EP2360347B1 - Expandable ball seat - Google Patents
Expandable ball seat Download PDFInfo
- Publication number
- EP2360347B1 EP2360347B1 EP11154062.1A EP11154062A EP2360347B1 EP 2360347 B1 EP2360347 B1 EP 2360347B1 EP 11154062 A EP11154062 A EP 11154062A EP 2360347 B1 EP2360347 B1 EP 2360347B1
- Authority
- EP
- European Patent Office
- Prior art keywords
- ball
- drop
- ball seat
- drop ball
- seat
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Not-in-force
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- 238000000034 method Methods 0.000 claims description 15
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- 230000003213 activating effect Effects 0.000 claims description 8
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- 230000015572 biosynthetic process Effects 0.000 description 22
- 238000005755 formation reaction Methods 0.000 description 22
- 238000002347 injection Methods 0.000 description 12
- 239000007924 injection Substances 0.000 description 12
- 229930195733 hydrocarbon Natural products 0.000 description 11
- 150000002430 hydrocarbons Chemical class 0.000 description 11
- 239000004568 cement Substances 0.000 description 6
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 6
- 239000011435 rock Substances 0.000 description 5
- 239000000126 substance Substances 0.000 description 4
- 230000004936 stimulating effect Effects 0.000 description 3
- 241000282472 Canis lupus familiaris Species 0.000 description 2
- 229910000831 Steel Inorganic materials 0.000 description 2
- 230000004913 activation Effects 0.000 description 2
- 239000000654 additive Substances 0.000 description 2
- 230000003247 decreasing effect Effects 0.000 description 2
- 238000009434 installation Methods 0.000 description 2
- -1 oil and/or gas Chemical class 0.000 description 2
- 239000010959 steel Substances 0.000 description 2
- 239000002253 acid Substances 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
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Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
- E21B34/142—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools unsupported or free-falling elements, e.g. balls, plugs, darts or pistons
Definitions
- the present invention relates to an expandable ball seat for use in subterranean wells, in particular for wells used for production of hydrocarbons from subterranean formations.
- a well extending through several strata of rock in a formation is provided.
- the well is usually constructed by drilling a borehole a distance through the rock, insert a steel casing into the wellbore and cement it to the formation.
- Cementing usually involves pumping wet cement down through a tubular liner and casing, out through a floating or sliding sleeve valve and up through the annulus formed by the formation and casing before the cement is left to set.
- the next section is drilled through the formation in the extension of the existing casing. A liner is then hung off by a liner hanger, and cemented to the formation.
- a well comprising a number of sections with ever decreasing diameters have reached the desired depth.
- one or more strata of the formation contain hydrocarbons, and typically the productive strata are separated by rock that does not carry oil or gas.
- the casing may be penetrated at depths corresponding to the productive strata, and the formation may be hydraulically fractured to facilitate the flow of fluid from the formation into the production well.
- Horizontal wells may also branch out from a vertical production well, and extend several kilometres through a layer containing hydrocarbons.
- a production pipe is typically provided within the casing or liner, and the completed well can be divided into several production zones by using packers. Valves control the flow of fluid during cementing. Other valves control fluid flow into a segment of production pipe corresponding to the production zone. In operation, fluid flowing from several zones at different rates can be mixed and conveyed up the production pipe to the surface.
- various chemicals may be injected into the formation.
- the chemical may be water, brine, acids, solvents, surfactants etc, and it can be injected through the production well, or through one or more injection wells that may be provided at a distance from the production well.
- a typical oil or gas field can comprise one or more production wells, and zero or more injection wells.
- an injection well may for example inject water or gas into or more zones to increase the pressure in the reservoir.
- Various additives to decrease the viscosity of fluid in a particular zone may also be injected. Such methods are collectively known as "stimulating a zone", and their purpose is to enhance production from the zone. Particular methods for stimulating a zone are not part of the present invention, and hence not described in further detail in this disclosure. However, it should be understood that providing a larger number of injection points in a zone would help in distributing fluids and/or chemical additives in the zone.
- valves and packers may be provided to be able to isolate a certain section or zone in the horizontal well at a later time should this situation occur.
- the cost of valves and the time required to open a large number of valves when the zone is to be put into production can limit the number of sections or zones per branch. In turn, this might result in relatively large "dead zones" containing hydrocarbons that cannot be retrieved.
- various mechanical devices are used during construction, completion and production, e.g. liner hangers, packers and valves of different sizes and designs.
- One of several ways to operate a mechanical device in a well is by using a drop ball, which are dropped or pumped with a fluid down into the well until it lands on a ball seat. Then, hydraulic pressure acts on the equipment and causes a relative movement between two parts, which movement activates the device.
- Devices activated by drop balls or other similar objects are comparatively inexpensive, and they do not require costly interrupts in the production, such as those caused when a working string or running tool must be run into the well.
- US 4,4862,966 relates to a selectively releasable valve in a wiper plug releasably attached to a hydraulic setting tool for a liner hanger in a wellbore.
- the selectively releasable valve has an annular valve seat member having collapsible finger members for sealingly receiving a ball member.
- the annular valve seat member is movable under predetermined hydraulic pressure to shift and expand the collapsible finger members to release the ball member.
- the annular valve seat member is retained in the wiper plug.
- US 2,454,839 concerns a device for removing whipstocks from bore holes and adapted to be included within a drill string above a bit.
- a dart plug may be inserted in the fluid flow just ahead of the cement when a liner is to be cemented to the formation during completion of the well.
- the dart plug has a cylindrical body to separate the cement from the fluid below, and it typically has a rounded conical nose similar to a drop ball.
- the dart When the pressure reaches a predetermined level, shear pins or the like, which originally prevented relative movement between inner and outer sleeves of the valve, breaks. Then the sliding sleeve of the cementing valve slides downstream and opens the cementing valve, allowing cement to enter the annulus between the liner and the formation.
- the dart may conventionally be broken, e.g. by a drill bit when the next section of the well is constructed.
- a drop ball might have been used for the same purpose.
- the dart has the same function as a drop ball in that it lands on a seat, thereby closing fluid circulation such that hydraulic pressure can operate on a device.
- a series of drop ball might be used to operate valves and other devices at different times and locations.
- a series of drop balls may be used to operate a series of valves in different zones in order to open or shut off production from different zones in a production phase of a well.
- this is done by decreasing the diameters of the ball seats with increasing depth and using balls of different sizes.
- a drop ball having a certain diameter will pass all the seats with larger diameters and land on the first seat having a diameter less than the diameter of the ball.
- hydraulic pressure builds up behind it, and can be used to activate the device, e.g. by breaking a shear pin and/or provide some relative movement between parts within the device.
- a well may extend 2000 meters or more vertically and/or horizontally.
