Abstract: An apparatus that is usable with a well includes an assembly, which includes a whipstock and a lateral deflector that are adapted to be run downhole into a first wellbore of the well as a unit. The whipstock is adapted to guide at least a drilling string to form a second wellbore, and the lateral deflector is adapted to guide a liner during installation of the liner into the second wellbore.

Abstract: Tubular drill string component for drilling a hole with circulation of a drilling fluid around the component and in a direction going from a drill hole bottom to the surface. The component includes a first end including a female threading, a second end including a male threading, and a substantially tubular central zone. The component includes a communication tube arranged at least in the central zone and in contact with a bore of the central zone. A signal transmission cable is arranged in the tube. The communication tube includes a body formed from at least one metal strip arranged with an annular component. The body includes, in section along a plane passing through the axis of the tube, at least two axially elongated lengths, partially overlapping one another with an axial play selected to accommodate the maximum elastic deformation of the component under axial compressive and/or bending stress.

Abstract: A wired pipe coupler that carries at least a data signal includes a carrier having a plurality of electrical components disposed therein and one or more antennas supported by and spaced from the carrier, the one or more antennas being electrically coupled to the carrier through respective ones of the plurality of electrical components.

Abstract: A retainer and guide ring includes a first ring half and a second ring half that when placed adjacent to one another forms a complete ring. The retainer and guide ring also includes a kerf that is formed between ends of each of the first and second ring halves, which ranges from about zero inches to about 0.010 inches. In some exemplary embodiments, the retainer and guide ring is formed by obtaining two identical rings and making a cut along an edge of the diameter on each ring thereby forming a larger ring arc and a smaller ring arc for each of the rings. The two larger ring arcs are used to form the retainer and guide ring. In another exemplary embodiment, the retainer and guide ring is formed by obtaining a single ring and making a cut along the diameter.

Abstract: A floating apparatus for use in a casing string is provided. The apparatus includes an outer sleeve having a valve centrally positioned therein. A cement body is affixed to the check valve and the housing by use of a bonding material.

Abstract: A dual pipe rod assembly section includes an inner rod section and an outer rod section, with a probe which is arranged in the dual pipe rod assembly section, a horizontal drilling device and a probe housing. The probe is arranged in the inner rod section and rotationally coupled to the outer rod section.

Abstract: A method and device for moving racked tubulars, such as pipe and casing joints on pipe racks at oil and gas well sites. The pipe moving tool comprises a wheel assembly with a long straight handle. The wheels fit inside the pipe, which is then moved by simply pushing or pulling the handle forward or backward, as needed. Several wheel assemblies of different diameters may be used interchangeably with a single handle. An extension handle also may be included. The use of this tool makes moving the pipe safer as the worker's hands are not exposed to injury. Additionally, the handle on the tool makes it possible to easily and more safely reach and move shorter pipes racked above or below longer pipes in a multi-level pipe rack; it is not necessary for the worker to lean over or under the longer pipes.

Abstract: A guide dolly for a drilling rig, the guide dolly having: a first dolly engagement roller assembly that is to move in parallel with a drilling mast of the drilling rig. The guide dolly also having a first dolly arm pivotably connected to the first dolly engagement roller assembly. The first dolly arm is configured to attach to a top drive of the drilling rig. A movement of the first dolly arm is to change a position of the top drive over a drilling location.

Abstract: An integral diverter system for diverting drilling fluid returns into flowlines connected to outlets for return to the drilling fluid reservoirs or other desirable locations is disclosed. The diverter assembly includes a lower tubular body that is coupled to a conductor and an upper tubular body having one or more diverter flow outlets, and one or more additional outlets. A connecting means secures the lower tubular body to the upper tubular body. One or more additional packer elements are disposed within the upper tubular body and locking means are provided for securing the one or more additional packer elements in position within the upper tubular body.

Abstract: A manifold directs the flow of drilling mud from a drilling rig. A longitudinal tubular body has a first end and a second end, such that the longitudinal tubular body is supported by at least two supports of a platform. The platform can support a monorail that is parallel to the longitudinal tubular body, so that it is five feet of the longitudinal tubular body. The longitudinal tubular body can have at least three side directed input ports so that the ports are adapted to receive a mud pipe for attachment. Each of the three side-directed input ports can face substantially towards and above the monorail to provide unobstructed lateral attachment of a mud pipe to the longitudinal tubular body.

