever.

US Pat. No. 10,920,463

SIDE DOOR OCCUPANT LATCH WITH MANUAL RELEASE AND POWER LOCK

INTEVA PRODUCTS, LLC, Tr...

1. A latch comprising:a frame having a slot extending inwardly from a peripheral edge of the frame, the frame having a corner located adjacent to the slot at the peripheral edge;
a claw pivotally mounted to the frame and configured to rotate between an unlatched position and a latched position;
a pawl pivotally mounted to the frame at the corner and configured for movement between an engaged position and a disengaged position, the pawl retains the claw in the latched position when the pawl is in the engaged position and the pawl releases the claw when it is in a disengaged position, wherein the claw is free to move from the latched position to the unlatched position when the pawl is in the disengaged position; and
a bumper located on the pawl to dampen noises as the pawl is moved by a portion of the claw, wherein a main body portion of the pawl is orthogonally positioned with respect to the peripheral edge of the frame located adjacent to the corner when the pawl is in the engaged position and the main body portion of the pawl is also generally parallel to a load path applied to the pawl by the claw when the pawl is in the engaged position and the claw is in the latched position, wherein pawl extends from a pivot to a distal end, the pivot pivotally mounts the pawl to the frame and the distal end has a contact portion configured to contact and engage contact portions of the claw, wherein the contact portions of the claw are located on opposite sides of a throat of the claw and wherein the pawl extends a first distance from the pivot to the distal end, the first distance being greater than a second distance from the pivot to the corner.

US Pat. No. 10,920,462

HANDLE FOR A VEHICLE DOOR

U-SHIN ITALIA S.P.A., Pi...

1. A handle for a vehicle door, comprising:an activation member configured to activate a latch of a vehicle door so as to unlatch the door;
a grip member configured to cooperate with the activation member so as to unlatch the door,
wherein the grip member comprises a gripping part, the grip member being movable between:
a flushing position in which the gripping part extends flush to an external panel of the door,
an active position in which the gripping part projects with respect to the external panel and becomes graspable, and the grip member cooperates with the activation member, and
an opening position in which the grip member drives the activation member to activate the latch and unlatch the door; and
an actuator lever configured to engage the grip member to drive the grip member between the flushing position and the active position,
a driving mechanism comprising a structure of the actuator lever configured to cooperate with a structure on the gripping part; and
a retaining means operable in a retaining state, in which the actuator lever is retained, and a releasing state, in which the actuator lever is released to move;
the handle being configured such that when the grip member is pulled according to an opening direction, the grip member drives the activation member which in turn activates the latch to unlatch the door,
wherein the grip member is rotatably mounted about a grip axis and the actuator lever is rotatably mounted about an actuator axis, the grip axis and the actuator axis being substantially parallel to each other,
wherein the grip axis is disposed longitudinally in front of the gripping part of the grip member,
wherein the actuator lever is configured to be moved manually or by a motor to move the grip member between the flushing position and the active position,
wherein, during manual operation, after an external force is applied toward the grip member, the driving mechanism moves the retaining means into the releasing state, such that the actuator lever cooperates with the grip member to drive the grip member between the flushing position and the active position, and
wherein, during motorized operation, a motor is configured to move the actuator lever to cause the driving mechanism to move the retaining means into the releasing state, to cause the actuator lever to cooperate with the grip member to drive the grip member between the flushing position and the active position.

US Pat. No. 10,920,461

VEHICLE DOOR LATCH ASSEMBLIES

1. A door latch assembly comprising:a handle bezel comprising a main body portion and a rib extending from the main body portion;
a rotatable handle configured to be operatively coupled to a door latch, the rotatable handle coupled to the handle bezel and comprising a handle lever extending through the main body portion of the handle bezel, wherein the handle lever extends alongside the rib of the handle bezel; and
a bezel cap defining a bezel rib receiving channel, wherein the bezel cap is positioned in a first position at an end of the rib so as to provide clearance for the handle lever of the rotatable handle to rotate thereby, wherein the bezel cap via the bezel rib receiving channel is configured to move along the rib toward the main body portion of the handle bezel to interfere with a rotation of the handle lever during a side impact condition, wherein a force of the side impact condition is transferred to the bezel cap.

US Pat. No. 10,920,460

FORGED FRAME HANDCUFFS

ARMAMENT SYSTEMS AND PROC...

1. A method of manufacturing a handcuff comprising:a. bending a first bar of alloy into a curve roughly matching a shape of a desired cheek plate half;
b. heating the first bar to a forging temperature;
c. die forging the first heated, curved bar into a first cheek frame forging having a first lockset cavity portion;
d. trimming the first cheek frame forging to shape to a form a first forged cheek from half having a first cheek arm;
e. repeating steps a-c with a second bar of alloy thereby obtaining a second cheek frame forging having a second lockset cavity portion;
f. trimming the second cheek frame forging to form a second forged cheek frame half having a second cheek arm;
g. joining the first cheek frame half directly to the second cheek frame half, the first lockset cavity portion and the second lockset cavity portion combining to form a lockset cavity;
h. pivotally attaching a bow between the first and second cheek arms;
i. installing a lockset in the lockset cavity.

