Abstract: A fluid separating device comprises: a cylinder; a plurality of separators disposed around a cylinder; a first elastic piece disposed between one of the separators and the cylinder and applying an elastic force to the separator outwardly in the radial direction of the cylinder; a first guiding device passing through the cylinder axially and configured to reciprocate between an expanded position and a contracted position in the axial direction of the cylinder; a second guiding device penetrating the cylinder, connected to the separator at one end, and slidably fitted with the first guiding device at the other end via a fitting surface. The fluid separating device eliminates the friction between the separator and the inner wall of the wellhole when descending, therefore descending to the bottom of the well quickly.

Abstract: A fluid separating device includes a cylinder; a plurality of separators disposed around the cylinder; a first elastic piece disposed between one of the separators and the cylinder and applying an elastic force to the separator outward in a radial direction of the cylinder; a mandrel passing through the cylinder axially and configured to reciprocate between an expanded position and a contracted position in an axial direction of the cylinder; an elastic energy storage device slidably passing through the cylinder along the radial direction of the cylinder, the elastic energy storage device having one end connected to the mandrel and another end connected to the separator, the elastic energy storage device being configured to apply another elastic force to the mandrel in a direction from the contracted position to the expanded position; a first locking structure disposed on the cylinder; and a second locking structure disposed on the mandrel.

Abstract: A system and method for controlling a drilling tool inside a wellbore makes use of projection of optimal rate of penetration (ROP) and optimal controllable parameters such as weight-on-bit (WOB), and rotations-per-minute (RPM) for drilling operations. Optimum controllable parameters for drilling optimization can be predicted using a data generation model to produced synthesized data based on model physics, an ROP model, and stochastic optimization. The synthetic data can be combined with real-time data to extrapolate the data across the WOB and RPM space. The values for WOB an RPM can be controlled to steer a drilling tool. Examples of models used include a non-linear model, a linear model, a recurrent generative adversarial network (RGAN) model, and a deep neural network model.

Abstract: Systems and methods for controlling subsurface drilling operations are described. The methods include performing the subsurface drilling operation using a bottomhole assembly having a disintegrating device, detecting, with a sensor, a formation layer orientation, approaching, with the disintegrating device, a rock layer, and generating a steering command to change an angle of attack of the disintegrating device relative to the rock layer based on the detected formation layer orientation.

Abstract: Image sensors are positioned around a rig floor. An on-site edge or fog computing gateway is communicably coupled to the image sensors. The on-site edge or fog computing gateway includes one or more processors and a non-transitory computer-readable storage medium coupled to the one or more processors and storing programming instructions for execution by the one or more processors. The programming instructions instruct the one or more processors to do the following: receive an image stream form at least one of the plurality of image sensors; generate, from the image stream, an operating condition; determine that an automation rule includes the operating condition generated from the image stream; in response to determining that an automation rule includes the operating condition, send an instruction to drive a controllable device; and, in response to sending an instruction to drive the controllable device, drive the controllable device.

Abstract: Systems and methods for controlling drilling operations are provided. The methods include performing a drilling operation using a bottomhole assembly having a disintegrating device located at an end of a drill string. Detecting and monitoring formation layer orientations with one or more sensors is performed to obtain formation layer orientation information indicative of a formation layer orientation. Monitoring of a drilling operational performance of at least one of the disintegrating device and the bottomhole assembly is performed. A change in the drilling operational performance is detected and adjustment of a steering command is performed to set an angle of attack by the disintegrating device to the formation layer orientation based on the formation layer orientation information.

Abstract: In some embodiments, systems for automatically and dynamically controlling a drill string for drilling an earth formation may include a length of drill pipe, an earth-boring tool, a drawworks, a rotational apparatus, and a pump. A control unit may store software that causes the control unit to: accept a planned trajectory; divide the planned trajectory into a predetermined number of sections, normalizing the distance; receive operational state data from the drawworks, the rotational apparatus, and the pump; at least periodically calculate a normalized performance metric at least in part by dividing a raw performance metric by a distance per section; compare the calculated normalized performance metric to a benchmark performance metric; and send a control signal to cause the drawworks, the rotational apparatus, the pump, or any combination of these to automatically change an operating parameter to better match a corresponding operating parameter that achieved the benchmark performance metric.

