TECHNICAL FIELD The present disclosure relates generally to oil or gas wellbore equipment, and, more particularly, to a frac manifold.
BACKGROUND Frac manifolds, also referred to herein as zipper manifolds, are designed to allow hydraulic fracturing operations on multiple wells using a single frac pump output source. Frac manifolds are positioned between the frac pump output and frac trees of individual wells. A frac manifold system receives fracturing fluid from the pump output and directs it to one of many frac trees. Fracturing fluid flow is controlled by operating valves to isolate output to a single tree for fracking operations.
Frac zipper manifolds may be rigged up to frac trees before frac equipment arrives at the well site. Once onsite, the frac equipment need only be connected to the input of the frac manifold. Because individual frac trees do not need to be rigged up and down for each fracking stage and because the same frac equipment can be used for fracking operations on multiple wells, zipper manifolds reduce downtime for fracking operations while also increasing safety and productivity. Another benefit includes reducing equipment clutter at a well site.
Despite their benefits, further efficiencies and cost savings for zipper manifolds may be gained through improved designs. In particular, the valves that have traditionally been used to control the flow of fracturing fluid to individual trees are expensive and greatly increase the cost of using a zipper manifold. With multiple valves required for each frac tree, when a zipper manifold is arranged to connect to several adjacent wells, the cost of the valves can easily be several hundred thousand dollars. Accordingly, what is needed is an apparatus, system, or method that addresses one or more of the foregoing issues related to frac zipper manifolds, among one or more other issues.
SUMMARY OF THE INVENTION The frac manifold isolation tool uses one or more mandrels that may be hydraulically positioned to control frac fluid flow to one or more outputs of the manifold. When the mandrel is in the open position, frac fluid is able to flow to a bridge that is connected to a frac tree or wellhead, and the connected well can be fracked. When in the closed position, the mandrel stops flow to the bridge. With this design, the mandrel can serve to replace or reduce the number of valves that would otherwise control fluid in the manifold, thus making the use of a frac manifold much less expensive and more efficient.
BRIEF DESCRIPTION OF THE DRAWINGS Various embodiments of the present disclosure will be understood more fully from the detailed description given below and from the accompanying drawings of various embodiments of the disclosure. In the drawings, like reference numbers may indicate identical or functionally similar elements.
FIG. 1 illustrates a zipper manifold as known in the prior art.
FIG. 2 illustrates an improved zipper manifold with a mandrel in the open position.
FIG. 3 illustrates an improved zipper manifold with a mandrel in the closed position.
FIG. 4 illustrates an improved zipper manifold with a hydraulic setting cylinder.
FIG. 5 is an enlarged view of a mandrel cup tool.
FIG. 6 illustrates an embodiment of a hydraulic setting cylinder with two mandrels and stay rods.
FIG. 7 illustrates an embodiment of a hydraulic setting cylinder with two mandrels and stay rods.
FIG. 8 illustrates an embodiment of a hydraulic setting cylinder with two mandrels.
FIG. 9 illustrates an embodiment of a lock mechanism in the unlocked position.
FIG. 10 illustrates a lock mechanism in the locked position.
FIG. 11 illustrates a lock mechanism with a linear actuator.
FIG. 12 illustrates an alternative embodiment of an improved zipper manifold.
FIG. 13 illustrates the embodiment of FIG. 12 with the mandrel in the open position.
FIG. 14 is an enlarged view of the bottom portion of the mandrel shown in FIG. 13.
FIG. 15 illustrates the embodiment of FIG. 12 with the mandrel in the closed position, after the seal is set.
FIG. 16 illustrates a top view of the lock mechanism shown in FIG. 10.
FIG. 17 illustrates the position of an upper locking ring when the mandrel is in the closed position, but prior to the seal being set.
FIG. 18 illustrates the position of an upper locking ring when the mandrel is in the closed position and the seal has been set.
FIG. 19 illustrates an improved zipper manifold with a mandrel in an open position
FIG. 20 illustrates an improved zipper manifold with a mandrel in a closed position.
FIG. 21A is an enlarged view of the improved cup tool shown in FIG. 19.
FIG. 21 B is the cup tool shown in FIG. 19 with energized seal assemblies.
FIG. 22A illustrates a improved cup tool with a single seal assembly.
