Abstract: A hanger system for use with a housing of a wellhead includes a hanger assembly. The hanger assembly includes a hanger having a respective radially-outer surface and a radially-extending surface, as well as a first annular wedge having a respective radially-outer surface with a first annular wedge surface texture. The radially-extending surface is configured to engage a shoulder of the housing of the wellhead while the hanger assembly is in a landed position within the housing of the wellhead, and the first annular wedge surface texture is configured to engage a respective-radially inner surface of the housing of the wellhead while the hanger assembly is in a sealed position within the housing of the wellhead.

Abstract: Provided are techniques for operating a hydrocarbon well system that include installing a wellhead seal assembly at a wellhead of a hydrocarbon well system, conducting pressure testing of a wellhead seal cavity defined by the seal assembly to verify its integrity, disposing a control fluid into the wellhead seal cavity, conducting baseline ultrasonic imaging of the wellhead seal cavity to generate a baseline ultrasonic image that depicts a signature of the control fluid disposed in the wellhead seal cavity at a first point in time, conducting updated ultrasonic imaging of the wellhead seal cavity to generate an updated ultrasonic image that depicts a signature of substances disposed in the wellhead seal cavity at a second point in time, comparing the updated ultrasonic image to the baseline ultrasonic image to determine whether the integrity of the wellhead seal cavity has been compromised.

Abstract: A managed pressure drilling (MPD) manifold has one or more valves that are operable by one or more actuators configured to synchronize the opening of one or more passageways in the valves with the closing of one or more of the other passageways in the valves, in order to minimize the likelihood of error and reduce response time. The valves are configured to transition smoothly between positions without fully blocking fluid flow in the manifold while changing the flow direction. The synchronization may be achieved mechanically, electrically, hydraulic, and/or pneumatically. The actuators may be remotely controlled by a control unit having a processor and control logic software, based on data collected by one or more sensors in the MPD manifold. The positions of the valves of the MPD manifold may be automatically adjusted by the control unit via the actuators.

Abstract: A rotating control device (RCD) for use in pressurized drilling operations. The RCD having a non-rotating RCD housing enclosing an elongate passage, a tubular RCD mandrel extending along the elongate passage of the RCD housing, wherein the RCD mandrel has a longitudinal axis and is configured in use to rotate relative to the RCD housing about the longitudinal axis, and a stripper element which is mounted on an end of the RCD mandrel and which is configured to seal against and rotate with a tubular drill pipe extending along the elongate passage of the RCD housing, wherein the stripper element is secured to the end of the RCD mandrel by a flexible sleeve which is more flexible than the stripper element.

Abstract: A cylindrical protection sleeve is insertable into the bore of a tubing hanger in a wellhead, and has a skirt that projects into the bore of the tubing hanger to cover the lift thread formed in the upper region of the hanger bore, thus shielding the lift thread from contact by frac fluid and proppant particles flowing through the hanger bore and preventing resultant damage to the lift thread. Optionally, an annular deflection lip may be provided within the bore of the protection sleeve's skirt to deflect the downward flow of proppant particles toward the center of the flow path through the hanger, and thus minimizing contact of proppant particles with the back-pressure valve (BPV) thread profile formed in the hanger bore below the lift thread, and preventing or reducing resultant damage to the BPV thread profile.

Abstract: A technique facilitates pressure testing of seals along a tubing hanger, such as a tubing hanger used in a subsea application. In some applications, the tubing hanger is sealed along its exterior with an upper tubing hanger seal and a lower tubing hanger seal. A valve assembly is deployed along a fluid passageway which is routed to the tubing hanger seals. The valve assembly may be selectively actuated to a test position, e.g. a closed position, which enables pressure isolation and pressure testing of the tubing hanger seals. The valve assembly may also be selectively utilized to introduce fluids into the formation below the tubing hanger.

Abstract: A system including a backpressure valve (BPV) system configured to mount in a hydrocarbon extraction system, wherein the BPV system includes a body comprising a vent port and a test passage, and a plunger configured to form a seal with the body around the vent port wherein the BPV system is configured to test the seal by pumping a fluid into the body through the test passage.

Abstract: A hanger assembly for use in a vertical production tree that includes an annular piping spool member having a side opening, and a hanger having an outer surface profiled to selectively land in the piping spool member and a side opening registered with the side opening of the piping spool member. The hanger assembly also includes a vertical penetrator having an end selectively connected to a submersible device and an opposing end inserted into the hanger, and that is in communication with the side openings.