Abstract: Disclosed herein are devices, systems and methods useful for downhole sensors and electronics suitable for harsh thermal and mechanical environment associated with high-temperature geothermal drilling and high-temperature/high-pressure oil and gas drilling.

Abstract: A monitoring system includes an image sensor positioned about a rig, the image sensor directed at a drill string component positioned on the rig, and an onsite gateway communicably coupled to the image sensor and disposed proximate to the rig. The onsite gateway includes one or more processors, and a non-transitory computer-readable storage medium coupled to the one or more processors and storing programming instructions for execution by the one or more processors. The programming instructions instruct the one or more processors to receive an image stream of the drill string component from the image sensor, identify an operating parameter of the drill string component, generate an operating condition of the drill string component, determine that the generated operating condition meets a failure threshold of the drill string component, and send an instruction to drive a controllable device.

Abstract: A method of identifying and diagnosing open gas lift valves in a gas lift production well, the gas lift production well including a production tubular having a plurality of mechanical gas lift valves, and a casing surrounding a portion of the tubular to form an annulus. The method includes reducing injection pressure below the minimum design opening pressure of each of the plurality of mechanical gas lift valves to close each of the plurality of mechanical gas lift valves; incrementally increasing injection pressure to operating or designed injection pressure to sequentially open one or more of the plurality of mechanical gas lift valves; measuring pressure, amplitude, frequency and/or wave patterns produced by the sequential opening of the one or more mechanical gas lift valves; and determining the location of the one or more mechanical gas lift valve locations.

Abstract: A method of operating a reciprocating system including a rod pump for pumping liquids from a wellbore. The method includes determining rod position of the rod pump using a wave-based technology detector, the rod pump comprising a rod string carrying a down hole pump and a drive system including a drive motor coupled to the rod string through a transmission unit; communicating rod position to a data acquisition system receiving one or more other measurements of rod pump operation to determine rod pump performance; and adjusting at least one operating parameter to enhance rod pump performance. A method of determining operating parameters and optimizing performance of an oil or gas production rod pump, and a system for determining rod position of an oil or gas production rod pump are also provided.

Abstract: A downhole drilling system is disclosed. The downhole drilling system may include a pulse-generating circuit; a drill bit including a first and second electrode electrically coupled to the pulse generating circuit to receive an electrical pulse from the pulse-generating circuit and to form an electrical arc between the first and second electrodes during a pulsed drilling operation in a first wellbore; a sensor to record responses to a magnetic field generated by a current in a second wellbore, the current generated by the electrical arc; and a sensor analysis system communicatively coupled to the sensor, the sensor analysis system configured to obtain a measurement from the sensor, the measurement representing the recorded response to the magnetic field and determine a distance between the drill bit and the second wellbore based on the measurement.

Abstract: One or more images of a tubular being run into a well are captured. The one or more images can be captured by an image sensor. The tubular includes a first tubular section and a second tubular section connected together by a connection. An onsite edge gateway local to the image sensor is configured to perform various operations. Based on the captured one or more images, an elevation of the connection relative to a reference elevation of the well is determined. Based on the determined elevation, an operating condition is determined. It is determined whether the operating condition is included in an automation rule. In response to determining that the automation rule includes the operating condition, a signal is transmitted to drive a controllable device.

Abstract: Herein disclosed are methods and systems related to processes for injection wells generally utilized in the oil and gas industry. More particularly, disclosed herein are methods and systems related to improving the accuracy of profiling and determining individual cumulative fluid injection profiles for an injection period for multiple zones of an injection well in reservoir systems utilizing conventional warmback models. The methods herein allow for proper modeling and allocation of all injection zones, including zones experiencing a cooldown phenomena during shut-in by transforming the cooldown zonal temperature profiles into temperature profiles which can be utilized in a conventional warmback analysis. These methods are particularly useful in mature reservoir systems where the background reference temperature profile is no longer governed by the geothermal reference temperature profile.

Abstract: A method and system for estimating a thickness of at least one casing string in a cased hole may comprise obtaining a plurality of induction measurements from a plurality of channels using a casing inspection tool, computing a quality vector for the plurality of channels, wherein each element of the quality vector is a numeric output, identifying the plurality of channels is a high-quality or a low-quality based at least in part on an evaluation of the quality vector to obtain a high-quality subset of the plurality of channels and a low-quality subset of the plurality of channels, and estimating the thickness of the at least one casing with an inversion using a high-quality subset of the plurality of channels. A system may comprise a multi-channel induction tool and an information handling system. The multi-channel induction tool may comprise at least one transmitter and at least one receiver.