US Pat. No. 10,920,459

MULTI-LOCK HANDCUFFS

1. A multi-lock handcuff assembly comprising:an outer frame;
at least one bow pivotally coupled to the outer frame, and comprising an arcuate shape and a plurality of ratchet teeth;
a first locking bar pivotally coupled within the outer frame and comprising a plurality of ratchet teeth and a first shoulder;
a second locking bar pivotally coupled within the outer frame and comprising a plurality of ratchet teeth and a second shoulder offset from the first shoulder;
at least one spring disposed within the outer frame and comprising a first portion biasing the plurality of ratchet teeth of the first locking bar to interlock with the plurality of ratchet teeth of the at least one bow and a second portion biasing the plurality of ratchet teeth of the second locking bar to interlock with the plurality of ratchet teeth of the at least one bow when the at least one bow is brought into cooperation with the first locking bar and the second locking bar; and
a third locking bar pivotally coupled within the outer frame and comprising a plurality of ratchet teeth and a third shoulder offset from the second shoulder and aligned with the first shoulder,
wherein the first locking bar, the second locking bar, and the third locking bar are pivotally connected to a pivot pin within the outer frame and the second locking bar is disposed in between the first locking bar and the third locking bar, and
wherein the at least one bow comprises a first bow, a second bow, and a third bow, wherein the first portion of the at least one spring biases the plurality of ratchet teeth of the first locking bar to interlock with the plurality of ratchet teeth of the first bow, the second portion of the at least one spring biases the plurality of ratchet teeth of the second locking bar to interlock with the plurality of ratchet teeth of the second bow, and a third portion of the at least one spring biases the third locking bar to interlock with the plurality of ratchet teeth of the third bow.

US Pat. No. 10,920,458

PROTECTIVE CASE

LEICA GEOSYSTEMS AG, Hee...

1. A portable protective case for transporting an electrical measuring device, the portable protective case comprising:an outer shell with internal cladding which encloses an interior space configured to accommodate the electrical measuring device, wherein the interior space has at least one mounting configured to accommodate a specific type of measuring device with known dimensions;
a handle configured to enable the protective case to be carried by a user;
a locking mechanism configured to enable the protective case to be opened by the user;
a communication unit integrated into the protective case;
a power supply unit having at least one accumulator for supplying power to the communication unit; and
a verification means for verifying a presence and an identity of the electrical measuring device in the interior space, wherein the communication unit is configured to:
retrieve data about the presence and identity of the electrical measuring device,
retrieve and send data via an external wireless network, and
receive localization data that provides at least an approximate position of the protective case,
wherein the communication unit is configured:
to retrieve data from an external server over the internet, from which data a legitimacy or illegitimacy of the user's possession of the measuring device can be determined, and
to determine, based on said data, whether the user is in legitimate or illegitimate possession of the measuring device,
wherein the portable protective case is configured to automatically perform an anti-theft functionality if the communication unit has determined that the possession is illegitimate, wherein in the context of the anti-theft functionality, the communication unit is configured to automatically send a command to a measuring device located in the interior space in order to activate a locked mode of the measuring device, in which locked mode essential functions of the measuring device are not available.

US Pat. No. 10,920,457

ELECTRO-MECHANICAL LATCHING/LOCKING WITH INTEGRATED TOUCH/PUSH ACTIVATION

Accuride International In...

1. A first controller for controlling a locking mechanism for a drawer coupled to cabinetry by at least two drawer slides, the first controller maintaining an indication of status of the drawer, the first controller configured to:receive a first indication from a first sensor that the drawer is pressed inward into the cabinetry;
receive a second indication from a second sensor that the drawer is pressed inward into the cabinetry; and
upon receipt of either the first indication or the second indication, if the indication of status of the drawer is closed, command a locking mechanism associated with the first drawer slide to move to an unlocking position.

