BACKGROUND
A well has one or more casings installed in a borehole to reinforce and seal it, and wellhead components install at the surface above the exposed end of the casings. For example, FIG. 1 shows a wellhead arrangement according to the prior art. Typically, an outermost conductor pipe is driven into place in the borehole, and a base assembly 11 is on the exposed end of conductor pipe 10. A casing head 30 lands on the base assembly 11 and connects to a surface casing 14 supported inside the conductor pipe 10. Typically, the space between the casing 14 and pipe 10 is filled with cement. One or more adapters 40 and components 50 of a blow-out preventer can connect above the casing head 30. As shown in FIG. 1, flanged connections are typically used to connect the various components together.
Because various operations may be performed at the wellhead, the arrangement of components may be modified to accommodate different operations, pressures, and implementations. One typical wellhead operation involves fracing. According to conventional practices, an isolation tool, such as a stinger, installs in the wellhead to isolate bores and outlets from pressures that may be higher than pressure-ratings for the wellhead's flange connections.
In one typical wellhead arrangement, a casing hanger supports casing in the casing head, and a tubing spool nipples to the casing head so that another hanger can be used in the tubing spool to support tubing in the casing. Typically, an adapter must be installed on the casing head prior to nippling up the tubing spool so that the adapter can pack-off or seal around the casing hanger. In another typical wellhead arrangement, a fluted casing hanger support casing in the casing head so that drilling fluids during cementing operations are allowed to return through the hanger's flutes. Later, a pack-off bushing installs above the fluted casing hanger to seal off the flutes. Typically, there is only a limited ability to test the seal created by such a pack-off.
SUMMARY
A wellhead completion assembly is capable of versatile arrangements. The assembly has a first head component that connects to surface casing. A rotatable flange or the like can be used to connect various components to a threaded end of this first head component. Alternatively, second head components can threadably stack on top of one another and can threadably stack on top of the first head component to create a multi-bowl arrangement.
For either arrangement, the assembly can use a casing hanger that installs in the head (i.e., first head component in a single-bowl arrangement or the top most second head component in a multi-bowl arrangement). In either case, the hanger's upper end extends beyond the head's top edge. This exposed end has an external threaded connection to connect to various wellhead components using a rotatable flange or the like. For example, a head or locking ring can threadably connect to the head's threaded end to support the casing hanger in the head. Then, a rotatable flange can threadably connect to the hanger's exposed end so that another component, such as a completion spool or gate valve, can nippled up directly to the casing hanger.
The casing hanger can be fluted or not, and a pack-off plate can be used to seal the casing hanger in the head. This pack-off plate can have a test port accessible through an opening in the head ring holding the hanger in the head. The test port allows operators to test the inner and outer sealing integrity of the pack-off plate. In one particular arrangement, the casing hanger has a sealing ring positioned about its external surface. The pack-off plate threads onto an external threaded connection on the casing hanger, and a lip on the pack-off plate positions in wedged engagement between the sealing ring and a portion of the external surface of the casing hanger.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 is a partial cross-sectional view illustrating a wellhead arrangement according to the prior art.
FIG. 2 is a cross-sectional view illustrating a wellhead completion assembly in one arrangement having portion of a Blow-Out Preventer (BOP) stack nippled up to a casing head.
FIG. 3A is a cross-sectional view illustrating the assembly of FIG. 2 in another arrangement having a completion spool nippled up to the casing hanger.
FIG. 3B is a detail illustrating portions of the casing hanger, the locking ring, and the casing head of FIG. 3A.
FIG. 4 is a cross-sectional view illustrating the assembly of FIG. 2 in yet another arrangement having a gate valve nippled up to the casing hanger.
FIGS. 5A-5B are top and cross-sectional views illustrating a fluted casing hanger for the disclosed assembly.
FIG. 6 is a cross-sectional view illustrating a pack-off plate.
FIG. 7A is a partial cross-sectional view illustrating a flange and the pack-off components on the fluted casing hanger of FIGS. 5A-5B.
FIG. 7B is a detail of FIG. 7A illustrating features of the pack-off components.
FIG. 8 is a cross-sectional view illustrating the casing head of FIG. 2 landed through a riser.
FIGS. 9A-9B are cross-sectional views illustrating the casing head of FIG. 2 used with other wellhead components.