Abstract: A subsea completion for a well is presented that includes a tubing spool, a tubing hanger, a fluid coupling, an electrical coupling, a control system, a valve, and a production tree. The tubing spool includes a central bore, a side wall, and a fluid supply passage extending through the tubing spool. An electrical supply passage can also extend through the side wall of the tubing spool. The tubing hanger includes a fluid control passage. The tubing hanger can also include an electrical control passage. The control system includes a fluid control conduit to provide fluid to the tubing spool fluid supply passage from outside the tubing spool. The valve is connectable to the outside of the tubing spool to control fluid flow between the control system fluid conduit and the tubing spool fluid supply passage.

Abstract: A communication arrangement is disclosed for communication between a downhole line and a wellhead body having a through-hole and a valve member for closing the through-hole. The communication arrangement provides a fluid passage that extends from a wellhead body port to the downhole line thus allowing communication between the wellhead body and a safety valve or valves and/or the injection of chemicals or fluids into the well without the need to rework the valve member or disable the valve member.

Abstract: An assembly supports a control line of a downhole tool, such as a downhole deployment valve. The tool deploys on casing and has a control line extending from the wellhead to the tool. To support the line separately from any casing hanger, a split bowl disposes around the casing and lands on a shoulder in the head. A port in the bowl has one opening that aligns with a side port in the head. Another opening of the bowl's port connects to the control line that extends to the downhole tool. A section of the control line from the split bowl can be flexible to help prevent kinking or breaking of the line during installation procedures. A hanger disposes on another shoulder in the head uphole from the bowl. The hanger supports the casing in the head separate from the bowl's support of the control line.

Abstract: A system, in certain embodiments, includes a subsurface safety valve (SSV) biased toward a closed position, and configured to open by application of hydraulic pressure. The system also includes a tubing hanger running tool (THRT), including a conduit in fluid communication with the SSV, and a pressure release valve fluidly coupled to the conduit. The pressure release valve is configured to maintain sufficient hydraulic pressure within the conduit to hold the SSV in an open position while the pressure release valve is in a closed position.

Abstract: A system and methodology for controlled entry of a tubing string, and cable adjacent thereto, into a wellbore. A stationary housing is fit to a wellhead and has a bore in communication with the wellbore. The cable can be laterally displaced from the bore into a cable access formed into the housing's side wall for fitting a sealing assembly to the bore and engages a sealing surface therein. The sealing assembly seals tubulars passing therethrough. The cable access interrupts the sealing surface. A cable bypass sub is fit to the cable access and permits the cable to extend sealingly from above the sealing surface to the wellbore wherein the cable bypasses the sealing assembly and sealing surface. A seal reconstitutes the interrupted portion of the sealing surface at the cable access.

Abstract: Wellhead control line deployment involves replacing the seat/retainer plate of a master valve of the wellhead with a modified retainer plate. The retainer plate defines a first port communicating from a central opening of the plate to outside the plate. A modified bonnet installs on the master valve, and the bonnet has two ports, one communicating with the first port in the retainer plate and the second communicating with a needle valve port. The communication ports are linked by a tube with outside diameter seals that inserts between the retainer plate and the bonnet. A control line hanger can be retained by locking into an adapter sleeve or directly in the back-pressure valve threads of a tubing hanger. The adapter sleeve can be attached to the retainer plate or have a collet to snap into the back-pressure valve threads of the tubing hanger.

Abstract: A well completion system includes a wellhead, a control line assembly for use in completions that is mounted to the wellhead, and a tubing hanger. The control line assembly includes a cylinder, a main housing assembly, a passage and a metal-to-metal seal. A split lockout ring provides a positive lock to the passage. Control lines enter the tubing hanger and exit via the wellhead. This arrangement on the wellhead provides sufficient height and clearance to allow for the installation of a plurality of control lines.

Abstract: Apparatus and method for isolating an annular bore below a tubing hanger body disposed in a wellhead assembly. The hanger body is characterized by at least two annulus flowby passages that are capable of fluid communication with areas outside the hanger body through the central bore of the hanger body. An integral valve piston is disposed within the central bore of the hanger body, and is operable to axially displace within the central bore between a closed and opened position. The displacement of the piston is caused by the alternating introduction of pressurizing fluid into separate actuation chambers. In the closed position, the piston is positioned so that at least one of the flowby passages is sealingly engaged in a manner that prevents fluid flow through the hanger body from outside sources such as an annulus bore located below the hanger body.

