EP0579497B1 - Procédé pour l'amplification de pression du transfert d'un fluide de production d'un puits - Google Patents

Procédé pour l'amplification de pression du transfert d'un fluide de production d'un puits Download PDF

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Publication number
EP0579497B1
EP0579497B1 EP93305563A EP93305563A EP0579497B1 EP 0579497 B1 EP0579497 B1 EP 0579497B1 EP 93305563 A EP93305563 A EP 93305563A EP 93305563 A EP93305563 A EP 93305563A EP 0579497 B1 EP0579497 B1 EP 0579497B1
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EP
European Patent Office
Prior art keywords
chamber
gas
line
pressure
production fluid
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.)
Expired - Lifetime
Application number
EP93305563A
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German (de)
English (en)
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EP0579497A1 (fr
Inventor
Hans Paul Hopper
Thomas Gus Cassity
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.)
Cameron International Corp
Original Assignee
Cooper Cameron Corp
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Filing date
Publication date
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Priority to EP93305563A priority Critical patent/EP0579497B1/fr
Publication of EP0579497A1 publication Critical patent/EP0579497A1/fr
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Publication of EP0579497B1 publication Critical patent/EP0579497B1/fr
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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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/36—Underwater separating arrangements
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/38—Arrangements for separating materials produced by the well in the well
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D1/00—Pipe-line systems
    • F17D1/08—Pipe-line systems for liquids or viscous products
    • F17D1/12—Conveying liquids or viscous products by pressure of another fluid