Abstract: A computer-implemented system includes a downhole tool in a bottom hole assembly attached to a drill string, configured to perform gas measurements during drilling operations. The downhole tool includes a housing to house the downhole tool; sensors positioned along external walls of the housing and including coaxial resonators; electrical circuitry located inside the downhole tool and configured to enable communication by, and operation of, the downhole tool; at least one processor configured to convert scattering parameter 11 (S11) signals received from sensors to permittivity values and determine signatures from permittivity values; a memory for storing data collected by sensors; and a sensor system monitoring changes from a baseline signal of drill mud that is produced during the drilling operations, the changes based at least in part on signatures determined from permittivity values. The downhole tool provides communications to surface systems when a gas kick event is detected by the downhole tool.

Abstract: A method of detecting an event by: obtaining a first sample data set; determining a frequency domain feature(s) of the first sample data set over a first time period; determining a first threshold for the a frequency domain feature(s) using the first sample data set: determining that the frequency domain feature(s) matches the first threshold; determining the presence of an event during the first time period based on determining that the frequency domain feature(s) matches the first threshold; obtaining a second sample data set; determining a frequency domain feature(s) of the second sample data set over a second time period; determining a second threshold for the frequency domain feature(s) using the second sample data set; determining that the frequency domain feature(s) matches the second threshold; and determining the presence of the event during the second time period based on determining that the frequency domain feature(s) matches the second threshold.

Abstract: A downhole assembly includes a first tubular including a first shoulder and a second tubular including a second shoulder. The assembly further includes a transmission element having a first portion disposed in the first shoulder, the first portion includes an electrically conductive member having a first arc length and a second portion disposed in the second shoulder. The second portion includes a contacting element having a second arc length that is substantially less than the first arc length and further includes an outer insulating carrier that defines a groove. The contacting element is disposed in the groove. When the first tubular is joined to the second tubular, the contacting element contacts the electrically conductive member and the second portion defines at least one region between the electrically conductive member and the second portion in areas of the groove where the contacting element does not contact the electrically conductive member.

Abstract: A hybrid sensing apparatus for collecting data inside a well, the apparatus including an optical cable that acquires a first set of data; and an array of discrete probes connected to each other with an electrical cable. The discrete probes are configured to acquire a second set of data. The apparatus further includes an attachment system attached to the discrete probes and configured to hold the optical cable. The attachment system is configured to expose the optical cable to directly contact the well.

Abstract: A device and method used to correct beamforming of an acoustic phased array in cases of eccentricity of the acoustic device in a tubular. A processor calculates the eccentricity from multiple scan lines and create a geometric model of a well or pipe relative to the device. The processor may correct each scan line's focus and/or angle of incidence at a surface of the well or pipe based on the observed eccentricity.

Abstract: A pumping schedule for stimulating a well can be dynamically optimized. For example, a layer in a well can be determined to have a highest value for a characteristic. The layer can be assigned as a first layer in an ordered list. A pump rate and type of fluid to pump into the wellbore for reducing an amount of blockage to below a threshold value can be determined based on a feature of the first layer. The blockage can reduce a flow of a production fluid from the first layer into the wellbore. Changes to values for the characteristics of layers in the well resulting from pumping the fluid can be determined. Another layer in the well can be determined to have the highest value for the characteristic as a result of pumping the fluid into the wellbore and can be assigned as the first layer in the ordered list.

Abstract: Methods and systems for characterizing fractures in a subterranean formation are provided. The method includes introducing an encapsulated explosive unit into a casing located in a wellbore within the subterranean formation and maintaining the encapsulated explosive unit in a stage of the casing. The method also includes detonating the encapsulated explosive unit within the stage to generate a pressure wave that passes through a group of perforations and into the fractures and measuring a reflected pressure wave using a pressure sensor coupled to the bridge plug to produce a pressure measurement. The method further includes converting the pressure measurement into an acoustic signal correlated with the pressure measurement by an acoustic signal generator contained in the bridge plug and transmitting the acoustic signal to apply acoustic pressure on a fiber optic cable coupled to an exterior surface of the casing.