FIG. 10A is a cross-sectional view illustrating another embodiment of a wellhead completion assembly in one arrangement.
FIG. 10B is a cross-sectional view illustrating the assembly of FIG. 10A in another arrangement.
FIGS. 11A-11D are cross-sectional views illustrating a wellhead completion assembly having modular head components in various stages of assembly.
FIGS. 12A-12B are cross-sectional views illustrating the modular assembly using only a first head component.
FIG. 13 is a cross-sectional view illustrating the modular assembly using three head components.
FIGS. 14A-14C are cross-sectional views illustrating the modular assembly when stuck pipe occurs.
FIGS. 15A-15C are cross-sectional views illustrating the modular assembly having a control line when stuck pipe occurs.
DETAILED DESCRIPTION
A versatile wellhead completion assembly is capable of various arrangements. The assembly includes a casing head that lands on a conductor pipe and connects to surface casing. The head's upper end has an external threaded connection to which various components can be connected depending on the desired arrangement. For example, a rotatable flange or other connector can thread onto the head's upper end, and a component of a blow-out preventer (BOP) can bolt to the rotatable flange above the casing head.
The assembly also includes a casing hanger that lands in the casing head to support production casing within the surface casing. When installed in the head, the hanger's upper end extends beyond the head's top edge. This exposed end has an external threaded connection that allows various components to connect to the hanger's upper end depending on the desired arrangement. For example, a locking ring can threadably connect to the head's external threaded connection to support the casing hanger in the casing head. Then, a rotatable flange or other connector can threadably connect to the hanger's exposed end so that a completion spool, gate valve, or other wellhead component can bolt to the rotatable flange above the casing hanger.
In other arrangements, the casing head can be used with conventional wellhead components and can be landed through a riser using a running tool threaded to internal threads in the casing head. In addition, the casing hanger used in the various arrangements can be fluted, and a pack-off assembly that allows testing of inner and outer seals can be used with the fluted casing hanger. In still other arrangements, modular head components of the assembly permit operators to make various arrangements of the head components to suit their needs in either single-bowl or multiple-bowl arrangements and to facilitate contingency operations in the event a stuck pipe occurs.
Turning now to the drawings, FIG. 2 illustrates a well completion assembly having a casing head 100 and a casing hanger 200. The casing head 100 with a landing ring 22 attached thereto lands on a support ring 20 on an exposed end of conductor pipe 10, and an internal threaded connection 104 connects to surface casing 12. Side ports 102 for valves or the like are provided in the head's bore 101 for various uses during well operations. When the casing head 100 is installed as shown, flutes (not shown) in the rings 20/22 can allow cement to be inserted between the conductor pipe 10 and the surface casing 12 during a cementing job.
In the arrangement, a rotatable flange 110 threadably connects to an external threaded connection 106 on the casing head's upper end, and a BOP stack component 50 nipples up to the casing head 100 by bolting to the flange 110. To seal this connection, a gasket is disposed in a groove at head's top edge. Rather than using the rotatable flange 110 as shown, a drilling adapter, such as element 530 shown in FIG. 10A, or other connector could alternatively be used.
Also in the arrangement, the casing hanger 200 has production casing 14 connected by an internal threaded connection 204 at the hanger's lower end. To install the hanger 200 and the casing 14, a running tool 52 connects by a coupling 54 to an external threaded connection 206 at the hanger's upper end, and the hanger 200 and the casing 14 are run through the BOP stack component 50 and into the casing head 100. Once run in, the casing hanger 200 lands in the head 10 by engaging an internal shoulder 103 so that the production casing 14 is supported within the surface casing 12.
As will be appreciated, each of the components of the assembly is composed of a suitable material known in the art for a wellhead component. Preferably, the threaded connections (106, 204, and 206) have ACME-2G left-handed thread forms. For some exemplary dimensions, the conductor pipe 10 may be 16-in. casing, and the surface and production casings 12/14 may respectively be 9⅝-in. and 4½-in. casings. The connection of the rotatable flange 110 to the BOP stack component 50 may be 11-in. rated at a working pressure of 5,000-PSI. As one skilled in the art will appreciate, these values are provided as examples for illustrative purposes, and components of the assembly can be sized for 13-inch connections and other sizes of casing.
