[go: up one dir, main page]

WO2015059530A1 - A containment system and a method for using said containment system - Google Patents

A containment system and a method for using said containment system Download PDF

Info

Publication number
WO2015059530A1
WO2015059530A1 PCT/IB2014/000569 IB2014000569W WO2015059530A1 WO 2015059530 A1 WO2015059530 A1 WO 2015059530A1 IB 2014000569 W IB2014000569 W IB 2014000569W WO 2015059530 A1 WO2015059530 A1 WO 2015059530A1
Authority
WO
WIPO (PCT)
Prior art keywords
dome
volume
fluid
containment system
cavity
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.)
Ceased
Application number
PCT/IB2014/000569
Other languages
French (fr)
Inventor
Van-Khoi Vu
Jean-Claude BOURGUIGNON
Bertrand DE-GELIS
Guillaume VAILLANT
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.)
TotalEnergies SE
Original Assignee
Total SE
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 Total SE filed Critical Total SE
Priority to BR112016006924A priority Critical patent/BR112016006924A2/en
Priority to US15/031,154 priority patent/US20160265317A1/en
Publication of WO2015059530A1 publication Critical patent/WO2015059530A1/en
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
    • E21B43/0122—Collecting oil or the like from a submerged leakage
    • E—FIXED CONSTRUCTIONS
    • E02—HYDRAULIC ENGINEERING; FOUNDATIONS; SOIL SHIFTING
    • E02B—HYDRAULIC ENGINEERING
    • E02B15/00—Cleaning or keeping clear the surface of open water; Apparatus therefor
    • E—FIXED CONSTRUCTIONS
    • E02—HYDRAULIC ENGINEERING; FOUNDATIONS; SOIL SHIFTING
    • E02B—HYDRAULIC ENGINEERING
    • E02B15/00—Cleaning or keeping clear the surface of open water; Apparatus therefor
    • E02B2015/005—Tent-like structures for dealing with pollutant emissions below the water surface

Definitions

  • the present invention concerns a containment system for recovering spilled oil that is leaking under water.
  • the present invention concerns more precisely a containment system for recovering a hydrocarbon fluid from a leaking device that is situated at the seafloor and that is leaking the hydrocarbon fluid from a well.
  • the sea water is cold (for example around only 5°C) and at a high pressure.
  • These environment conditions may transform the sea water and hydrocarbon fluid into hydrates having a quasi-solid phase and which can fill and clogged any cavity .
  • Hydrates inhibitors like methanol could be injected to avoid hydrate formation. But, the needed quantity of such chemical is huge and inhibitors are also pollution for the environment.
  • Heating of the containment system could be used to avoid hydrate formation. But, as the volume of cavity of the containment system is great, the heating is slow and amount of heat is too important.
  • One object of the present invention is to provide a containment system that avoids the formation of hydrates inside the dome. More specifically, the aim of the invention is to provide a containment system having a large cavity volume, but that needs a reduced quantity of inhibitors or a reduced amount of heat to avoid hydrates formation and clogging of the containment system.
  • the containment system of present invention is adapted to be landed at the seafloor corresponding to a base level of the containment system. It comprises :
  • dome intended to be secured to the seafloor around the leaking device and forming a cavity under said dome, said cavity being adapted to completely surround and include the leaking device, and to accumulate hydrocarbon fluid coming upwardly from the leaking device, said dome comprising at least one upper output opening adapted to extract the hydrocarbon fluid for recovering, and
  • the dome of the invention is composed at least of a first dome having a first volume adapted to receive the leaking device, and a second dome having a second volume smaller than the first volume, the second dome being situated upper the first dome, and the first and second volumes being in communication via a dome opening.
  • the second volume can be more easily controlled for preventing or remediating hydrates formation.
  • the containment system can be installed more easily without the annoying hydrates.
  • the anti hydrates system may be an injection system that injects injection fluid inside the cavity for preventing or remediating hydrates formation. Then, the second volume can be filled with the injection fluid, and hydrates formation can be prevented inside said second volume .