- the mean distance between drop ball activated devices becomes 100 meters or more. This may exceed the thickness of a production zone. Because at least one valve should control the flow of fluid from each production zone, less than 20 ball operated valves will be available for use in horizontal wells branching out into the production zone(s).
- valves By there was a way to open an arbitrary number of valves by one drop ball in e.g. one production zone and/or horizontal branch, a large number of inexpensive valves could be installed. This would help when stimulating a zone in that fluid could be injected through a large number of injection points, and to drain the formation fluid into a production pipe through an arbitrary number of valves.
- a main objective of the present invention is to provide an apparatus capable of activating an arbitrary number of drop ball operated devices using one drop ball only.
- valves it would be feasible to install a greater number of valves to increase the number of injection points in an injection well. It would also be feasible to increase the number of valves in a long horizontal well, because all of them could be opened fast with one drop ball only. If, for example, water breaks through at a later time, a relatively small zone could be shut off, limiting the "dead zone" or pocket of hydro carbons that cannot be retrieved from the formation. Such a shutdown of certain valves could be done using methods known in the art, e.g. by providing the valves with standard fittings for conventional tools, and run a tool into the well by coiled tubing, slickline, a well tractor or running tool etc.
- a drop ball seat is concentrically and axially slidably disposed in an outer sleeve comprising a first, internal cylinder face, wherein the seat comprises at least one outwardly biased lug, which, when abutting the first, internal cylinder face extends radially inwards and defines a first seat diameter less than the diameter of the drop ball; the sleeve comprising at least one groove in its internal surface; and the lug, when received in the groove, defining a second seat diameter being at least as large as the diameter of the drop ball.
- the drop ball (or dart or similar object) will pass through and proceed to the next ball operated device, where the process is repeated.
- one ball may be used to operate an arbitrary number of devices having similar seat diameters, e.g. all valves or devices of a certain type in a zone.
- differently sized balls may conveniently be provided as in prior art.
- one ball might be used to open an arbitrary number of valves in a production zone, whereas the next larger ball might be used to operate any number of devices in the production zone above.
- any desired number of drop ball operated valves or other devices can be installed in a production zone, greatly reducing the number of expensive valves operated by other means and/or improve the production from a zone.
- the present invention provides a method using the apparatus.
- the present invention comprises a method for activating and deactivating an arbitrary number of drop ball operated devices in a well using a single drop ball.
- Fig. 1 is a schematic cross sectional view of a well system used in production of hydrocarbons, i.e. oil and/or gas, from a subterranean reservoir.
- a hole or wellbore 101 is drilled through several strata of rock in the formation.
- two strata or layers 100 and 200 are shown.
- the wellbore is lined with a steel casing 102, which is cemented to the formation.
- the layers 100 and 200 contain hydrocarbons, and may be separated by rock layers that do not contain oil or gas.
- the casing 102 may be penetrated at depths corresponding to the productive strata 100 and 200, and hydraulic fracturing may be used to create and open cracks in the formation to facilitate fluid flow from the formation into the production well.
- Horizontal wells 100', 100" and 200' may also branch out from a vertical production well, and extend several kilometres through a layer 100, 200 containing hydrocarbons.
- a production pipe 103 is typically provided within the casing or liner 102, and the completed well can be divided into several production zones by using packers (not shown).
- the valves 110A-C, 210A-C, ... in Fig.1 control fluid flow from a formation100, 200 into the segment of production pipe corresponding to the production zone.
- the valves will generally be of different design or types, e.g. sliding sleeve valves, butterfly valves and ball valves of different sizes and designs used for different purposes as known in the art.
- fluid flowing from several zones shown by arrows 120
- fluid flowing from several zones shown by arrows 120
- one or more injection wells 300 may be provided at a distance from the production well.
- An injection well inserts fluid into one or more zones, e.g. to increase the pressure in the reservoir or to provide some chemical composition, and can be made in a similar manner as the production well.
- a typical oil or gas field can comprise one or more production wells and zero or more injection wells.
- ball operated device is intended to include these and other devices when hydraulically operated using a drop ball, dart or similar device. All such ball operated devices comprises a seat on which the ball, dart or similar device can land.
- Fig. 2 shows a sliding sleeve valve using a preferred embodiment 4 of the ball seat according to the present invention.
- a sliding sleeve valve is open when holes in the sleeves 1 and 2 are aligned, and closed when the holes are not aligned.
- the valve may be operated by a simple axial displacement, and is well suited for illustrative purposes.
- the device on Fig. 2 comprises an outer sleeve 1 having an internal surface having two parts: an internal cylindrical surface and an annular groove 7 with a slightly larger diameter adapted to receive one or more lugs 6 as described below.
- a sliding sleeve 2 is disposed concentrically within the outer sleeve 1.
- the sliding sleeve 2 is able to slide axially along the inner face of sleeve 1, and is attached to a cage 4 implementing the ball seat as described in connection with Fig. 10 below.
- the particular valve in Fig.2 is retained in a natural closed position during installation of the valve in a well, and designed to open when activated. Another embodiment may of course be retained in an open position during installation, and designed to close when activated. In either case, the elements may be connected by shear pins, which are designed to break when a predetermined force is applied to them.
- the ball seat cage 4 is retained in the inner sleeve 2 by shear pins 3.
- the shear pins 3 have heads abutting an inner shoulder on the outer sleeve, and thus retain the inner sleeve 2 in the outer sleeve 1 until an activating force is applied.
- the activating force is applied when a ball 9 lands on the seat and prevents fluid flow axially along the valve. Hydraulic pressure then builds up behind the ball, until it provides a force that it sufficient to break the shear pins 3.
- Fig. 3 shows the device of Fig. 2 where a drop ball 9 has landed on the seat.
- the seat is provided by flexible fingers on the cage 4 that are pressed radially inwardly by lugs 6 when the lugs abut the inner cylindrical surface of the outer sleeve 1.
- the inner sleeve 2 has moved relative to the outer sleeve, such that the heads of the shear pins can be pushed radially inwards. With the retaining heads out of the way, the inner sleeve 2 is allowed to slide axially within the outer sleeve 1 to the position shown in figure 4 .
- This first release mechanism is illustrated by heads of the pins 3 skipping past a small shoulder on the interior face of the outer sleeve 1. However, it should be understood that shear pins could provide the first release mechanism in another embodiment.
- Lugs 6 are at the axial position of an annular groove 7 with extended diameter.
- the lugs 6 might at this point snap or move outwards and into the groove 7, thereby releasing the ball 9.
- the lugs 6 are still prevented from extending into the groove 7. This may be done in a number of ways, e.g. by providing stoppers 5 between the fingers and the outer sleeve, thus preventing the fingers from flexing radially outwards. This prevents the lugs 6 from extending into the groove until the inner sleeve has moved axially past the stoppers 5 as shown in Fig.
