Packer assembly for an offshore riser and method of using same

PACKER ASSEMBLY FOR AN OFFSHORE RISER AND METHOD OF USING SAME

BACKGROUND

[0001] The disclosure relates generally to techniques for performing wellsite operations. More specifically, the disclosure relates to techniques, such as risers, joints and/or connectors and related devices, for passage of fluid at a wellsite.

[0002] Oilfield operations may be performed to locate and drill for hydrocarbons. Once located, production operations may be performed to gather and collect valuable downhole fluids. During drilling operations, the recovered fluids may be, for example, drilling fluids and/or transient oil, gas and water. During production operations, the fluids may be produced hydrocarbons.

[0003] Some such oilfield operations are performed at offshore locations. Offshore platforms may be used to draw fluids from subsea locations to a surface vessel. Subsea equipment may be positioned about the sea floor to access fluid in subsurface formations. A production or drilling riser may extend from the subsea equipment to a platform to bring the fluid to the surface for capture. The riser may be, for example, a drilling riser or a production riser including a series of tubulars connected together to form a fluid path for passage of fluids.

[0004] The tubulars of the riser may be exposed to various subsea conditions, such as currents, fluid pressures, sea life, and the like, which may apply forces or otherwise affect performance of the tubulars. Various tubulars have been developed for use in subsea operations as described, for example, in US Patent/Application Nos. 7913767, 7686342, 6557637, 6070669, 5259459, 5066048, 4844511, 4662785, 4496172, 4436157, 4124231, 20100326671, and 20050146137.

[0005] Some tubulars along the riser may be provided with various connection devices, such as joints to connect portions of the tubulars together, or to other components, such as the wellhead or the platform. Seals may be provided about the tubulars and/or connection devices to prevent leakage. Examples of risers and/or connectors are provided in US Patent/ Application Nos.

7913767 and 2003/0111799.

SUMMARY

[0006] In at least one aspect, the present disclosure relates to a packer assembly for sealing about a subsea riser. The subsea riser is operatively connectable between a platform and subsea equipment. The packer assembly includes a packer housing and at least one packer. The packer housing is positionable about a telescoping assembly. The telescoping assembly operatively connects the subsea riser to the platform. The packer(s) are positionable along an inner surface of the packer housing to form a seal with the telescoping assembly, and includes a plurality of packer segments. Each of the segments has male and female connectors on each end thereof matably connectable to the male and female connectors of another of the segments to form a seal connection therebetween. The seal connection defines a non-linear leak path whereby leakage of fluid between the segments is resisted.

[0007] The packer housing may have flanged ends, and/or pressure ports therethrough. The inner surface of the packer housing includes a first diameter portion and a second diameter portion. The first diameter portion may be larger than the second diameter portion and defines a shoulder therebetween. The packer may be positionable along the first diameter portion adjacent the shoulder.

[0008] The packer assembly may also include a compression ring, a spacer, and/or an o-ring. The packers may be positionable between the compression ring and the shoulder.

[0009] The packer(s) may include an inner packer and an outer packer, and/or a body portion and upper and lower rings. The body portion may have grooves. The packer(s) may include an upper portion and a lower portion with an indentation therebetween. The male and female connectors may each include at least one horizontal portion and at least one vertical portion. The horizontal and vertical portions may be linear, non-linear, offset, and/or linked. The male and female connectors may include tongue and groove connectors, and/or a bevel end section and the female connector comprises a bevel cavity to receive the bevel end. The leak path may be disjointed.

[00010] In another aspect, the disclosure relates to a telescoping assembly for operatively connecting a surface end of a subsea riser to a platform. A subsea end of the riser may be operatively connectable to subsea equipment. The telescoping assembly may include an inner barrel operatively connectable to the platform, an outer barrel operatively connectable to the subsea riser (the outer barrel slidingly receiving the inner barrel therein), and at least one seal assembly positionable about the inner and outer barrels to form a seal thereabout.

[00011] The packer assembly includes a packer housing and at least one packer. The packer housing is positionable about a telescoping assembly. The telescoping assembly operatively connects the subsea riser to the platform. The packer(s) are positionable along an inner surface of the packer housing to form a seal with the telescoping assembly, and includes a plurality of packer segments. Each of the segments has male and female connectors on each end thereof matably connectable to the male and female connectors of another of the segments to form a seal connection therebetween. The seal connection defines a non-linear leak path whereby leakage of fluid between the segments is resisted.