  • the quantity of injection fluid is reduced compared to the quantity that would be needed to avoid hydrates formation inside the volume of the first dome.
  • the anti hydrates system may be a heating system that heats at least a portion of the cavity, and more particularly the second volume. Then, the second volume is heated to a temperature so as hydrates formation can be prevented inside said second volume.
  • the hydrocarbon fluid can be extracted from the second volume by the output opening situated on the upper portion of the second dome.
  • one and/or other of the following features may optionally be incorporated.
  • the second volume is smaller than a l/4 th of the first volume, and preferably smaller than a l/10 th of the first volume.
  • the second volume is higher than a l/20 th of the first volume .
  • the dome opening is between 2 and 4 meters wide.
  • the first dome is thermally insulated with an insulating material for having an overall heat transfer coefficient of the first dome lower than 1 W.m ⁇ .KT 1 .
  • the anti hydrates system is only situated into or onto the second dome.
  • the anti hydrates system is a heating system for heating at least a portion of the cavity.
  • the anti hydrates system is an injection systems that inputs an injection fluid into the cavity.
  • the injection system comprises a plurality of output ports spread only inside the second volume or at the dome opening, said output ports being fed with the injection fluid .
  • the containment system further comprises a fluid heater for heating the injection fluid before injection into the cavity .
  • the injection fluid comprises one or a combination of the fluid components chosen in the list of water, salted water, dead oil, an alcohol, an ethanol, a methanol, a glycol, an ethylene glycol, a diethylene glycol, and a low-dosage hydrate inhibitor (LDHI) .
  • LDHI low-dosage hydrate inhibitor
  • the containment system further comprises a pipe having an inner tube forming an inner channel, and an outer tube surrounding said inner tube and forming an annular channel, and wherein the inner channel is used to extract the hydrocarbon fluid from the upper output opening and the annular channel is used to feed the injection system with at least an injection fluid, or inversely.
  • Another object of the invention is to provide a method for using a containment system for recovering hydrocarbon fluid from a leaking device that is situated at the seafloor and that is leaking hydrocarbon fluid from a well.
  • the containment system comprises at least:
  • dome forming a cavity under said dome to accumulate hydrocarbon fluid coming upwardly from the leaking device, said dome comprising at least one upper output opening adapted to extract the hydrocarbon fluid for recovering, and - an anti hydrate system that actively prevents or remediates hydrates inside the cavity, and
  • the dome comprises a first dome having a first volume, and a second dome having a second volume smaller than the first volume, the second dome being situated upper the first dome.
  • the method of the invention comprises the following successive steps:
  • the dome can be installed above the leaking device without hydrates formation inside the cavity, and the quantity of injection fluid is lower.
  • one and/or the other of the following features may optionally be incorporated.
  • the anti hydrates system is a heating system for heating at least a portion of the cavity.
  • the anti hydrates system is an injection systems that inputs an injection fluid into the cavity.
  • the injection system injects the injection fluid into the second volume of the second dome before step b) .
  • the containment system further comprises a level sensor and an output valve connected to the upper output opening, and the method further comprises after step b) the following steps:
  • the injection system injects the injection fluid at a velocity that is low, and preferably at a velocity that is lower than 0.5 meter per seconds.
  • the output valve is controlled so as to keep the interface level lower or equal to a level of output of the hydrocarbon fluid from the leaking device.
  • FIG. 1 is a schematic view of a vertical cut of a containment system according to a first embodiment of the invention
  • FIG. 2 is a schematic view of a vertical cut of a containment system according to a second embodiment of the invention.
  • Figures 3a to 3e are an exemplary of a containment system according to the schematic of figure 1, showing a method for using or installing a containment system according to the invention
  • FIG. 4 is a schematic view of a vertical cut of a containment system according to the invention incorporating a separation and mixing function
  • FIG. 5 is a schematic view of a vertical cut of a containment system incorporating a separation and mixing function.
  • the direction Z is a vertical direction.
  • a direction X or Y is a horizontal or lateral direction.
  • FIG. 1 is a first embodiment of a containment system 1 according to the invention.
