EP0595907B1 - Appareil ameliore pour tete de production d'essai sous-marine - Google Patents

Appareil ameliore pour tete de production d'essai sous-marine Download PDF

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Publication number
EP0595907B1
EP0595907B1 EP92915716A EP92915716A EP0595907B1 EP 0595907 B1 EP0595907 B1 EP 0595907B1 EP 92915716 A EP92915716 A EP 92915716A EP 92915716 A EP92915716 A EP 92915716A EP 0595907 B1 EP0595907 B1 EP 0595907B1
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EP
European Patent Office
Prior art keywords
blowout preventer
string
sleeve
valve
rams
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Expired - Lifetime
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EP92915716A
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German (de)
English (en)
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EP0595907A1 (fr
Inventor
Graeme Forbes Coutts
Jeffrey Charles Edwards
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Expro North Sea Ltd
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Expro North Sea Ltd
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    • 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
    • E21B34/02—Valve arrangements for boreholes or wells in well heads
    • E21B34/04—Valve arrangements for boreholes or wells in well heads in underwater well heads
    • E21B34/045—Valve arrangements for boreholes or wells in well heads in underwater well heads adapted to be lowered on a tubular string into position within a blow-out preventer stack, e.g. so-called test trees

Definitions

  • This invention relates to an improved gas or oil well sub-sea test tree and to apparatus for use with a test tree.
  • the invention further relates to a method of killing a live well after activation of the well blowout preventer in which the landing string above the test tree is sheared and the sub-sea test tree valves close to seal off the landing string.
  • blowout preventer During well testing (drilling) operations and the like, which are carried out from a floating vessel, such as a drillship or semi-submersible, well control is achieved by a sub-sea blowout preventer, which is mounted on the sea-bed to the well head.
  • blowout preventers typically comprise a tubular central housing on which are mounted a number of sets of hydraulic rams, for example, four which carry various sealing and cutting tools.
  • the rams are axially spaced along the housing.
  • the lower, or pipe rams are provided with semi-circular sealing faces, so that when these rams are activated the semi-circular faces mate with the outer surfaces of the well tool.
  • the uppermost set of rams are known as shear rams and are provided with cutting surfaces which can cut through or close the bore of the well tool and isolate the pressurised reservoir fluid from the riser and the upper part of the well tool.
  • well pressure control equipment In oil and gas well testing, well pressure control equipment is utilised in addition to the downhole test equipment mounted at the end of the test string, the well pressure control equipment being located above the well head and blowout preventer on the landing string. This equipment provides various safety features and allows for complete well control.
  • One of the tools utilised in well testing is a sub-sea test tree, a safety valve which is located inside the blowout preventer.
  • the sub-sea safety tree provides a primary safety system to control tubing pressure and to provide means to disconnect the riser rapidly and safely from the well should adverse conditions occur, such as bad weather or loss of a floating vessels' positioning system. This is partly achieved by providing "fail-safe" valves in the tree, which, for example, are held open during normal operating conditions by supplied hydraulic pressure.
  • valves will close, isolating the test string below the tree.
  • An upper portion of the tree may then be unlatched from the lower portion of the tree containing the valves, and the landing string and other well pressure control equipment located above the tree withdrawn.
  • the shearing rams of the blowout preventer are activated and seal the string by shearing through the landing string above the sub-sea tree leaving it inside the blowout preventer.
  • the pipe rams are normally extended during well testing and thus also form a seal around the outside of the string.
  • To bring the well back to a safe condition and permit retrieval of the downhole test tools it is necessary to "kill" the live well, such that an uncontrolled flow of fluid will not result when the blowout preventer is opened. This is accomplished by reducing the well pressure, which may be achieved by, for example, pumping a fluid such as barium mud, brine or sea water into the string.
  • US 4116272 discloses a sub-sea test tree for placement in a blowout preventer stack, which uses ball valves.
  • the ball valves are moved to the open position by hydraulic pressure supplied to the well annulus below a closed set of blowout preventer rams.
  • the ball valves are spring operated to close when pressure on either side of the blowout preventer is equalised.
  • US 4880060 discloses a hydraulic control system for controlling a retainer valve in an underwater well test system.
  • the control system uses a ball type valve which is biased to the open position and when closed may be locked by continuous application of closing pressure.
  • One of the primary objects of this invention is to provide a sub-sea test tree which facilitates killing of a live well after activation of a blowout preventer. This is achieved by providing apparatus, in the form of a shear or kill sleeve in a string above a sub-sea test tree and which is located between the pipe rams and shear rams of a blowout preventer.
  • the sleeve includes a pressure sensitive valve which may be opened, by pressurising between the blowout preventer rams, to permit fluid to be pumped from the blowout preventer through the valve and into the string, to choke or kill the well.
  • the blowout preventer may be opened to permit removal of the well tools.