US Pat. No. 10,920,456

SAFE LOCKING APPARATUS WITH ENHANCED STRENGTH

1. A locking apparatus with enhanced strength for use with a safe, the safe comprising a housing with a door pivotably mounted to an opening in the housing connected to an internal cavity, the door configured to pivotably adjust to an open position to permit access to the internal cavity or a closed position to seal the internal cavity, the locking apparatus comprising:a cam comprising a plurality of outer curved slots and rotatably mounted to a rear wall of the door, the cam positioned within the internal cavity of the safe in the closed position;
a plurality of arm members slidably mounted to the cam, each arm member in the plurality of arm members being in direct communication with one of the plurality of outer curved slots in the cam, each arm member in the plurality of arm members coupled to a primary roller bearing disposed within one of the plurality of outer curved slots of the cam by a primary set of fasteners, the primary roller bearing configured to travel within the outer curved slot to enable the arm member to slidably adjust to an extended position or a retracted position, each arm member in the plurality of arm members comprising at least one guide slot disposed therethrough and in direct communication with the rear wall of the door by a secondary set of fasteners;
a shaft coupled to the cam and extending through the door of the safe; and
a bearing assembly connecting the cam to the door, the bearing assembly comprising:
a hub coupled to the rear wall of the door;
a plurality of ball bearings disposed around the hub; and
an outer race coupled to the hub and disposed around the plurality of ball bearings,
wherein:
the shaft is maneuvered to rotate the cam in a first direction to permit the plurality of arm members to slidably adjust to the extended position away from the cam and beyond a perimeter of the door within the internal cavity, thereby locking the door in the closed position,
the shaft is maneuvered to rotate the cam in a second direction to permit the plurality of arm members to slidably adjust to the retracted position toward the cam within the perimeter of the door, thereby unlocking the door and allowing pivotal movement of the door to the open position, and
the hub comprises an opening with a cam roller bearing disposed thereto configured to permit the shaft to extend therethrough.

US Pat. No. 10,920,455

LOCKING MECHANISM FOR BORED LOCK

Sargent Manufacturing Com...

1. A bored, cylindrical or tubular lock comprising:a locking element constructed and arranged to alternately move between an unlocked and a locked position;
a reversible electric motor operably coupled to the locking element;
an auger operably coupled to the electric motor; and
a spiral lock spring disposed between the locking element and the motor, the lock spring having only a first portion having an essentially constant diameter and a second portion having an essentially constant diameter, wherein the diameter of the second portion of the spring is larger than the diameter of the first portion of the spring, the first portion of the spring being at least partially wound around the auger and the second portion of the spring contacting the locking element,
wherein the electric motor is operable to drive the auger in a first rotational direction to retract the spring to a retracted position toward the motor and reduce spring force on the locking element, thereby moving the locking element to one of an unlocked or locked position, and
wherein the electric motor is operable to drive the auger in a second rotational direction to extend the spring to an extended position away from the motor and increase spring force on the locking element, thereby moving the locking element to the other of the unlocked or locked position.

US Pat. No. 10,920,454

MECHANISM FOR SECURING A DIGITAL LOCK FROM UNAUTHORIZED USE

AXTUATOR OY, Helsinki (F...

1. A digital lock, comprising:a semi-hard magnet; and
a hard magnet, wherein:
the hard magnet is configured to move to close the digital lock in the event of malicious attack, blocking the intruder by the magnets acting as a blocking pin,
at least one of a mechanical or electromagnetic energy of the attack is configured to move the hard magnet to seal the digital lock from the intruder, and
a first blocking pin is configured to block the lock in the event of a mechanical attack, and a second blocking pin is configured to block the lock in the event of magnetic attack.

US Pat. No. 10,920,453

MORTISE LOCK WITH MULTI-POINT LATCH SYSTEM

Sargent Manufacturing Com...

1. A latch dogging switch for a vertical rod door latch in a door having a latch assembly operable by a handle, the latch assembly comprising a mid-point door latch, a first vertical latch at the top of a door frame and a second vertical latch at the bottom of the door frame, the mid-point and vertical latches being mechanically linked to retract cooperatively from an extended position, a first vertical rod attached to and driving the first vertical latch and a second vertical rod attached to and driving the second vertical latch, the switch comprising:a housing;
an arm fixture affixed to and vertically slideable within the switch housing, the arm fixture attached to one of the vertical rods and moveable therewith; and
a switch block inside the housing and attached to the switch, the switch being alternately slideable into a single-point position and a multi-point position;
wherein when the one of the vertical rods is moved by operation of the handle to retract the vertical latch, the switch may move the switch block to the single-point position, the switch block holding the one of the vertical rods and the vertical latches in place in the retracted position; and
wherein the vertical latches remain retracted upon release of the handle back to its normal position;
and wherein the mid-point latch continues to operate normally between open and closed positions in conjunction with the subsequent operation of the handle while the switch is in the single point position.

US Pat. No. 10,920,452

QUICK INSTALL METHOD AND APPARATUS FOR DOOR LOCKS

Schlage Lock Company LLC,...

1. A lock assembly, comprising:an inner housing positionable on one side of a structure;
an outer housing positionable on an opposite side of the structure;
a pocket connection region having an aperture formed through a wall of the inner housing;
a fastener extendable through the aperture in the pocket connection region; and
a clamp device connected to the pocket connection region of the inner housing;
wherein the clamp device is displaceable between first and second positions relative to the inner housing; and
wherein a head of the fastener freely passes through the aperture when the clamp device is in the first position and the head of the fastener is prevented from passing through the aperture when the clamp device is in the second position.

US Pat. No. 10,920,451

INTERFACE MODULE DEVICE OF DIGITAL DOOR LOCK

AMADAS CO., LTD., Seoul ...