Abstract: An apparatus and method to wipe a tubular member includes a first wiper section and a second wiper section, in which the first wiper section and the second wiper section are movable with respect to each other towards a point of convergence. The apparatus may further include a base having an aperture formed therein to receive the tubular member such that the first wiper section and the second wiper section are connected to the base and movable with respect to the base between an open position and a closed position.

Abstract: A bearing assembly comprises a bearing enabling a rotatable body to rotate about a rotational axis relative to a stationary body. The bearing includes a bearing inner ring and a bearing outer ring, each having at least first and second roller body tracks provided in or on non-parallel surfaces of the ring. The respective roller body tracks of the bearing outer ring are aligned with the respective roller body tracks of the bearing inner ring and a row of roller bodies is disposed between each of the respective sets of roller body tracks. At least one of the rows of roller bodies comprises one of tapered rollers and spherical rollers, at least one of the rows of roller bodies supports at least axial forces and at least one of the rows of the roller bodies supports at least radial forces.

Abstract: Multiple sensors on a drill string can be utilized to perform equivalent circulation density (ECD) analysis. By utilizing multiple ones of the sensors, the pressure drop in each section of the wellbore can be classified. Additionally, the inclusion of multiple sensors in the drill string allows a wellbore to be sectioned into intervals bounded by any two sensors. Pressure events occurring in a single section of the wellbore bounded by any two sensors can be isolated and analyzed. The isolation can be achieved by subtracting the pressure measured on the shallower sensor from that measured on the deeper sensor.

Abstract: Provided is a method and apparatus for pulling a crown plug from a subsea horizontal christmas tree, the method comprising: (a) providing a subsea lubricator having a longitudinal through bore and a jack attached to the subsea lubricator, the jack having a landing area, and the landing area having an opening which is fluidly connected to the lubricator's through bore; (b) providing a jacking string which includes a landing sub and a crown plug connector, the sub having a landing surface; (c) without the jacking string in step “b”, lowering the subsea lubricator of step “a”, to the horizontal christmas tree and attaching the lubricator to the christmas tree; (d) lowering the jacking string to the lubricator, and, while the landing surface of the landing sub is spaced above and not supported by the landing area of the jack, connecting the plug connector to the crown plug while the landing sub is above and not touching the landing area of the jack; (e) jacking up the jack such that the landing area of the jack c

Abstract: There is provided a high power laser riser blowout preventer system and controller for operation thereof. The system utilizes high power laser cutters that are associated with the riser and the blowout preventer to provide an integrated operation to quickly weaken or cut tubulars to address potential emergency and emergency situations that can arise during deep sea drilling.

Abstract: Systems and methods to inhibit packoff events during downhole assembly motion within a wellbore comprise a downhole assembly that includes an energy-storing structure that defines a charged state and a discharged state and is configured to generate a motive force upon transitioning from the charged state to the discharged state. A fluidizing stream is generated with the motive force from the energy-storing structure which emits the fluidizing stream from the downhole assembly to fluidize a portion of a cuttings bed that may be within the wellbore and proximal to the downhole assembly.

Abstract: Systems and methods to inhibit packoff during drilling assembly removal from a wellbore, utilizing a drilling assembly that includes a transition region between a first section having a first cross-sectional area and a second section having a second cross-sectional area, wherein the second cross-sectional area is greater than the first cross-sectional area. The transition region includes a fluidizing assembly configured to partially fluidize a portion of the cuttings bed that is proximal to the transition region, and/or be in fluid communication with a flow control assembly configured to control flow rate of a fluidizing stream from the fluidizing assembly and to the portion of cuttings bed.

Abstract: A blowout preventer system is provided. In one embodiment, such a system includes a blowout preventer stack including hydraulic components. The blowout preventer stack is coupled to a lower marine riser package that includes additional hydraulic components. The lower marine riser package further includes a pair of control pods that enables redundant control of the hydraulic components of the blowout preventer stack and the additional hydraulic components of the lower marine riser package. Still further, the lower marine riser package also includes a third control pod that enables additional redundant control of the hydraulic components of the blowout preventer stack and the additional hydraulic components of the lower marine riser package. Additional systems, devices, and methods are also disclosed.