Definitions

  • the well may be a very long way from an export point, such as the deck of a platform or landfall, in the case of a subsea well, and the pressure drop in the correspondingly long pipeline may reduce the flow rate to an unacceptable level or not at all.
  • an export point such as the deck of a platform or landfall
  • a similar problem arises when there is insufficient reservoir pressure to achieve an acceptable flow rate through a wellhead to an export point.
  • Oil tapped from an oil well is invariably accompanied by a gaseous component which will increasingly come out of solution with reduced pressure.
  • the production fluid the transfer of which is to be boosted, conventionally incorporates liquid and gaseous components in indeterminate and widely varying proportions ranging from slugs of liquid oil through frothy mixtures to pockets of gas. Therefore the optimum position for a pump is below the hydrocarbon bubble point.
  • Downhole pumps that have to be run inside the casing are necessarily small and have a short life.
  • US-A-3486297 discloses a method of pumping a liquid from a source to a destination, the method comprising providing at least one chamber connected via valving with a supply at a first pressure, from the source, of a fluid of which the liquid forms at least a part, the chamber having its lower part connected via valving with a feeder for at least the liquid component of the fluid to the destination, the chamber having its upper part connected by a valving with both a high pressure gas supply line at a second pressure greater than the first pressure and with a low pressure gas vent line at a third pressure less than the first pressure; and alternately introducing gas from the gas supply line into the chamber to displace the liquid component of the fluid from the chamber into the feeder, and venting the chamber to the gas vent line whilst allowing the fluid to enter the chamber from the supply.
  • US-A-4761225 discloses the concept of removing liquid hydrocarbons from ground water using compressed air in a downhole pump chamber.
  • a method of pumping production fluid from down an oil well in a sub sea oil field to an export point above the mud line comprises providing down hole a tool string comprising a tubular casing extending axially of the well, the casing containing axially extending tubing forming part of a feeder line for at least a liquid component of the production fluid to the export point, the space within the casing outside the tubing being divided into two axially spaced chambers each connected via valving within the casing with a source of production fluid at a first pressure within the well and outside the casing, each chamber having its lower part connected via valving within the casing with the interior of the tubing, and each chamber having its upper part connected via valving within the casing with both a high pressure gas supply line at a second pressure greater than the first pressure and with a low pressure gas vent line at a third pressure less than the first pressure, the supply and vent lines leading to above the mud line where the high and low gas pressures are controlled; and alternately
  • the new method has the advantage that liquid can be pumped at the relatively inaccessible location below the mudline in a subsea oil field, preferably below the bubble point, without the need for any local pumps and/or motors, using the energy provided through the gas supply line leading from a pumping station in an accessible position, such as on a platform or landfall.
  • the gas vent line will normally run alongside the gas supply line to the same station.
  • the gas vent line can provide a low back pressure, which may be controlled at the pumping station to enable the chamber to act as a self filling pump at the appropriate part of the cycle during which the chamber is filled with fluid from the fluid supply.
  • any gas released from the production fluid on entering the chamber may rise to the top of the chamber and be vented with the gas already in the gas chamber, up the gas vent line during the filling of the chamber.
  • the reduction in the quantity of gas in the production fluid liquid component also delays the onset of multiphase flow problems.
  • gas vent line pressure to cause a release of gas from the production fluid, gas can be removed so that a controlled single phase liquid can be achieved.
  • the pressure in the gas supply line is then adjusted to ensure a single phase flow or stable multiphase flow through the feeder to the export point.
  • the liquid phase is thus pumped by the supply of energy to the liquid phase only.
  • the gas supply should be compatible for hydrocarbon pumping, e.g. oxygen-free and may be, e.g. nitrogen on start-up. Usually however it will be recompressed gas from the production fluid, e.g. recycled from the vent line via the remote station. This is efficient as it is only necessary to provide enough energy to raise the gas pressure from that in the vent line to that necessary to pump the liquid.
  • the valving is changed over from introducing gas into the chamber, to venting the chamber, by sensing the level of the liquid in the chamber. Essentially this will involve a high and/or low level sensor for the chamber.
  • the sensors may be of any conventional type, such as distance or density sensors which are appropriately coupled to the chamber to detect the surface of the liquid or, possibly, a float which moves with the surface of the liquid.
  • the sensors may operate the changeover valving either electrically, for example by solenoid operation, hydraulically or passively using pilot gas pressure.
  • a plurality of pairs of the chambers are preferably mounted in parallel between common source, feeder and gas supply and vent lines. This has the advantage that malfunction of one or one pair will not affect the other or others. However if their changeovers are all synchronized, a comparatively uniform flow along the feeder can be achieved.