  • This containment system 1 is adapted for recovering hydrocarbon fluid from a leaking device 2 that is situated at a seafloor 5 of a deep offshore installation.
  • the leaking device 2 is for example the well itself, a pipeline, a blow out preventer device, a wellhead or any device connected to the wellhead.
  • the leaking device 2 is therefore usually a large device. It may be larger than 5 m.
  • the seafloor 5 is for example at more than 1500 meters deep below the sea surface 4. At this depth, the sea water is cold, for example around only 5°C and at high pressure.
  • the hydrocarbon fluid may be liquid oil, natural gas, or a mix of them.
  • the leaking device 2 is leaking a hydrocarbon fluid from an undersea well 3.
  • the hydrocarbon fluid exiting from the undersea may be rather hot, for example above 50°C.
  • the environment cold temperature and high pressure may transform the sea water and hydrocarbon fluid into hydrates having a quasi-solid or solid phase. These hydrates can fill and clogged any cavity.
  • the containment system 1 of present invention is landed and fixed to the seafloor by any means, such as anchoring or heavy weights 29 for compensating the upward Archimedes force applied on the containment system 1 by the hydrocarbon fluid that is lighter than the sea water (lower mass density) .
  • the seafloor corresponds in the present description to a base level of the containment system 1.
  • the other levels are defined going upwards, in the vertical direction Z towards the sea surface 4.
  • the containment system 1 of present invention comprises at least:
  • dome 20 intended to be secured to the seafloor around the leaking device 2 and forming a cavity 21 under said dome 20, said cavity being adapted to completely surround and include the leaking device, and to accumulate the hydrocarbon fluid coming upwardly from the leaking device, said dome comprising at least one upper output opening 22 to extract the hydrocarbon fluid for recovering, and
  • an anti hydrates system 30 that actively prevents or remediates hydrates inside the cavity.
  • the term "actively" means that the anti hydrates system 30 inputs some amount of energy inside the cavity to prevent the hydrates.
  • the added energy may be of any type. It may be a chemical energy and/or a thermal energy.
  • the anti hydrates system 30 is not a "passive" device, just thermally insulating the dome or doing a gravity separation of the components in the fluid inside the dome.
  • the dome 20 is preferably fixed and/or sealed to the seafloor.
  • the dome 20 comprises foot 20c having heavy weights for sealing and securing the dome 20 to the seafloor .
  • the dome 20 completely surrounds the leaking device 2.
  • the dome 20 In a horizontal plane (XY) , the dome 20 has a closed loop shape encompassing the leaking device 2.
  • Said shape may be for example a circle shape, a square shape or any polygonal shape.
  • the dome 20 has a diameter D20. This outer diameter corresponds to a maximum distance between two internal points of the dome, taken in a horizontal plane at a level near the base level BL .
  • the diameter D20 is for example of 6 meters or more.
  • the dome 20 is higher than a total height of the leaking device 2. It has a height H20 of approximately 3 meters or more. It completely includes the leaking device 2 (i.e. the part above the base level. All that is under the seafloor is not taken into account as the dome is sealed to the seafloor) .
  • the dome 20 defines an inner dome volume, called the cavity 21. This volume is isolated (not in communication) with the environment sea water. The thermal exchange between the cold sea water and the hydrocarbon fluid is cancelled. This first effect reduces the hydrate formation.
  • the dome 20 is a hollow structure.
  • the dome 20 according to the invention comprises at least two parts:
  • a second dome (20 2 ) having a second volume smaller than the first volume, said second dome being situated upper the first dome (20i) , and the first and second volumes being in communication via a dome opening 26.
  • the term "dome” means here a general enclosure or container having a downwardly opened portion so as to be positioned above and to enclose a member.
  • the dome has a lateral portion (like a vertical cylinder) that extends vertically from a base level to an upper level and an upper portion (like a cap) that extends horizontally from the upper end of the lateral portion so as to close the upper portion.
  • the dome has an inner cavity with a volume adapted to receive the member.
  • the lateral portion and/or upper portion may have some holes adapted for specific purposes (fluid exchange between the inner volume and the outside of the dome) .