FIG. 22 B illustrates the improved cup tool in FIG. 22A with the energized seal assembly.
FIG. 23A illustrates a improved cup tool with dual actuation and a dual seal assembly.
FIG. 23 B illustrates the improved cup tool in FIG. 23A with the energized seal assemblies.
FIG. 24A illustrates a improved cup tool with dual actuation and a dual seal assembly with an external beveled piston.
FIG. 24 B illustrates the improved cup tool in FIG. 24A with the energized seal assemblies.
DETAILED DESCRIPTION FIG. 1 illustrates an example of a prior art zipper manifold 100. The manifold may be positioned vertically, as shown in FIG. 1, or it may be positioned horizontally. The frac manifold 100 can include two or more well configuration units 101. Each well configuration unit 101 includes one or more valves 102 and a bridge connector header 103, and the well configuration units 101 may be collectively or individually (as shown) positioned on skids 106. Each bridge connector header 103 connects to a frac tree. As shown in FIG. 1, each well configuration unit 101 typically includes a hydraulically actuated valve 102a and a manually actuated valve 102b. The well configuration units 101 of the zipper manifold 100 are connected together by zipper spools 104, and the final zipper spool 104 may be capped off or connected to other well configurations 101 as needed. The zipper manifold 100 connects to the output of the frac pump at the frac supply header 105.
The bridge connector head 103 connects to the frac head of a frac tree. In operation, the valves 102 of one well configuration unit 101 are opened to allow fluid flow to the corresponding frac tree through its bridge connector 103 while the valves 102 of other well configuration units 101 in the zipper manifold 100 are closed. The valves 102 may be closed and opened to control the flow to different well configuration units 101 of the zipper manifold 100.
FIG. 2 illustrates an exemplary embodiment of an improved well configuration unit 210. Improved well configuration unit 210 includes a hydraulic setting cylinder 220 (as shown in FIG. 4) connected to a mandrel 250. The bridge connector header 230, which connects to a frac tree, comprises a horizontal throughbore 225, as well as an axial throughbore 235 which forms a “T” junction by connecting to a lower bore, such as that shown within lower spool 240. It is not necessary that bridge connector header 230 include two throughbores. For example, bridge connector header 230 may comprise only a portion 225a of bore 225, and not portion 225b, or vice versa. All that is required is a throughbore 235 to provide an inlet allowing fluid to flow into bridge connector header 230 and a second bore, such as 225a or 225b, to provide an outlet for fluid to flow out of bridge connector header 230.
The hydraulic setting cylinder 220 actuates a mandrel 250 that moves within throughbore 235 and axially in line with the lower bore, e.g., lower spool 240. In the embodiment shown in FIG. 2, as described in more detail below, the hydraulic setting cylinder 220 and mandrel 250 are used in place of valves in the well configuration unit 210. In another embodiment, valves (whether manually or hydraulically actuated) may be used in conjunction with the hydraulic setting cylinder 220 and mandrel 250 in a well configuration unit 210 to control fluid flow.
Two or more well configuration units 210 are used in a zipper manifold to provide connectivity and fluid control to multiple frac trees and wells. Improved well configuration units 210 are fluidly connected through zipper spools 104 along the zipper manifold. A frac supply header 105 (similar to that shown in FIG. 1) provides fluid connectivity from the frac pump to the zipper manifold and zipper spools 104.
The hydraulic setting cylinder 220 moves the mandrel 250 into two primary positions. When the well configuration unit 210 is in the open position, which is shown in FIG. 2, the cup 260 of the mandrel 250 sits above bridge connector header 230, which allows fluid to flow from the zipper spool 104, through the lower spool 240, and through the “T” junction of the bridge connector header 230 to the connected bridge and frac tree. The mandrel 250 is solid at the cup 260 such that fluid does not flow through the mandrel 250. The cup 260 includes one or more seals 265, such as o-rings, that are able to form a seal against an inner spool above the “T” junction of the bridge connector header 230 and prevent pressure leaks and fluid flow around the cup 260 and to the hydraulic setting cylinder 220.