  • a method of providing fluid communication between a blowout preventer stack defining an internal chamber and a well tool located in said chamber and defining an internal bore, when at least two sets of rams of the blowout preventer are closed and the well tool forms part of a tubular test string including a sub-sea test tree and defining an internal bore in communication with the internal bore of the well tool comprising the steps of: providing a pressure sensitive valve in the well tool between the two sets of closed rams; and pressurising the internal chamber of the blowout preventer between the two sets of closed rams to open the pressure sensitive valve and permit fluid communication between the internal chamber of the blowout preventer and the well tool.
  • the open pressure sensitive valve may be used to permit fluid, such as barium mud, brine or seawater to be pumped through the well tool to kill a live well to allow opening of the blowout preventer and retrieval of equipment on the well tool below the blowout preventer.
  • fluid such as barium mud, brine or seawater
  • the valve is sensitive to a difference in pressure between two areas, where the first area is the internal chamber of the blowout preventer between the rams and the internal bores of the well tool, and the second area is the string, and will only open when the pressure differential is above a predetermined level.
  • the valve includes a valve member maintained in the closed position by a valve member retaining means which prevents movement of the valve member until a predetermined differential pressure force is applied to the valve member.
  • the valve member may be in the form of an annular sleeve, axially slidable within a valve body.
  • the valve member retaining means is in the form of a shear pin extending, in the closed position, between the valve body and the valve member.
  • the sleeve has a first end surface on which the pressure in the internal chamber of the blowout preventer, and the exterior of the string, acts, and when the valve is opened fluid may flow past this end surface.
  • the valve body preferably includes a low pressure chamber to receive the sleeve as the valve is opened, and the applied pressure acting on the first end surface thus holds the valve open. Conveniently this low pressure chamber contains air at atmospheric pressure.
  • the method includes the steps of providing a portion of increased cross-section on the string, above the sub-sea test tree and between the two sets of closed rams, said portion being adapted to open and then engage a descending overshot fishing tool;
  • the pressure sensitive valve and the portion of increased cross-section are provided by a separate sleeve in the drill string upstream of the sub-sea test tree.
  • the opening of the pressure sensitive valve permits the pressurising of the interior of the string between the upper set of rams of the blowout preventer and the test tree fail safe valves to open the valves and permit fluid to be pumped into the string below the tree.
  • fluid communication apparatus in combination with a sub-sea test tree and a blowout preventer, the apparatus and test tree for forming part of a string and for location in the blowout preventer, the blowout preventer comprising: wall defining an inner passage for receiving the string, and at least two sets of rams, and the wall including a valve which may be configured to allow fluid communication between the exterior of the wall and the internal passage between the two sets of rams; the apparatus comprising: a sleeve defining an inner passage and the sleeve including a pressure sensitive valve, a preselected pressure differential across the sleeve causing the valve to open to allow fluid communication between the exterior of the sleeve and the inner passage.
  • the invention relates to apparatus and methods for use primarily in sub-sea oil and gas exploration and extraction, and in particular relates to improvements to sub-sea test trees, as used in well testing from floating vessels such as semi-submersibles and drillships.
  • Figures 1 and 2 of the drawings show, diagrammatically, apparatus provided at a well head during well testing.
  • a riser 10 depends from the drill-ship or semi-submersible (not shown) and is connected to the upper end of a blowout preventer stack 12 mounted on the wellhead 14.
  • the blowout preventer stack 12 includes a generally tubular housing 16 on which are mounted four sets of hydraulic rams 18, 20, 22, 24.
  • the lower set of rams 22, 24 are in the form of pipe rams provided with semi-circular sealing faces and these rams are normally extended, as shown, to engage with string 26 during well testing.
  • the uppermost set of rams 18 are in the form of shear rams and may be activated to cut through the string 26, when required, as shown in Figure 2.
  • well pressure control equipment Located within the riser 10 and blowout preventer stack 12 and mounted on the landing string 26 is well pressure control equipment including a safe lubricator valve 28, a safe retainer valve 30 and a sub-sea test tree 32 including fluid communication apparatus 34 for providing fluid communication between the blowout preventer 12 and the string 26, as will be later described in detail.
  • the fluid communication apparatus 34 is termed a "kill sleeve" or "kill sub”.
  • a hanger assembly 36 sits at the well head 14 on the well head casing 38 and a test string 40 depends from the assembly 36.
  • the test tree 32 includes fail safe valves (not shown) which may be maintained in the open position by hydraulic pressure. If the hydraulic pressure supply is cut off, the valves will close, isolating the test string 40 below the test tree 32. The valves may be reopened by fluid pressure in the string above the tree, and this allows the valves to be reopened if the hydraulic supply lines have been cut.
  • SAFE tree sub-sea test tree of this form is available from Expro (North Sea) Ltd., Aberdeen, Scotland, U.K. An upper portion of the tree may also be unlatched mechanically or hydraulically from a lower portion containing the valves, to allow the landing string 26 to be withdrawn rapidly and safely in the event of, for example, bad weather.
  • the shear rams 18 of the blowout preventer are activated to shear through the landing string 26 above the sub-sea test tree 32 and kill sleeve 34 and seal the well.
  • the shear rams 18 will also cut through the hydraulic supply lines which normally hold the valves open. Thus, the valves will close, if they have not already been closed.
