WO1998003766A1 - Clapet de fond de puits anti-retour et a deux voies - Google Patents

Clapet de fond de puits anti-retour et a deux voies Download PDF

Info

Publication number
WO1998003766A1
WO1998003766A1 PCT/CA1997/000520 CA9700520W WO9803766A1 WO 1998003766 A1 WO1998003766 A1 WO 1998003766A1 CA 9700520 W CA9700520 W CA 9700520W WO 9803766 A1 WO9803766 A1 WO 9803766A1
Authority
WO
WIPO (PCT)
Prior art keywords
valve
downflow
ball
orifice
closed state
Prior art date
Application number
PCT/CA1997/000520
Other languages
English (en)
Inventor
Rick Picher
Charles Huard
Original Assignee
Rick Picher
Charles Huard
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 Rick Picher, Charles Huard filed Critical Rick Picher
Priority to AU35349/97A priority Critical patent/AU3534997A/en
Publication of WO1998003766A1 publication Critical patent/WO1998003766A1/fr

Links

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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
    • E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained

Definitions

  • the present invention relates to a check valve device and in particular to such a device for downhole use in oil and gas wells.
  • a typical producing oil and gas well may comprise several hundreds of meters of casing and tubing.
  • a pump connected to the bottom of the tubing permits artificial lift of well fluids which may consist of oil, water, gas or mixtures thereof as well as abrasive solids such as sand, gyp, or scale.
  • a progressing cavity or rotary vane pump is employed to impart this artificial lift.
  • the pump's rotating drive element (rotor) is connected to a rod string which extends upward through the tubing and terminates at a surface drive head.
  • the motor driven surface drive head provides rotational energy which is transmitted downward through the rod string to the pump's drive element, creating the pumping action required to move well fluids to the surface where they can be collected.
  • Rapid flow of fluid back down the tubing string may create several undesirable conditions.
  • the rapid decompression within the well has a damaging effect on the elastomers used in the manufacture of the aforementioned pump types. Gases that have permeated the elastomer expand rapidly causing blistering and swelling, which leads to dramatically reduced run lifes.
  • the most critical concern associated with this rapid flow reversal is the significant safety hazard for personnel on the surface.
  • the rapid reversal of the fluid travelling down the tubing string enters the pump from the discharge end, transforming it into a hydraulic motor. This rotational action is then transmitted back up the rod string to the surface drive.
  • the velocity of this reverse rotation may cause surface components such as electric motor fans and drive sheaves to exceed maximum rim velocities. If that happens, the result is an explosive disintegration of the component sending shrapnel flying hundreds of feet.
  • Existing anti-reverse surface braking devices offered to date have not been reliable in preventing these accidents.
  • Reverse flow may be prevented by a check valve located in the tubing string.
  • a check valve located in the tubing string.
  • one-way check valves that merely prevent reverse flow are not entirely desirable. It is sometimes necessary to induce downward flow through the tubing to flush restrictive particles, such as sand, gyp or scale, that have built up at the suction end of the pump.
  • a conventional check valve while eliminating reverse flow concerns, would not permit this flushing requirement. It would also hamper the insertion of the rotor within the stator due to pressure buildup from fluid being trapped that would otherwise be displaced.
  • the rig must then send a special tool (overshot) down the tubing to latch onto the dart to extract it from the PSN.
  • the rod string is then rerun into the well and landed. This operation is expensive due to rig costs and lost production the expense is increased by limited availability of rigs during peak seasons and during spring breakup.
  • the invention is a check valve for use in the production tubing of a well bore, comprising: (a) a valve body having a lower opening and an upper opening;
  • valve seat member having an upflow orifice and a downflow orifice
  • an upflow valve associated with the upflow orifice and having an open state allowing fluid flow through the upflow orifice and a closed state preventing said fluid flow;
  • biasing means associated with the downflow valve means for maintaining the downflow valve means in the closed state which biasing means may be overcome by artificially induced fluid pressure, switching the downflow valve to the open state.
  • the upflow valve comprises a first valve ball and a first ball cage engaging the valve seat member around the upflow orifice for retaining the first valve ball and the downflow valve comprises a second valve ball and a second ball cage engaging the valve seat member around the downflow orifice.
  • the biasing means tends to maintain the second valve ball against the second valve seat, i.e. in the closed position.
  • the biasing means comprises a coil spring and the valve further comprises adjusting means for varying the force exerted by the spring on the second valve ball.