  • Figure 1 shows three pressure retaining vessels 5A, 5B and 5C, each having an internal chamber 5' and which may be considered either as the same vessel at a sequence of times in a pumping cycle, or as different vessels at different stages in the pumping cycle at the same time.
  • the internal chamber 5' of each vessel is connected via an inlet valve 6 with a high pressure gas supply line 7, and via an outlet valve 8 with a low pressure gas vent line 9.
  • a chamber 5' of each vessel has an inlet, connected via a non-return inlet check valve 10 with a fluid supply line 11, and an outlet connected via a non return outlet check valve 12 with a feeder line 13.
  • a float operated shut off valve 14 at the top of each vessel chamber 5' seals the chamber from the line 9 in the event of liquid 15 filling the chamber up to an unsafe upper level upon failure of a high level sensor to be described.
  • a float operated shut off valve 16 seals the outlet at the bottom of each chamber 5' from the feeder line 13, in the event of the liquid 15 in the chamber dropping to an unsafe lower level, in the event of failure of a low level sensor to be described.
  • FIG. 2 shows in more detail how the valves 6,8 in Figure 1 are changed over.
  • the valves 6,8 for the vessel 5 are combined into a two position spool valve 68.
  • the upper position of the spool as in Figure 2, the upper end of the chamber 5' is in communication with the high pressure gas supply line, while in the lower position, the upper end of the chamber 5' is in communication with the low pressure gas vent line 9.
  • the spool is changed over between its upper and lower positions by pilot pressure applied to a piston and cylinder device 17. Both sides of the piston of which are connected via a duo-orifice bleed unit 18 and filter 19, to the line 7.
  • the cylinder space of the device 17 above its piston is connected via a line 20 to a spool of a high level sensor in the form of an upper float operated pilot spool valve 21 and the cylinder of the device 17 below its piston is connected via a line 22 to a low level sensor in the form of a lower float operated pilot spool valve 23.
  • the other side of each pilot valve 21 and 23 is connected by a line 24 to the gas vent line 9.
  • the spool of the valve 68 changes over as, with the spool of the pilot valve 21 in its lower position, the high pressure from the line 7 applied to above the piston of the device 17, will cause the piston and the spool of the valve 68 to move downwardly to the position in which the upper end of the chamber 5' is connected to the gas vent line 9.
  • the events represented by the vessels 5B and 5C in Figure 1 will then take place, the chamber 5' filling with liquid from the supply line 11.
  • the float of that valve will cause its spool to rise so that the line 20 and upper side of the piston of the device 17 are vented to the gas vent line 9 via the line 24 and, with the spool of the pilot valve 23 in its upper position, the higher pressure applied to the underside of the piston of the device 17 will cause the piston of the device 17 to rise, together with the spool of the valve 68, so that the upper part of the chamber 5' is reconnected to the high pressure gas supply line 7 to restart the pumping cycle.
  • Figure 3 shows how the vessel of Figures 1 and 2 may be used in practice.
  • the Figure suggests a subsea oil field with a subsea terrain 25, sea 26, and floating or fixed platforms 27 and 28.
  • the compressor stations, at which the gas supply and vent lines 7 and 9 may terminate, may be provided at the platforms 27 and 28.
  • 29 represents a water pump injection well through which water may be injected into the subsea oil reservoir 30. More usefully, for production, the pumping chambers will be mounted within a subsea well 31. The chambers will be used for pumping, by means of the high pressure gas supply, production fluid liquid through an export line 34 to an export point, which may be at the platforms 27,28 or elsewhere.
  • the chambers When the chambers are used for pumping production fluid from downhole in a well 31, as shown schematically in Figure 4, there may be a number of the vessels 5 connected in a stacked formation one above the other in the well. They may be mounted within a production casing 35 so that production fluid from a reservoir 36, passing up through a tail pipe 37, sealed by a packer 38, may flow through ported tubing 39 to the annulus between the production casing 35 and vessels 5, exposed to inlets 40 of the individual vessel chambers. These chambers will have the appropriate valving, connecting them in parallel to the high pressure gas supply line 7, gas vent line 9, and production fluid export line 34.
  • valve 68 when the valve 68 is transmitting the high pressure from the line 7, this is applied through a line 41 to the valve 68A, the spool of which rises against the action of a return spring 42. Conversely when the valve spool of the valve 68 is in its lower position, in which it is connected to the low pressure gas line 9, the pressure transmitted through the line 41 to the slave valve 68A results in the valve being pressure balanced which allows the spring 42 to move the spool downwards. It will therefore be appreciated that when the top of the vessel 5A is connected to the high pressure gas line 7, the vessel 5C is connected to the low pressure gas line 9, and vice versa.
  • Figure 5 the vessel 5A is pumping out and this continues until the liquid level drops sufficiently to change over the valve 23 and hence also the valves 68 and 68A. If the chamber 5C should fill before the valve 23 of the vessel 5A has been actuated, the shut off valve 14 will close to prevent further filling of the chamber 5C.
  • Figure 5 shows a tandem system using a low float operation, the system could be adapted to use a high float operation or a high-low cascade system for a train of chambers.