During operations, it would be desirable to be able to nipple up a tubing spool above a production casing hanger without requiring the use of secondary pack-off to seal around the hanger. As shown in FIG. 3A, the disclosed assembly allows a completion spool 60 to nipple up to the casing hanger 200 of the disclosed assembly without the need for secondary pack-off. In this arrangement, a locking ring 120 defining a central opening 122 installs over the hanger's end exposed above the head 100, and internal threads on the ring's sides 126 couple to the external threaded connection 106 on the casing head 100. This connection 106 can be 11-in. rated at a working pressure of 10,000-PSI. As shown in the detail of FIG. 3B, the ring's inside surface 124 engages the hanger's upper shoulder 207 to hold the hanger 100 in the head 100. Also, the inside surface 122 engages a gasket 108 disposed in a groove at the head's top edge.
With the ring 120 installed, the tubing spool 60 can couple directly to the exposed end of the hanger 200. In particular, a rotatable flange 62 or other connector threads onto the hanger's external threaded connection 206, and the spool 60 bolts to the rotatable flange 62. A gasket is disposed in a groove at the hanger's top edge to seal the connection. This connection between hanger 200 and spool 60 can be 4 1/16-in. rated at a working pressure of 10,000-PSI, for example. With the spool 60 connected, other components can then be connected above the spool 60, and tubing (not shown) can eventually be hung in the spool's bowl using a tubing hanger (not shown). Because the completion spool 60 nipples up directly to the hanger 200, the casing hanger 200 essentially acts as a spool, and the need for secondary pack-off is eliminated.
As shown in detail in FIG. 3B, the hanger's upper shoulder 207 defines a test port 208 that communicates between two sealing seats 209 disposed about the hanger's outer cylindrical surface. With the hanger 200 installed in the head's internal bore 101 as shown, this test port 208 is accessible through the ring's opening 122 so that the seal formed between the sealing seats 209 and the casing head's internal bore 101 can be tested.
FIG. 4 shows a similar arrangement with a gate valve 65 nipple up to the casing hanger 200 of the assembly. Again, the rotatable flange 62 couples to the external threaded connection 206 on the exposed end of the hanger 200, and the gate valve 65 bolts to the flange 62. As will be appreciated, the gate valve 65 may be used for fracing operations or the like. With respect to frac operations, it would be desirable to be able to frac at high pressures without needing to use an isolation tool in the wellhead. In current arrangement of the disclosed assembly, there is no need to use an isolation tool (or a nipple up/down apparatus for such an operation). Rather, interior frac pressures can reach as high as the internal yield pressure of the production casing 14 itself because the housing of the casing 14 communicates directly with the gate valve 65 through the casing hanger 200. Therefore, frac pressures that can be used with the disclosed assembly are not limited by conventional flange pressure ratings of adapters or the like that would typically be used above a production casing hanger.
The hanger 200 shown in FIG. 4 has flutes that allow fluid returns past the hanger 200 when used in some arrangements. In FIG. 4, however, a pack-off assembly 210 having a pack-off plate and other components forms a seal between the fluted hanger 200 and the inside surface of locking ring 120. When this form of pack-off is done, it is desirable to have an adequate and convenient way to test the pack-off's inner and outer seals. In the prior art, however, the only way to test the integrity of a pack-off's seals requires operators to nipple up the next spool above the pack-off assembly and to then perform a flange pressure test. For example, FIG. 9A discussed below shows a conventional pack-off plate 74 having an inner seal that engages casing 14 and having an outer seal that engages casing head 100. To test the seals, a tubing spool 70 must be nippled up to the casing head 100, and a flange pressure test must be performed using a test port 73 on the spool 70. If the test fails, operators have to nipple down the spool 70 and pull out the pack-off plate 74 to investigate the cause. This procedure can be time intensive.
In contrast, the pack-off assembly 210 in FIG. 4 has a top-access test port 212 accessible through the sealing ring's opening 122. This test port 212 communicates between two sets of inner and outer seals on the assembly 210. In this way, the sealing integrity of the assembly's inner and outer seals can be tested simultaneously and as soon as the assembly 210 is installed so that time can be saved on site. Further details of a fluted hanger and a pack-off assembly are discussed below with reference to FIGS. 5A through 8C.