[00012] The seal assembly may include a platform flange operatively connectable to the platform and a platform seal, a collar, a latching mechanism, a guide ring, bracing, bellows, a bellows cover, an adapter spool, an inner barrel locking collar, a shoe assembly, and/or a shoe and a riser flange.

[00013] Finally, in another aspect, the disclosure relates to a method of forming a seal about a subsea riser. The subsea riser is operatively connected to a platform by a telescoping assembly. The method involves providing the telescoping assembly with at least one packer assembly. The packer assembly includes a packer housing positionable about the telescoping assembly and at least one packer positionable along an inner surface of the packer housing to form a seal with the telescoping assembly. The packer(s) include a plurality of packer segments. Each of the segments has male and female connectors on each end thereof. The method further involves resisting leakage of fluid between the plurality of segments by forming a seal connection with a non-linear leak path between the male and female connectors by matably connecting to the male and female connectors of the segments with another of the plurality of segment.

[00014] The resisting may involve squeezing the plurality of segments together in response to hydraulic pressure and/or compressing the at least one packer into the packer housing with a compression ring. The packer(s) may include an inner packer and an outer packer. The resisting may also involve pushing the outer packer against the inner packer in response to hydraulic pressure. BRIEF DESCRIPTION OF THE DRAWINGS

[00015] So that the above recited features and advantages may be understood in detail, a more particular description, briefly summarized above, may be had by reference to the embodiments thereof that are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments and are, therefore, not to be considered limiting in scope. The figures are not necessarily to scale and certain features and certain views of the figures may be shown exaggerated in scale or in schematic in the interest of clarity and conciseness.

[00016] Figure 1 is a schematic view of an offshore wellsite having a riser extending from a surface platform to subsea equipment with a telescoping assembly therebetween.

[00017] Figure 2 is a longitudinal, cross-sectional view of the telescoping assembly of

Figure 1 having a packer assembly.

[00018] Figure 3 is a longitudinal, cross-sectional view of an upper portion 3 of the telescoping assembly of Figure 2.

[00019] Figure 4 is a longitudinal, cross-sectional view of a lower portion 4 of the telescoping joint assembly of Figure 2.

[00020] Figure 5 is an end view of the packer assembly of Figure 2 having inner and outer packers.

[00021] Figure 6 is a longitudinal cross-sectional view of the packer assembly of Figure 5.

[00022] Figure 7 is an assembly view of the packer assembly of Figure 5.

[00023] Figure 8 is a perspective view of a segment of the inner packer of Figure 5.

[00024] Figure 9 A is a top view of the segment of the inner packer of Figure 8.

[00025] Figure 9B is a cross-sectional view of the segment of the inner packer of Figure

9 A taken along lines 9B-9B.

[00026] Figure 10 is an assembly view of the segment of the inner packer of Figure 8.

[00027] Figure 11 is a top view of the segment of the inner packer of Figure 10.

[00028] Figure 12 is a cross-sectional view of the segment of the inner packer of Figure 11 taken along line 12-12.

[00029] Figures 13A-13D are schematic perspective views of various inner packers having various seal connections. [00030] Figures 14A-14B are schematic diagrams depicting forces on an interlocking seal connection between segments of an inner packer.

[00031] Figures 15A-15C are schematic diagrams depicting forces on another interlocking seal connection between segments of another inner packer.

DETAILED DESCRIPTION

[00032] The description that follows includes exemplary systems, apparatuses, methods, and instruction sequences that embody techniques of the inventive subject matter. However, it is understood that the described embodiments may be practiced without these specific details.

[00033] The techniques herein relate to a telescoping assembly for adjustably connecting a tubular riser to a surface platform. The telescoping assembly includes a packer assembly with inner and outer packers positionable therein to seal the flexible assembly. The inner packer includes two (or more) segments with mated ends sealably connectable together to form a continuous ring. The mated ends provide a mated seal connection with an interlocking geometry therebetween. The interlocking geometry may define a longitudinal (or axial) leak path therebetween to prevent the passage of fluid therethrough. The leak path may have horizontal, vertical and/or curved portions that provide an overall non-linear geometry between the segments.