  • Figure 6 shows lower parts of a 24,45 cm (9 5/8 inch) casing 45, containing, as shown exploded, sections each consisting of 17,78 cm (7 inch) casing 46 fitted between upper and lower housings 87 and 88. As shown in Figures 6a and 6c, each section is connected by a screw threaded sleeve 89 and sealed to the adjacent section above and below with the aid of orientation pins and sockets 49,50.
  • Each section contains a length of 8,89 cm (31 ⁇ 2 inch) tubing 34 which terminates in the end housings 87 and 88 such that when the string of sections is made up at the surface prior to running in, the tubing of adjacent sections are interconnected by mating spigots and sockets 90,91 of the end housings.
  • the space of crescent-shaped cross section within each section of casing 46 not occupied by the tubing 34 defines a closed chamber forming one of the chambers 5'.
  • adjacent sections will operate in pairs to provide multiple tandem units substantially as described with reference to Figure 5.
  • the gas lines 7,9 and the interconnections between the valves 23, 68, 68A will be provided within the chambers 5' and will be inserted into the string when it is made up.
  • the casing 45 corresponds to the production casing shown schematically at 35 in Figure 4.
  • production fluid flows up through an annulus 51 between the casings 45 and 46 to an inlet 40 and hence through an inlet valve 10 to one of the chambers 5'.
  • the annulus thus corresponds to the line 11 in Figure 5.
  • the inlet valve 10 comprises a valve body 53 which is sealed in a mounting 54 of the tool section with the aid of a seal 55; and a valve cap 56 having apertures 58 interconnecting the interior of the valve body with the respective chamber 5'.
  • Within the valve body is a vertically sliding closure member 59 cooperating with a seating 60 in the valve body, and oriented by anti-rotation pins 61.
  • valve closure member 59 During a filling part of the cycle in which production fluid is flowing into the chamber 5', the valve closure member 59 will be raised to open the valve, as shown in Figure 7b.
  • the valve element 59 When the pressure within the chamber 5' is greater than the production fluid supply pressure, the valve element 59 will be forced downwardly to close the valve as shown in Figure 7a.
  • valve 12 As shown in Figure 6, above the valve 10 is to be found the outlet valve 12 which is shown in more detail in Figure 8.
  • the valve 12 has a body 61 which is secured to the outside of the tubing 34 within the chamber 5' and has at its bottom an orifice plate 63, at its top a cap 64 and in its side wall an aperture 65 leading to within the tubing 34, which corresponds to the feeder line 13 in Figure 5.
  • this valve body Within this valve body is another vertically slidable closure member 66 which cooperates with a valve seating 67.
  • the differential pressure across the valve 12 causes the valve closure member to move to its lower position and close the valve as shown in Figure 8a.
  • the differential pressure across the valve closure member causes it to rise and open the valve as shown in Figure 8b.
  • the float operated pilot spool valve 23 which is shown in detail in Figure 9 and which consists of a cylinder housing 70 having a vent hole 74 at its upper end and to the lower end of which is secured a float guide 71 containing a float 72.
  • the housing 70 is formed with upper and lower annular grooves 73 which lead at one annular position to respective ports effectively forming the ends of the control lines 22 and 24.
  • a piston 75 which is raised and lowered by the float 72, controls the interconnection between the grooves 73 such that when the float and piston are in their lower position as shown in Figure 9a, the lines 22 and 24 are interconnected, and when the float and piston are in their raised position as shown in Figure 9b, the grooves 73 are isolated from one another and hence the lines 22 and 24 are isolated from one another.
  • the valve is pressure balanced, so that it is only operated by float movement, because an auxiliary piston 92, connected to the main piston 75 by a stem 93, works in an upper part of the cylinder housing 70.
  • the high pressure gas acts with equal force on the top of the main piston 75 and on the underside of the auxiliary piston 92.
  • the tool string section incorporates the high level shut off valve 14 which is shown in more detail in Figure 10.
  • This is connected to the bottom of the changeover spool valve 68,68A and consists of a housing 76 forming a float tube, and containing a float 77 which operates via a push rod 78 on a valve closure member 79 having a lip seal 80 which cooperates with an annular seating 81 at the bottom of the spool valve 68.
  • a travel stop 82 At the bottom of the housing 76 there is a travel stop 82, a spring 83 and a float orifice damper 84.
  • a vent hole 85 is provided in the side of the housing.
  • the high and low pressure gas lines are thus accommodated within the inner casing string 46 and these are the only external connections which are necessary in order for the production liquid to be pumped gently and substantially continually and alternately from the chambers of a tandem unit of two elements up through the tubing 34. No controls or signals therefore need to be sent downhole, other than those resulting from controlling above the well the high and low gas pressures. Control is otherwise entirely automatic as this is effected by the gas pilot system switched by the fluid level sensing.
  • tubing sections provide an uninterrupted passage for wireline operations below the pumping chambers, for example for logging or zone isolation operations.
  • the bottom of the bottom section of tubing would then be provided with a wireline set plug which could be removed and replaced by a seal such as a stuffing box to enable wireline operations during pumping.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Health & Medical Sciences (AREA)
  • Public Health (AREA)
  • Water Supply & Treatment (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Jet Pumps And Other Pumps (AREA)