- the lugs may be prevented from extending into groove 7 by providing a breakable band around the distal ends of the fingers 41 shown on Fig. 10 .
- the ball seat still has its smaller diameter. This allows a further build up of hydraulic pressure until the force working on the ball and seat is sufficient to activate a second release mechanism, which may be convenient to ensure a predetermined minimum force required to ensure that the device is properly operated.
- This second release mechanism can be shear pins, a breakable band, lugs or other release mechanisms known in the art.
- shear pins could be designed to break at a force that is guaranteed to pull the sliding sleeve valve entirely open.
- the cage 4 has been released from the inner sleeve by a second release mechanism, e.g. by broken shear pins 3.
- the seat 4 has moved further downstream until it has been stopped by the stoppers 5, which at this point have engaged the end of cage 4, or more particularly the ring 40 on Fig. 10 .
- the cage may be prevented from moving downstream by a shoulder 8. Now, the lugs 6 may be pressed radially outwards into the groove 7.
- lugs 6 are pressed radially outwards into the groove 7 provided on the inner surface of the outer sleeve 1. This expands the ball seat to a diameter where it no longer retains the ball 9. This is illustrated by the ball 9 in a position downstream, i.e. to the right in the figures, of the cage 4. The ball 9 may proceed to the next apparatus, which of course can have the same diameter on the seat as the one previously disclosed.
- one ball may in this way be used to operate an arbitrary number of devices.
- a sliding sleeve valve is an example only.
- Another application of the ball seat according to the invention could be within a butterfly valve or ball valve, in which a rotary movement rather than the linear movement disclosed previously, is used to activate the device.
- a pair of helical shoulders could be provided on the inner and outer sleeves.
- the seat 4 moves until the helical shoulders (not shown) engage each other.
- hydraulic pressure behind the drop ball may be allowed to build up sufficiently to guarantee a relative rotation between the sleeves. This rotation may be used to rotate a circular plate in a butterfly valve or a ball in a ball valve.
- the second release mechanism illustrated above as a broken shear pin, could equally well be radially biased dogs or some other means known in the art.
- the purpose of the release mechanisms are simply to ensure that sufficient force is available to operate the device properly before the next step in operating a device or before the drop ball is released further downstream.
- Fig. 7 shows a generalized outer sleeve 1. No holes are shown in the sleeve in order to illustrate that the ball seat of the invention may be used in any ball operated device, not only in a sliding sleeve valve.
- the outer sleeve 1 may comprise standard threading in both ends for inclusion into a tubular string, such as a production pipe, a liner or a casing, before it is inserted into a wellbore as part of the tubular string.
- the features of importance for the present invention is its internal surface comprising one or more grooves 7 to receive lugs 6 as discussed with reference to figures 2-6 .
- Figure 8 shows an inner sleeve for a sliding valve, such as the one discussed above.
- the sleeve has a cylindrical main portion with radially extending ports 22. One end has an end part 21 with extended radius.
- the shoulder formed between the main cylinder and the end part 21 stops the sleeve 2 from moving downstream as it engages a corresponding shoulder on the inner face of the outer sleeve. This may be used to activate the first release mechanism described above if relative axial movement between the cage 4 and the sleeve 2 is allowed.
- Figure 9 shows an embodiment of a pin 3 used to illustrate the first and second release mechanisms in the description referring to Figs. 2-6 .
- the tapered head of pin 3 is intended to illustrate the first release mechanism.
- the pin shown in Fig. 9 is biased radially outwards.
- a force e.g. a spring force.
- the tapered face and the bias can be adjusted to provide a first release mechanism releasing cage 4 when a first force or pressure is achieved.
- similar release mechanisms in the form of spring biased dogs or similar devices may be used to implement a release mechanism.
- a shear pin 3 provides a second release mechanism in the examples above, some embodiments may have no second release mechanism. Other embodiments may have a different second release mechanism, e.g. a biased pin or lug.
- Figure 10 shows cage 4 formed by a number of fingers 41 parallel to each other, and attached to a ring 40 at one end.
- the ring 40 is upstream when the cage is in use, and the ball seat is provided inside the cage opposite ring 40.
- the fingers can be inflexible, e.g. formed of a material that undergoes a plastic deformation when the fingers are bent inwards. In this case the force required to bend them back may provide part or all of the resistance required to prevent the lugs 6 from entering the groove 7 in Fig. 4 , when the cage 4 is not yet retained by stoppers 5 or shoulder 8.
- the fingers may be flexible and provide a force directed radially outwards when pressed in by lugs 6. In this case, the situation in Fig. 5 would be extremely short, as flexible fingers immediately would snap outwards, moving the lugs 6 into groove 7.
- Yet another alternative is to attach the fingers 41 to the ring 40 by hinges, and provide the fingers with spring bias, retaining rings etc as required by the application.
- Radially extending lugs (not shown in Fig. 10 ), such as the lugs 6 described above, is a convenient way of pressing the fingers radially inwards.
- the distal or downstream ends of the fingers 41 may be pressed together to form a continuous ring 42, the ball seat being defined by the inner diameter of ring 42.
- a breakable band may be provided around the ring 42 in order to prevent the lugs 6 from snapping into groove 7 until a certain minimum force is available.
- the space between the sections of ring 42 is shown as quite narrow for illustrative purposes. However, it should be understood that the space between the sections of ring 42 may be wider, such that the inner diameter of the continuous ring 42 forms a ball seat with a minimum diameter. In this case one type of cage 4 can be used for several ball diameters between this minimum diameter and the diameter of the ring 40 simply by providing lugs 6 of different lengths.
- the cage 4 is typically retained within an outer housing until released by a release mechanism.
- the holes 401 in ring 40 are adapted to the lower part 30 of the pin 3 shown in Fig. 9 , thus indicating that the cage 4 is released from the sleeve 2 by the second release mechanism of the embodiment described above.
- shear pins are just one convenient release mechanism, and the cage 4 can be provided with other elements than the holes 401 to fit another release mechanism if desired.
- Fig. 11 illustrates a cylindrical stopper 5 having an outer diameter slightly less than the space shown between the fingers and rings 40 and 42 in Fig. 10 .
- the main function of the stoppers 5 is to prevent the cage 4 from travelling downstream when the valve is open.
- a shoulder 8 may be provided for the same purpose.
- Fig. 12 shows a lug 6, which in the preferred embodiment is used to press a finger 41 radially inwards when disposed between e.g. the outer circumference of ring 42 and the inner surface of the sleeve 1, thus preventing the finger 41 from moving outwards until the lug 6 reaches the groove 7.
- Lugs 6 of different lengths may be used to provide ball seats of different diameters.
- the invention comprises a method for activating an arbitrary number of drop ball operated devices in a well, comprising the steps of:
- a suitable apparatus for this method is the one described previously, in which hydraulic pressure is the only means necessary to operate an arbitrary number of devices.