1. An interface module device of a door lock, comprising:a bracket;
an interface bracket fastened with the bracket and defining longitudinal nut guides; and
an interval alignment disposed between the bracket and the interface bracket to adjust an interval between fastening nuts inserted into fastening holes of a locking device of the door lock, the interval alignment defining arched alignment holes;
wherein the fastening nuts are inserted into the nut guides and moved along the nut guides, and
wherein the interval alignment is configured to be fitted with engaging protrusions formed on the interface bracket and rotated, with head protrusions of the fastening nuts being fitted in alignment guides, so that when one of the fastening nuts is manually moved along one of the nut guides, the interval alignment is rotated and another one of the fastening nuts is moved with the rotation of the interval alignment to the opposite direction along the nut guides, so that the fastening nuts are capable of maintaining symmetry about a center of rotation of the alignment guides.

US Pat. No. 10,920,450

LOCKING STRUCTURE FOR COVER COVERING HANDLE SEAT

KURIKI MANUFACTURE CO., L...

1. A locking structure for a cover covering a disk-shaped handle seat, the cover being placed to cover a front surface and a circumferential surface of the handle seat mounted opposite an inner side surface and an outer side surface of a door for supporting a square core equipped with a handle for actuating a latch mechanism arranged within the door, the locking structure comprising:a cover locking mechanism including a plurality of protrusion-shaped cover-side locking portions protruding inward at circumferential intervals at an opening end edge of the cover, and a plurality of handle seat-side locking portions, each formed of a groove portion extending from a front surface to a rear surface, and through which each of the cover-side locking portions formed on the cover can be inserted when the cover is placed over the handle seat, and a hooking groove portion formed continuously and transversely to the groove portion in a rotation direction of the cover when the cover is placed over the handle seat, to which the cover is moved into a hooked state when the cover-side locking portions formed on the cover are inserted when the cover placed is rotated; and
a rotation prevention mechanism including a latch arranged to be movable back and forth and biased in a direction of an end along an axis from a center to an outer circumferential surface of the handle seat at a position of one of the groove portions forming the handle seat-side locking portion and having, at an end, an engagement portion projecting and retracting with respect to a bottom surface of the groove portion such that, when the cover is placed over the handle seat, the cover-side locking portion will enter the groove portion, engaging the engagement portion of the latch so as to retract the engagement portion, allowing further insertion of the cover-side locking portion so as to arrive at the hooked state, the engagement portion is biased back to the groove portion and contacts the cover-side locking portion erected on the cover preventing withdrawal of the cover from the handle seat.

US Pat. No. 10,920,449

HANDLE ADAPTER FOR SLIDING GLASS DOORS

LUUV INC, Cape Coral, FL...

1. A handle adapter for a sliding door comprising:a sliding member comprising a first slide channel and a second slide channel defined on opposing sides of the sliding member and parallel with one another;
a cap comprising a top cap channel, a first side cap channel, and a second side cap channel, wherein the first side cap channel and the second side cap channel are parallel with one another and perpendicular relative to the top cap channel, wherein the cap is aligned with the sliding member along a plane; and
a handle member comprising a top end and a bottom end, wherein the top end is coupled to the cap and the bottom end is coupled to the sliding member, wherein the handle member is substantially protruding beyond the plane.

US Pat. No. 10,920,448

FENCING TOOL

1. A fencing tool comprising:a first end and a second end separated by a shaft,
wherein the first end, the shaft and the second end are coaxial;
wherein the diameter of the shaft and the outermost diameter of the second end are the same size;
wherein the outermost width of the first end has a larger size than the diameter of the shaft, wherein the outermost width is measured in a direction parallel to the diameter of the shaft;
the second end further comprising:
a. an opening drilled through the second end and partially extending through the length of the shaft and
b. a plurality of grooves, wherein the plurality of grooves surround the exterior of only the second end, and the plurality of grooves extend the length of the second end.

US Pat. No. 10,920,447

TENT PEG AND THE PROCESSING METHOD THEREOF

1. A tent peg, comprising a tent peg cover, a tent peg prong and a prism shape tent peg body; wherein the tent peg cover and the tent peg prong are made of alloy, the tent peg body is made of carbon fiber, the tent peg cover is disposed on a top side of the tent peg body, and the tent peg prong is disposed at a bottom side of the tent peg body;wherein a first locking plate is provided on the top side of the tent peg body; a second locking plate is provided at the bottom side of the tent peg body; the tent peg cover is connected to the first locking plate, and the tent peg prong is connected to the second locking plate.

US Pat. No. 10,920,445

DEPLOYABLE SHELTER STRUCTURE

PATRIOT CAMPERS HOLDINGS ...