  • kill sleeve 34 forms part of the string 26 and is located above the main body of the sub-sea test tree 32 and, in use, is positioned just below the shear rams 18 of the blowout preventer.
  • the kill sleeve 34 define an inner passage 42 of similar diameter to the test string inner diameter and the ends of the sleeve are provided with conventional coupling means (not shown), for connecting the sleeve 34 in the string 26.
  • the sleeve 34 comprises four main parts; an upper portion in the form of a top sub 44; a lower portion in the form of a bottom sub 46; an annular sleeve 58; and a valve member in the form of a further annular sleeve 84.
  • the top sub 44 has an upper portion 48 and a lower portion 50 of greater diameter.
  • the shoulder 52 between the portions 48, 50 may be used to locate an overshot fishing tool, while the lower shoulder 54 of the portion 50 provides a surface to engage the fishing tool.
  • the subs 44, 46 are joined by means of a threaded connection 56 on the inner surface of the lower portion 50 of top sub 44 and the outer surface of the upper end of the bottom sub 46.
  • a fixed annular sleeve 58 Located between the subs 44, 46 and defining a portion of the inner passage 42 is a fixed annular sleeve 58.
  • the upper end 60 of the sleeve 58 is received in an annular groove 62 in the top sub 44 while the lower end 64 abuts a face 66 of the bottom sub 46.
  • the lower end 64 of the sleeve 58 is castellated, that is provided with four equi-spaced grooves (90° apart) around its circumference to define four passages 68, 69, 70 (only three shown) between the inner passage 42 and an annular chamber 78 formed between the sleeve 58 and the subs 44, 46.
  • passages 80, 82 (only two shown) are provided in the sleeve wall of the lower portion 50 of the top sub 44, and together with the passages 68, 70 define circulation ports, normally closed by a valve member in the form of an annular sleeve 84 located in the chamber 78.
  • Figure 3 shows the annular sleeve 84 positioned to close the circulation ports, while Figure 4 shows the sleeve 84 raised so that the circulation ports are open.
  • the sleeve 84 is slidable in the annular chamber 78 which defines an upper portion 86 at low or atmospheric pressure and an enlarged lower portion 88 between the passages 68, 70 and 80, 82.
  • the circulation sleeve 84 is normally located with its upper end 90 located in the lower end of the upper portion 86 of the chamber 78 and its lower end 92 abutting the base 93 of the lower portion 88 of the chamber 78.
  • the lower end of the sleeve includes a shoulder 94 which seals against an inner side wall of the chamber 78.
  • a shear pin 96 is mounted on the top sub 44 and extends into a recess 98 in the outer wall of the sleeve 84.
  • the sleeve 84 is further held in the closed position by means of the pipe pressure, from the interior of the string, exerted over area A 1 .
  • Acting to move the sleeve 84 to open the circulation ports is the annular pressure, between the interior of the blowout preventer and the string, acting on area A 2 ; in a live well the annular pressure is normally substantially lower than the pipe pressure.
  • area A 2 is substantially larger than area A 1 , such that the "upward" pressure force acting over area A 2 will be greater than the "downward" pressure force acting over area A 1 when the annulus pressure is still substantially lower than the tubing pressure.
  • the kill sleeve 34 is formed from K-500 Monel (trade mark) metal, and three O-ring seals 98 provided on the sleeve are formed of an elastomer, preferably Viton (trade mark), and the shear pin 96 is preferably of aluminium-bronze.
  • the kill sleeve 34 is of a minimum length, preferably around 12" long, and typically has an inside diameter of 3" and an outside diameter of 8".
  • the kill sleeve 34 is utilised after the shear rams 18 of the blowout preventer have been activated to cut through the string 26, as may be seen in Figure 2.
  • the sleeve 84 allows fluid communication between the volume 100 of the blowout preventer between the shear rams 18 and the lower sets of rams 22, 24 and the interior of the drill string, to permit operators to choke or kill the well. This is achieved by pressurising the volume 100 by pumping fluid from the surface through the supply lines 102 and a valve 104 ( Figure 2) in the blowout preventer housing 16.
  • the annular pressure force on the area A 2 is sufficient to overcome the pipe pressure force on the area A 1 , and shear the pin 96 to move the circulation sleeve 84 into the upper portion 86 of the chamber 78 and open the circulation ports.
  • the pressure in the volume 100 and now also the string above the test tree 32 is then used to open the closed ball valves in the sub-sea test tree 32.
  • Fluid such as barites mud, brine or sea water may then be pumped through the circulation ports of the kill sleeve, into the string and through the test tree 32 until the pipe pressure at the well head falls to a level, usually zero, to permit the blowout preventer to be opened by retracting the rams 18, 22, 24.
  • the kill sleeve 34, test tree 32, hanger assembly 36 and test string 40 carrying the downhole test equipment may then be retrieved by means of an overshot fishing tool which, as it descends, is located by the enlarged cross-section portion of the sleeve 34, at the shoulder 52 and then latches around this portion, at the lower shoulder 54.
  • the above described kill sleeve in conjunction with the other apparatus, provides means for quickly killing a well after actuation of a blowout preventer and which permits retrieval of the apparatus from a well.
  • blowout preventer described and the vast majority of existing blowout preventers, operate using hydraulic rams, however other means of closing a well may be developed and it is clear that the kill sleeve described may operate in conjunction with blowout preventers of other forms.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Testing Of Devices, Machine Parts, Or Other Structures Thereof (AREA)
  • Catching Or Destruction (AREA)
  • Investigating Or Analysing Biological Materials (AREA)
  • Testing Or Calibration Of Command Recording Devices (AREA)
  • Earth Drilling (AREA)
  • Safety Valves (AREA)