  • the invention is a check valve for downhole use in the production tubing of a well bore comprising:
  • valve body having a lower opening and an upper opening, the valve body defining a first flow passage and a second flow passage;
  • an upflow valve associated with the first flow passage and having an open state allowing fluid flow through the first flow passage and a closed state preventing said fluid flow;
  • biasing means associated with the downflow valve for maintaining the downflow valve in the first closed state, which biasing means may be overcome by fluid pressure, switching the downflow valve to the open state or the second closed state.
  • the downflow valve comprises a downflow valve seat having a first downflow orifice, a tubular downflow valve body having an upper end and a lower end wherein the upper end engages the downflow valve seat around the first downflow orifice, a valve ball disposed within the downflow valve body, and a second valve seat having a second downflow orifice associated with the lower end of the downflow valve body whereby the first closed state is created by the seating of the valve ball against the downflow valve seat and the second closed state is created by the seating of the valve ball against the second valve seat.
  • the invention is a check valve for downhole use in the production tubing of a well bore comprising:
  • valve body having a lower opening and an upper opening, the valve body defining a first flow passage, a second flow passage and a bypass opening;
  • biasing means associated with the downflow valve for maintaining the downflow valve in the first closed state
  • a fluid pressure differential created by higher pressure in the upper opening than in the lower opening causes the downflow valve to switch from the first closed state to the open state
  • a higher fluid pressure differential causes the downflow valve to switch from the open state to the second closed state
  • an even higher fluid pressure differential activates the disengagement means causing the bypass cover to disengage from the valve body thereby uncovering the bypass opening
  • valve body is cylindrical and hollow
  • bypass cover is cylindrical and hollow and the bypass cover slidingly engages the valve body in a concentric manner.
  • the disengagement means comprises a shear pin fixing the bypass cover in a position closing the bypass opening.
  • Figure 1 is a pictorial view of the invention located in the tubing string of a producing oil and gas well.
  • Figure 2 is a cross-sectional view of a preferred embodiment of the invention.
  • Figure 3 is a cross-section along line 3-3 in Figure 2.
  • Figure 4 is a cross-section along line 4-4 in Figure 2.
  • Figure 5 is a cross-section along line 5-5 in Figure 2.
  • Figure 6 is the cross-sectional view of Figure 2 demonstrating upward flow of fluid through a preferred embodiment of the invention.
  • Figure 7 is the cross-sectional view of Figure 2 demonstrating a preferred embodiment of the invention preventing downward flow of fluid.
  • Figure 8 is the cross-sectional view of Figure 2 demonstrating use of a preferred embodiment of the invention during a flushing operation.
  • Figure 9 is the cross-sectional view of Figure 2 demonstrating use of a preferred embodiment of the invention during a pressure testing operation.
  • Figure 10 is the cross-sectional view of Figure 2 demonstrating a preferred embodiment of the invention after a blow-out operation.
  • the invention is a device generally comprised of a tubular, cylindrical body containing two valve elements oriented in opposing directions.
  • the device (10) is part of the tubing string (12), below the position of the pump (14), which is shown to be a rotating progressing cavity pump.
  • the tubing string (12), including the pump (14) and device (10), are enclosed in the well casing (16).
  • the rotating progressing cavity pump (14) comprises a rotor (18) and a stator (20).
  • the rotor (18) is rotationally driven by the rod string (22) which extends upward through the tubing (12) up to the wellhead (24).
  • the rod string (22) is driven by a drive element (not shown) which is typically located above the flowtee (26).
  • Flowlines (28) extend from the flowtee (26) in a conventional fashion.
  • a pressure gauge (30) is provided to monitor pressure of the well fluid within tubing string (12).
  • the construction of a preferred embodiment of the device (10) is shown in cross-sectional detail in Figure 2.
  • the device (10) is comprised of the main housing (34) and the upper housing (36), both of which are cylindrical and tubular.
  • the main and upper housings (34, 36) are in sealed connection to each other by means of conventional O-ring gaskets (38) and shear pins (40).
  • the upper portion of the main housing (34) which overlaps the upper housing (36) defines bypass openings (42).
  • the function of the upper housing (36), shear pins (40) and bypass openings (42) will be described in further detail below in conjunction with Figure 10.
  • valve seat plate (48) Integral to both the upflow valve (44) and the downflow valve (46) is a valve seat plate (48) which is a circular plate defining two orifices: the upflow orifice (50) and the downflow orifice (52). Fluid passing through the main housing (34) must pass through either of these two orifices (50, 52).