FIGS. 5A-5B illustrate a fluted casing hanger 300 for use with the disclosed assembly in top and cross-sectional views, respectively. As with other hangers disclosed herein, the fluted hanger 300 has an internal bore 302 with an internal threaded connection 303 at its lower end to connect to production casing (not shown). In addition, the hanger's upper end has an external threaded connection 306 for coupling to running tool as in FIG. 2 or to a rotatable flange as in FIG. 3A. Furthermore, the hanger's top edge defines an annular well 308 for a gasket (not shown) used to seal engagement between the hanger 300 and the various other components discussed herein.
Being fluted, however, the hanger's lower end defines a plurality of flutes or cutaways 304 (four shown in FIG. 5A) that enable fluid returns to communicate past the hanger 300. In another distinction, the hanger 300 as shown in FIG. 5B has a blunt or flat lower end as opposed to the substantially extended and narrowed lower end of the other hangers disclosed herein. It will be appreciated that any of the other hangers (either fluted or not) disclosed herein may have a similar blunt end if desired.
As briefly discussed above in FIG. 4, a pack-off assembly 210 can be used to seal communication through flutes of a fluted hanger when returns are no longer desired. When used, the pack-off assembly 210 preferably allows the sealing integrity of inner and outer seals to be tested in an adequate and convenient way. For such as a pack-off assembly, FIG. 6 illustrates a pack-off plate or sealing ring 400 capable of such testing ability, and FIGS. 7A-7B illustrate the pack-off plate 400 and an additional sealing ring 430 positioned on the fluted casing hanger 300 of FIGS. 5A-5B.
As best shown in FIGS. 7A-7B, the sealing ring 430 positions adjacent a lowermost shoulder 309a on the hanger 300. The pack-off plate 400 (shown in cross-section in FIG. 6) has a central opening 402 and positions over the hanger's narrower end and threads its internal threads 407 onto intermediate threaded connection 307 on the hanger 300. This pack-off plate 400 may be referred to as a production casing hanger pack-off or an H-plate.
As the pack-off plate 400 is tightened onto the hanger 300, internal seals 450 (e.g., O-rings) on the pack-off plate 400 eventually engage a side portion 309c of the hanger's surface, while outer seals 440 (e.g., O-rings) engage the internal wall of the casing head's bore (not shown). Likewise, the plate's lower lip 404 wedges in between the lowermost ring 430 and a side portion 309b of the hanger's surface so that the lowermost ring 430 seals against the internal wall of the casing head's bore (not shown).
To test the sealing integrity, the pack-off plate 400 defines a test port 406 in its top surface 405 that is accessible when the locking ring (e.g., 120 in FIG. 4) is used. As best shown in the cross-section of the plate 400 in FIG. 6, the test port 406 communicates with spaces between the outer and inner seats 408/409 for the seals (440/450) so that their sealing integrity can be tested. Because this test port 406 is accessible through the locking ring's opening (122), this testing can be done during partial assembly of the pack-off or after complete assembly of the arrangement.
In addition to being used with the casing hanger 200, pack-off assembly 210, and other components discussed above, the casing head 100 can be used on its own with various other wellhead components in a number of other arrangements. In one example shown in FIG. 8, the casing head 100 can be run through a riser 16 and landed on a support ring 20 using an internal running tool 18. To run the head 100, the internal running tool 18 has a coupling 19 that attaches to an internal threaded connection 107 in the casing head's bore 101.
In other uses, the casing head 100 can also be used on its own in conjunction with some conventional wellhead components. For example, FIG. 9A shows the casing head 110 having a completion spool 70 nippled up to the head 100 with a rotatable flange 110. FIG. 9B shows a similar arrangement, but in this example, a completion spool 80 and adapter 82 nipple up to the casing head 100 with a rotatable flange 110.
In both arrangements, a conventional hanger 76 having slips 77 lands on the head's internal shoulder 103 to support the production casing 14, and a conventional pack-off plate 74 seals against the production casing 14 and the head 100. Segmented rings 72 engage against the production casing 14 within the spool 70 in FIG. 9A, while internal seals in the adapter 82 engage against the end of production casing 14 in FIG. 9B.
The casing head 100 disclosed above represents a single-bowl type, meaning that it defines a single bowl and has a length for supporting a single hanger. FIGS. 10A-10B illustrates a wellhead completion assembly having a casing head 500 that represents a double-bowl type. Accordingly, one casing hanger 510 (FIG. 10A) or two casing hangers 510/540 (FIG. 10B) can be used with this casing head 500. Although shown as fluted, the casing hangers 510/540 could be mandrel hangers, if desired.