[00034] With some techniques, the leak path of the packer is configured to block fluid flow by forcing rubber of the packer in a direction perpendicular to a direction of force applied thereto. In such cases, this perpendicular sealing force may be increased to force rubber circumferentially (e.g., 90 degrees) to close vertical splits between portions of an inner packer. In other cases, the perpendicular sealing force may be used to press portions of the inner packer against the inner surface of the packer assembly such that a leak path between the segments is blocked. The inner packer may be configured to reduce a clamp force therein and reduce the amount of pressure required to block the flow along the leak path. (For example, the pressure may be applied on the packers by a driller to seal off mud leakage around the inner packer.) The reduced pressure inner packer may be configured to operate at higher pressures (e.g., from about 500 to about 1000 psi (35.16-70.32 kg/cm)) during short periods (e.g., emergency situations) thereby reducing wear on the inner packer. The inner packer may also be used to address leakages that may create environmental issues. [00035] Figure 1 depicts a wellsite 100 having a surface platform 102 and subsea equipment 104, with a riser 106 therebetween. The surface platform 102 has a rig 108 and other surface equipment 110 for operating the wellsite 100. The subsea equipment 104 is positioned about a wellhead 112 located on sea floor 114 adjacent a wellbore 116. The subsea equipment 104 is schematically depicted as a component positioned adjacent the wellhead 112, but may be positioned about the sea floor 114 and may include various subsea components, such as blowout preventers, manifolds and/or other subsea devices for performing subsea operations. While Figure 1 shows a subsea application, it will be appreciated that the techniques herein may be used in a variety of land or water based applications.

[00036] The riser 106 is a system of tubulars 118 that forms a long tube for joining the drilling rig 108 on the platform 102 to the wellhead 112 on the sea floor 114. The riser 106 may also be provided with one or more external conduits 122 for performing various functions, such as an electrical or fluid conduit (e.g., choke and kill, glycol, hydraulics, and/or riser-fill-up, etc.) The conduit(s) 122 may run along the riser 106 from the surface platform 102 to the subsea equipment 104. The conduits 122 may include various tubing, cables or other passage mechanisms for the passage of fluids. The tubulars 118 may be tubular members with a tubular connection 120 therebetween.

[00037] A telescoping assembly 111 may be positioned about the riser 106 for operatively connecting with the floating platform 102. The telescoping assembly 111 has telescoping portions that permit the platform 102 to adjustably position relative the riser 106, for example, as the platform 102 moves with the sea water.

[00038] Figure 2 depicts the telescoping assembly 111 in greater detail. The telescoping assembly 111 includes a seal assembly 224 at a surface end and a shoe assembly 226 at a subsea end thereof with an inner barrel 230 and an outer barrel 228 therebetween. The seal assembly 224 has a platform flange 223 operatively connectable to the platform 102 via a platform assembly 227. The platform assembly 227 may include various connectors, such as a flex joint, diverter, etc. At the lower end of the telescoping assembly 111, the shoe assembly 226 has a shoe 222 and a riser flange 225 operatively connected to the riser 106 as schematically depicted.

[00039] The inner barrel 230 is connected to the platform flange 223 at a surface end thereof. A lower end of the inner barrel 230 slidingly extends into the outer barrel 228 for telescopic movement therebetween, and is threaded into the shoe 222. The outer barrel 228 connects to the riser flange 225 of shoe assembly 226. The outer barrel 228 receives the inner barrel 230 therein for sliding and telescopic movement therebetween. The telescopic movement of the inner barrel 230 relative to the outer barrel 228 allows the telescoping assembly 111 to extend and retract as needed.

[00040] Figure 3 shows a portion of the telescoping assembly 111 with the seal assembly

224 of Figure 2 in greater detail. As shown in this view, the seal assembly 224 includes the platform flange 223 and a platform seal 332. The platform flange 223 is depicted as a circular member at a surface end of the inner barrel 230. As used herein circular shall refer to any elliptical shape, and non-elliptical may also optionally be used. The platform flange 223 provides a contact surface for operative connection to the platform assembly 227. The platform assembly 227 may be connected, for example, by bolts 344 to the platform flange 223.

[00041] The platform seal 332 is positionable along an inner surface of the platform flange

223 and the platform assembly 227 for providing a seal there along. The platform seal 332 is a circular member and may be made of a flexible material mounted in a removeable steel holder. The platform seal 332 may sealingly receive the inner barrel 230 for sealing connection therebetween.