In the closed position, which is shown in FIG. 3, the hydraulic setting cylinder 220 may move the mandrel 250 through the “T” junction of the bridge connector header 230, such that the cup 260 of the mandrel 250 will seat at a location below the “T” junction. As shown in FIG. 3, the cup 260 may optionally seal within lower spool 240, where seals 265 form a seal against the lower spool's 240 inner surface, which is preferably corrosion resistant. Alternatively, some or all of cup 260 may form a seal with the inner surface of bridge connector header 230, as long as the seal is formed below the “T” junction. When the mandrel 250 is in the closed position and a seal has been formed at a location below the junction of bridge connector header 230, fluid cannot flow past the cup 260 to the bridge connection header 230.
In an embodiment, which is shown in FIGS. 2 and 3, the inner diameter of the lower spool 240 and lower portion of bridge connector 230 is consistent, and the mandrel 250 is stroked to a location far enough down below the “T” junction of bridge connector header 230 to allow mandrel cup 260 to seal. The mandrel cup seals 265 may form a seal with the inner surface of the lower spool 240 and/or the inner surface of bridge connector 230 when the mandrel cup 260 is axially compressed and the seals 265 extrude radially outward. The mandrel cup 260 will axially compress when the pressure below the mandrel cup 260 sufficiently exceeds the pressure above it, or in other words, when the pressure differential exceeds a particular threshold. The mandrel 250 is preferably moved from one position to another only when a seal has not been formed to avoid damaging the sealing elements. Thus, before the mandrel 260 is moved, the pressure above and below the mandrel cup 260 may be equalized, which will decompress the mandrel cup 260 and disengage the seals 265 from the inner surface of the spool.
In an embodiment, the mandrel cup 260 may be actuated to seat at or near an inner shoulder on the inner surface of the lower spool 240. In an embodiment, the inner shoulder serves as a physical stop for the actuation of the hydraulic setting cylinder 220, and the inner shoulder itself may be used as a stop against which to compress the mandrel cup 260, such that it forms a seal with the inner surface of the lower spool 240.
In an embodiment, the mandrel 250 may include one or more locking mechanisms. FIG. 4 illustrates an example of a hydraulic setting cylinder 220 that is connected on top of the bridge connection header 230. The hydraulic setting cylinder 220 includes a mandrel lock 270. The mandrel lock 270 accommodates a lock pin 280 that may be actuated by a second hydraulic cylinder (not shown). After the mandrel 250 has been stroked down to allow mandrel cup 260 to seal in the lower spool 240 and/or the inner surface of bridge connector header 230, the lock pin can be actuated into mandrel lock 270 to mechanically fix the mandrel 250 into position. Other types of locking mechanisms may also be used, such as cams, dogs, or wing nuts.
The hydraulic setting cylinder 220 may be electronically controlled to actuate the mandrel 250. Similarly, the back-up mechanism, such as lock pin and mandrel lock 270 system, may also be actuated electronically or pneumatically. In this way, the flow paths within the zipper manifold 220 may be opened and closed remotely, thus enhancing worker safety. As described above, in an embodiment, manually actuated valves may also be used as an alternative or a backup to the hydraulically actuated cylinder 220.
FIG. 5 illustrates a close up view of an exemplary sealing configuration for a mandrel cup tool 260. Cup tool 260 has o-rings 265 and plates 266, which act as pack off seals with the inner surface of the spools when the mandrel 250 is either above or below the bridge header connection 230.
FIGS. 6-8 show embodiments in which the mandrel system actuated by the hydraulic setting cylinder 620 may be a dual mandrel system. In the dual mandrel system, two concentric mandrels, an inner 645 and an outer 640, are used. The two mandrels 640 and 645 are moved together by the hydraulic setting cylinder 620 to position the mandrel cup tool 260 at the pack off location in either the open or closed position. The inner mandrel 645 can be moved independently of the outer mandrel 640 by a second hydraulic setting tool 625. Once the mandrel cup tool 260 has been positioned at the pack off location, the second hydraulic cylinder 625 is pressurized to move upwards, or away from the mandrel cup tool 260, which causes the inner mandrel 645 to move upward relative to the outer mandrel 640. The inner mandrel 645 is connected to one end of the mandrel cup tool 260 while the outer mandrel 640 is connected to the other. The upward movement of the inner mandrel 645 relative to the outer mandrel 640 causes the mandrel cup tool 260 to be compressed and the seals 265 to be extruded and form a seal at the pack off location.