Abstract: Provided is a system, including a first module (35b) configured to process fluid from a well, wherein the first module (35b) has an extension conduit (5b), having a connection that is coupleable to a central mandrel of a manifold (5), a processing device arranged in a region surrounding the extension conduit (5b), a processing input (18a), and a processing output (19a). Further provided is a method of processing well fluids, including diverting fluids from a bore of a manifold (1) to a processing module (35b), wherein the processing module (35b) is coupled to a mandrel of the manifold (5), processing the fluids in the processing module (35b), and returning the fluids to a flowpath (19a) for recovery.

Abstract: There is provided a system and method for temporarily locking a wellhead component while cementing it in place within a mineral extraction system. As cement is pumped into the wellhead, its temperature may be increased, leading to thermal expansion of the cement and movement of wellhead components. Disclosed embodiments include a hold-down ring configured to cooperate with tie-down screws to temporarily lock a running tool in place within the wellhead during cementing. In another embodiment, the tie-down screws may cooperate directly with the running tool. The locked running tool then blocks other wellhead components, such as a hanger run into the wellhead by the running tool, from upward axial movement due to thermal expansion of the cement during the cementing process. After the hanger is cemented in place, the running tool may be unlocked and retrieved from the wellhead.

Abstract: A casing head assembly for landing on a stem head of a floating structure can include a stem head adapter assembly that includes a ring shaped stem head adapter plate. A solid upper ring is spaced axially above the stem head adapter plate, defining an adapter gap between the upper ring and the stem head adapter plate. At least one load cell can have a first end that is supported by the stem head adapter plate and a second end that engages the upper ring. At least one piston assembly is selectively secured to the upper ring. The casing head assembly also includes a casing head landed on, and secured to, the upper ring of the stem head adapter assembly. The load cell is selectively constrained between the upper ring and the stem head adapter plate by a load on the casing head.

Abstract: A ball drop wellhead control apparatus provides a control ball between a frac ball drop or frac ball injector used to drop frac balls into a frac fluid stream being pumped into a subterranean well to ensure that only frac balls intended to be dropped reach the frac fluid stream.

Abstract: A ball drop wellhead control apparatus provides a ball controller between a frac ball drop or frac ball injector used to drop frac balls into a frac fluid stream being pumped into a subterranean well.

Abstract: A method of deploying a downhole tool into a wellbore includes: lowering a cable into the wellbore; after lowering the cable, engaging a mold with an outer surface of the cable; injecting sealant into the mold and into armor of the cable, thereby sealing a portion of the cable; lowering the downhole tool to a deployment depth using the cable; engaging a seal with the sealed portion of the cable; and operating the downhole tool using the cable.

Abstract: A packer is disclosed comprising a body with a first end and a second end, wherein the first end and the second end are configured to establish a connection with downhole equipment and wherein at least one of the first end and the second end is configured to establish a fluid flow between the downhole equipment, at least one guard drain, at least one sample drain, at least one guard drain flow line, at least one sample drain flow line configured to transport fluid flow from and to the at least one sample drain and one of the first end and the second end of the body, two swivel connections and a sealing element.

Abstract: The present invention relates to a plugging device (1), comprising a packer device (4) for pressure tight sealing of a pipe. The packer device (4) comprises a cone device (10) comprising a first cone (12) and a second cone (14), each having their base faced towards each other and each comprising a tapering surface (12a, 14a). A first packer supporting device (20) is provided on a first side of the cone device (10), a second packer supporting device (22) is provided on a second side of the cone device (10) and a packer body (50) provided is between the first packer supporting device (20) and the second packer supporting device (22). The first and second packer supporting devices (20, 22) comprise supporting arms (24) having a first end (24a) movably connected to the plugging device (1) and a second end (24b) connected to either a front supporting element (30) or a rear supporting element (40).

Abstract: An anchor mechanism for use in a well including a housing with a plurality of openings evenly distributed along the circumference of the housing and each opening arranged to narrowly house a radially movably slip including first and second end portions, a gripping side facing a well wall, the gripping side being provided with a plurality of teeth, an underside facing the opposite direction, two side faces extending from the gripping side to the underside and to two end faces; the slip having, at its first and second end portions, with a first inclined face and a second inclined face substantially sloping from the end faces and towards the middle portion of the slip on the underside; the slip provided, on its end faces, with laterally projecting tongues having a longitudinal direction parallel to the inclined faces; the slip provided, on its two side faces, with guide portions exhibiting a longitudinal direction perpendicular to the longitudinal direction of the slip and the guide portion complementarily fitti

Abstract: Disclosed are annular flow control devices and their methods of use. One flow control device includes an annular inner shroud coupled to a work string that defines one or more flow ports therein, and an annular outer shroud also coupled to the work string and radially offset from the inner shroud such that a channel is defined between at least a portion of the inner and outer shrouds, the channel being in fluid communication with at least one of the one or more flow ports and configured to restrict a flow rate of a fluid.