[00042] The seal assembly 224 also includes a collar 334, a latching mechanism 336, packer assemblies 338, and a guide ring (or collar) 340 positioned about the inner barrel 230. The collar 334 is positioned about a surface end of the latching mechanism 336. The packer assemblies 338 and guide ring 340 are positioned at a riser end of the latch mechanism 336. The latching mechanism 336 may be a conventional latch having, for example, locking dogs, collars, bolts and other devices to secure the outer barrel 228 about the inner barrel 230 as needed while permitting the inner barrel 230 to slidingly move therein. Other devices, such as a bellows 331, a bellows cover 337, an adapter spool 333 and an inner barrel locking collar 335 may also be provided along the seal assembly 224 to support operation thereof.

[00043] An outer barrel tension ring receiver 329 is positioned about the outer barrel 228 adjacent the guide ring 340. A tension ring (not shown) may be attached to the outer barrel tension ring receiver 329. Packer assemblies 338 are positioned between the latching mechanism 336 and the outer barrel tension ring receiver 329. The packer assemblies 338 are attached to the surface end of the outer barrel 228. The guide ring 340 is positioned about the packer assembly 338 adjacent the outer barrel 228. The outer barrel tension ring receiver 329 is positioned adjacent a subsea end of the guide ring 340.

[00044] Two packer assemblies 338 are shown stacked together to provide a seal between the inner barrel 230 and outer barrel 228 and to prevent leakage therebetween. Two packer assemblies 338 are depicted, but one or more may be used. The surface (or upper) packer assembly 338 may be used as the primary packer. The riser (or lower) packer assembly may act as a backup for redundant leakage prevention, for example, should the upper packer fail.

[00045] Bracing 342 extends between the outer barrel 228 and the outer barrel receiver

329 and fixedly secures the outer barrel 228 thereto. The outer barrel 228 may be provided with seals, tension rings or other devices to secure the outer barrel 228 in position. The outer barrel 228 supports the guide ring 340 adjacent thereto and about the packer assembly 338.

[00046] Figure 4 shows the shoe assembly 226 in greater detail. The shoe assembly 226 includes the riser flange 225 and the shoe 222. The riser flange 225 is operatively connectable to a surface end 450 of the riser 106. The riser flange 225 is a circular member that may be connected to the riser 106 by bolts 448.

[00047] The outer barrel 228 is connected to the riser flange 225 (e.g., by weld). The shoe

222 is positioned in the outer barrel 228. The shoe 222 receivingly engages the inner barrel 230. The shoe 222 may have a shoulder (or other surface) 452 to limit the extension of the telescopic assembly 111 (Figure 1).

[00048] Figures 5-7 depict various aspects of the packer assembly 338. Figures 5 and 6 show top and longitudinal cross-sectional views, respectively, of the packer assembly 338. Each packer assembly 338 includes a packer housing 554, an inner packer 556, an outer packer 558 and a compression ring 559. The packer housing 554 is a circular member with flanged platform and surface ends on opposite sides thereof. The packer housing 554 is provided with bolt holes 555 for operative connection with adjacent components, such as another packer assembly 338 and/or outer barrel receiver 329 as shown in Figure 3.

[00049] The packer housing 554 has an inner housing surface 557 and a shoulder 560 defining different diameters along the inner housing surface 557 for receiving the packers 556, 558. As shown, there are two diameters along the inner housing surface 557 with a surface diameter being larger than a subsea diameter thereof, but any number and dimensions may be selected. The inner and outer packers 556, 558 are concentrically positioned in the packer housing 554 and in abutment against shoulder 560. The compression ring 559 is positioned adjacent the packers 556, 558 along the inner surface 557 of the packer housing 554. The inner packer 556 is split into multiple segments (e.g., for quick field change). While the inner packer is depicted as being split into two segments, two or more may be used. The outer packer is solid and sealed with o-rings 563 thereabout.

[00050] Figure 7 shows an exploded view of the packer assembly 338. As shown in this view, the packer assembly 338 may also include a spacer 760. The spacer 760 is positioned about the outer packer 558 and may be used, for example, to facilitate assembly.

[00051] The packer housing 554 may also be provided with ports, such as water port 764 and pressure ports 762 connected via hoses to a remote control system. Seals, gaskets or other features may be provided about the packer assembly to facilitate sealing. For example, o-ring 766 may be positioned at the riser end of the platform housing 554 for sealing engagement with the outer barrel 228 (see, e.g., Figure 3).