1. A deployable shelter structure comprising:a base defining a support surface and having a fixed portion supported on a structure and a moveable portion pivotally mounted to the fixed portion to pivot about a first axis, the moveable portion being displaceable from a folded position in which the fixed and moveable portions generally face each other and an unfolded position, in which the fixed and moveable portions are generally coplanar and define the support surface dimensioned to support at least one user, wherein the deployable shelter structure is supported off of the ground;
a collapsible hood including a cover and a plurality of support members supporting the cover, the support members being pivotally connected to the base such that, by pivotal movement of the support members, the hood can be moved between a collapsed state and a deployed state in which the hood covers the support surface to form the shelter; and
an elongate stair or step ladder assembly comprising a first support member and a second support member forming stringers of the stair or step ladder assembly, wherein the stair or step ladder assembly is pivotally mounted on the moveable portion to pivot about a second axis perpendicular to the first axis for movement between a stored position in which the first support member of the stair or step ladder assembly is aligned with an edge or side of the moveable portion and a downwardly extending in-use position, the first support member of the stair or step ladder assembly extending alongside an edge or side of the moveable portion which forms an outermost edge or side of the moveable portion when the moveable portion is displaced to be generally coplanar with the fixed portion,
wherein the stair or step ladder assembly is pivotally mounted to a mounting bracket extending from a first hinge means.

US Pat. No. 10,920,444

MOBILE TOWER FOR TRANSPORTATION AND REMOTE DEPLOYMENT

Tower Solutions, LLC, Me...

1. A mobile tower for transportation to and rapid deployment at remote sites where the mobile tower is configured and arranged to be engaged with the ground, the mobile tower comprising:an extendable and retractable tower secured to a mobile support structure; the mobile support structure including a trailer having a frame; the trailer including a plurality of deployable outriggers for ground engagement; wherein the outriggers are configured and arranged to be compactly secured to the frame during transportation to such remote sites and deployed to stabilize the tower at such remote sites; wherein the tower includes three series of pivotally interconnected tower segments; wherein tower segments in each of the respective series of pivotally interconnected tower segments engage with tower segments in each of the other two of the three series of pivotally interconnected tower segments when the tower is assembled such that one tower segment from each of the three series of tower segments will be engaged with one tower segment of each of the other two series of pivotally interconnected tower segments to form a series of tower stories each including three tower segments; wherein when the tower is assembled, each tower story will have an axis central to and generally equidistant from each of the respective tower segments within each of the respective tower stories;
the mobile tower further including a rigging apparatus and a plurality of guy wires for stabilizing the tower when the tower is assembled, wherein the rigging apparatus is secured to the tower proximate one of the respective tower stories when the tower is assembled; wherein the rigging apparatus generally encircles the tower proximate one of the respective tower stories when it is secured to the tower; and wherein each of the respective plurality of guy wires is secured to and interconnected between the rigging apparatus and one of the plurality of outriggers when the respective outrigger is deployed; wherein each of the respective outriggers is secured to two of the plurality of guy wires proximate an end of the respective outrigger when the respective outrigger is deployed and the tower is assembled; wherein each of the two guy wires is secured proximate the respective end of the respective outriggers and is also secured to the rigging apparatus; wherein each of the two guy wires secured between each of the respective outriggers and the rigging apparatus are interconnected to the rigging apparatus in first and second connecting positions that are displaced from one another about an outer perimeter of the rigging apparatus.

US Pat. No. 10,920,443

AUXILIARY DEVICE AND METHOD FOR REALIZING A BOLT CONNECTION BETWEEN CONNECTING FLANGES OF A FIRST AND A SECOND STRUCTURE

DEME Offshore BE NV, Zwi...

1. An auxiliary device for realizing a bolt connection between connecting flanges, placed against each other, of a first and a second structure, comprising a support body provided with a number of receiving positions for a bolt, wherein the support body takes substantially the form of a circle segment for co-action with substantially circular connecting flanges, wherein the receiving positions are aligned with corresponding bolt holes in the connecting flanges to be placed against each other, and wherein the auxiliary device further comprises moving means for moving the support body toward the connecting flanges which are arranged against each other so that a number of bolts arranged in the receiving positions are collectively arranged through the bolt holes, wherein the support body is movably connected via the moving means to the first structure, and wherein a first part of the moving means, which is connected to the support body, can be moved relative to a second part of the moving means, which is connected to the first structure, under the influence of a mechanically, electrically, pneumatically and/or hydraulically generated force.

US Pat. No. 10,920,442

EXPEDIENT RETROFIT FOR EXISTING BUILDINGS

UNITED STATES of AMERICA ...