Abstract: A system and method for accessing an annulus within a wellhead assembly while the annulus is pressurized. The system includes a tubular body with an attached valve assembly and adapter. The adapter to the wellhead assembly with a sealed annular fitting. The body houses a selectively extendable plunger assembly rotatable by an attached motor. A bit or milling device is provided on the end of the plunger assembly, so that selectively extending the plunger assembly through the valve assembly and adapter contacts the bit against the wellhead assembly. An opening is formed through the wellhead assembly with the rotating bit allowing access to the annulus.

Abstract: A well head barrier assembly (1, 2, 3) including a termination of an instrument tube (9) installed in a well and a primary pressure barrier (3) for the well pressure comprising a tool (10) arranged for being pushed into a passage (5) in which the instrument tube (9) is arranged. The closing of the passage (5) provides an additional secondary pressure barrier in the well head, thus enabling re-establishment of a double pressure barrier following a breakage of the instrument tube (9).

Abstract: A technique is provided for terminating tubing. In the technique, a tubing termination assembly is used to terminate control line tubing from a downhole safety valve at a wellhead component. The tubing termination assembly utilizes a seal ring to form a seal around control line tubing extending from a port through a wellhead component. A seating surface is provided in the seal ring, rather than in the wellhead component, to which a seal member is abutted to form the seal with the control line tubing. The seal ring also comprises a threaded portion to enable a threaded member to urge the seal member against the seating surface.

Abstract: The invention relates to washpipes for use in drilling operations such as drilling for oil and gas, and more particularly to an auto lubricating washpipe and liner system and method.

Abstract: An adapter for connecting a casing annulus remediation system to a well having a wellhead with standard lateral ports. The adapter has a body with first and second ends. The first end of the adapter body has a substantially planar surface adapted to cover the lateral ports and be in abutting contact with the wellhead when the two are connected to one another. The second end of the adapter body has a planar surface positioned at an angle greater than 0 degrees and up to 90 degrees to the planar surface of the first end. The second end of the adapter is adapted to be connected to a casing annulus remediation system.

Abstract: A mineral extraction system includes a branch having a branch passage, a diverter coupled to the branch passage, and a capillary injection conduit disposed inside to the branch passage. A method of injecting chemicals includes injecting a chemical into a capillary injection conduit disposed internal to a production passage, wherein the chemical injection capillary conduit comprises an inlet and an outlet configured to terminate proximate a well formation.

Abstract: A system in some embodiments includes sealing system including an energizing member that simultaneously seats a plurality of sealing elements about a plurality of control lines, respectively. Further embodiments provide a method including disposing a plurality of sealing elements about a plurality of control lines, respectively, and fastening an energizing member to simultaneously seat each of the sealing elements.

Abstract: A valve (136, 136?, 136?, 200) adapted to replace an existing valve of a wellhead (114). Valve (136, 136?, 136?, 200) can have similar dimensions as the existing valve it replaces to utilize existing wellhead connections. In one embodiment, a replacement bypass master valve (136) incorporates a fluid bypass pathway (168) to enable communication and conveyance of a production enhancing fluid (132) from a location external to the well through small diameter tubing (126) to a specific downhole location independent the position of a flow control member in interior chamber (166). Replacement bypass master valve (136?) can include anchor seal assembly (122?) disposed in locking profile 180 of upstream inlet bore (162) to enable communication from fluid bypass pathway (168) to lower injection conduit (128). In another embodiment, replacement valve (200) includes a groove in gate (208) sealingly receiving capillary injection tubing (204) when in a closed position.

Abstract: A utility line connector assembly having a male stab having a central bore with a port that communicates with a second bore in a receptacle where the stab is fixedly inserted into a receiving female opening in the receptacle, the receptacle has an L shaped opening with a protruding partial spherical pocket, a ring groove for sealing said stab to a riser package, and where the stab and receptacle are placed between a lower marine riser and the blow out preventer in fluid communication therebetween. The stab and receptacle may be sealed with ring seals and the assembly may be used in riser auxiliary line connections, sub sea production tree connections, drape hose connections and surface bop auxiliary line connections.