Abstract

On décrit un appareil et un procédé pour tuer un puits actif après utilisation d'un bloc obturateur de puits. On peut mettre en ÷uvre ce procédé grâce à un appareil en forme de manchon de cisaillement ou d'extinction (34) dans une colonne (26), au-dessus d'une tête de puits d'essai sous-marine, situé entre les mâchoires d'obturateur (24, 24) et les mâchoires de cisaillement (18) d'un bloc obturateur (12) de puits. Dans le cas où les mâchoires de cisaillement seraient actionnées et obtureraient la colonne au-dessus du manchon de sécurité (34), le manchon comporte une vanne sensible à la pression (84) qui peut être ouverte, par pressurisation entre les mâchoires (18, 22) du bloc obturateur de puits, pour permettre de pomper le fluide du bloc obturateur de puits (12) à travers la vanne (84) et de l'envoyer dans la colonne (40) afin d'obstruer ou de tuer le puits. Après avoir tué le puits, on peut ouvrir le bloc obturateur (12) de puits pour en ressortir les outils. Des modes de réalisation de l'invention sont également décrits.

Claims (13)

  1. Procédé de création d'une communication de fluide entre une cheminée de vanne d'éruption (12) définissant une chambre intérieure, et un manchon (34) placé dans ladite chambre et définissant un conduit intérieur (42), lorsqu'au moins deux groupes de pistons (18,22) de la vanne d'éruption (12) sont fermés, le manchon (34) faisant partie d'une colonne d'essai tubulaire (40) qui comporte une tête d'essai sous-marine (32) et définit un conduit intérieur en communication avec le conduit intérieur (42) du manchon, le procédé comprenant les étapes de :
    création d'une soupape sensible à la pression (78,84) dans le manchon (34) entre les deux groupes de pistons fermés (18,22) ; et
    mise en pression de la chambre intérieure de la vanne d'éruption (12) entre les deux groupes de pistons fermés (18,22), de manière à ouvrir la soupape sensible à la pression (78,84) et à permettre une communication de fluide entre la chambre intérieure de la vanne d'éruption (12) et le manchon (34).
  2. Procédé suivant la revendication 1, dans lequel la soupape sensible à la pression est utilisée pour permettre à un fluide, tel qu'une boue de baryum ou une saumure ou de l'eau de mer, d'être refoulé à travers le conduit intérieur (42) du manchon afin de tuer un puits actif et de permettre l'ouverture de la vanne d'éruption (12) et l'enlèvement d'un équipement sur l'outil de puits au-dessous de la vanne d'éruption (12).
  3. Procédé suivant la revendication 1 ou 2, dans lequel la soupape (78,84) est sensible à une différence de pression entre deux zones, la première zone étant la chambre intérieure de la vanne d'éruption (12) entre les pistons et les conduits intérieurs de l'outil de puits et la deuxième zone étant la colonne de tiges, et la soupape s'ouvre seulement lorsque la différence de pression est supérieure à une valeur prédéterminée.
  4. Procédé suivant la revendication 1, dans lequel la soupape (78,84) comprend un élément obturateur (84) maintenu dans la position fermée par un moyen de retenue d'élément obturateur (96) qui empêche le mouvement de l'élément obturateur (84) jusqu'à ce qu'une force correspondant à une différence de pression prédéterminée soit appliquée à l'élément obturateur (84).
  5. Procédé suivant la revendication 4, dans lequel l'élément obturateur (84) est sous la forme d'une chemise annulaire qui peut coulisser axialement à l'intérieur d'un corps de soupape (78).
  6. Procédé suivant la revendication 5, dans lequel la chemise présente une première surface d'extrémité sur laquelle agit la pression dans la chambre intérieure de la vanne d'éruption et à l'extérieur de la colonne, et, lorsque la soupape est ouverte, le fluide s'écoule le long de cette surface d'extrémité.