1. A platform assembly for installation near an interior wall surface of a building, the platform assembly comprising:a first exterior base unit comprising a threaded post, a plate, an exterior pin, and a lateral pin;
a second exterior base unit comprising a threaded post, a plate, an exterior pin, and a lateral pin;
an exterior stability bar comprising a first sleeve configured to slidingly engage the lateral pin of the first exterior base unit and a second sleeve configured to slidingly engage the lateral pin of the second exterior base unit;
a first lower exterior locking nut configured to threadingly engage the threaded post of the first exterior base unit;
a second lower exterior locking nut configured to threadingly engage the threaded post of the second exterior base unit;
a first exterior intermediate post comprising an upper portion and a lower portion;
a second exterior intermediate post comprising an upper portion and a lower portion;
a first lower exterior support comprising a pin and a collar configured to receive the upper portion of the first exterior intermediate post;
a second lower exterior support comprising a pin and a collar configured to receive the upper portion of the second exterior intermediate post;
a first exterior connector post having an upper portion and a lower portion, wherein the lower portion is configured to be received by the upper portion of the first exterior intermediate post;
a second exterior connector post having an upper portion and a lower portion, wherein the lower portion is configured to be received by the upper portion of the second exterior intermediate post;
a first exterior upper post comprising an upper portion and a lower portion configured to receive the upper portion of the first exterior connector post;
a second exterior upper post comprising an upper portion and a lower portion configured to receive the upper portion of the second exterior connector post;
a first exterior top unit comprising a threaded post and a plate;
a second exterior top unit comprising a threaded post and a plate;
a first upper exterior support comprising a pin and a collar configured to receive the threaded post of the first exterior top unit;
a second upper exterior support comprising a pin and a collar configured to receive the threaded post of the second exterior top unit;
a first upper exterior locking nut configured to threadingly engage the threaded post of the first exterior top unit;
a second upper exterior locking nut configured to threadingly engage the threaded post of the second exterior top unit;
a base z-bar comprising an interior trough, an exterior trough, a first sleeve configured to receive the exterior pin of the first exterior base unit, and a second sleeve configured to receive the exterior pin of the second exterior base unit;
a lower z-bar comprising an interior trough, an exterior trough, a first sleeve configured to receive the pin of the first lower exterior support, and a second sleeve configured to receive the pin of the second lower exterior support;
an upper z-bar comprising an interior trough, an exterior trough, a first sleeve configured to receive the pin of the first upper exterior support, and a second sleeve configured to receive the pin of the second upper exterior support;
a lower panel having a lower portion and an upper portion, wherein the lower portion is received by the exterior trough of the base z-bar and the upper portion is received by the interior trough of the lower z-bar; and
an upper panel having a lower portion and an upper portion, wherein the lower portion is received by the exterior trough of the lower z-bar and the upper portion is received by the interior trough of the upper z-bar.

US Pat. No. 10,920,441

TRANSFERRING CARRIAGE OF VEHICLES FOR AN AUTOMATIC MECHANIC PARKING SYSTEM

SOTEFIN PATENTS SA, Luga...

1. A method of moving a vehicle in an automatic mechanic parking, said method comprising:moving two transferring carriages of vehicles for automatic mechanic parking systems along a longitudinal axis; each of said transferring carriages being placed in correspondence of two wheels of a vehicle, the wheels being opposed to each other and being of a same axle of the vehicle;
and for each of said transferring carriages:
moving two movable supports of said transferring carriage along two opposite transverse directions with respect to said longitudinal axis, each of said movable supports housing a device for centering, taking and raising a wheel of the same axle of the vehicle, each of said devices for centering, taking and raising the wheels being provided with two clamp elements;
exerting on a first wheel of each of the axles of a vehicle a transversal force with respect to said longitudinal axis by contacting said first wheel with a first device for centering, taking and raising, said transversal force moving said first wheel transversally up to the moment in which a second device of centering, taking and raising the wheels contacts a second wheel of the same axle of the vehicle;
rotating each of the clamp elements of each device for centering, taking and raising the wheels from a first open position to a second closed position, wherein the second closed position of each clamp element is reached by a rotatory movement around an axis that is perpendicular with respect to said longitudinal axis until the raising of the wheels is obtained, and wherein
the rotation of each of the clamp elements is triggered by a reaction force exerted by the wheels on the corresponding device of centering, taking and raising the wheel.

US Pat. No. 10,920,440

POOL CLEANING ROBOT AND A REMOVABLE ELEMENT

MAYTRONICS LTD., Kibbutz...

1. A pool cleaning robot comprising:a housing;
an opening formed in the housing;
an impeller that is configured to rotate and to induce fluid to flow through the pool cleaning robot;
a filter for filtering fluid that flows through the pool cleaning robot; and
wherein the filter and the impeller are configured to concurrently exit the pool cleaning robot through the opening.

US Pat. No. 10,920,439

SWIMMING POOL SKIMMER INCLUDING SLIDABLE WEIR GATE AND RELATED METHODS

Jackson Pools, Inc., For...

20. A method of skimming a swimming pool comprising:operating a filter pump coupled to a skimmer comprising a skimmer housing having a water inlet opening coupled to an aperture in a wall of the swimming pool at a waterline thereof, the skimmer housing having first and second opposing vertical skimmer housing passageways;
operation of the filter pump causing a weir gate carried by the skimmer housing to be slideably moveable within the first and second opposing vertical skimmer housing passageways relative to the water inlet opening between open position and closed position blocking the water inlet opening, the weir gate having first and second opposing vertical weir gate passageways therein to engage a plurality of protruding bodies coupled to the skimmer body within the first and second opposing vertical skimmer housing passageways.