- the pressure, or an equivalent like the load of a circulating pump may be monitored to determine the point in time when the drop ball (9) arrives at a ball seat, at which time an increased pressure may be detected.
- pump pressure may be added to the hydraulic pressure exerted by the column of fluid behind the drop ball in order to operate one or more release mechanisms for the device as described more fully above.
- a drop in pressure or pump load can indicate that the drop ball has left the device, and no longer inhibits fluid flow in the string.
- each zone having several devices.
- several groups of devices may be provided, each group being operated by one drop ball, and each group may be operated by a drop ball of different size than the drop ball for the other groups.
- this group of devices would be the first to be activated. This matches a normal production scenario, in which, for example, a waterfront from an injection well is expected to reach the most far away parts of a production well first.
- the present invention may be used to open a less remote section of the well containing a number of drop ball operated devices using one single drop ball. Obviously, this may save considerably time otherwise required for intervention.
Description
- The present invention relates to an expandable ball seat for use in subterranean wells, in particular for wells used for production of hydrocarbons from subterranean formations.
- To produce hydrocarbons, i.e. oil and/or gas, from subterranean reservoirs, a well extending through several strata of rock in a formation is provided. The well is usually constructed by drilling a borehole a distance through the rock, insert a steel casing into the wellbore and cement it to the formation. Cementing usually involves pumping wet cement down through a tubular liner and casing, out through a floating or sliding sleeve valve and up through the annulus formed by the formation and casing before the cement is left to set. The next section is drilled through the formation in the extension of the existing casing. A liner is then hung off by a liner hanger, and cemented to the formation. This process is repeated until a well comprising a number of sections with ever decreasing diameters have reached the desired depth. Typically one or more strata of the formation contain hydrocarbons, and typically the productive strata are separated by rock that does not carry oil or gas. To access the formation fluids, the casing may be penetrated at depths corresponding to the productive strata, and the formation may be hydraulically fractured to facilitate the flow of fluid from the formation into the production well. Horizontal wells may also branch out from a vertical production well, and extend several kilometres through a layer containing hydrocarbons.
- A production pipe is typically provided within the casing or liner, and the completed well can be divided into several production zones by using packers. Valves control the flow of fluid during cementing. Other valves control fluid flow into a segment of production pipe corresponding to the production zone. In operation, fluid flowing from several zones at different rates can be mixed and conveyed up the production pipe to the surface.
- To increase the amount and/or rate at which hydrocarbons are produced from a zone, various chemicals may be injected into the formation. The chemical may be water, brine, acids, solvents, surfactants etc, and it can be injected through the production well, or through one or more injection wells that may be provided at a distance from the production well. Thus, a typical oil or gas field can comprise one or more production wells, and zero or more injection wells. In some cases, an injection well may for example inject water or gas into or more zones to increase the pressure in the reservoir. Various additives to decrease the viscosity of fluid in a particular zone may also be injected. Such methods are collectively known as "stimulating a zone", and their purpose is to enhance production from the zone. Particular methods for stimulating a zone are not part of the present invention, and hence not described in further detail in this disclosure. However, it should be understood that providing a larger number of injection points in a zone would help in distributing fluids and/or chemical additives in the zone.
- It would also help production if the production well could be divided in more zones in a convenient and economical manner. For example, if water is injected through an injection well and breaks through the formation at some point along a horizontal branch of a well, the water content in the produced fluid could quickly exceed a predetermined level, and cause a decision to shut down that particular branch. However, there may be significant pockets of oil and gas left in the formation outside the region of water breakthrough. Hence, valves and packers may be provided to be able to isolate a certain section or zone in the horizontal well at a later time should this situation occur. On the other hand, the cost of valves and the time required to open a large number of valves when the zone is to be put into production can limit the number of sections or zones per branch. In turn, this might result in relatively large "dead zones" containing hydrocarbons that cannot be retrieved.
- As indicated above, various mechanical devices are used during construction, completion and production, e.g. liner hangers, packers and valves of different sizes and designs. One of several ways to operate a mechanical device in a well is by using a drop ball, which are dropped or pumped with a fluid down into the well until it lands on a ball seat. Then, hydraulic pressure acts on the equipment and causes a relative movement between two parts, which movement activates the device. Devices activated by drop balls or other similar objects are comparatively inexpensive, and they do not require costly interrupts in the production, such as those caused when a working string or running tool must be run into the well.
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US 4,4862,966 -
US 2,454,839 concerns a device for removing whipstocks from bore holes and adapted to be included within a drill string above a bit. - The terms "drop ball" and "ball seat" are used for convenience herein, as drop balls are the most common means for activating devices in the well hydraulically. However, it should be understood that other equivalent objects used for the same purpose are considered as well. For example, a dart plug may be inserted in the fluid flow just ahead of the cement when a liner is to be cemented to the formation during completion of the well. The dart plug has a cylindrical body to separate the cement from the fluid below, and it typically has a rounded conical nose similar to a drop ball. When the dart lands on a seat connected to the valve, the fluid circulating through the liner is shut off, and hydraulic pressure builds up behind the dart. When the pressure reaches a predetermined level, shear pins or the like, which originally prevented relative movement between inner and outer sleeves of the valve, breaks. Then the sliding sleeve of the cementing valve slides downstream and opens the cementing valve, allowing cement to enter the annulus between the liner and the formation. After use, the dart may conventionally be broken, e.g. by a drill bit when the next section of the well is constructed. In a similar manner, a drop ball might have been used for the same purpose. Thus, the dart has the same function as a drop ball in that it lands on a seat, thereby closing fluid circulation such that hydraulic pressure can operate on a device.
- A series of drop ball might be used to operate valves and other devices at different times and locations. For example, a series of drop balls may be used to operate a series of valves in different zones in order to open or shut off production from different zones in a production phase of a well. Conventionally, this is done by decreasing the diameters of the ball seats with increasing depth and using balls of different sizes. Then, a drop ball having a certain diameter will pass all the seats with larger diameters and land on the first seat having a diameter less than the diameter of the ball. Once the ball shuts off circulation, hydraulic pressure builds up behind it, and can be used to activate the device, e.g. by breaking a shear pin and/or provide some relative movement between parts within the device.
- However, there is a limit to the number of different ball sizes that can be used in a well. If, for example, the diameters of two balls are too close to each other, even a minor piece of debris, sand or grit might cause a ball to land on a seat with a diameter slightly larger than the intended seat, thereby unintentionally activating the wrong device. Hence, there must be a minimum diameter difference between the drop balls to be used in a certain application. This also limits the number of pieces of equipment that can be operated by conventional drop balls or seats in a given well. Typically, about 20 or less ball seats may be used in one well for the reason discussed above.