Abstract: A down hole pressure isolation tool is placed in a pipe string and includes a pair of pressure discs having one side that is highly resistant to applied pressure and one side that ruptures when much lower pressures are applied to it. The weak sides of the pressure discs face each other. Rather than rupturing the discs by dropping a go-devil into the well, a first of the discs is ruptured or broken by the application of fluid pressure from the well head or surface. Formation pressure is then used, in different ways according to the different embodiments, to rupture the remaining disc.

Abstract: An apparatus and method autonomously controls fluid flow in a subterranean well, as the fluid changes in a characteristic, such as viscosity, over time. An autonomous reciprocating member has a fluid flow passageway there through and a primary outlet and at least one secondary outlet. A flow restrictor, such as a viscosity dependent choke or screen, is positioned to restrict fluid flow through the primary outlet. A vortex chamber is positioned adjacent the reciprocating member. The reciprocating member moves between a first position where fluid flow is directed primarily through the primary outlet of the reciprocating member and into the primary inlet of the vortex assembly, and a second position where fluid flow is directed primarily through the at least one secondary outlet of the reciprocating member and into the at least one secondary inlet of the vortex assembly. The movement of the reciprocating member alters the fluid flow pattern in the adjacent vortex chamber.

Abstract: Surface controlled subsurface control valves for use in wells and methods of controlling the same. In one embodiment, a valve includes a valve body, a bore closure assembly, a mechanical linkage, a drive assembly, and a control assembly. The valve body defines a bore for fluid to flow through when the bore closure assembly is in an open position. When the bore closure assembly is in its closed position, the bore closure assembly prevents fluid from flowing through the bore. The mechanical linkage is operatively connected to the bore closure assembly and to the drive assembly. The primary control assembly determines a force to apply to the mechanical linkage based on a present operating condition of the valve and causes the drive assembly to apply the determined force to the mechanical linkage. As a result, the mechanical linkage drives the bore closure assembly.

Abstract: A tool for selectively treating a wellbore with fluid that includes a tubing string having a sidewall defining an inner bore, the sidewall comprising a flow area having at least one fluid flow port that permits fluid flow through the sidewall. Fluid is prevented from flowing through the flow area when a closure is in a closed position. When in the open position, fluid flows through the flow area. An axial seal is connected to the closure to selectively close the inner bore against fluid pressure to apply the predetermined opening force to move the closure to the open position. A releasable connector connects the axial seal to the closure and a retrieval tool attachment releases the axial seal from the closure upon application of a predetermined release force by a retrieval tool.

Abstract: A debris collecting tool for use within a wellbore is provided. The tool comprises a filter body having an upstream end and a downstream end. A first fluid passage extends longitudinally between the upstream and downstream ends of the filter body, and at least one second fluid passage connects the first fluid passage with the exterior of the filter body. A filter is located between the first fluid passage and the at least one second fluid passage. The tool further comprises a flow controller movable between a first position in which fluid is prevented from entering the at least one second fluid passage from the exterior of the filter body, and a second position in which fluid is permitted to enter the at least one second fluid passage from the exterior of the filter body. An agitator body is attached to the upstream end of the filter body, and includes at least one radially projecting agitation member. Methods of using the tool to collect debris and clean a wellbore are also provided.

Abstract: In a subsea system where subsea devices are operated using a pressurized fluid from one or more accumulators, the method of providing flow of pressurized fluid to operate a device which is greater than the flow from an accumulator providing the flow, comprising discharging the accumulator to drive one or more motors, driving one or more pumps by the one or more motors, the one or more pumps having a larger displacement than the one or more motors such that the one or more pump outputs a greater volume of fluid than the motor consumes, and delivering the output of the one or more pumps to operated the subsea device.