Abstract: A Christmas tree is used between production tubing elevation and flow line elevation. The tree has a lower portion, an intermediate portion, and an upper portion. The intermediate portion is positioned between the production tubing elevation and the flow line elevation and has an axial dimension configured to substantially maintain the axial dimension between the elevations. The intermediate portion has first and second shut-off valves for closing fluid communication of the axial bore. A hanger is positioned in the axial bore of the intermediate portion between the first and second shut-off valves. The hanger defines a bore and a port. The port communicates a side of the hanger with the lower end of the hanger. The coil tubing attaches to the port at the lower end of the hanger, and the port at the side of the hanger communicates with the feed line of the intermediate portion.

Abstract: An apparatus for retaining two strings of tubulars characterized in that said apparatus comprises body parts of a device for retaining a single string of tubulars and a converting member. A device for retaining a string of tubulars, said device comprising at least one body part having a curved tapered surface upon which inserts are located for engagement with said string of tubulars characterized in that said curved tapered surface comprises a recess for the passage of cables.

Abstract: A stuffing box for a rotating rod includes a stationary housing and a tubular rotating inner housing. The stationary outer housing has an upper end, a lower end, an exterior surface and an inner surface defining an interior cavity. The inner housing is positioned within the interior cavity of the outer housing. The inner housing has an upper end, a lower end, an exterior surface and an inner surface defining an interior bore adapted to accommodate a rod. Bearings are disposed between the outer housing and the inner housing to facilitate rotation of the inner housing. An inner seal assembly provides a seal that prevents the migration of fluids between the inner housing and the rod. An outer seal assembly provides a seal that prevents the migration of fluids between the inner housing and the outer housing.

Abstract: A wellhead assembly to seal and suspend an in-casing hydraulic drive unit for a downhole pump, including pressure-containing wellhead body members with a vertical bore and a production bore at its uppermost portion. A hydraulic pump hanger is retained and sealed in the vertical bore. The hydraulic pump hanger suspends and seals the hydraulic cylinder, includes a bore extending vertically therethrough, forms at least one hydraulic line to communicate with hydraulic fluid supply lines, forms a hydraulic inlet port to each hydraulic line, and provides a check valve sealed in each hydraulic inlet port. The wellhead body member(s) includes a stem port aligned with each hydraulic inlet port, with a valve actuating stem sealed in each stem port to actuate each check valve between a normally closed and open position. The wellhead body member(s) also includes hydraulic injection port(s) formed to supply hydraulic fluid to each hydraulic inlet port.

Abstract: A subsea wellhead assembly has a tubing annulus path that extends partly through the tubing hanger and partly through the wellhead housing. A tubing hanger tubing annulus passage extends through part of the tubing hanger from a lower port on the lower end of the tubing hanger to an upper port on the exterior surface of the tubing hanger below the tubing hanger seal. A wellhead housing tubing annulus passage within the sidewall of the wellhead housing has a lower end at the bore below the tubing hanger seal and an upper end at the bore above the tubing hanger seal. A valve is mounted to the wellhead housing and accessible by an ROV from the exterior for opening and closing the inner wellhead housing tubing annulus passage.

Abstract: A dual bore well jumper establishing fluid communication between a subsea well and a subsea flowline. The dual bore well jumper comprises a first pipe comprising a first pipe bore and a second pipe comprising a second pipe bore, the second pipe being located within the first pipe bore or side-by side with the first pipe. The dual bore well jumper further comprises termination couplings at each for establishing fluid communication with either the subsea flowline or the subsea well. The first and second pipe bores isolate fluid flow in the first pipe bore from fluid flow in the second pipe bore. The dual bore well jumper may optionally further comprise junction assemblies allowing a change in fluid flow direction. The dual bore well jumper may further optionally comprise a bore access module attached to a junction assembly for selective fluid communication with the first and second bores.

Abstract: An apparatus for washing undesirable matter off of the exterior of tubular conduits forming a conduit string during trip out of the conduit string within a subterranean well. The tubular conduits may be drill or workover pipe, or the like. A cylindrical housing has first and second opposite ends. A removable elastomeric seal means is provided across each of the first and second ends. The seal means is selectively secured relative to the housing. Each seal means defines an open passageway therethrough and which is centrally positioned there across. The open passageway through each seal means is sized for introduction, of the tubular conduits into and out of the cylindrical housing and the seal means. A circumferentially extending lip area of each seal means faces toward the respective passageways for snug, wiping contact around the exterior of the tubular conduits during movements of the conduit string into and out of the cylindrical housing.