- As modern reservoirs increase in size and/or in depth, using drop balls in the conventional manner becomes impractical. For example, a well may extend 2000 meters or more vertically and/or horizontally. Using a maximum of 20 drop balls of different sizes, the mean distance between drop ball activated devices becomes 100 meters or more. This may exceed the thickness of a production zone. Because at least one valve should control the flow of fluid from each production zone, less than 20 ball operated valves will be available for use in horizontal wells branching out into the production zone(s).
- In some cases it would be advantageous or necessary to provide more than one valve controlling the flow of formation fluid into the production pipe, limiting the number of ball activated valves available for other zones and/or horizontal wells even further. Using equipment operated by other means quickly becomes costly, as electrical motors need to handle the temperatures and pressures in deep wells, hydraulic lines become longer etc. Hence, it would be advantageous to provide a system wherein one drop ball could open an arbitrary number of valves in a vertical or horizontal well.
- If there was a way to open an arbitrary number of valves by one drop ball in e.g. one production zone and/or horizontal branch, a large number of inexpensive valves could be installed. This would help when stimulating a zone in that fluid could be injected through a large number of injection points, and to drain the formation fluid into a production pipe through an arbitrary number of valves.
- Thus, a main objective of the present invention is to provide an apparatus capable of activating an arbitrary number of drop ball operated devices using one drop ball only.
- In particular, it would be feasible to install a greater number of valves to increase the number of injection points in an injection well. It would also be feasible to increase the number of valves in a long horizontal well, because all of them could be opened fast with one drop ball only. If, for example, water breaks through at a later time, a relatively small zone could be shut off, limiting the "dead zone" or pocket of hydro carbons that cannot be retrieved from the formation. Such a shutdown of certain valves could be done using methods known in the art, e.g. by providing the valves with standard fittings for conventional tools, and run a tool into the well by coiled tubing, slickline, a well tractor or running tool etc.
- The main objective is achieved by providing an apparatus operated by a drop ball wherein a drop ball seat is concentrically and axially slidably disposed in an outer sleeve comprising a first, internal cylinder face, wherein the seat comprises at least one outwardly biased lug, which, when abutting the first, internal cylinder face extends radially inwards and defines a first seat diameter less than the diameter of the drop ball; the sleeve comprising at least one groove in its internal surface; and the lug, when received in the groove, defining a second seat diameter being at least as large as the diameter of the drop ball.
- As the seat diameter increases to the second seat diameter, the drop ball (or dart or similar object) will pass through and proceed to the next ball operated device, where the process is repeated. Thus, one ball may be used to operate an arbitrary number of devices having similar seat diameters, e.g. all valves or devices of a certain type in a zone. Still, differently sized balls may conveniently be provided as in prior art. With the present invention one ball might be used to open an arbitrary number of valves in a production zone, whereas the next larger ball might be used to operate any number of devices in the production zone above. Thus, any desired number of drop ball operated valves or other devices can be installed in a production zone, greatly reducing the number of expensive valves operated by other means and/or improve the production from a zone.
- In another aspect, the present invention provides a method using the apparatus.
- In yet another aspect, the present invention comprises a method for activating and deactivating an arbitrary number of drop ball operated devices in a well using a single drop ball.
- The invention will be fully explained in the following detailed description with reference to the accompanying drawings in which similar numbers references similar or equivalent parts, and in which:
-
Fig. 1 is a schematic view of a well comprising several zones and branches; -
Figs. 2-5 show a drop ball activated valve using the invention in several stages during activation; -
Fig. 6 shows the device onfigs. 2-5 in the final stage, wherein the drop ball is released; and -
Figs. 7-12 show various details of the device. -
Fig. 1 is a schematic cross sectional view of a well system used in production of hydrocarbons, i.e. oil and/or gas, from a subterranean reservoir. A hole orwellbore 101 is drilled through several strata of rock in the formation. InFig 1 , two strata orlayers steel casing 102, which is cemented to the formation. InFig. 1 , thelayers casing 102 may be penetrated at depths corresponding to theproductive strata Horizontal wells 100', 100" and 200' may also branch out from a vertical production well, and extend several kilometres through alayer - A
production pipe 103 is typically provided within the casing orliner 102, and the completed well can be divided into several production zones by using packers (not shown). Thevalves 110A-C, 210A-C, ... inFig.1 control fluid flow from a formation100, 200 into the segment of production pipe corresponding to the production zone. The valves will generally be of different design or types, e.g. sliding sleeve valves, butterfly valves and ball valves of different sizes and designs used for different purposes as known in the art. In operation, fluid flowing from several zones (shown by arrows 120) at different rates can be mixed and conveyed up the production pipe to thesurface 10. - In order to increase the amount and/or rate at which hydrocarbons are produced from a zone, one or
more injection wells 300 may be provided at a distance from the production well. An injection well inserts fluid into one or more zones, e.g. to increase the pressure in the reservoir or to provide some chemical composition, and can be made in a similar manner as the production well. A typical oil or gas field can comprise one or more production wells and zero or more injection wells. - As discussed above, various devices like sliding sleeve valves, butterfly valves and ball valves of different sizes and designs, can be used to control fluid flow and for other purposes. For convenience, the term "ball operated device" is intended to include these and other devices when hydraulically operated using a drop ball, dart or similar device. All such ball operated devices comprises a seat on which the ball, dart or similar device can land.