FIG. 6 shows an embodiment in which the lock mechanism 670 is relatively close to the pack off location where the mandrel cup 260 will be positioned. The stay rods 690 provide access to the lock mechanism 670 and the packing boxes 622 and 624, but also increase the well configuration unit's overall height. The packing box 622 seals between the outer mandrel 640 and the flange 623 to prevent pressurized fluid from leaking out of the well configuration unit. Similarly, the packing box 624 provides a seal between the outer mandrel 640 and the hydraulic cylinder 620 to contain the pressurized fluid within the hydraulic cylinder 620. The stay rods 695 maintain the position of the inner mandrel 645 relative to the outer mandrel 640 and provide access to the packing boxes 626 and 628.
FIG. 7 shows an embodiment in which the lock mechanism 670 is positioned above the first hydraulic cylinder 620. The stay rods 690 and 695 are able to be shortened relative to those shown in FIG. 6, but still allow access to the packing boxes 622 and 624.
FIG. 8 illustrates an embodiment which does not use stay rods. Once a seal has been formed at the mandrel cup tool 260, the relative position of the inner mandrel 645 to the outer mandrel 625 may be fixed by a second lock mechanism 625 so that the seal is maintained. When the mandrel system needs to be moved again, from one position to another, the second lock mechanism is unlocked so that the inner and outer mandrels are able to move relative to each other. The inner and outer mandrels are moved relative to each other such that the sealing element does not form a seal against the spool, and then the mandrels may be moved together to the open or closed position.
FIGS. 9-11 illustrate an exemplary lock mechanism 900. The lock mechanism 900 may comprise a plate 905 which comprises slots 910. The slots 910 are positioned near the outer circumference of plate 905 and radially extend inward/outward, such that the radial distance from one end of the slot to the center of the plate 905 is different than the radial distance from the other end of the slot to the center of the plate 905. Pins 915 are engaged in the slots 910. Each pin 915 is connected to a lock segment 920, such that when the pins 915 travel along the slots 910, the change in radial distance for the pins 915 causes the lock segments 920 to correspondingly constrict or enlarge in inner circumference. The lock segments 920 circumscribe a mandrel, which is not shown in FIGS. 9-11. When the lock segments 920 are constricted, they engage the mandrel and lock it in place. The plate 905 can be rotated to cause the lock segments 920 to lock or unlock.
FIG. 9 illustrates the lock mechanism 900 in an unlocked position, FIG. 10 illustrates the lock mechanism 900 in a locked position. FIG. 11 illustrates that a linear actuator may be used to rotate the plate 905 to lock and unlock the lock mechanism. FIG. 11 further illustrates a second lock mechanism 940, which may be similarly locked or unlocked using a linear actuator. FIG. 16 illustrates a top view of lock mechanism 900 in a locked position.
FIG. 12 illustrates an alternative embodiment of an improved well configuration unit 1210. Improved well configuration unit 1210 includes two hydraulic setting cylinders 1220 and 1225. Setting cylinders 1220 and 1225 comprise outer housings 1221 and 1226 respectively, which are connected to flange 1235. Flange 1235 is connected to bridge connector header 1230 via bolts 1232. Bridge connector header 1230 forms a “T” junction with a lower bore, such as lower spool 1240, similar to the above discussion concerning the embodiment shown in FIGS. 2-11. As with that above discussion, it is not necessary for bridge connector header to include two throughbores, as long as it has one throughbore to serve as a fluid inlet and a second bore to serve as a fluid outlet.
Setting cylinders 1220 and 1225 also comprise rods 1222 and 1227 respectively. Rods 1222 and 1227 each comprise an upper end, each of which is connected to lower plate 1245. As shown in FIG. 13, lower plate 1245 is also connected to mandrel head 1251, which is in turn connected to outer mandrel 1250. Cup tool 1260, comprising gage ring 1261 and seals 1265, is located at the lower end of outer mandrel 1250.
Similar to the embodiment shown in FIGS. 6-8, improved well configuration unit 1210 comprises a dual mandrel system. In the dual mandrel system, two concentric mandrels, an inner 1255 and an outer 1250, are used. Inner mandrel 1255 comprises a lower end which is connected to compression member 1700. Compression member 1700 comprises a generally planar surface 1703 and may also comprise concave lower surfaces 1701 and 1702, which may serve to divert high-pressure flow and protect the integrity of seals 1265.