Abstract: A wellbore system includes a first fracture formed from a wellbore at a first location; a second fracture formed from the wellbore at a second location; a wellbore seal positioned in the wellbore between the first and second locations and configured to fluidly seal a first portion from a second portion of the wellbore; a pressure gauge positioned in the first portion; a pressure gauge positioned in or uphole of the second portion; and a control system configured to communicably couple to the pressure gauges.

Abstract: Apparatuses and systems and methods implementing the apparatuses and systems include a blender base unit having an rpm sensor and the methods determines a minimum rpm value that is converted to a shear rate, a fluid velocity rate, and an estimated maximum fracture width.

Abstract: A liner system, including a plurality of arcuate panels vertically interlocked, each arcuate panel comprising fiber reinforced composite. Each arcuate panel includes a first engagement tab disposed at a first edge of a panel frame, a second engagement tab disposed at a second edge of the panel frame, the second edge arranged opposite the first edge, a third engagement tab disposed on a third edge of the panel frame, and a fourth engagement tab disposed on a fourth edge of the panel frame, the fourth edge arranged opposite the third edge.

Abstract: The invention discloses a protective device for the occurrence of a mine roof fall, which includes a machine body. A load-bearing cavity 72 is provided in the machine body 10, a load-bearing platform 11 is fixedly arranged on the lower side of the machine body 10, and four circumferences of the machine body 10 are evenly distributed on the outside. The cavity 69 and the load-bearing cavity 72 are provided with a weight-bearing device 75 for lifting a weight. The weight-bearing device can withstand the falling top plate, and the hydraulic cylinder therein can make the device bear the pressure of the top plate on the device and fix the device at the same time. The stabilizing device can keep the device in a stable state under the action of pressure, will not fall, and share part of the pressure. The load-bearing device can support the device to support the pressure on the roof of the mine and drill into the ground.

Abstract: A device that allows for the sequential operations of hole drilling, resin and catalyst insertion and rod insertion in a single machine is provided. The drilling part uses a regular mining drilling machine that is fitted onto the device. Once the hole is drilled, a pipe is inserted into the hole. There are two possible versions of the pipe, a single pipe configured to work with an air cannon shooting resin tubes and a co-joined double pipe to inject resin and a catalyst in separate co-joined pipes so as to emerge unmixed at the end of the pipes. The next step consists in screwing in the rod into the hole, the twisting motion mixes resin and catalyst and in a matter of seconds, the rod is fully inserted and the chemical reaction has started. Because of the speed and accuracy of insertion and the thoroughness of mixing, more catalyst than usual can be used for a faster hardening of the resin, which secures the rod much better and faster.

Abstract: An apparatus, system, and method for automated support of a gate entry for underground full extraction mining that includes gathering entry data for a condition of a gate entry by way of a gate entry support. The method also includes determining, by way of the gate entry support, the condition of the gate entry, advancing the gate entry support in response to determining that the condition satisfies an entry condition threshold. The method may also signal a halt condition for a production cycle, if the condition fails to satisfy the entry condition threshold.

Abstract: A rotor disc retention assembly of a gas turbine includes a tension bolt, a rotor disc with a hub, a web, a blade retention arrangement, a rotational axis, a first axial side and a second axial side. The hub has a central bore around the rotational axis. The web is integrally formed with and extends radially outwards from the hub to the blade retention arrangement. The blade retention arrangement has a centre of mass. A radial plane perpendicular to the rotational axis passes through the centre of mass. The first axial side engages the tension bolt. The radial plane intersects the hub defining a first axial side portion towards the first axial side and a second axial side portion towards the second axial side. The second axial side portion has an axial extent which is between 10% and 30% greater than an axial extent of the first axial side portion.

Abstract: A turbine blade includes a base and an airfoil. The airfoil includes a skin extending from the base and defining a leading edge and a trailing edge opposite the leading edge. The trailing edge includes 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. The tuning region edge includes an upper transition edge, a middle transition edge, a lower transition edge, an upper tuning edge, and a middle tuning edge. The upper transition edge extends from the outer edge towards the inner edge. The middle transition edge is disposed between the upper transition edge and the inner edge. The lower transition edge is disposed between the middle transition edge and the inner edge. The upper tuning edge is 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.