[00052] Figures 8 - 12 show a portion of the inner packer 556 in greater detail. As shown in this view, the inner packer 556 may be made of multiple segments that are connectable to form the circularly shaped inner packer 556 positionable along the packer housing 554 as shown in Figures 5-7. As shown in Figures 8-12, the inner packer 556 has two segments that form a single inner packer 338. While two segments are depicted, two or more may be used.

[00053] The inner packer 556 includes body portions 862, and upper and lower ring portions 864. The body portion 862 may be made of a non-metal, such as molded polyethylene, polyurethane, rubber and the like, for example, to provide wear resistance and sealing capabilities. The selected material may allow for limited movement and/or flexion during operation. The body portion 862 may have various grooves for flexing. The inner packer 566 is positioned by the metal rings of the outer packer, with the compression ring on top and the housing shoulder on the bottom.

[00054] The upper and lower rings 864 are positionable adjacent the body portion 862 on opposite ends thereof. The upper ring 864 is positionable in engagement with the compression ring 559, for example, by bolts (not shown), as schematically shown in Figure 6. The lower ring 864 is positionable in engagement with the shoulder 560 of the packer housing 554 as also shown in Figure 6.

[00055] Mated packer connectors 866a,b are provided between the segments for sealing engagement therebetween. The mating as shown is a tongue and groove type connection, but may be in other configurations. The packer connectors 866a,b are positioned at connection ends of the body portion 862. Each segment has a female connector 866a and a male connector 866b at each end thereof. The male and female connectors 866a,b are positioned on connection faces 868a,b of the body portion 862.

[00056] The male and female connectors 866a,b are depicted as non-linear connectors extending longitudinally along each connection face of the body portion 862. When two segments are positioned together, the male connector 866b of a first packer segment is sealingly and interlockingly connectable with the female connector 866a of a second packer segment. When the segments are joined, the sealed connection between the segments defines a leak path therealong to prevent the flow of fluid therethrough.

[00057] Figures 13A-14B depict various seal connections usable between segments of an inner packer, such as the inner packer 556 described herein. Figures 13A-13D depict various inner packers 556a-d having non-linear seal connections 1370a-d defining non-linear leak paths 1372a-d therebetween. As used herein non-linear leak paths refer to an overall non-linear configuration of a leak path extending from a surface end to a subsea end of the inner packer. As shown in Figures 13A-13D, portions of the leak path may be linear, but the linear flow from end to end is interrupted by portions that deviate from a vertical line along the inner packer. While non-linear leak paths are shown, certain arrangements may incorporate linear connectors with linear leak paths. The sealed connections 556a-d provide various configurations of a non-linear connection, such as a tongue and groove arrangement. The various segments are configured such that any two segments may be assembled together to form the solid ring inner packer.

[00058] The non-linear seal connections 1370a-d have interlocking pieces therealong which interlockingly engage to create the non-linear leak path along the length of the inner packer 556a-d. As shown in Figures 13A-13D, the leak path has discrete portions to prevent a straight vertical line (or linear) path between the segments. As shown in Figures 13B-13D, the leak path defined by the connection may be zig-zagged (or jagged).

[00059] In the configuration of Figure 13 A, the leak path 1372a has offset longitudinal and horizontal portions 1374a, 1376a that provide a disjointed path to block the passage of fluid. The inner packer 556a has an upper portion 1377a and a lower portion 1377b with an indentation 1379 therebetween. The inner packer 556a is split horizontally and vertically at locations staggered 90 degrees apart to define an offset path. In Figure 13B, the leak path 1372b has linked longitudinal portions 1374b and horizontal portions 1376b to define an L path. In Figure 13C, the leak path 1372c has multiple longitudinal portions 1374c and horizontal portions 1376c forming a stepped (or labyrinth) path. Figure 13D is similar to Figure 13C, except that the leak path 1372d has curved portions 1374d that define a wavy path.

[00060] Figures 14A - 15C depict examples of forces applied to a seal connection 1370e,f between segments of inner packers 556e,f. Figures 14A and 15A show the seal connections 1370e,f from a top view looking down onto the seal connections 1370e,f. Figures 14B and 15B are side views of the seal connections 1370e,f. Figure 15C is an end view of the seal connection 1370f. These figures depict views of the seal connection 1370e,f showing the interlocking tongue 1478 and groove 1479 connection therebetween.