  • the second volume may be smaller than one fourth (l/4 th ) of the first volume.
  • the second volume is smaller than one fifth (l/5 th ) of the first volume.
  • the second volume is smaller than one tenth (l/10 th ) of the first volume.
  • the second volume is therefore much smaller than the first volume, and hydrates formation can be more easily prevented inside the second volume than in the first volume.
  • the second volume is not null.
  • the second volume is higher than one thirtieth (l/30 th ) of the first volume, and more preferably the second volume is higher than one twentieth (l/20 th ) of the first volume.
  • the second volume corresponds to a buffer volume comprised between 3 minutes and 10 minutes of hydrocarbon fluids, when the flow of hydrocarbon fluids from the leaking device 2 is taken into account.
  • the second volume corresponds to a buffer volume higher than 5 minutes of the flow of hydrocarbon fluids from the leaking device 2.
  • the first volume of the first dome 20i corresponds to between 30 minutes to 60 minutes (or more) of the flow of hydrocarbon fluids from the leaking device 2.
  • the leaking device 2 may extend 6 meters in all directions ;
  • the fist dome 2 0 1 may be 7 meters in all directions, having a first volume of approximately 350 m 3 ;
  • the dome opening is between 2 and 4 meters wide (preferably between 3 and 4 meters wide) ;
  • the second dome 20 2 may be less than 4 meters wide in all directions, or less than 3 meters in all directions, or having a second volume lower than 50 m 3 .
  • the leaking device is bigger (e.g. when it is a Christmas tree having a blowout preventer) :
  • the leaking device 2 may extend 9 meters in all directions;
  • the first dome 2 0 1 may be 10 meters in all directions, corresponding to a huge first volume of 1000 m 3 .
  • the first dome 2 0 1 is landed on the seafloor and contains the leaking device 2. It is a hollow structure having :
  • lateral portion 25 extending from the upper portion 24 downwardly between an upper end 25a and a lower end 25b, said lower end 25b comprising for example the foot 20c.
  • the lateral portion 25 has said diameter D20. Its inner diameter is wider than a total wide of the leaking device 2. For example, the inner diameter is of 6 meters or more .
  • the lateral portion 25 of the first dome is downwardly opened so as to surround the leaking device 2.
  • the upper portion 24 of the first dome 2 0 1 comprises the dome opening 26 having of small diameter compared to the dome diameter.
  • the upper portion 24 and/or the dome opening 26 are adapted to be connected to the second dome 20 2 .
  • the dome opening 26 has for example a diameter of 3 meters or less.
  • the second dome 20 2 is secured to the upper portion 24 of the first dome 2 0 1 . It is a hollow structure having a similar general shape as the first dome, i.e. having :
  • the lateral portion of the second dome 20 2 has a diameter wider than the dome opening 26.
  • the diameter of the lateral portion is higher than 3 meters, and preferably lower than 5 meters.
  • the second dome 20 2 comprises downwardly a bottom opening having a width equal to the dome opening 26 or wider than said dome opening.
  • the bottom opening comes substantially into coincidence with the dome opening 26, and the second volume is in communication with the first volume via said dome opening 26 (and reciprocally) .
  • the hydrocarbon fluid that exits from the leaking device 2 is going naturally upwardly from the first volume to the second volume via said dome opening 26.
  • the first and second domes 2 0 l r 20 2 may comprise fastening means so as the second dome 20 2 is automatically secured to the first dome 2 0 1 as soon as the second dome is set down on the first dome.
  • Any known mechanical means can be used for said fastening means, such as pins, spring loaded pins, etc...
  • the fastening means are locked automatically by the setting down of the second dome above the first dome. They might be unlocked manually or remotely or via any actuation mean.
  • the containment system 1 can be composed of a plurality of modules, each one being installed above the other.
  • the modules are preferably automatically secured one to the other by fastening means that automatically lock themselves when a second module is set down above a first module .
  • the upper portion of the second dome 20 2 comprises the upper output opening 22 of the dome 20 and is adapted to be connected to a pipe 50 for extracting the hydrocarbon fluid from the containment system 1 to a recovery boat 6 at the sea surface 4, so as the hydrocarbon fluid is recovered .