-
Fig. 2 shows a sliding sleeve valve using apreferred embodiment 4 of the ball seat according to the present invention. A sliding sleeve valve is open when holes in thesleeves Fig. 2 comprises anouter sleeve 1 having an internal surface having two parts: an internal cylindrical surface and anannular groove 7 with a slightly larger diameter adapted to receive one ormore lugs 6 as described below. - A sliding
sleeve 2 is disposed concentrically within theouter sleeve 1. The slidingsleeve 2 is able to slide axially along the inner face ofsleeve 1, and is attached to acage 4 implementing the ball seat as described in connection withFig. 10 below. The particular valve inFig.2 is retained in a natural closed position during installation of the valve in a well, and designed to open when activated. Another embodiment may of course be retained in an open position during installation, and designed to close when activated. In either case, the elements may be connected by shear pins, which are designed to break when a predetermined force is applied to them. InFig. 2 , theball seat cage 4 is retained in theinner sleeve 2 by shear pins 3. The shear pins 3 have heads abutting an inner shoulder on the outer sleeve, and thus retain theinner sleeve 2 in theouter sleeve 1 until an activating force is applied. The activating force is applied when aball 9 lands on the seat and prevents fluid flow axially along the valve. Hydraulic pressure then builds up behind the ball, until it provides a force that it sufficient to break the shear pins 3. -
Fig. 3 shows the device ofFig. 2 where adrop ball 9 has landed on the seat. The seat is provided by flexible fingers on thecage 4 that are pressed radially inwardly bylugs 6 when the lugs abut the inner cylindrical surface of theouter sleeve 1. Infigure 3 , theinner sleeve 2 has moved relative to the outer sleeve, such that the heads of the shear pins can be pushed radially inwards. With the retaining heads out of the way, theinner sleeve 2 is allowed to slide axially within theouter sleeve 1 to the position shown infigure 4 . This first release mechanism is illustrated by heads of thepins 3 skipping past a small shoulder on the interior face of theouter sleeve 1. However, it should be understood that shear pins could provide the first release mechanism in another embodiment. - In
Fig. 4 , thecage 4 with theball 9 has pulled theinner sleeve 2 along theouter sleeve 1.Lugs 6 are at the axial position of anannular groove 7 with extended diameter. In another embodiment, thelugs 6 might at this point snap or move outwards and into thegroove 7, thereby releasing theball 9. However, in the present embodiment thelugs 6 are still prevented from extending into thegroove 7. This may be done in a number of ways, e.g. by providingstoppers 5 between the fingers and the outer sleeve, thus preventing the fingers from flexing radially outwards. This prevents thelugs 6 from extending into the groove until the inner sleeve has moved axially past thestoppers 5 as shown inFig. 5 . Alternatively, the lugs may be prevented from extending intogroove 7 by providing a breakable band around the distal ends of thefingers 41 shown onFig. 10 . Thus, the ball seat still has its smaller diameter. This allows a further build up of hydraulic pressure until the force working on the ball and seat is sufficient to activate a second release mechanism, which may be convenient to ensure a predetermined minimum force required to ensure that the device is properly operated. This second release mechanism can be shear pins, a breakable band, lugs or other release mechanisms known in the art. Thus, in the present exemplary embodiment, shear pins could be designed to break at a force that is guaranteed to pull the sliding sleeve valve entirely open. - In
Fig. 5 , thecage 4 has been released from the inner sleeve by a second release mechanism, e.g. by broken shear pins 3. Theseat 4 has moved further downstream until it has been stopped by thestoppers 5, which at this point have engaged the end ofcage 4, or more particularly thering 40 onFig. 10 . In an alternative embodiment, the cage may be prevented from moving downstream by ashoulder 8. Now, thelugs 6 may be pressed radially outwards into thegroove 7. - In
Fig. 6 , thelugs 6 are pressed radially outwards into thegroove 7 provided on the inner surface of theouter sleeve 1. This expands the ball seat to a diameter where it no longer retains theball 9. This is illustrated by theball 9 in a position downstream, i.e. to the right in the figures, of thecage 4. Theball 9 may proceed to the next apparatus, which of course can have the same diameter on the seat as the one previously disclosed. - By providing a series of valves or other devices with a ball seat according to the invention, one ball may in this way be used to operate an arbitrary number of devices.
- It should be understood that the embodiment of a sliding sleeve valve is an example only. Another application of the ball seat according to the invention could be within a butterfly valve or ball valve, in which a rotary movement rather than the linear movement disclosed previously, is used to activate the device. In order to translate the inherently linear movement of the drop ball to a rotation, a pair of helical shoulders could be provided on the inner and outer sleeves. When the seat is released by the first release mechanism, the
seat 4 moves until the helical shoulders (not shown) engage each other. Then, hydraulic pressure behind the drop ball may be allowed to build up sufficiently to guarantee a relative rotation between the sleeves. This rotation may be used to rotate a circular plate in a butterfly valve or a ball in a ball valve. The second release mechanism, illustrated above as a broken shear pin, could equally well be radially biased dogs or some other means known in the art. The purpose of the release mechanisms are simply to ensure that sufficient force is available to operate the device properly before the next step in operating a device or before the drop ball is released further downstream. -
Fig. 7 shows a generalizedouter sleeve 1. No holes are shown in the sleeve in order to illustrate that the ball seat of the invention may be used in any ball operated device, not only in a sliding sleeve valve. Theouter sleeve 1 may comprise standard threading in both ends for inclusion into a tubular string, such as a production pipe, a liner or a casing, before it is inserted into a wellbore as part of the tubular string. The features of importance for the present invention is its internal surface comprising one ormore grooves 7 to receivelugs 6 as discussed with reference tofigures 2-6 . -
Figure 8 shows an inner sleeve for a sliding valve, such as the one discussed above. The sleeve has a cylindrical main portion with radially extendingports 22. One end has anend part 21 with extended radius. The shoulder formed between the main cylinder and theend part 21 stops thesleeve 2 from moving downstream as it engages a corresponding shoulder on the inner face of the outer sleeve. This may be used to activate the first release mechanism described above if relative axial movement between thecage 4 and thesleeve 2 is allowed. -
Figure 9 shows an embodiment of apin 3 used to illustrate the first and second release mechanisms in the description referring toFigs. 2-6 . The tapered head ofpin 3 is intended to illustrate the first release mechanism. In one embodiment, the pin shown inFig. 9 is biased radially outwards. When the tapered face of the head engages a shoulder on the interior surface of the outer sleeve, thepin 3 will be pressed radially inwards against a force, e.g. a spring force. The tapered face and the bias can be adjusted to provide a first releasemechanism releasing cage 4 when a first force or pressure is achieved. Obviously, similar release mechanisms in the form of spring biased dogs or similar devices may be used to implement a release mechanism. It should also be understood that while ashear pin 3 provides a second release mechanism in the examples above, some embodiments may have no second release mechanism. Other embodiments may have a different second release mechanism, e.g. a biased pin or lug. -
Figure 10 showscage 4 formed by a number offingers 41 parallel to each other, and attached to aring 40 at one end. Thering 40 is upstream when the cage is in use, and the ball seat is provided inside the cage oppositering 40. The fingers can be inflexible, e.g. formed of a material that undergoes a plastic deformation when the fingers are bent inwards. In this case the force required to bend them back may provide part or all of the resistance required to prevent thelugs 6 from entering thegroove 7 inFig. 4 , when thecage 4 is not yet retained bystoppers 5 orshoulder 8. Alternatively, the fingers may be flexible and provide a force directed radially outwards when pressed in bylugs 6. In this case, the situation inFig. 5 would be extremely short, as flexible fingers immediately would snap outwards, moving thelugs 6 intogroove 7. Yet another alternative is to attach thefingers 41 to thering 40 by hinges, and provide the fingers with spring bias, retaining rings etc as required by the application. - There is a space between the
fingers 41, such that the ends opposite thering 40 may be pressed radially inwards to form a ball seat inside thecage 4 as described above. Radially extending lugs (not shown inFig. 10 ), such as thelugs 6 described above, is a convenient way of pressing the fingers radially inwards. The distal or downstream ends of thefingers 41 may be pressed together to form acontinuous ring 42, the ball seat being defined by the inner diameter ofring 42. A breakable band may be provided around thering 42 in order to prevent thelugs 6 from snapping intogroove 7 until a certain minimum force is available. - In
figure 10 , the space between the sections ofring 42 is shown as quite narrow for illustrative purposes. However, it should be understood that the space between the sections ofring 42 may be wider, such that the inner diameter of thecontinuous ring 42 forms a ball seat with a minimum diameter. In this case one type ofcage 4 can be used for several ball diameters between this minimum diameter and the diameter of thering 40 simply by providinglugs 6 of different lengths. - The
cage 4 is typically retained within an outer housing until released by a release mechanism. Theholes 401 inring 40 are adapted to thelower part 30 of thepin 3 shown inFig. 9 , thus indicating that thecage 4 is released from thesleeve 2 by the second release mechanism of the embodiment described above. Of course, shear pins are just one convenient release mechanism, and thecage 4 can be provided with other elements than theholes 401 to fit another release mechanism if desired. -
Fig. 11 illustrates acylindrical stopper 5 having an outer diameter slightly less than the space shown between the fingers and rings 40 and 42 inFig. 10 . The main function of thestoppers 5 is to prevent thecage 4 from travelling downstream when the valve is open. Alternatively, ashoulder 8 may be provided for the same purpose. -
Fig. 12 shows alug 6, which in the preferred embodiment is used to press afinger 41 radially inwards when disposed between e.g. the outer circumference ofring 42 and the inner surface of thesleeve 1, thus preventing thefinger 41 from moving outwards until thelug 6 reaches thegroove 7.Lugs 6 of different lengths may be used to provide ball seats of different diameters. - In another aspect, the invention comprises a method for activating an arbitrary number of drop ball operated devices in a well, comprising the steps of:
- inserting a drop ball into a tubular string comprising at least one apparatus able to be activated and to release the ball after activation,
- monitoring and controlling the pressure, and
- determine when the drop ball has activated and been released from the arbitrary number of devices.