US Pat. No. 10,920,438

POOL COVER SYSTEMS AND METHODS

ALOI GROUP PTY LTD, Melb...

1. A pool cover arrangement comprising: a body configured to be positioned on a surface of a body of water; a number of cells provided by the body of the pool cover arrangement; and a number of ventilation passages extending through the body of the pool cover arrangement, wherein each ventilation passage of the number of ventilation passages has an inlet and an outlet for allowing chlorine gas to vent from the water, the inlet and the outlet of each ventilation passage being offset with respect to vertical when the body of the pool cover arrangement is positioned on the body of water to limit direct water exposure to sunlight during the middle of the day.

US Pat. No. 10,920,437

APPARATUS AND METHOD FOR DESIGN AND INSTALLATION OF A CUSTOMIZABLE SOCCER MINI-PITCH SYSTEM

Musco Corporation, Oskal...

1. A customizable portable system for creating a field-based sport venue and one or more playing fields each having a perimeter comprising:a. a plurality of structural components which when assembled approximates the perimeter of the one or more playing fields, said plurality comprising:
i. one or more components designed to withstand a specified wind load and provide rigidity; and
ii. one or more gates to allow access to the one or more playing fields;
b. one or more pole components in operative connection with the plurality of structural components each pole component including an elevated pole;
c. one or more electrically powered devices mounted to the one or more elevated poles;
d. one or more components to house power means for the one or more electrically powered devices and in operative connection with the plurality of structural components;
e. one or more seating components in operative connection with the plurality of structural components;
f. one or more adjustable leveling feet to level at least one of the structural components, pole components, components to house power means, and seating components; and
g. a plurality of fasteners for operatively connecting components.

US Pat. No. 10,920,436

ARRANGEMENT AND METHOD FOR OPERATING A HYDRAULICALLY OPERATED BOOM CARRYING A TOOL IN A CARRIER

HUSQVARNA AB, Huskvarna ...

1. A carrier comprising a controller, at least a first hydraulic cylinder and a second hydraulic cylinder both having each a piston and a piston position sensor, wherein the carrier is arranged to carry a tool via the first and second hydraulic cylinders and wherein the controller is configured to:receive control information for controlling at least one of the first and the second hydraulic cylinder to move the tool in a direction along a working line;
receive position information for the first hydraulic cylinder;
receive position information for the second hydraulic cylinder;
determine if the working line for the tool is maintained, and if the working line is not maintained then
adapt for movement of said at least one of the first and the second hydraulic cylinder by providing control of at least the other of the first and the second hydraulic cylinder to maintain the working line for the tool and thereby feeding the tool along the working line.

US Pat. No. 10,920,435

LINTEL LIFT APPARATUS AND METHOD

Lintel Lift, LLC, Mounta...

1. A lift mechanism for a lintel lift apparatus, the lift mechanism comprising:a nut and bolt assembly, comprising a bolt that is configured to extend through a nut that is configured to rotate around the bolt;
wherein the nut comprises a narrow portion having a first width and a flange that extends outwardly and has a second width that is greater than the first width; and
wherein a bottom surface of the flange is configured to engage a top portion of a support column of the lintel lift apparatus, and the narrow portion of the nut is configured to reside within an interior portion of the support column.

US Pat. No. 10,920,434

PORTABLE ROBOTIC CONSTRUCTION SYSTEM

1. A movable gantry robotic apparatus comprising:a chassis platform with a propulsion system, a power supply and a computing system controller;
an expandable and rotating turret system arises from the chassis platform to support a gantry bridge;
the turret system comprises a lower turret boom riser, a turret and an adjustable boom;
the turret system is able to rotate 360 degrees and move upwards and downwards;
the gantry bridge having a first extendable gantry support leg and a second extendable gantry support leg;
the extendable gantry support legs are connected to microcontrollers and the computing system controller;
the gantry bridge having a bridge conveyor belt system, which has a plurality of conveyor accessory arms, which run along the gantry bridge;
the gantry bridge having a trolley system;
the trolley system comprising at least one track frame and at least one trolley track rail and at least one trolley;
the gantry bridge having at least one gantry accessory arm;
multiple sensors, which are connected to the computing system controller;
whereby the bridge conveyor belt system allows for moving a first item or tool along the gantry bridge; the trolley system allows for moving a second item or tool along the gantry bridge; and the at least one gantry accessory arm allows for moving a third item or tool and while the computing system controller and multiple sensors maintain that the gantry bridge is parallel to the ground by directing the microcontrollers to adjust said extendable gantry support legs.

US Pat. No. 10,920,433

HEAVY DUTY SPANNING FORMS AND RELATED SYSTEMS AND METHODS

Wilian Holding Co., Des ...