In the arrangement of FIG. 10A, a BOP stack component 50 nipples up to the casing head 500. In this example, the connection uses a drilling adapter 530 that has a locking assembly 532 for quick connect to the casing head 500, pack-off screws 534 for other purposes, and a flange 536 for bolting to the BOP stack component 50. The casing hanger 510 lands in the casing head 500 through the BOP stack component 50 using a running tool (not shown). A pack off assembly 520 having pack-off elements 522 installs above the casing hanger 510, and pack-off screws 524 on the head 500 engage the elements 522. Once installed, the pack-off assembly 520 forms an additional bowl in the head 500. In this example, the conductor pipe 10 can be 20-in. casing, and the surface casing 12 can be 9⅝-in casing. The casing hanger 510 can support 7-in. production casing.
In the arrangement of FIG. 10B, the casing hanger 510 and the pack-off assembly 520 again install in the casing head 500, and a fluted hanger 540 and pack off assembly 545 install in the end of the casing head 500. A locking ring 550 threads onto the end of the casing head 500 and engages the pack-off assembly 545, and a completion spool 560, gate valve, or other component nipples up to the end of the fluted hanger 540 with a rotatable flange 562 or other connector. In this example, the first hanger 510 can support 7-in. production casing 14, while the second hanger 540 can support 4.5-in. casing 15.
In addition to these arrangements of FIGS. 10A-10B, the double-bowl type casing head 500 can be landed through a 20-in. riser using a running tool in much the same manner as depicted in the example of FIG. 8, with the exception that the running tool couples to the outer threaded connection at the top end of the casing head 500. Moreover, the casing head 500 and other components of FIGS. 10A-10B can be used with completion spools, adapters, and other conventional components similar to the arrangements in FIGS. 9A-9B (e.g., elements 70, 72, 74, 76, 77, 80, and 82).
The double-bowl type casing head as shown in FIGS. 10A-10B can be used in various operations when several casing strings are to be run downhole. FIGS. 11A-11D illustrate another wellhead completion assembly 600 in various stages of assembly that can support several casing strings. In addition, to being able to support multiple strings, this assembly 600 has modular head components 610 and 620 that offer a number of advantages, including allowing the assembly 600 to be assembled in different arrangements and facilitating contingency operations when a stuck pipe occurs before a hanger can be properly landed in the head.
As shown in FIG. 11A, the modular assembly 600 includes first and second head components 610 and 620. The first head component 610 can be similar to the casing head of previous embodiments, such as casing head 100 in FIG. 2, and can be used alone in a single bowl type of arrangement. Alternatively, the second head component 620 can connect to the first head component to make a double-bowl type of casing head.
In assembling the double bowl arrangement, for example, the first head component 610 connected to outer casing 12 lands on the landing assembly 20, and the second head component 620 supported by running tool 54 threads to the first component 610 at a threaded connection 630. This threaded connection 630 can use the same type of threading and rating as previous embodiments. For example, this connection 630 can be similar to the connection 106 in FIG. 2 having ACME-2G left-handed thread form and can be 11-in. rated at a working pressure of 10,000-PSI. Holes 632 and setscrews (not shown) may also be used to couple the second component 620 to the first component 610.
As shown in FIG. 11B, another running tool 54 runs a hanger 650 and attached inner casing 14 through the head components 610/620 and lands the hanger 650 on the shoulder 612 inside the first component 610. Subsequently, as shown in FIG. 11C, another running tool 56 lands a pack-off plate 660 above the hanger 650. The modular assembly 600's resulting double-bowl type of arrangement is shown in FIG. 11D. At this point in the assembly, additional pack-off components, another inner casing, and an additional hanger can be landed in the second head component 620 as with the assembly in FIGS. 10A-10B. In this way, the modular assembly 600 can support multiple casing strings. For example, an 11-inch embodiment of the assembly 600 could support two casing strings, while a 13-inch embodiment of the assembly 600 could support three casing strings.