As described in further detail below, the two mandrels 1255 and 1250 are moved together by the setting cylinders 1220 and 1225 to position the cup tool 1260 at the pack off location below bridge connector header 1230, as shown in FIG. 15.
The inner mandrel 1255 can be moved independently of the outer mandrel 1250 by a second hydraulic setting tool 1625. Second hydraulic setting tool 1625 comprises hydraulic cylinders 1630 and 1635, which are connected to upper plate 1640. Hydraulic cylinders 1630 and 1635 comprise outer housings 1628 and 1629 respectively, which are connected to upper plate 1640. Hydraulic cylinders 1630 and 1635 also comprise rods 1626 and 1627 respectively. Rods 1626 and 1627 each comprise a lower end, each of which is connected to lower plate 1245.
In operation, improved well configuration unit 1210 begins in the position shown in FIG. 13, with cup tool 1260 located above bridge connector header 1230. In this position, fluid is free to flow through bridge connector header 1230. The position of the cup tool is shown in more detail in FIG. 14.
When the operator desires to seal bridge connector header 1230, hydraulic fluid is injected into the upper portion of hydraulic setting cylinders 1220 and 1225, thereby forcing rods 1222 and 1227 downward. Due to the connection between rods 1222 and 1227 and lower plate 1245, as well as the connection between lower plate 1245 and mandrel head 1251, the downward movement of rods 1222 and 1227 causes outer mandrel 1250 to move downward through bridge connector 1230 and into lower spool 1240 to the point that cup tool 1260 is located below the “T” junction of bridge connector header 1230 as shown in FIG. 15. In addition, due to the connection between rods 1626 and 1627 and upper plate 1640, inner mandrel 1255 and compression member 1700 also move downward towards lower spool 1240.
Once the cup tool 1260 has been positioned at the pack-off location, and the operator desires to engage seals 1265, hydraulic cylinders 1630 and 1635 are pressurized such that rods 1626 and 1627 move upwards, or away from the cup tool 1260, which causes the inner mandrel 1255 to move upward relative to the outer mandrel 1250. When this happens, upper surface 1703 of compression member 1700 contacts the lower surface of gage ring 1261 of cup tool 1260. Because the upper surface of gage ring 1261 contacts seals 1265, continued upward movement of inner mandrel 1255 and compression member 1700 causes gage ring 1261 to compress seals 1265, with the result that seals 1265 are extruded outward and form a seal within lower spool 1240 and/or the inner surface of bridge connector 1230.
Improved well configuration unit 1210 may also comprise upper lock mechanism 1800 and lower lock mechanism 1900. Upper lock mechanism 1800 and lower lock mechanism 1900 are generally structured consistent with the design discussed above in connection with lock mechanism 900, and shown in FIGS. 9-11 and 16. The linear actuator for upper lock mechanism 1800 and lower lock mechanism 1900 may comprise hydraulic cylinder 925. As will be understood by those of ordinary skill in the art, the linear actuator may also comprise an electronic actuator.
As illustrated in FIG. 15, lower lock mechanism 1900 is locked when cup tool 1260 has been moved into position below bridge connector header 1230. The lock segments of lower lock mechanism 1900 engage with a groove 1100 on the outer surface of the mandrel head 1251. This engagement prevents outer mandrel 1250 from being forced upward by high-pressure fluid within lower spool 1240, and thus maintains the integrity of the seal formed by seals 1265.
As shown in FIGS. 17 and 18, upper lock mechanism 1800 may be engaged in two distinct positions. FIG. 17 illustrates improved well configuration unit 1210 when cup tool 1260 has been moved into the pack-off location below bridge connector header 1230, but before seals 1265 have been engaged. Inner mandrel 1255 comprises inner mandrel head 1355, which also comprises lower portion 1365. Lower portion 1365 comprises a beveled lower face 1366 and a planar upper face 1367. As shown in FIG. 17, before seals 1265 have been engaged, upper lock mechanism 1800 is locked such that its segments 920 engage with planar upper face 1367 of lower portion 1365 of inner mandrel head 1355. In this position, seals 1265 cannot be engaged until upper lock mechanism 1800 is disengaged.