[00061] As shown in Figures 14A and 14B, forces F_op from an outer packer (e.g., 558 of

Figure 6) may be applied along an outer surface of the inner packer 556e,f. In cases where a linear seal is provided, a pressure or force F_tan may be used to seal the leak path. F_tan is produced by rubber squeeze or distortion resulting from F_op as shown in Figure 14A. In this case, an additional force F_op may also be required resulting in additional squeeze on the seal connection 1370e.

[00062] In cases with a non-linear seal connection (e.g., in Figures 5-13D), the force F_tan is not required to seal the leak path and may be considered negligible as shown in Figures 15A- 15C. In this version, the connection 1370f is formed between a male end having the tongue 1478 on a beveled end 1482 and a female end having a groove 1479 in a bevel cavity 1483. Leak path sealing may be a result of force F_op compressing the bevel end sections 1482. Additional force F_op may not be needed to seal against the inner barrel to seal the leak path, e.g., where the force may be transmitted through the interlocking beveled section 1482.

[00063] In operation as shown in the figures, the telescoping assembly 111 provides a movable, sealed connection between the riser 106 and the floating platform 102. The packer assembly 338 of the telescoping assembly 111 includes the housing 554 and inner and outer packers 556, 558 form a seal about the telescoping assembly 111. Air or hydraulic pressure may be introduced between the outer packer 558 and the housing 554 and may be inflated to squeeze the inner packer 556 onto the movable inner barrel 227 of the packer assembly 338 sealing the returning drilling mud in the annulus between the drill pipe and riser 106.

[00064] The nonlinear seal connections (e.g., 370a-d) may be positioned along the inner packer 556. Since a split between the segments is vertical and along the leak path direction, a seal is formed against the inner barrel 230 by squeezing the inner packer 556a-d with hydraulics to push the outer packer 558 to force the split in the inner packer 556 together circumferentially to close any small gap that may remain between the segments of the inner packer 556 at the sealed connection. When a non-linear connection is provided between the segments, the force that seals the mud circumferentially also seals the leak path.

[00065] When the outer packer 558 is pressured up and squeezes the inner packer 556, the non-linear leak path may be used to stop the leakage before a vertical split line of the sealed connection is squeezed together. The hydraulic pressure necessary to seal may be all the pressure that is needed to squeeze the inner packer against the inner barrel without additional pressure that would be required to squeeze the rubber or polyurethane against a linear split line. The non-linear seal connection may be configured to reduce the clamping force between the inner packer 556 and the inner barrel 228. The interlocking geometry of the seal connection may continue to provide sealing as the packer 556 wears through.

[00066] It will be appreciated by those skilled in the art that the techniques disclosed herein may be implemented for automated/autonomous applications via software configured with algorithms to perform the desired functions. These aspects can be implemented by programming one or more suitable general-purpose computers having appropriate hardware. The

programming may be accomplished through the use of one or more program storage devices readable by the processor(s) and encoding one or more programs of instructions executable by the computer for performing the operations described herein. The program storage device may take the form of, e.g., one or more floppy disks; a CD ROM or other optical disk; a read-only memory chip (ROM); and other forms of the kind well known in the art or subsequently developed. The program of instructions may be "object code," i.e., in binary form that is executable more-or-less directly by the computer; in "source code" that requires compilation or interpretation before execution; or in some intermediate form such as partially compiled code. The precise forms of the program storage device and of the encoding of instructions are immaterial here. Aspects of the subject matter may also be configured to perform the described functions (via appropriate hardware/software) solely on site and/or remotely controlled via an extended communication (e.g., wireless, internet, satellite, etc.) network.

[00067] While the embodiments are described with reference to various implementations and exploitations, it will be understood that these embodiments are illustrative and that the scope of the inventive subject matter is not limited to them. Many variations, modifications, additions and improvements are possible. For example, one or more packer assemblies with one or more inner and outer packers may be provided with one or more segments with a variety of non-linear connectors therebetween to form a sealed mated connection defining a leak path therebetween.

[00068] Plural instances may be provided for components, operations or structures described herein as a single instance. In general, structures and functionality presented as separate components in the exemplary configurations may be implemented as a combined structure or component. Similarly, structures and functionality presented as a single component may be implemented as separate components. These and other variations, modifications, additions, and improvements may fall within the scope of the inventive subject matter.