  • the valve seat (48) rests on shoulder (56) formed in the interior of the main housing (34) and is shrink-fit into place in a conventional fashion.
  • the upflow valve (44) comprises a ball (58) and ball cage (60) which retains the ball (58) within it but permits the ball (58) to travel up and down, on and off the valve seat (48).
  • the ball cage (60) is cylindrical, tubular, open ended and forms flow openings (62) along its length.
  • the upper end of the ball cage (60) abuts the tag plate (64) which is a disc-like element fitting the interior of the main housing (34) having two or more radial arms (66). As shown in Figure 3, the preferred embodiment has four radial arms (66). One of the radial arms (66) extends across the upper opening of the ball cage (60) to retain the ball (58) within the ball cage (60).
  • the tag plate (64) rests on shoulder (68) formed in the interior of the main housing (34) and is shrink-fit into place.
  • the lower end of the ball cage (60) abuts the valve seat (48) around the upflow orifice (50).
  • the valve seat (48) has a circular concave surface which surrounds the upflow orifice (50) and which mates with the ball (58) to seal off the upflow orifice (50).
  • the downflow valve (46) comprises a ball (70), downflow valve housing
  • the downflow valve housing (72) is tubular and open at both ends.
  • the top end of the downflow valve housing (72) abuts against the lower side of the valve seat plate (48), surrounding the downflow orifice (52). It is also attached to the interior of the main housing (34) in an offset concentric fashion, as shown in Figure 5.
  • the biasing means (74) comprises ball retainer (76), coil spring (78), adjusting screw (80), end plate (82) and lock nut (84).
  • the ball retainer (76) attaches to the ball (70) and the upper end of coil spring (78).
  • the lower end of coil spring (78) is attached to the upper end of the adjusting screw (80) which is threaded to engage a threaded bore through the end plate (82).
  • the force which the coil spring (78) imparts to the ball (70) may be adjusted by raising or lowering the adjusting screw (80) and locking it into position with the lock nut (84).
  • the end plate (82) has flow passages (86) to allow fluid flow through the downflow valve housing (72).
  • operation of the pump (14) results in fluid flowing upward through the device (10).
  • the pressure differential between the outlet (88) and the inlet (90) lifts ball (58) off of the valve seat (48), opening the upflow valve (44). Fluid may then flow in the inlet (90), up through the upflow orifice (50), through the ball cage flow passages (62), through the tag plate (64) and finally up the outlet (88).
  • the downflow valve (46) is maintained in a closed position with the downflow ball (70) biased against the downflow orifice (52) by the biasing means (74). Also, the pressure differential created by the pump (14) tends to keep the downflow valve (46) closed.
  • the device (10) permits downward flow of fluid if the pressure differential exceeds the biasing force of the coil spring (78).
  • Such pressure differential may be intentionally applied to fluid with the tubing string (12) to flush the tubing string (12), including the pump (14) and the device (10), of sedimentary deposits which may inhibit fluid flow.
  • insertion or reinsertion of the rod string (22) and rotor (18) creates such pressure in the tubing string above the device (10). Therefore, the device (10) permits such insertion without first draining the fluid in the tubing string (12).
  • Figure 9 demonstrates the device (10) during a pressure testing operation.
  • the fluid in the tubing string is pressurized to an extent that the pressure differential across the downflow valve (46) completely compresses the coil spring (78).
  • the downflow ball (70) rests against the valve seat (92) formed within the downflow valve housing (72) at its lower end to seal off the downflow valve (46).
  • the tubing string (12) is closed off except for any leaks that may exist in the tubing string (12).
  • the spring (78) maintains the downflow valve (46) in the closed state against pressures of up to approximately 250 to 500 p.s.i. over static fluid head pressure.
  • the spring (78) should also be compressed entirely at pressures of approximately 1 ,500 p.s.i. over static fluid head pressure so that pressure testing can be performed. Intermediate pressures of between approximately 750 p.s.i. and 1,500 p.s.i. over static fluid head pressure will then partially compress the spring (78), allowing the flushing operation described above.
  • the range of pressures where the downflow valve (46) transitions from closed to open to closed again will vary according to the particular characteristics of the well and the formation being tapped.
  • the spring (70) must be chosen and adjusted with the adjusting screw (80) accordingly.
  • the number and size of the shear pins (40) is selected such that they will give way at pressures exceeding the pressure testing capacity of the device (10).
  • the shear pins (40) may be selected to give way at approximately 3,000 p.s.i.
  • Typical commercially available shear pins will break at approximately 750 to 900 p.s.i. each. Therefore, the illustrated preferred embodiment has 4 shear pins (40).