  7. Procédé suivant la revendication 6, dans lequel le corps de soupape comprend une chambre basse pression (86) pour recevoir la chemise lorsque la soupape est ouverte, et la pression appliquée agissant sur la première surface d'extrémité maintient ainsi la soupape ouverte.
  8. Procédé suivant une quelconque des revendications précédentes, comprenant les étapes de :
    création d'une partie de plus grande section transversale (50) sur la colonne, au-dessus de la tête d'essai sous-marine et entre les deux groupes de pistons fermés, ladite partie pouvant ouvrir et venir ensuite en prise avec un outil de repêchage à surcourse descendant ; et
    une fois que le puits a été tué, ouverture des pistons de la vanne d'éruption ;
    ensuite, descente de l'outil de repêchage dans la vanne d'éruption pour saisir la partie de plus grande section transversale sur la colonne ;
    puis relevage de l'outil de repêchage et récupération de la colonne.
  9. Procédé suivant la revendication 8, dans lequel la tête d'essai sous-marine comporte des soupapes de sécurité qui sont ouvertes par une pression de tubage prédéterminée appliquée au-dessus des soupapes, l'ouverture de la soupape sensible à la pression permettant la mise en pression de l'intérieur de la colonne, entre le groupe supérieur de pistons de la vanne d'éruption et les soupapes de sécurité de la tête d'essai, afin d'ouvrir les soupapes et de permettre le refoulement de fluide dans la colonne au-dessous de la tête.
  10. Combinaison d'un appareil de communication de fluide avec une tête d'essai sous-marine (32) et une vanne d'éruption (12), l'appareil (34) et la tête d'essai (32) faisant partie d'une colonne de tiges et étant placés dans la vanne d'éruption (12), la vanne d'éruption (12) comprenant une paroi,qui définit un passage intérieur pour recevoir la colonne, et au moins deux groupes de pistons (18,22), et la paroi incluant une soupape qui peut être configurée de manière à permettre une communication de fluide entre l'extérieur de la paroi et le passage intérieur,entre les deux groupes de pistons ; l'appareil comprenant un manchon (34) qui définit un passage intérieur (42), et le manchon (34) incluant une soupape sensible à la pression (78,84), de sorte qu'une différence de pression prédéterminée de part et d'autre du manchon (34) provoque l'ouverture de la soupape pour permettre une communication de fluide entre l'extérieur du manchon (34) et le passage intérieur (42).
  11. Combinaison suivant la revendication 10, dans laquelle l'appareil comprend une partie de plus grande dimension, ladite partie (50) étant prévue pour ouvrir et venir ensuite en prise avec un outil de repêchage à surcourse descendant.
  12. Combinaison suivant la revendication 11, dans laquelle la soupape sensible à la pression (78,84) et la partie de plus grande-section transversale (50) sont portées par un manchon séparé, situé dans la colonne de forage en amont de la tête d'essai sous-marine.
  13. Combinaison suivant la revendication 12, dans laquelle la tête d'essai sous-marine comporte des soupapes de sécurité qui sont ouvertes par une pression de tubage prédéterminée appliquée au-dessus des soupapes, l'ouverture de la soupape sensible à la pression permettant la mise en pression de l'intérieur de la colonne, entre le groupe supérieur de pistons de la vanne d'éruption et les soupapes de sécurité de la tête d'essai, afin d'ouvrir les soupapes et de permettre le pompage de fluide et son introduction dans la colonnne au-dessous de la tête.
EP92915716A 1991-07-30 1992-07-23 Appareil ameliore pour tete de production d'essai sous-marine Expired - Lifetime EP0595907B1 (fr)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
GB919116477A GB9116477D0 (en) 1991-07-30 1991-07-30 Improved sub-sea test tree apparatus
GB9116477 1991-07-30
PCT/GB1992/001352 WO1993003254A1 (fr) 1991-07-30 1992-07-23 Appareil ameliore pour tête de production d'essai sous-marine