1. A modular metal concrete form panel, comprising:(a) a face sheet secured to a perimeter flange, the perimeter flange comprising:
(i) side rails;
(ii) end rails; and
(iii) a lip disposed on the side rails and the end rails;
(b) two opposing bolt blocks secured to the face sheet, wherein each of the two opposing bolt blocks is further secured to the perimeter flange where one of the side rails meets one of the end rails, and wherein each of the two opposing bolt blocks comprises a protrusion disposed in a notch defined in the lip of one of the end rails, whereby each of the two opposing bolt blocks is secured directly to one of the side rails and the lip of the one side rail; and
(c) a strengthening bar disposed inside one of the side rails at a distance from the one side rail and extended between and secured to each of the two opposing bolt blocks, wherein the strengthening bar is secured to the face sheet.

US Pat. No. 10,920,432

HIDDEN CLIP AND FASTENING SYSTEM FOR DECKING

MN Fastener LLC, Paynesv...

1. A decking clip assembly, comprising:a plurality of operatively connected decking clips defining a clip strip, each of the plurality of decking clips including one or more connecting tabs configured to frangibly connect to an adjacent one of the plurality of decking clips, one or more compression tabs, and an aperture configured to receive a fastener,
wherein each of the decking clips comprises:
a planar top portion, the planar top portion defining a leading edge and a trailing edge opposite the leading edge, wherein at least one connecting tab spans between a respective leading edge and trailing edge of adjacent decking clips in the clip strip; and
a vertically extending portion that extends downward from a bottom surface of the planar top portion,
wherein the one or more compression tabs extend vertically downward from a bottom surface of the vertically-extending portion.

US Pat. No. 10,920,431

DRAIN AND VENT COVER

1. A drain and vent cover, comprising:a slide latch comprising a first end adapted to extend at least partially over at least one of a drain or a vent opening;
an attaching component comprising a first end coupled to a second end of the slide latch, and
a wire screen disposed to cover a second end of the attaching component,
wherein the slide latch comprises a hollow body in fluid communication with the at least one of the drain or the vent opening,
wherein the attaching component is in fluid communication to the slide latch, and
wherein the wire screen allows exhaust of waste from the drain or the vent opening and prevents entry of foreign matter into the drain or the vent opening, further comprising a gasket at an interior side of the first end of the slide latch.

US Pat. No. 10,920,430

SUPPORT STRUCTURE FOR SUPPORTING FLOOR PANEL AND ACCESS FLOOR SYSTEM INCLUDING SUPPORT STRUCTURE

HAE KWANG CO., LTD.

1. A support structure on which a floor panel is seated, the support structure comprising:a plurality of first beam elements disposed in a first direction;
a plurality of second beam elements disposed in a second direction perpendicular to the first direction;
a post supporting at least part of the plurality of first beam elements and the plurality of second beam elements; and
a plurality of pedestals seated on top of the plurality of first beam elements and the plurality of second beam elements, and supporting the floor panel,
wherein each of the plurality of pedestals seats on top of a pair of first beam elements and a pair of second beam elements,
wherein the pedestal includes:
a base portion comprising four base assemblies and four pedestal connection members;
a head portion supporting the floor panel; and
a connection portion inserted into the base portion and the head portion, wherein the connection portion is a height-adjustable thread,
wherein each of the four pedestal connection members connects the base portion with each of the pair of the first beam elements and the pair of the second beam elements by passing through each of the four base assemblies.

US Pat. No. 10,920,429

SIDING PANEL WITH IMPROVED LOCKING MECHANISM AND METHOD OF MANUFACTURE

CertainTeed LLC, Malvern...

1. A siding system comprising a plurality of siding panels each secured to an exterior face of a building by a fastener, the plurality of siding panels being arranged in a vertically overlapping fashion to form a plurality of overlapping pairs of siding panels, with each overlapping pair having an underlapping siding panel and an overlapping siding panel having a bottom edge overlapping a top edge of the underlapping siding panel, wherein each of the plurality of siding panels comprises:a siding panel having a front face, a rear face, a first side, and a second side;
a first locking mechanism disposed on the rear face of the siding panel adjacent the top edge, the first locking mechanism being configured to interlock with a second locking mechanism of a second siding panel, the first locking mechanism being formed as a protrusion having a first angled portion;
a second locking mechanism disposed on the rear face of the siding panel, the second locking mechanism being formed as a C-shaped portion having a flat angled portion and a groove, the second locking mechanism being configured to interlock with a first locking mechanism of a third siding panel; and
wherein in each of the overlapping pairs of siding panels, the first locking mechanism of the underlapping siding panel is interlocked with the second locking mechanism of the overlapping siding panel;
wherein the first angled portion of the protrusion of first locking mechanism abuts the flat angled portion of the second locking mechanism, and wherein the protrusion of the first locking mechanism does not fit completely within the groove of the second locking mechanism, and
wherein a front surface of the protrusion of the first locking mechanism of the underlapping siding panel abuts a rear surface of the overlapping siding panel adjacent the second locking mechanism thereof.