Abstract: A cutting unit for a slot-type perforator is mounted in a casing, driven by a pusher, containing cutting tools with an extension mechanism for extending thereof, including a holder fixed to the pusher and another holder fixed to the casing. The holders are capable of rotating, causing an extension and retraction of the cutting tools from and to the casing. The extension mechanism includes a balance beam, having shoulders for placing the cutting tools and being assembled in the casing between the holders. The beam rotates around an axle during interaction with the holders. The axle is adapted to move along the longitudinal axis of the casing, e.g. in a groove arranged therein. The cutting unit may include at least two balance beams sequentially mounted between the holders. The cutting unit can be equipped with a retractable mechanism bringing parts thereof into a transportation position and fixing them therein.

Abstract: A system for injecting high pressure abrasive fluid into an abrasive jet tool in a wellbore comprises an abrasives hopper; a slurry tank connected to the abrasives hopper; a low pressure abrasive pump connected to the slurry tank; a first high pressure vessel connected to the low pressure pump through a first high pressure valve; a high pressure non-abrasive pump connected to the first high pressure vessel through a second high pressure valve; and an abrasive jet tool connected to the first high pressure vessel through a third high pressure valve.

Abstract: A shaped charge includes a casing defining an interior volume, wherein the casing is prepared by sintering a metal powder or a mixture of metal powders; a liner located in the interior volume; and an explosive between the liner and the casing. A method for manufacturing a shaped charge casing includes the steps of mixing a metal powder or a metal powder mixture with a binder to form a pre-mix; pressing the pre-mix in a mold to form a casing green body; heating the casing green body to a first temperature to vaporize the binder; raising the temperature to a second temperature in an inert or reducing atmosphere to sinter the metal powder or the metal powder mixture to produce the shaped charge casing.

Abstract: A wellbore select fire switch retaining member system and method with an integrated through wire and ground wire in a switch sub. The system/method includes a retaining member that has a form factor acceptable by a conventional switch sub. The retaining member incorporates an electrical connection to the center pin of a pressure switch. The system further includes a secondary piston aligned with a piston in the switch (switch piston) so that external pressure is fully acted upon the entire switch piston creating a reliable switch connection. Another system includes an integrated retaining member and switch module having a form factor compatible with existing switch subs. The integrated module inputs include a ground wire and a through wire and the outputs include a ground wire, through wire and an arming wire.

Abstract: An injector insert apparatus includes a body that has an inner oil passage that is configured and arranged to allow oil to pass therethrough. The body further has an annular chamber formed around the inner oil passage. The annular chamber has a chamber opening that is configured to be coupled to receive a flow of thermal gas medium. The body also has at least one injector orifice that provides a passage between the annular chamber and the inner oil passage. The at least one injector orifice is configured to inject the thermal gas medium into oil passing through the inner oil passage.

Abstract: A steam-assisted gravity drainage or cyclic steam injection method for recovering oil from a development region of an underground reservoir, further employing water injection along one or more peripheral side edges of the development region via a horizontal well or wells to thereby bound the development region on at least one side edge thereof, and preferably along two or more side edges, with water to thereby reduce steam loss from the development region and thus reduce steam-to-recovered oil ratio (SOR). The water may be combined with diluents. The water which is injected into the horizontal well or wells may comprise produced water recovered from said reservoir.

Abstract: A method of producing hydrocarbons in situ from a fixed-bed hydrocarbon formation disposed below a ground surface and having a higher permeability zone substantially parallel to, and between a top lower permeability zone and a bottom lower permeability zone. The steps include providing at least one injection well and first and second production wells in the higher permeability zone, injecting a heated thermal-energy carrier fluid (TECF) into the injection well, circulating the carrier fluid through the zone and creating a substantially horizontal situ heating element (ISHE) between the injection well and the production wells for mobilizing the hydrocarbons.

Abstract: A method and apparatus for conducting a fracturing operation using a wellbore fracturing assembly. The assembly may be mechanically set and released from a wellbore using a coiled tubing string to conduct a fracturing operation adjacent an area of interest in a formation. The assembly may include an unloader for equalizing pressure between the assembly and the wellbore, a pair of spaced apart packers for straddling the area of interest, an injection port disposed between the packers for injecting fracturing fluid into the area of interest, and an anchor for securing the assembly in the wellbore. After conducting the fracturing operation, the assembly may be relocated to another area of interest to conduct another fracturing operation.