FIG. 18 illustrates improved well configuration unit 1210 when cup tool 1260 has been moved into the pack-off location below bridge connector header and after seals 1265 have been engaged by the upward movement of inner mandrel 1255 and compression member 1700. As shown in FIG. 17, upper lock mechanism 1800 is locked such that its segments 920 engage with beveled lower face 1366 of lower portion 1365 of inner mandrel head 1355. In this position, inner mandrel 1255 and compression member 1700 may not be moved downward, thereby disengaging seals 1265, until upper lock mechanism 1800 is disengaged.
The improved well configuration unit 2000 may include an improved cup tool 2005. A cup tool 2005 allows for a way to divert flow in order to energize a seal assembly. The cup tool 2005 replaces the current method of using a valve for dual closure on the zipper manifold. The cup tool 2005 reduces the total number of valves needed for a multi-well pad which results in less maintenance, repair, and transportation costs. The cup tool 2005 also increases efficiency and provides added safety benefits.
In the embodiment shown in FIG. 19, as described in more detail below, a cup tool 2005 is used in place of the mandrel cup tool discussed in FIGS. 2-5. As shown in FIG. 19, a hydraulic setting cylinder 2015 actuates a mandrel 2010 to stroke down to allow a cup tool 2005 to engage with a lower spool 2075. The hydraulic setting cylinder 2015 includes a mandrel lock 2025. The mandrel lock 2025 may be engaged to lock the cup tool 2005 in position.
FIG. 19 illustrates the mandrel 2010 in the open position. While the mandrel 2010 is in the stroked out or open position, the cup tool 2005 sits above the “T” junction of bridge connector header 2070, which allows fluid to flow through the “T” junction to the connected bridge and frac tree. The mandrel 2010 is solid at the cup tool 2005 such that fluid does not flow through the mandrel 2010.
In the closed position, which is shown in FIG. 20, the hydraulic setting cylinder 2015 may move the mandrel 2010 through the “T” junction of the bridge connector header 2070, such that the cup tool 2005 of the mandrel 2010 will seal at a location below the “T” junction. As shown in FIG. 20, the cup tool 2005 may optionally seal within lower spool 2075, where the seal assemblies of the cup tool form a seal against the lower spool 2075's inner surface. When the mandrel 2010 is in the closed position and a seal has been formed at a location below the junction of bridge connector header 2070, fluid cannot flow past the cup tool 2005 to the bridge connector header 2070.
The improved well configuration unit 2000 is actuated from the open position to the closed position when fluid flows through a hydraulic port 2060 into the cavity 2055 of the hydraulic setting cylinder 2015. The fluid drives the mandrel head 2050 from the open position to the closed position. The mandrel head 2050 is connected to the mandrel 2010. By driving the mandrel head 2050 into the closed position, the mandrel 2010 moves from the open position to the closed position.
FIGS. 21-24 show various embodiments of the cup tool 2005. FIG. 21A depicts the preferred embodiment of the cup tool 2005. In the preferred embodiment, a cup tool 2005 comprises a single actuator 2030 with a dual seal assemblies 2040 and 2045. The cup tool 2005 also comprises seals 2065 on the outer surface of a piston 2080. The seals 2065 prevent the hydraulic fluid flow from leaking past the pistons 2080 into the spool 2075 or interfering with the operation of the seal assemblies 2040 and 2045. The seal assemblies 2040 and 2045 are energized by the pistons. As shown in FIG. 21B, hydraulic fluid flows through the actuator 2030. The fluid then pushes the pistons 2080. The pistons 2080 then energize the seal assemblies 2040 and 2045 so that the seal assemblies extrude outward from the cup tool 2005 and seal with the inner surface of the lower spool 2075.
FIG. 22A depicts an alternative embodiment of the cup tool 3005. In the illustrated embodiment, the cup tool 3005 comprises a single actuator 3030 with a single seal assembly 3040. The cup tool 3005 also comprises seals 3065 on the outer surface of a piston 3080. In the illustrated embodiment, the cup tool 3005 also comprises seals 3065 on the inner surface of the cup tool 3005 above the piston 3080. Similarly to FIG. 21B, FIG. 22B depicts the energized seal assemblies 3040. The seal assembly 3040 is energized in the same was as in FIG. 21 B, with hydraulic fluid flow actuating a piston 3080 to energize the seal assembly 3040.