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Check Valves (AREA)

Abstract

Cette invention concerne un clapet anti-retour de fond de puits qui est utilisé dans le tubage de production d'un puits de gaz ou de pétrole. Ce clapet possède un corps de clapet tubulaire, lequel comprend un plateau de siège de clapet qui possède une surface supérieure, une surface inférieure, un orifice de débit ascendant ainsi qu'un orifice de débit descendant. Le corps de clapet comprend également une première bille de clapet, laquelle est logée dans une première cage de bille qui repose sur la surface supérieure de la plaque de siège de clapet de manière à fermer l'orifice de débit ascendant. Le corps de clapet comprend en outre une seconde bille de clapet, laquelle est logée dans une enceinte de clapet pour débit descendant qui repose sur la surface inférieure de la plaque de siège de clapet de manière à fermer le l'orifice de débit descendant. La seconde bille de clapet est poussée en position de fermeture par un ressort hélicoïdal qui est monté à l'intérieur de l'enceinte de clapet pour débit descendant. La pression du fluide s'exerçant sous le clapet anti-retour va déloger la première bille de clapet de manière à assurer le débit ascendant du fluide à travers ledit clapet anti-retour et le tubage de production. La pression du fluide s'exerçant sur le clapet anti-retour va faire reposer la première bille sur le siège et assurer la fermeture, tandis que la seconde bille va rester en place grâce au ressort hélicoïdal. Cette position permet d'empêcher tout débit descendant du fluide. Une pression supplémentaire peut être intentionnellement exercée de manière à comprimer partiellement le ressort hélicoïdal et à déloger la seconde bille de clapet, ce qui permet d'assurer le débit descendant du fluide à travers le clapet anti-retour et le tubage de production. Lorsque l'on exerce une pression encore plus importante, le ressort hélicoïdal est complètement comprimé et la seconde bille de clapet va reposer sur un second siège de clapet opposé à la plaque de siège de clapet, ce qui permet d'empêcher tout débit descendant du fluide dans cette position.
PCT/CA1997/000520 1996-07-19 1997-07-17 Clapet de fond de puits anti-retour et a deux voies WO1998003766A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU35349/97A AU3534997A (en) 1996-07-19 1997-07-17 Downhole two-way check valve

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
CA 2181671 CA2181671A1 (fr) 1996-07-19 1996-07-19 Clapet de retenue a deux voies pour forage
CA2,181,671 1996-07-19

Publications (1)

Publication Number Publication Date
WO1998003766A1 true WO1998003766A1 (fr) 1998-01-29

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PCT/CA1997/000520 WO1998003766A1 (fr) 1996-07-19 1997-07-17 Clapet de fond de puits anti-retour et a deux voies

Country Status (3)

Country Link
AU (1) AU3534997A (fr)
CA (1) CA2181671A1 (fr)
WO (1) WO1998003766A1 (fr)