  • the upper portion 24 of the first dome 2 0 1 may have a convergent shape from the lateral portion 25 up to the dome opening 26.
  • the dome 20 is a cover that can have advantageously an inverted funnel shape .
  • the hollow structure of the dome 20 (first and second domes 2 0 l r 20 2 ) forms a largely opened cavity 21 in the direction to the seafloor. It is positioned above and around the leaking device 2 so as to accumulate the light hydrocarbon fluid.
  • the cavity 21 accumulates hydrocarbon fluid coming upwardly from the leaking device 2, i.e. oil and/or natural gas.
  • the hydrocarbon fluid fills the upper volume of the cavity, down to an interface level IL.
  • the anti hydrates system 30 is an injection system that injects an injection fluid IF into the cavity 21.
  • the injection system 30 may inject the injection fluid inside the first volume of the first dome 2 0 1 and/or the second volume of the second dome 20 2 .
  • the injection system inputs injection fluid having a chemical effect on the fluids inside the cavity to actively avoid hydrates formation or hydrates agglomeration that may increase fluid viscosity in forming a slurry fluid .
  • the injection system 30 may comprise a plurality of output ports spread only inside the second volume (the volume of the second dome 20 2 ) so as to ensure a treatment of the hydrocarbon inside said second volume. Hydrates formation is then prevented inside the second volume. Then, the containment system cannot be clogged. And, the hydrocarbon fluid can be extracted via the upper output opening 22 of the second dome 20 2 .
  • the injection system 30 may injects injection fluid IF from the upper portion, the lateral portion or from both portions of the second dome 20 2 .
  • the injection system 30 may comprise a plurality of output ports spread near or at the dome opening 26.
  • the injection fluid IF may be sea water pumped near the sea surface 4 via a pump 63.
  • the pumped sea water may be used as it, i.e. at the temperature of sea water at the sea surface 4, or heated by additional means.
  • the injection fluid may be water, salted water, sea water, oil, gas oil, dead oil, or crude oil.
  • the injection fluid may be an alcohol, an ethanol, a methanol, a glycol, an ethylene glycol, a diethylene glycol, or a low-dosage hydrate inhibitor (LDHI) .
  • LDHI low-dosage hydrate inhibitor
  • the injection fluid may be additionally heated by a fluid heater or not, for preventing to form hydrates.
  • the injection fluid is preferably heated.
  • the fluid heater may by on a vessel at sea surface, or integrated in the injection system itself, or integrated in the second dome 20 2 .
  • the injection system 30 preferably injects the injection fluid at a velocity that is low, and preferably at a velocity that is lower than 0.5 meter per seconds.
  • the injection fluid is better mixed to the fluid inside the cavity, and preferably better mixer to the fluid inside the second volume of the second dome 20 2 .
  • the anti hydrates system 30 is a heating system that heats at least a portion of the cavity for actively preventing or remediating hydrates formation inside the cavity and/or for preventing adhesion of hydrates on an inner surface of the first and/or second dome.
  • the heating device inputs heat energy having a thermal effect to actively avoid hydrates formation and/or hydrates adhesion.
  • the heating system is for example a fluid circuit fed with a heated or hot fluid, or a resistive electric circuit.
  • the heating system is for example situated in or on the second dome 20 2 .
  • the second dome 20 2 and/or the second volume of the second dome and/or a portion of the second volume is heated.
  • the boundary layer is eventually less than 10 mm thick, and for example less than 5 mm thick. Thanks to the heated boundary layer, hydrates do not adhere to the inner surface of the second dome 20 2 and can be extracted from the cavity via the flow of hydrocarbon fluid.
  • the term "heated” means having a temperature increase enough to obtain the anti hydrates effect (no formation or no adhesion) .
  • the temperature may be increased of at least 10°C, and preferably between 10°C and 15 °C above a hydrate formation temperature.