As shown in FIGS. 11A-11D, the first and second head components 610/620 of the modular assembly 600 can be used to create a double-bowl type of casing head. Because the disclosed assembly 600 is modular, the first head component 610 can be used by itself. As shown in FIGS. 12A-12B, for example, the first head component 610 can be landed on the landing assembly 20 with a running tool 54, and a quick connect drilling adapter 530 or some other desired component can be attached to the first component 610 to complete the assembly. Alternatively, the first head component 610 can be used in other arrangements disclosed herein, such as in FIGS. 2, 3A, 4, and 9A-9B. In another alternative shown in FIG. 13, two of the second head components 620a-b can be stacked on top of one another above the first head component 610 to create a three component modular assembly, which can be used to support multiple casing strings.
Not only does the modular assembly 600 provide for versatile arrangements, but it facilitates contingency operations when a stuck pipe occurs. When running the casing 14 and hanger 650 through the head components 610/620 and the outer casing 12, for example, the inner casing 14 may become stuck in what is commonly referred to as a stuck pipe situation—an example of which is shown in FIG. 14A. Because the inner casing 14 cannot be inserted enough to allow the attached hanger 650 to be landed on the shoulder 612, operators must perform a contingency operation that involves using slips to secure the inner casing 14 in tension within the casing head and cutting the excess portion from the inner casing 14 that has been prevented from passing through the casing head.
In a conventional double-bowl casing head, cutting the excess casing can be difficult because the point at which the cut must be made lies deep within the double-bowl casing head. In other words, an operator has to carefully cut the casing within the confined space of the double-bowl head with a welding tool and then to prepare the end of the cut casing properly for further operations.
The modular assembly 600, however, facilitates stuck pipe contingency operations. When a stuck pipe occurs as in FIG. 14A, operators position a slip assembly 670 and pack-off 672 in the first component 610 as shown in FIG. 14B and then remove the second component 620 from the first component 610 at the threaded connection 630. Removing the second component 620 leaves the excess casing 14 exposed above the first component 610. Operators can then more readily cut the excess casing 14 at the appropriate point, level the cut end 15, and create the needed chamfer at the edge. After these steps have been completed, operators can reconnect the second component 620 to the first component 610. Alternatively, operators can attach a rotating flange 674 to the connection end 631 of the first component 610 as shown in FIG. 14C or couple components of some other desired arrangement to the first component 610.
In addition to facilitating preparation of the inner casing 14 during stuck pipe contingency operations, the modular assembly 600 also helps operators perform modifications to a control line when a stuck pipe occurs. For example, FIG. 15A shows the modular assembly 600 having a control line 700 that runs down the annulus to a valve or the like (not shown). The control line 700 connects by a ferrule coupling 702 to a hanger 650, and a side coupling 704 in the first head component 610 communicates with a port in the hanger 650 to communicate with the control line 700.
If a stuck pipe occurs while running the inner casing 14, the hanger 650, and the control line 700 downhole, operators have to modify the arrangement of the control line 700 to connect it to the side coupling 704. In a conventional double-bowl type of head, operators would have to modify the control line's connection by making modifications deep within the double-bowl head and confined in the annulus between the inner casing and the head.
The disclosed modular assembly 600, however, alleviates some of this difficulty. For example, as shown in FIG. 15B, the second component 620 can be removed from the first head component 610 giving operators easier access to the control line 700 and the inside of the coupling 704. Before putting the slip assembly 670 and pack-off 672 in the head, for example, operators can wind excess amounts of control line 700 in wraps 705 around the casing 14 and attach the line 700 to the coupling 704 inside the first component 610 while having easier access inside the annulus. After setting up the control line 700, putting the slip assembly 670 and pack-off 672 in the first head component 610, and cutting the excess of the casing 14, operators can reconnect the second component 620 to the first component 610. Alternatively, operators can attach a rotating flange 674 to the end of the first component 610 as shown in FIG. 15C, or couple components of some other desired arrangement to the first component 610.
The foregoing description of preferred and other embodiments is not intended to limit or restrict the scope or applicability of the inventive concepts conceived of by the Applicants. For example, it will be appreciated with the benefit of the present disclosure that components of one embodiment of the wellhead completion assembly can be combined with components of another embodiment to produce a variety of versatile arrangements for well completions. In exchange for disclosing the inventive concepts contained herein, the Applicants desire all patent rights afforded by the appended claims. Therefore, it is intended that the appended claims include all modifications and alterations to the full extent that they come within the scope of the following claims or the equivalents thereof.
Patent Application
20100288483