Cited By (21)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2009020883A1 (fr) * 2007-08-03 2009-02-12 Zupanick Joseph A Système de commande d'écoulement comportant un dispositif d'isolation pour empêcher l'interférence de gaz pendant les opérations de retrait de liquide de fond
EP2088279A2 (fr) 2008-02-07 2009-08-12 Pump Tools Limited Outil de complétion de fond de puits
CN101592024A (zh) * 2009-07-15 2009-12-02 中国海洋石油总公司 油井密闭生产空间用放气系统
WO2010144580A3 (fr) * 2009-06-10 2011-04-07 Baker Hughes Incorporated Dispositif de sièges et procédé
RU2449192C1 (ru) * 2010-11-29 2012-04-27 Общество с ограниченной ответственностью "Русская электротехническая компания" ("РУСЭЛКОМ") Клапан обратный реверсивный
RU2455546C1 (ru) * 2010-12-30 2012-07-10 Общество с ограниченной ответственностью "Конкистадор" Обратный клапан
US8276673B2 (en) 2008-03-13 2012-10-02 Pine Tree Gas, Llc Gas lift system
EP2535507A1 (fr) * 2007-04-04 2012-12-19 Weatherford/Lamb Inc. Soupapes de déploiement de fond de trou
CN103080470A (zh) * 2010-07-01 2013-05-01 史密斯运输股份有限公司 用于以减小的泵送压力水力压裂的多球-球座
CN103415732A (zh) * 2011-03-07 2013-11-27 株式会社三国 将止回阀安装于在内部具备流体通路的外壳的安装构件
CN104420849A (zh) * 2013-09-04 2015-03-18 中国石油天然气股份有限公司 一种稠油水平井井下套压放气阀调压方法及装置
US9181778B2 (en) 2010-04-23 2015-11-10 Smith International, Inc. Multiple ball-ball seat for hydraulic fracturing with reduced pumping pressure
US20170102085A1 (en) * 2015-10-08 2017-04-13 National Coupling Company, Inc. Subsea BOP Control System With Dual- Action Check Valve
CN106703750A (zh) * 2015-11-12 2017-05-24 中海石油深海开发有限公司 深水套管高压弹簧式泄压阀
US10184317B2 (en) 2015-10-12 2019-01-22 Baker Hughes, A Ge Company, Llc Check valve with valve member biased by connectors extending from a valve seat for operation of a subterranean tool
US10214991B2 (en) 2015-08-13 2019-02-26 Packers Plus Energy Services Inc. Inflow control device for wellbore operations
RU191416U1 (ru) * 2019-04-19 2019-08-05 Акционерное общество "Новомет-Пермь" Скважинное клапанное устройство
CN110762258A (zh) * 2019-10-31 2020-02-07 南通龙源电站阀门有限公司 超高温高压的大口径止回阀
US10975659B2 (en) * 2013-04-01 2021-04-13 Zenith Oilfield Technology Limited Automatic blanking completion tool
RU204086U1 (ru) * 2020-12-29 2021-05-05 Акционерное общество "Новомет-Пермь" Скважинное клапанное устройство
RU2821625C1 (ru) * 2023-03-06 2024-06-25 Ирек Мехаметнаилович Гильмуллин Скважинное клапанное устройство автоматического переключения потока

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US5320181A (en) * 1992-09-28 1994-06-14 Wellheads & Safety Control, Inc. Combination check valve & back pressure valve

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US3468337A (en) * 1965-12-06 1969-09-23 Borg Warner Flow control valve assembly
US4810172A (en) * 1987-10-01 1989-03-07 Isco, Inc. Gas-operated positive displacement pump
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Cited By (50)