FIG. 23A depicts an alternative embodiment of the cup tool 4005. In the illustrated embodiment, the cup tool 4005 comprises dual actuators 4030 and 4035 with a dual seal assemblies 4040 and 4045. The cup tool 4005 also comprises seals 4065 on the outer surface of the piston 4050. In the illustrated embodiment, the cup tool 4005 also comprises seals 4065 on the inner surface of the cup tool 4005 above the piston 4080. In the illustrated embodiment, the pistons 4050 and 4080 are internal beveled pistons. Similarly to the embodiments discussed above, FIG. 23B depicts the energized seal assemblies 4040 and 4045. As shown in FIG. 23B, hydraulic fluid flows through actuator 4035 to piston 4080. Piston 4080 then energizes seal assembly 4045 so that seal assembly 4045 extrudes from the cup tool 4005 and seals against the inner surface of lower spool 4075. Actuator 4030 directs hydraulic fluid flow to piston 4050. Piston 4050 energizes seal assembly 4040 in the same way as piston 4080 energizes seal assembly 4045.
FIG. 24A depicts an alternative embodiment of the cup tool 5005. In the illustrated embodiment, the cup tool 5005 comprises dual actuators 5030 and 5035 with dual seal assemblies 5040 and 5045. The cup tool 5005 also comprises seals 5065 on the outer surface of the piston 5050. In the illustrated embodiment, the cup tool 5005 also comprises seals 5065 on the inner surface of the cup tool 5005 above the piston 5080. In the illustrated embodiment, the pistons 5050 and 5080 are external beveled pistons. Similar to the FIG. 23 B discussed above, FIG. 24 B depicts the energized seal assemblies 5040 and 5045. The seal assemblies 5040 and 5045 are energized in the same ways as in FIG. 23 B, with hydraulic fluid flow traveling through actuators 5035 and 5030 to actuate pistons 5080 and 5050 respectively so that piston 5080 can energize seal assembly 5045 and piston 5050 can energize seal assembly 5040.
It is understood that variations may be made in the foregoing without departing from the scope of the present disclosure. In several exemplary embodiments, the elements and teachings of the various illustrative exemplary embodiments may be combined in whole or in part in some or all of the illustrative exemplary embodiments. In addition, one or more of the elements and teachings of the various illustrative exemplary embodiments may be omitted, at least in part, and/or combined, at least in part, with one or more of the other elements and teachings of the various illustrative embodiments.
Any spatial references, such as, for example, “upper,” “lower,” “above,” “below,” “between,” “bottom,” “vertical,” “horizontal,” “angular,” “upwards,” “downwards,” “si de-to-si de,” “left-to-right,” “right-to-left,” “top-to-bottom,” “bottom-to-top,” “top,” “bottom,” “bottom-up,” “top-down,” etc., are for the purpose of illustration only and do not limit the specific orientation or location of the structure described above. Similarly, references to the general shape of certain components, such as for example, “planar” or “cylindrical,” are for the purpose of illustration only and do not limit the specific configuration of the structure described above.
In several exemplary embodiments, while different steps, processes, and procedures are described as appearing as distinct acts, one or more of the steps, one or more of the processes, and/or one or more of the procedures may also be performed in different orders, simultaneously and/or sequentially. In several exemplary embodiments, the steps, processes, and/or procedures may be merged into one or more steps, processes and/or procedures.
In several exemplary embodiments, one or more of the operational steps in each embodiment may be omitted. Moreover, in some instances, some features of the present disclosure may be employed without a corresponding use of the other features. Moreover, one or more of the above-described embodiments and/or variations may be combined in whole or in part with any one or more of the other above-described embodiments and/or variations.
Although several exemplary embodiments have been described in detail above, the embodiments described are exemplary only and are not limiting, and those skilled in the art will readily appreciate that many other modifications, changes and/or substitutions are possible in the exemplary embodiments without materially departing from the novel teachings and advantages of the present disclosure. Accordingly, all such modifications, changes, and/or substitutions are intended to be included within the scope of this disclosure as defined in the following claims. In the claims, any means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures. Moreover, it is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the word “means” together with an associated function.
