EP2360347A2 - Siège extensible pour une bille - Google Patents

Siège extensible pour une bille Download PDF

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Publication number
EP2360347A2
EP2360347A2 EP11154062A EP11154062A EP2360347A2 EP 2360347 A2 EP2360347 A2 EP 2360347A2 EP 11154062 A EP11154062 A EP 11154062A EP 11154062 A EP11154062 A EP 11154062A EP 2360347 A2 EP2360347 A2 EP 2360347A2
Authority
EP
European Patent Office
Prior art keywords
ball
drop
ball seat
devices
diameter
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.)
Granted
Application number
EP11154062A
Other languages
German (de)
English (en)
Other versions
EP2360347A3 (fr
EP2360347B1 (fr
Inventor
Kristoffer Braekke
Geir Lunde
Roger Antonsen
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
I-TEC AS
I Tec AS
Original Assignee
I-TEC AS
I Tec AS
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by I-TEC AS, I Tec AS filed Critical I-TEC AS
Publication of EP2360347A2 publication Critical patent/EP2360347A2/fr
Publication of EP2360347A3 publication Critical patent/EP2360347A3/fr
Application granted granted Critical
Publication of EP2360347B1 publication Critical patent/EP2360347B1/fr
Not-in-force legal-status Critical Current
Anticipated expiration legal-status Critical

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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.
  • 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.
EP11154062.1A 2010-02-11 2011-02-10 Siège extensible pour une bille Not-in-force EP2360347B1 (fr)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
NO20100211A NO338704B1 (no) 2010-02-11 2010-02-11 Fallkuleaktivert anordning og fremgangsmåte for aktivering av et antall av slike anordninger

Publications (3)

Publication Number Publication Date
EP2360347A2 true EP2360347A2 (fr) 2011-08-24
EP2360347A3 EP2360347A3 (fr) 2014-02-26
EP2360347B1 EP2360347B1 (fr) 2018-03-28

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Family Applications (1)

Application Number Title Priority Date Filing Date
EP11154062.1A Not-in-force EP2360347B1 (fr) 2010-02-11 2011-02-10 Siège extensible pour une bille

Country Status (4)

Country Link
EP (1) EP2360347B1 (fr)
CA (1) CA2731511C (fr)
NO (2) NO338704B1 (fr)
SA (1) SA111320192B1 (fr)

Cited By (8)

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WO2012037661A1 (fr) * 2010-09-23 2012-03-29 Packers Plus Energy Services Inc. Appareil et procédé de traitement de fluide d'un puits
GB2506265A (en) * 2012-07-31 2014-03-26 Petrowell Ltd Downhole Apparatus And Method
WO2015039696A1 (fr) * 2013-09-20 2015-03-26 Flowpro Well Technology Système et procédé de commande d'écoulement dans une tige à l'aide d'un purgeur de chambre
US9140097B2 (en) 2010-01-04 2015-09-22 Packers Plus Energy Services Inc. Wellbore treatment apparatus and method
EP2699760A4 (fr) * 2011-04-19 2016-05-18 Baker Hughes Inc Système et procédé d'actionnement pour tubulaire
US9366109B2 (en) 2010-11-19 2016-06-14 Packers Plus Energy Services Inc. Kobe sub, wellbore tubing string apparatus and method
WO2019070359A1 (fr) * 2017-10-04 2019-04-11 Baker Hughes, A Ge Company, Llc Vanne à deux étages à chute de bille
CN111425174A (zh) * 2019-01-09 2020-07-17 中国石油天然气股份有限公司 热力式同心分层电点火工艺管柱

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US11591873B2 (en) 2021-07-23 2023-02-28 Halliburton Energy Services, Inc. High-expansion well sealing using seal seat extender

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Cited By (18)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9970274B2 (en) 2010-01-04 2018-05-15 Packers Plus Energy Services Inc. Wellbore treatment apparatus and method
US9140097B2 (en) 2010-01-04 2015-09-22 Packers Plus Energy Services Inc. Wellbore treatment apparatus and method
WO2012037661A1 (fr) * 2010-09-23 2012-03-29 Packers Plus Energy Services Inc. Appareil et procédé de traitement de fluide d'un puits
US9797221B2 (en) 2010-09-23 2017-10-24 Packers Plus Energy Services Inc. Apparatus and method for fluid treatment of a well
US9366109B2 (en) 2010-11-19 2016-06-14 Packers Plus Energy Services Inc. Kobe sub, wellbore tubing string apparatus and method
EP2699760A4 (fr) * 2011-04-19 2016-05-18 Baker Hughes Inc Système et procédé d'actionnement pour tubulaire
US10077633B2 (en) 2012-07-31 2018-09-18 Petrowell Limited Downhole apparatus and method
US10018015B2 (en) 2012-07-31 2018-07-10 Weatherford Technology Holdings, Llc Downhole apparatus and method
GB2506265A (en) * 2012-07-31 2014-03-26 Petrowell Ltd Downhole Apparatus And Method
AU2013395452B2 (en) * 2013-09-20 2017-10-12 Flowpro Well Technology System and method for controlling flow in a pipe using a finger valve
CN105164365A (zh) * 2013-09-20 2015-12-16 弗洛泊威尔技术公司 使用指状阀来控制管道内流动的系统和方法
WO2015039696A1 (fr) * 2013-09-20 2015-03-26 Flowpro Well Technology Système et procédé de commande d'écoulement dans une tige à l'aide d'un purgeur de chambre
EA029960B1 (ru) * 2013-09-20 2018-06-29 Флоупро Велл Текнолоджи Ас Распределительный клапан и способ управления потоком в трубе с помощью такого клапана
WO2019070359A1 (fr) * 2017-10-04 2019-04-11 Baker Hughes, A Ge Company, Llc Vanne à deux étages à chute de bille
US10533397B2 (en) 2017-10-04 2020-01-14 Baker Hughes, A Ge Company, Llc Ball drop two stage valve
GB2581695A (en) * 2017-10-04 2020-08-26 Baker Hughes Incoporated Ball drop two stage valve
GB2581695B (en) * 2017-10-04 2022-04-20 Baker Hughes Incoporated Ball drop two stage valve
CN111425174A (zh) * 2019-01-09 2020-07-17 中国石油天然气股份有限公司 热力式同心分层电点火工艺管柱

Also Published As

Publication number Publication date
NO338704B1 (no) 2016-10-03
SA111320192B1 (ar) 2015-04-23
EP2360347A3 (fr) 2014-02-26
CA2731511C (fr) 2018-02-20
CA2731511A1 (fr) 2011-08-11
NO20100211A1 (no) 2011-08-12
NO2360347T3 (fr) 2018-08-25
EP2360347B1 (fr) 2018-03-28

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