Abstract: A system and method for subsea drilling/completion. The system comprises a high-pressure riser extending from a semi-submersible platform to a subsea wellhead. A landing string extends along the insider of the riser, and has a surface blowout preventer and at least one subsea blowout preventer attached thereto. A tubing hanger running tool is run from the platform toward the wellhead. In one embodiment, hydraulic control for various functions of the tubing hanger running tool is communicated either through the tubing string or through the riser. In another embodiment, hydraulic control lines for the tubing hanger running tool extend from the platform to the tubing hanger running tool through an umbilical line, which may either run through the tubing string, inside the riser but outside the tubing string, or outside and alongside the riser.

Abstract: A wellhead has, instead of a conventional Christmas tree, a spool tree in which a tubing hanger is landed at a predetermined angular orientation. As the tubing string can be pulled without disturbing the tree, many advantages follow, including access to the production casing hanger for monitoring production casing annulus pressure, and the introduction of larger tools into the well hole without breaching the integrity of the well.

Abstract: A wellhead has, instead of a conventional Christmas tree, a spool tree (34) in which a tubing hanger (54) is landed at a predetermined angular orientation. As the tubing string can be pulled without disturbing the tree, many advantages follow, including access to the production casing hanger (21) for monitoring production casing annulus pressure, and the introduction of larger tools into the well hole without breaching the integrity of the well.

Abstract: A wellhead has, instead of a conventional Christmas tree, a spool tree in which a tubing hanger is landed at a predetermined angular orientation. As the tubing string can be pulled without disturbing the tree, many advantages follow, including access to the production casing hanger for monitoring production casing annulus pressure, and the introduction of larger tools into the well hole without breaching the integrity of the well.

Abstract: A reciprocable connector assembly for coupling a service line through a path in a wellhead and hangar wall, the assembly comprising: connector for coupling with a corresponding connector disposed in the hangar wall; a shuttle carrying said connector between a first position in which the connector is not coupled to the corresponding connector and a second position in which it is coupled, at least one service line connected at one end to the connector and wound in a plurality of turns to extend or retract with respect to one another as the shuttle moves between the first and second positions and a support for constraining movement of the turns.

Abstract: A well completion system includes a completion device defining a bore therein attached to a wellhead and a tool, disposed within the bore, comprising an operational element and a control receptacle in communication with the operational element. The system further includes a horizontal penetrator assembly disposed external to the completion device and comprising at least one horizontal penetrator capable of being extended into and retracted from the bore to engage the control receptacle such that the horizontal penetrator is in communication with the operational element of the tool. A method includes inserting a tool into a bore of a completion device, engaging a horizontal penetrator with a control receptacle of the tool, and operating an element of the tool via the horizontal penetrator.

Abstract: An apparatus for retaining two strings of tubulars characterized in that the apparatus comprises body parts of a device for retaining a single string of tubulars and a converting member. A device for retaining a string of tubulars, the device comprising at least one body part having a curved tapered surface upon which inserts are located for engagement with the string of tubulars characterised in that the curved tapered surface comprises a recess for the passage of cables.

Abstract: A method and assembly for recovering fluids from, or injecting fluids into, a well having a christmas tree; the fluids typically flow between first and second flowpaths in a continuous path. The assembly may be located within the main bore, or a side passage of the christmas tree. Embodiments of the invention allow the fluids to be fed to a processing apparatus, (e.g. a pump or chemical injection apparatus) for treatment, before being returned to the christmas tree. Optionally, the assembly may include a pump located inside the christmas tree body.

Abstract: A wellhead has, instead of a conventional Christmas tree, a spool tree in which a tubing hanger is landed at a predetermined angular orientation. As the tubing string can be pulled without disturbing the tree, many advantages follow, including access to the production casing hanger for monitoring production casing annulus pressure, and the introduction of larger tools into the well hole without breaching the integrity of the well.