- A suitable apparatus for this method is the one described previously, in which hydraulic pressure is the only means necessary to operate an arbitrary number of devices. The pressure, or an equivalent like the load of a circulating pump, may be monitored to determine the point in time when the drop ball (9) arrives at a ball seat, at which time an increased pressure may be detected. If desired, pump pressure may be added to the hydraulic pressure exerted by the column of fluid behind the drop ball in order to operate one or more release mechanisms for the device as described more fully above. Similarly, a drop in pressure or pump load can indicate that the drop ball has left the device, and no longer inhibits fluid flow in the string. These steps may be repeated until all devices are operated.
- Referring back to the introductory part of the present disclosure, it would be advantageous to subdivide a well into several zones, each zone having several devices. Using the apparatus disclosed previously, it can readily be seen that several groups of devices may be provided, each group being operated by one drop ball, and each group may be operated by a drop ball of different size than the drop ball for the other groups. By installing a group of devices operable by the smallest sized drop ball furthest away from the surface in a vertical or horizontal branch, this group of devices would be the first to be activated. This matches a normal production scenario, in which, for example, a waterfront from an injection well is expected to reach the most far away parts of a production well first.
- Once production from a remote or deep part of the well falls below a predetermined level, the present invention may be used to open a less remote section of the well containing a number of drop ball operated devices using one single drop ball. Obviously, this may save considerably time otherwise required for intervention.
- While the invention has been disclosed with reference to a preferred embodiment, it should be understood that a number of modifications may be done without departing from the scope defined by the accompanying claims.
Claims (11)
- A drop ball activated apparatus comprising an inner sleeve (2) and an outer sleeve (1), the inner sleeve (2) retaining, with the help of shear pins (3), a ball seat (4) operated by a drop ball (9) and being concentrically and axially slidably disposed within the outer sleeve (1) having a first internal cylindrical surface, wherein the ball seat (4) comprises a plurality of fingers (41) attached to a ring (40) at one end, where a radially extending lug (6) is adapted for pressing each finger (41), at its other or distal end, radially inwards, which in a first position abuts the first internal cylindrical surface, the lugs (6) of fingers (41) thereby defining a first ball seat diameter less than the diameter of the drop ball (9), wherein the outer sleeve (1) comprises at least one groove (7) in its internal surface, and the lugs (6) are adapted to be moved or received into said at least one groove (7) in a second position, the lugs (6) of fingers (41) thereby defining a second ball seat diameter at least as large as the diameter of the drop ball (9), characterized in that the inner sleeve (2) with the retained ball seat (4) is retained in the outer sleeve (1) by a first release mechanism adapted to release the ball seat (4) and the inner sleeve (2) from the outer sleeve (1) when a first predetermined hydraulic pressure works or acts on the drop ball (9), and then the ball seat (4) and the inner sleeve (2) are pulled or slid along the outer sleeve (1) while applying the first predetermined hydraulic pressure, and wherein a second release mechanism is adapted to release the ball seat (4) from the inner sleeve (2) when a second predetermined hydraulic pressure works or acts on the drop ball (9), and thereafter the ball seat (4) is moved to the second position and is radially expanded to its second ball seat diameter thus allowing the drop ball (9) to pass therethrough.
- Apparatus according to claim 1, wherein each finger (41) of the ball seat (4) is flexible and provides a radial outward bias on the lug (6).
- Apparatus according to claim 1, wherein the groove (7) is an annular recess having an inner diameter being larger than the inner diameter of the internal cylindrical surface.
- Apparatus according to claim 1, wherein the second release mechanism is selected from a group comprising: a shear pin, a radially biased pin/lug and a breakable retaining band.
- Apparatus according to claim 1, wherein the first release mechanism is provided by a head of at least one shear pin (3) or by at least one shear pin (3).
- Apparatus according to claim 1, wherein a helical shoulder is provided on the exterior of the inner sleeve connected to the ball seat, and a matching helical shoulder is provided on the internal surface of the outer sleeve, the shoulders engaging each other upon a release of the ball seat, whereby an axial movement of the ball seat is transformed to a rotation.