Abstract: An airfoil includes an airfoil body portion that has a pressure side and a suction side. A recessed area in the airfoil body portion is located on one of the pressure side or the suction side. At least one rib divides the recessed area into at least one geometric shape. A cover encloses the recessed area and includes at least one pedestal that engages a distal end of at least one rib. A weld extends through the cover and a portion of at least one rib. The weld spans a width of the distal end of at least one rib.

Abstract: The present invention relates to an impulse body module group with at least two impulse body modules, which, in particular, are identical in construction, for a gas turbine blade, wherein each of the impulse body modules comprises a housing, which, in particular, is of one piece and which has a first cavity, which is closed, in particular in an airtight manner, by a first cover, which is joined to the housing, in particular in a material-bonded manner, and in which a single, in particular spherical or cylindrical, first impulse body is accommodated with play of movement in at least one first direction of impact, wherein the housing has no additional cavity or a single additional cavity, in which a single, in particular spherical or cylindrical, additional impulse body is accommodated with play of movement in at least one direction of impact.

Abstract: A component, such as for a turbine engine, can include an airfoil with an outer wall defining an exterior surface bounding an interior and defining a pressure side and a suction side extending between a leading edge and a trailing edge to define a chord-wise direction and extending between a root and a tip to define a span-wise direction. The component can also include at least one cooling passage within the interior.

Abstract: Aspects generally relate to a method of forming a plexus within an additively-manufactured component. The method includes forming a fluid passage in the plexus by serially forming layers of material along a build direction to form a column defining the fluid passage along a first direction within an interior of a turbine engine component.

Abstract: A turbine blade includes an airfoil portion having a hollow portion extending along the blade height direction and film cooling holes arranged along the blade height direction, and an insert disposed in the hollow portion along the blade height direction and having impingement cooling holes. The insert includes a first high-density opening region having a higher density of the impingement cooling holes than in other surface regions of the insert. The geometric center of the first high-density opening region is positioned on the suction side of the airfoil portion in the leading-edge-to-trailing-edge direction and on the outer side of the midpoint of the airfoil portion in the blade height direction. The film cooling holes includes upstream film cooling holes disposed in the suction surface of the airfoil portion at a position corresponding to the first high-density opening region or at a position closer to a leading edge than the position.

Abstract: A wall of a hot gas component includes a hot and a cold-gas sided surface, one film cooling hole extending from an inlet in the cold-gas sided surface to an outlet in the hot-gas sided surface and with a metering section of constant cross-section and a diffuser section extending from the metering section. The diffuser section is bordered by a diffuser bottom and two opposing diffuser side walls, has a leading region, which extends from the metering section to the outlet, lies opposite the diffuser bottom and has a constant cross-section over its entire length corresponding to an elongation of a leading region of the metering section up to the outlet. The diffuser section has two diffuser arms dividing the flow into two subflows, generating delta-vortices, a v-shaped outlet, and a v-shaped outlet opening.

Abstract: An airfoil includes an airfoil section and a platform from which the airfoil section extends. The platform defines a shelf that extends from the airfoil section to a platform edge. The shelf includes a plenum and a plurality of cooling orifices extend from the plenum toward the platform edge. Each of the cooling orifices has a first orifice end that opens to the plenum and a second, closed orifice end adjacent the platform edge.

Abstract: Disclosed is a fan blade for a gas turbine engine, including: an airfoil, a cavity formed in the airfoil, a cover configured to cover the cavity, the cover when secured to the airfoil encloses the cavity in the airfoil, a conduit extending from the cavity to an exterior surface of the fan blade, and a check valve located in the conduit, the check valve configured to regulate an internal pressure of the cavity when the cover is secured to the airfoil.

Abstract: A vane ring for a gas turbine engine component includes a multiple of vanes that extend between an inner vane platform and an outer vane platform, each of the multiple of vanes contains an airfoil cooling circuit that receives cooing airflow through a feed passage located in the outer vane platform and an extension from the outer vane platform, the extension comprises a metering passage in communication with the feed passage.

Abstract: A vane ring for a gas turbine engine component includes a multiple of vanes that extend between an inner vane platform and an outer vane platform, each of the multiple of vanes contains an airfoil cooling circuit that receives cooing airflow through a feed passage located in the outer vane platform and an extension from the outer vane platform, the extension comprises a metering passage in communication with the feed passage.