Publications (2)

Publication Number Publication Date
EP0595907A1 EP0595907A1 (fr) 1994-05-11
EP0595907B1 true EP0595907B1 (fr) 1997-12-03

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EP92915716A Expired - Lifetime EP0595907B1 (fr) 1991-07-30 1992-07-23 Appareil ameliore pour tete de production d'essai sous-marine

Country Status (9)

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EP (1) EP0595907B1 (fr)
AU (1) AU668689B2 (fr)
CA (1) CA2114619C (fr)
DE (1) DE69223409T2 (fr)
GB (1) GB9116477D0 (fr)
GR (1) GR3026203T3 (fr)
NO (1) NO308912B1 (fr)
RU (1) RU2101460C1 (fr)
WO (1) WO1993003254A1 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2015094146A1 (fr) * 2013-12-16 2015-06-25 Halliburton Energy Services, Inc. Étagement de pression pour ensemble d'empilement de têtes de puits

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* Cited by examiner, † Cited by third party
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US5764365A (en) 1993-11-09 1998-06-09 Nova Measuring Instruments, Ltd. Two-dimensional beam deflector
IL107549A (en) 1993-11-09 1996-01-31 Nova Measuring Instr Ltd Device for measuring the thickness of thin films
US6179057B1 (en) * 1998-08-03 2001-01-30 Baker Hughes Incorporated Apparatus and method for killing or suppressing a subsea well
NO309439B1 (no) * 1999-10-01 2001-01-29 Kongsberg Offshore As Anordning ved undervanns lubrikator, samt fremgangsmåter for utsirkulering av fluider fra den samme
NO332404B1 (no) 2007-06-01 2012-09-10 Fmc Kongsberg Subsea As Fremgangsmate og innretning for redusering av et trykk i en forste kavitet i en undersjoisk anordning
RU2534876C1 (ru) * 2013-09-13 2014-12-10 Общество с ограниченной ответственностью Научно-производственная фирма "Пакер" Двухпакерная установка для эксплуатации скважин электроприводным насосом с одновременной изоляцией интервала негерметичности и циркуляционный клапан
RU2768811C1 (ru) * 2020-09-29 2022-03-24 Общество с ограниченной ответственностью "Газпром 335" Гидравлическая система управления колонны для спуска
RU2763868C1 (ru) * 2020-09-29 2022-01-11 Общество с ограниченной ответственностью "Газпром 335" Гидроэлектрическая система управления колонны для спуска с резервной системой управления последовательного включения со сбросом давления в полость водоотделяющей колонны

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AU668689B2 (en) 1996-05-16
CA2114619A1 (fr) 1994-01-31
DE69223409D1 (de) 1998-01-15
NO940307L (no) 1994-01-28
EP0595907A1 (fr) 1994-05-11
RU2101460C1 (ru) 1998-01-10
CA2114619C (fr) 1998-10-13
WO1993003254A1 (fr) 1993-02-18
GR3026203T3 (en) 1998-05-29
NO940307D0 (no) 1994-01-28
AU2342292A (en) 1993-03-02
GB9116477D0 (en) 1991-09-11
DE69223409T2 (de) 1998-06-04
NO308912B1 (no) 2000-11-13

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