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US8534362B2 (en) 2007-04-04 2013-09-17 Weatherford/Lamb, Inc. Downhole deployment valves
US8789603B2 (en) 2007-04-04 2014-07-29 Weatherford/Lamb, Inc. Downhole deployment valves
US8544549B2 (en) 2007-04-04 2013-10-01 Weatherford/Lamb, Inc. Downhole deployment valves
EP2535507A1 (fr) * 2007-04-04 2012-12-19 Weatherford/Lamb Inc. Soupapes de déploiement de fond de trou
US8522878B2 (en) 2007-04-04 2013-09-03 Weatherford/Lamb, Inc. Downhole deployment valves
US7753115B2 (en) 2007-08-03 2010-07-13 Pine Tree Gas, Llc Flow control system having an isolation device for preventing gas interference during downhole liquid removal operations
US7789157B2 (en) 2007-08-03 2010-09-07 Pine Tree Gas, Llc System and method for controlling liquid removal operations in a gas-producing well
US8528648B2 (en) 2007-08-03 2013-09-10 Pine Tree Gas, Llc Flow control system for removing liquid from a well
US7971648B2 (en) 2007-08-03 2011-07-05 Pine Tree Gas, Llc Flow control system utilizing an isolation device positioned uphole of a liquid removal device
US7971649B2 (en) 2007-08-03 2011-07-05 Pine Tree Gas, Llc Flow control system having an isolation device for preventing gas interference during downhole liquid removal operations
US7789158B2 (en) 2007-08-03 2010-09-07 Pine Tree Gas, Llc Flow control system having a downhole check valve selectively operable from a surface of a well
US8006767B2 (en) 2007-08-03 2011-08-30 Pine Tree Gas, Llc Flow control system having a downhole rotatable valve
WO2009020883A1 (fr) * 2007-08-03 2009-02-12 Zupanick Joseph A Système de commande d'écoulement comportant un dispositif d'isolation pour empêcher l'interférence de gaz pendant les opérations de retrait de liquide de fond
US8302694B2 (en) 2007-08-03 2012-11-06 Pine Tree Gas, Llc Flow control system having an isolation device for preventing gas interference during downhole liquid removal operations
US8162065B2 (en) 2007-08-03 2012-04-24 Pine Tree Gas, Llc System and method for controlling liquid removal operations in a gas-producing well
US8104540B2 (en) 2008-02-07 2012-01-31 Pump Tools Limited Completion tool
EP2088279A2 (fr) 2008-02-07 2009-08-12 Pump Tools Limited Outil de complétion de fond de puits
EP2088279A3 (fr) * 2008-02-07 2011-06-22 RMSpumptools Limited Outil de complétion de fond de puits
US8276673B2 (en) 2008-03-13 2012-10-02 Pine Tree Gas, Llc Gas lift system
US9316089B2 (en) 2009-06-10 2016-04-19 Baker Hughes Incorporated Seat apparatus and method
EP2440741A2 (fr) * 2009-06-10 2012-04-18 Baker Hughes Incorporated Dispositif de sièges et procédé
RU2570692C2 (ru) * 2009-06-10 2015-12-10 Бейкер Хьюз Инкорпорейтед Седловое устройство и способ проведения скважинной операции
CN102159789A (zh) * 2009-06-10 2011-08-17 贝克休斯公司 阀座设备和方法
WO2010144580A3 (fr) * 2009-06-10 2011-04-07 Baker Hughes Incorporated Dispositif de sièges et procédé
EP2440741A4 (fr) * 2009-06-10 2014-11-19 Baker Hughes Inc Dispositif de sièges et procédé
CN101592024A (zh) * 2009-07-15 2009-12-02 中国海洋石油总公司 油井密闭生产空间用放气系统
US9181778B2 (en) 2010-04-23 2015-11-10 Smith International, Inc. Multiple ball-ball seat for hydraulic fracturing with reduced pumping pressure
CN103080470B (zh) * 2010-07-01 2015-11-25 史密斯运输股份有限公司 用于以减小的泵送压力水力压裂的多球-球座
CN103080470A (zh) * 2010-07-01 2013-05-01 史密斯运输股份有限公司 用于以减小的泵送压力水力压裂的多球-球座
RU2449192C1 (ru) * 2010-11-29 2012-04-27 Общество с ограниченной ответственностью "Русская электротехническая компания" ("РУСЭЛКОМ") Клапан обратный реверсивный
RU2455546C1 (ru) * 2010-12-30 2012-07-10 Общество с ограниченной ответственностью "Конкистадор" Обратный клапан
CN103415732A (zh) * 2011-03-07 2013-11-27 株式会社三国 将止回阀安装于在内部具备流体通路的外壳的安装构件
CN103415732B (zh) * 2011-03-07 2015-03-11 株式会社三国 外壳与止回阀的安装结构和止回阀相对于外壳的安装方法
US10975659B2 (en) * 2013-04-01 2021-04-13 Zenith Oilfield Technology Limited Automatic blanking completion tool
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AU3534997A (en) 1998-02-10

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