- Method for activating an arbitrary number of drop ball operated or activated apparatuses in a well, where only one drop ball is to be used to activate an arbitrary number of drop ball activated apparatuses, the method being characterized by the steps of:- providing the arbitrary number of drop ball activated apparatuses in the well,- inserting a drop ball (9) into the well,- monitoring and controlling the pressure, and- determining when the drop ball (9) has activated and been released from the arbitrary number of drop ball activated apparatuses,wherein the drop ball activated apparatus comprises an inner sleeve (2) and an outer sleeve (1), the inner sleeve (2) retaining, with the help of shear pins (3), a ball seat (4) operated by a drop ball (9) and being concentrically and axially slidably disposed within the outer sleeve (1) having a first internal cylindrical surface,
wherein the ball seat (4) comprises a plurality of fingers (41) attached to a ring (40) at one end, where a radially extending lug (6) is adapted for pressing each finger (41), at its other or distal end, radially inwards, which in a first position abuts the first internal cylindrical surface, the lugs (6) of fingers (41) thereby defining a first ball seat diameter less than the diameter of the drop ball (9),
wherein the outer sleeve (1) comprises at least one groove (7) in its internal surface, and the lugs (6) are adapted to be moved or received into said at least one groove (7) in a second position, the lugs (6) of fingers (41) thereby defining a second ball seat diameter at least as large as the diameter of the drop ball (9),
wherein the inner sleeve (2) with the retained ball seat (4) is retained in the outer sleeve (1) by a first release mechanism adapted to release the ball seat (4) and the inner sleeve (2) from the outer sleeve (1) when a first predetermined hydraulic pressure works or acts on the drop ball (9), and then the ball seat (4) and the inner sleeve (2) are pulled or slid along the outer sleeve (1) while applying the first predetermined hydraulic pressure, and
wherein a second release mechanism releases the ball seat (4) from the inner sleeve (2) when a second predetermined hydraulic pressure works or acts on the drop ball (9), and thereafter the ball seat (4) is moved to the second position and is radially expanded to its second ball seat diameter thus allowing the drop ball (9) to pass therethrough and proceed to the next ball operated apparatus. - Method according to claim 7, wherein the step of monitoring and controlling the pressure further comprises:- determining the point in time when the drop ball (9) lands on or arrives at a ball seat (4),- monitoring and/or controlling the pressure to operate and/or activate the apparatus,- determining the point in time when the drop ball (9) departs or proceeds from the ball seat (4) down or further to the next ball operated apparatus, and- determining the point in time when the arbitrary number of apparatuses have been activated by the drop ball (9).
- Method according to claim 7, further comprising a step of dividing the arbitrary number of drop ball activated apparatuses into a plurality of groups, each group thereof being operable by one drop ball (9), where the diameter of the drop ball (9) is unique for each group.
- Method according to claim 9, further comprising a step of providing each group of drop ball activated apparatuses in a separate zone of the well.
- Method according to claim 10, further comprising a step of ordering the zones by size of the drop balls (9), such that a group of drop ball activated apparatuses operated by a smaller sized drop ball is more remote from the surface than a group of drop ball activated apparatuses operated by a larger sized drop ball.
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
NO20100211A NO338704B1 (en) | 2010-02-11 | 2010-02-11 | Ball-actuated device and method for activating a number of such devices |
Publications (3)
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EP2360347A2 EP2360347A2 (en) | 2011-08-24 |
EP2360347A3 EP2360347A3 (en) | 2014-02-26 |
EP2360347B1 true EP2360347B1 (en) | 2018-03-28 |
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EP11154062.1A Not-in-force EP2360347B1 (en) | 2010-02-11 | 2011-02-10 | Expandable ball seat |
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EP (1) | EP2360347B1 (en) |
CA (1) | CA2731511C (en) |
NO (2) | NO338704B1 (en) |
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CA2785713C (en) | 2010-01-04 | 2018-02-27 | Packers Plus Energy Services Inc. | Wellbore treatment apparatus and method |
WO2012037661A1 (en) * | 2010-09-23 | 2012-03-29 | Packers Plus Energy Services Inc. | Apparatus and method for fluid treatment of a well |
EP2640930A1 (en) | 2010-11-19 | 2013-09-25 | Packers Plus Energy Services Inc. | Kobe sub, wellbore tubing string apparatus and method |
US8770299B2 (en) * | 2011-04-19 | 2014-07-08 | Baker Hughes Incorporated | Tubular actuating system and method |
RU2629027C2 (en) | 2012-07-31 | 2017-08-24 | ВЕЗЕРФОРД ТЕКНОЛОДЖИ ХОЛДИНГЗ, ЭлЭлСи | Downhole device and method |
NO340047B1 (en) | 2012-09-21 | 2017-03-06 | I Tec As | Procedure, valve and valve system for completion, stimulation and subsequent restimulation of wells for hydrocarbon production |
AU2013395452B2 (en) * | 2013-09-20 | 2017-10-12 | Flowpro Well Technology | System and method for controlling flow in a pipe using a finger valve |
WO2016145540A1 (en) * | 2015-03-19 | 2016-09-22 | Packers Plus Energy Services Inc. | Sliding sleeve sub and method and apparatus for wellbore fluid treatment |
US10533397B2 (en) * | 2017-10-04 | 2020-01-14 | Baker Hughes, A Ge Company, Llc | Ball drop two stage valve |
CN111425174B (en) * | 2019-01-09 | 2022-02-01 | 中国石油天然气股份有限公司 | Thermal concentric layered electric ignition process pipe column |
US11591873B2 (en) | 2021-07-23 | 2023-02-28 | Halliburton Energy Services, Inc. | High-expansion well sealing using seal seat extender |
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Publication number | Priority date | Publication date | Assignee | Title |
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US2454839A (en) * | 1945-03-05 | 1948-11-30 | Sperry Sun Well Surveying Co | Retrieving apparatus |
US4862966A (en) * | 1988-05-16 | 1989-09-05 | Lindsey Completion Systems, Inc. | Liner hanger with collapsible ball valve seat |
US7021389B2 (en) * | 2003-02-24 | 2006-04-04 | Bj Services Company | Bi-directional ball seat system and method |
US7416029B2 (en) * | 2003-04-01 | 2008-08-26 | Specialised Petroleum Services Group Limited | Downhole tool |
US7322417B2 (en) * | 2004-12-14 | 2008-01-29 | Schlumberger Technology Corporation | Technique and apparatus for completing multiple zones |
US20090308588A1 (en) * | 2008-06-16 | 2009-12-17 | Halliburton Energy Services, Inc. | Method and Apparatus for Exposing a Servicing Apparatus to Multiple Formation Zones |
-
2010
- 2010-02-11 NO NO20100211A patent/NO338704B1/en unknown
-
2011
- 2011-02-10 EP EP11154062.1A patent/EP2360347B1/en not_active Not-in-force
- 2011-02-10 CA CA2731511A patent/CA2731511C/en active Active
- 2011-02-10 NO NO11154062A patent/NO2360347T3/no unknown
- 2011-02-12 SA SA111320192A patent/SA111320192B1/en unknown
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EP2360347A2 (en) | 2011-08-24 |
NO338704B1 (en) | 2016-10-03 |
SA111320192B1 (en) | 2015-04-23 |
NO2360347T3 (en) | 2018-08-25 |
CA2731511C (en) | 2018-02-20 |
NO20100211A1 (en) | 2011-08-12 |
CA2731511A1 (en) | 2011-08-11 |
EP2360347A3 (en) | 2014-02-26 |
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