Abstract: A vane ring for a gas turbine engine includes a multiple of vanes that extend between the inner vane platform and the outer vane platform, each of the multiple of vanes contains an airfoil cooling circuit that receives cooing airflow through a respective one of a multiple of feed passages; a multiple of metering passages in the outer vane platform, each of the multiple of metering passages in communication with the respective one of the multiple of feed passages; and a multiple of secondary passages in the outer vane platform, each of the multiple of secondary passages in communication with the respective one of the multiple of metering passages.

Abstract: A turbine engine airfoil and method of cooling includes an outer wall defining an exterior surface bounding an interior and defining a pressure side and a suction side extending between a leading edge and a trailing edge to define a chord-wise direction and extending between a root and a tip to define a span-wise direction. The airfoil can also include at least one cooling conduit and an impingement zone located within the at least one cooling conduit.

Abstract: An airfoil for a turbine engine includes an outer wall bounding an interior and defining a pressure side and a suction side, the outer wall extending axially between a leading edge and a trailing edge to define a chord-wise direction, and also extending radially between a root and a tip to define a span-wise direction. At least one cooling conduit can be formed in the interior of the airfoil, and a tip rail can project from the tip in the span-wise direction.

Abstract: A turbine blade having a base and an airfoil, the base including a root end. The airfoil including a skin extending from the base and defining a first edge, a second edge, having a tip end opposite from the root end. The turbine blade further including a base rib extending from the base and into the airfoil, a center divider extending from adjacent the first edge towards the second edge, a center rib disposed between the center divider and the second edge, extending from adjacent the center divider towards the tip end and extending from adjacent the center divider towards the root end, a tip center rib extending from adjacent the second edge towards the first edge, a tip rib extending from adjacent the tip center rib towards the base, a dividing rib and a first channel.

Abstract: An airfoil includes a cooling passage network is embedded in an airfoil wall between inner and outer portions of the airfoil wall. The cooling passage network has an entrance region adjacent the first end of the airfoil section, a plenum region between the entrance region and the second end of the airfoil section, and an exit region adjacent the plenum region. The entrance region includes a plurality of flow guides that divide the entrance region into a plurality of channels that open into the plenum region. The plenum region includes a plurality of pedestals that have a shape that is different from the flow guides.

Abstract: A component, such as for a turbine engine, can include an airfoil with an outer wall defining an exterior surface bounding an interior and defining a pressure side and a suction side extending between a leading edge and a trailing edge to define a chord-wise direction and extending between a root and a tip to define a span-wise direction. The component can also include at least one cooling passage within the interior.

Abstract: A leading edge cover member is provided on an outside of a leading edge area including a leading edge serving as a part on an airflow upstream side of a composite blade body containing reinforcement fibers and a resin. The leading edge cover member includes a composite cover base material that contains reinforcement fibers and a resin, and is provided to the outside of the leading edge area in a bonding manner; and a metallic reinforcement layer formed on at least a part of an outside of the composite cover base material.

Abstract: The invention relates to a turbine part, such as a turbine blade or a distributor fin, for example, comprising a substrate made of a monocrystalline nickel superalloy, a metal sublayer covering the substrate, and a protective layer of metal oxide covering the sublayer, characterised in that the metal sublayer has one surface in contact with the protective layer and the surface has a mean roughness of less than 1 ?m.

Abstract: Embodiments of the present disclosure can provide an apparatus for circumferentially separating turbine blades. An apparatus according to the present disclosure may include: a length-adjustable elongate member having opposing first and second ends; a first clasp coupled to the first end of the length-adjustable elongate member, the first clasp shaped to at least partially engage an airfoil profile of a first turbine blade positioned circumferentially adjacent to a dovetail slot, relative to a centerline axis of the turbomachine; and a second clasp coupled to the second end of the length-adjustable elongate member, the second clasp shaped to at least partially engage an airfoil profile of a second turbine blade circumferentially positioned adjacent to the dovetail slot, the first and second turbine blades being circumferentially adjacent to the dovetail slot at opposing circumferential ends thereof.

Abstract: A variable vane assembly may comprise a first vane and a second vane. The first vane may comprise a first strut portion and a first flap portion. The first flap portion may be configured to pivot relative to the first strut portion. The second vane may comprise a second strut portion and a second flap portion. The second flap portion may be configured to pivot relative to the second strut portion. The first flap may be configured to pivot independently of the second flap.