Abstract: In a method of hydraulically fracturing a hydrocarbon-bearing subterranean formation, a proppant stage is introduced into the fracture which contains a gaseous fluid and an ultra lightweight proppant suspended in a viscosified aqueous fluid. The gaseous fluid of the proppant stage contains at least about 90 volume percent of the combination of gaseous fluid and aqueous fluid. A pad fluid may first be introduced into the formation, the pad fluid containing a gaseous fluid and, optionally, an aqueous fluid. The gaseous fluid of the pad fluid mixture typically contains at least 70 volume percent of the mixture.

Abstract: A well completion and related method are provided for formations susceptible to simultaneous production of oil and water. In one embodiment, two closely spaced, preferably horizontal wellbores are drilled from a single well into the reservoir. The reservoir rock surrounding one leg (typically the upper leg) is chemically treated to make it hydrophobic, whereas the reservoir rock surrounding the other leg is chemically treated to make it hydrophilic. Separate production tubing and a dual completion is installed in order to enable independent flow from each leg. Drawdown pressures in both legs are controlled to be sufficiently close to each other such that only oil flows into one leg and only water into the other. The water produced is re-injected downhole or brought to the surface.

Abstract: A method for calculating orientation changes within a borehole using a gyro sensor to detect angular deflection rates in an attitude reference interval as a MWD system is moved from a first to a second location within the borehole. A compass shot may be taken at one or more of the first and second locations using a magnetometer and accelerometer or gyro sensor and accelerometer. Tieback and/or overlap processing may be applied to increase the accuracy of measured orientation within the borehole. Additionally, tieback and/or overlap processing may be applied to adjust sensor model parameters in response to discrepancies between calculated and measured locations. Iterated calculations of orientation change between subsequent intervals may allow MWD orientation to be computed for an entire drilling operation using only a single compass shot.

Abstract: A method of servicing a wellbore includes arranging an assembly within a lubricator coupled to a tree, the assembly including at least one downhole tool and a signal receiver subassembly. An acoustic signal is communicated to the signal receiver subassembly while the assembly is arranged within the lubricator. The acoustic signal is perceived with a transceiver communicably coupled to the signal receiver subassembly and thereby activates a timer communicably coupled to the signal receiver subassembly while the assembly is arranged within the lubricator. The assembly is introduced into the wellbore and advanced until reaching a target depth. A trigger signal is them transmitted with the signal receiver subassembly to the at least one downhole tool to actuate the at least one downhole tool.

Abstract: A measurement-while-drilling (MWD) telemetry system comprises a downhole MWD telemetry tool comprising a mud pulse (MP) telemetry unit and an electromagnetic (EM) telemetry unit. The MWD telemetry tool can be configured to transmit data in an EM-only telemetry mode using only the EM telemetry unit, in an MP-only mode using only the MP telemetry unit, or in a concurrent telemetry mode using both the EM and MP telemetry units concurrently. When transmitting data in the concurrent telemetry mode, the telemetry tool can be configured to transmit in a concurrent confirmation mode wherein the same telemetry data is transmitted by each of the EM and MP telemetry units, or in a concurrent shared mode wherein some of the telemetry data is transmitted by the EM telemetry unit, and the rest of the telemetry data is transmitted by the MP telemetry unit. The telemetry tool can be programmed to change its operating telemetry mode in response to a downlink command sent by an operator at surface.

Abstract: Formation wettability is quantifiably estimated from measurements of dielectric constant and conductivity. In particular, wettability state of formation rock in a subterranean environment is estimated from multi-frequency measurements of rock dielectric constant and conductivity. A dielectric dispersion model is used to invert the measurements and estimate the saturation exponent. The resulting saturation exponent is used to quantify wettability, e.g., by calculating a wettability index.

Abstract: The present invention relates to a method and system for identifying one or more characteristics within a subterranean reservoir of natural gas.

Abstract: A mining machine includes a boom, a cutter head, a valve, and an actuator. The boom defines an internal chamber and includes a first end coupled to a frame, a second end, and an opening in fluid communication with the internal chamber. The cutter head includes a plurality of cutting bits and is supported on the second end of the boom. The valve is coupled to the boom and is movable between a closed position in which the opening is covered and an open position in which the opening is at least partially uncovered. The actuator is coupled to the valve to selectively move the valve between the closed position and the opened position.