Abstract: A wellhead has, instead of a conventional Christmas tree, a spool tree in which a tubing hanger is landed at a predetermined angular orientation. As the tubing string can be pulled without disturbing the tree, many advantages follow, including access to the production casing hanger for monitoring production casing annulus pressure, and the introduction of larger tools into the well hole without breaching the integrity of the well.

Abstract: A subsea wellhead assembly has a wellhead housing at the upper end of the well. The wellhead housing supports one or more strings of casing, each having a casing hanger. A tubing spool connects to the upper end of the wellhead housing. The tubing spool has a landing shoulder with a plurality of auxiliary passages extending from the shoulder to the exterior of the tubing spool. The auxiliary passages are spaced circumferentially around the tubing spool. A receptacle on the exterior of the tubing spool communicates with these auxiliary passages. A tubing hanger lands in the tubing spool, the tubing hanger having auxiliary ports spaced circumferentially around it. These ports mate with the auxiliary passages to communicate with auxiliary lines extending alongside the tubing. A production tree mounts to the upper end of the tubing spool. A control unit mounted to the production tree assembly has a flexible lead that extend from it and plugs into the receptacle.

Abstract: Methods and apparatus for providing enhanced seal life of a swivel seal assembly by decreasing the effective differential pressure across a given rotating seal. The differential pressure is decreased by providing a pressurized fluid on the low-pressure side of the seal at a predetermined fraction of the operating pressure of the swivel seal assembly. A preferred swivel seal assembly utilizes a washpipe and packing box that are rigidly affixed to their respective conduits such that misalignment and dynamic run-out is compensated for in the gap between the washpipe and the packing box. A control system monitors and regulates the pressurized fluid supplied to the assembly.

Abstract: A wellhead assembly has an inner wellhead that lands in an outer wellhead, the inner wellhead having first and second internal passages. Each passage has an upper opening at the outer surface of the inner housing and a lower opening at the inner surface. An external shoulder of a casing hanger lands on an internal shoulder of the inner housing, the lower opening of the first passage being below the internal shoulder, the lower opening of the second passage being above the internal shoulder. The casing hanger has a substantially-vertical passage located in its sidewall, an upper port registering with the lower opening of the second passage, a lower port being located below the external shoulder for communicating with the annulus. Valve assemblies at the upper openings control the flow of heavy fluid injected into a casing annulus through the second passage and of cuttings injected into the annulus through the first passage.

Abstract: A well bore pressure containment device is provided. Operating as a single stripping and containment device compatible with a wide range of tool string and tubing sizes, the containment device may be integrated with rotating pressure control systems, and be used during completion and work over operations. The containment device has a spool, and a flexible bladder extending about the interior of the spool. The bladder may be controllably deformed to seal against a tool string passing through the device using an inwardly directed pressure, which preferably is exerted by a fluid in the interstitial space between the spool and the bladder.

Abstract: In an integral production pumping tree, the bottom connection, blow-out preventer, flow tee and top connection are positioned to one side, with the vertical rod bore off-center. Up to three vertical ports are provided in the other side of the tree, for providing access to the production casing bore for an electric heating string, an instrumentation string and a small diameter injection tubing string. The ports accommodate sealed connection assemblies, from which the strings extend. The upper portion of the other side of the tree is cut away to create space for introducing the connecting assemblies. The tubing hanger is provided with matching bores.

Abstract: A subterranean oil or gas well apparatus is provided. The apparatus includes a single-bore production tubing hanger arranged concentric with a wellhead. The tubing hanger includes a plurality of ports and channels arranged about the tubing hanger to give operators access to the production tubing annulus and provide chemical injection capability. The ports are closable by a sliding valve. The apparatus also includes annulus and production radial-bore stab assemblies between a christmas tree and an internal crossover assembly. The stab assemblies are extendable and retractable between the chirstmas tree and the crossover assembly to allow the retrieval and installation of each independently.

Abstract: A method and assembly for recovering production fluids from a well having a tree, using a conduit which is inserted into a production bore to divert the recovered fluids via chemical treatment, pumping or any other apparatus with minimal reduction in the rate of recovery of the production fluids.

Abstract: Drill string sections are provided comprising internal passages that may be used to facilitate the electrical or hydraulic connection of multiple devices, such as sensors, arranged at spaced apart positions along the length of the drill sections. Methods of manufacturing the drill string sections are also provided, wherein the internal passages are formed by a first passage, a second passage, and a connecting passage therebetween.