Claims (3)

  1. Procédé de pompage du fluide de production, depuis le fond d'un puits de pétrole, dans un champ de pétrole sous-marin, jusqu'à un point de sortie situé au-dessus de la ligne de boue, le procédé consistant à disposer au fond du puits un train d'outils comportant un cuvelage tubulaire (46) s'étendant selon l'axe du puits, le cuvelage comprenant un tubage (34) s'étendant axialement qui fait partie d'une conduite de transport pour au moins une composante liquide du fluide de production jusqu'au point de sortie, l'espace (5') situé à l'intérieur du cuvelage (46) à l'extérieur du tubage (34) étant divisé en deux chambres (5') axialement espacées l'une de l'autre, chacune reliée, par une robinetterie (10) à l'intérieur du cuvelage (46), à une source (51) de fluide de production, sous une première pression, à l'intérieur du puits et à l'extérieur du cuvelage (46), chaque chambre ayant sa partie inférieure repliée, par une robinetterie (12) à l'intérieur du cuvelage (46), avec l'intérieur du tubage (34), et chaque chambre ayant sa partie supérieure reliée, par une robinetterie (6, 8) à l'intérieur du cuvelage (46), à la fois, à une conduite (7) d'amenée de gaz sous haute pression, sous une seconde pression supérieure à la première pression, et à une conduite (9) d'évacuation du gaz sous basse pression, sous une troisième pression inférieure à la première pression, les conduites d'amenée et d'évacuation conduisant au-dessus de la ligne de boue où la pression haute et la pression basse du gaz sont contrôlées; et, alternativement, à introduire du gaz provenant de la conduite d'amenée du gaz dans une chambre pour déplacer la composante liquide du fluide de production depuis la chambre dans le tubage, et pour vider la chambre dans la conduite d'évacuation du gaz, tout en permettant au fluide de production d'entrer dans la chambre en provenance du puits, les deux chambres se remplissant et se vidant en déphasage l'une par rapport à l'autre, la commutation étant automatiquement contrôlée en réponse aux niveaux du liquide dans les chambres, les niveaux étant mesurés par des détecteurs qui actionnent les vannes pilotes (21, 23) qui contrôlent la robinetterie (6, 8) entre les parties supérieures des chambres (5') et les conduites (7, 9) d'amenée et d'évacuation des gaz.
  2. Procédé selon la revendication 1, dans lequel les détecteurs sont des flotteurs.
  3. Procédé selon la revendication 1 ou la revendication 2, dans lequel une séparation préliminaire des composantes gazeuse et liquide du fluide de production est obtenue en permettant au gaz qui est libéré par le fluide de production de quitter les chambres pour aller dans les conduites (9) d'évacuation du gaz pendant le remplissage des chambres, depuis le puits de pétrole (51).
EP93305563A 1992-07-15 1993-07-15 Procédé pour l'amplification de pression du transfert d'un fluide de production d'un puits Expired - Lifetime EP0579497B1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
EP93305563A EP0579497B1 (fr) 1992-07-15 1993-07-15 Procédé pour l'amplification de pression du transfert d'un fluide de production d'un puits

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
EP92306462 1992-07-15
EP92306462 1992-07-15
EP93305563A EP0579497B1 (fr) 1992-07-15 1993-07-15 Procédé pour l'amplification de pression du transfert d'un fluide de production d'un puits

Publications (2)

Publication Number Publication Date
EP0579497A1 EP0579497A1 (fr) 1994-01-19
EP0579497B1 true EP0579497B1 (fr) 1997-05-28

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EP93305563A Expired - Lifetime EP0579497B1 (fr) 1992-07-15 1993-07-15 Procédé pour l'amplification de pression du transfert d'un fluide de production d'un puits

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Families Citing this family (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
BR9602746A (pt) * 1996-06-12 1998-09-08 Petroleo Brasileiro Sa Método e aparelhagem para produção submarina de petróleo com separação primária de gás e escoamento através da injeção de gás a alta pressão
FR2758852B1 (fr) * 1997-01-29 1999-03-19 Elf Aquitaine Procede de pompage d'un fluide
SE0100721D0 (sv) * 2001-03-02 2001-03-02 Delaval Holding Ab A device for supplying a compressed gas to a conduit in orden to transport a liquid in the conduit
NO331265B1 (no) * 2009-07-15 2011-11-14 Fmc Kongsberg Subsea As Undersjoisk dreneringssystem
NL2003602C2 (nl) * 2009-10-06 2011-04-07 Tom Van De Ven Project Realisatie B V Pijpleiding netwerk voor het over grote afstand transporteren van vloeistoffen, drukinrichting, toepasbaar bij een dergelijk pijpleidingnetwerk en werkwijze voor het transporteren van vloeistof over grote afstanden door de transportleiding van dergelijk pijpleiding netwerk.
NO339584B1 (no) * 2011-03-09 2017-01-09 Aker Solutions As Fremgangsmåte og anordning for utskilling og oppsamling av væske i gass fra et reservoar
CN109441893B (zh) * 2018-12-19 2023-06-20 贵州创能科技有限公司 一种水压气泵

Family Cites Families (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2261100A (en) * 1941-07-25 1941-10-28 Salt Water Control Inc Brine injection method for oil wells
US3221816A (en) * 1961-12-07 1965-12-07 Shell Oil Co Underwater oil gathering installation
US3486297A (en) * 1967-10-06 1969-12-30 Exxon Production Research Co Liquid and gas pumping unit
US4761225A (en) * 1986-08-18 1988-08-02 Breslin Michael K Apparatus for controlling the removal of liquid hydrocarbons from groundwater
NO884598D0 (no) * 1988-10-14 1988-10-14 Aker Eng As Undervanns behandlings-, lagrings- og lossesystem for petroleumsproduksjon.
GB9006684D0 (en) * 1990-03-26 1990-05-23 British Offshore Eng Tech Subsea separator,storage & pumping unit and its associated control system

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