  • the hydrate formation temperature is determined by hydrocarbon fluid and the pressure near the leaking device 2 (i.e. the depth) . Temperature-pressure curves for every hydrocarbon fluid are known, these curves identifying the phase changes, and more particularly conditions for hydrates formation .
  • the fluid inside the second dome 20 2 is prevented of hydrates formation and/or hydrates adhesion on inner surface.
  • the hydrocarbon fluid accumulated inside said second dome can be extracted via the upper output opening.
  • the fluid inside the first dome 2 0 1 is itself prevented of hydrates formation by the heat from the hydrocarbon fluid itself, and filling a great portion of the first volume inside the first dome 2 0 1 .
  • the containment system 1 advantageously comprises at least one level sensor 60 for measuring the interface level IL of the fluid interface between sea water and the hydrocarbon fluid inside the dome 20.
  • the level sensor 60 may give a first measurement of a liquid level corresponding to the interface level IL between the liquid component of the hydrocarbon fluid (e.g. oil) and the sea water, and a second measurement of a gas level corresponding to an interface between the liquid component and a gas component (e.g. natural gas ) of the hydrocarbon fluid.
  • a liquid level corresponding to the interface level IL between the liquid component of the hydrocarbon fluid (e.g. oil) and the sea water e.g. oil
  • a gas component e.g. natural gas
  • the containment system 1 may also comprise a temperature sensor 70 for measuring a temperature of the fluid inside cavity 21.
  • the temperature sensor 70 may provide a local temperature value, a mean temperature value of a plurality of locations inside the cavity, or a plurality of temperature values inside the cavity.
  • the containment system 1 may also comprise a pressure sensor for measuring a pressure of the fluid inside cavity 21.
  • the containment system 1 additionally comprises an output valve 62 connected to the upper output opening 22 and/or pipe 50 for outputting the recovered hydrocarbon fluid to the recovery boat 6.
  • the output valve 62 is located in a vessel (as illustrated on figure 1) or just above the dome 20 or integrated in the dome at the upper output opening 22 (as illustrated on figure 2) .
  • a user or a control unit 61 determines or calculates a control value on the bases of a measured value of the interface level IL and/or the temperature inside the cavity and/or a pressure value, and operates the output valve on the bases of the control value for outputting hydrocarbon fluid from the cavity.
  • the user or the control unit 61 may determine the control value to keep the interface level at a constant level inside the cavity 21.
  • the containment system 1 may also comprise a exhaust output valve 64 for example situated above the dome 20 near the upper output opening 22.
  • the exhaust output valve 64 is adapted for opening and/or closing the cavity to the sea environment.
  • the sea output valve 64 is advantageously operated on the bases of an exhaust control value that is opposite to the control value of the output valve 62: the output valve 62 is closed when the exhaust output valve is opened, and the output valve 62 is opened when the exhaust output valve is closed.
  • the pipe 50 is advantageously a two concentric tubes pipe, having an inner pipe 51 forming an inner channel, and an outer tube 52 surrounding said inner pipe 51 and forming an annular channel between the inner tube and the outer tube.
  • the inner channel may be connected to the upper output opening 22 and used to extract the hydrocarbon fluid from the cavity 21.
  • the annular channel may be therefore connected to the injection system 30, and used to feed it with the injection fluid from the surface.
  • the two channel of such pipe can be connected to the dome according to the other inverse possibility without any change.
  • the containment system 1 may also comprise independent pipes: A first pipe 51 connected to the upper output opening 22 and used to extract the hydrocarbon fluid from the cavity 21, and a second pipe 52 connected to the injection system 30 and used to feed it with the injection fluid from the surface.
  • the containment system 1 may comprise other output openings and/or pipes for feeding additionally fluids, or for extracting other fluids, liquid or gases from the cavity .
  • the containment system 1 may comprise a drain valve for purging or limiting the quantity of water inside the cavity 21.
  • Said drain valve might be positioned proximal to the base level BL (seafloor) .
  • the cavity 21 can be used as a phase separator for separating the water and the hydrocarbon fluid, and for separating each phase of the hydrocarbon fluid (oil, gas) so as to extract them separately .
  • the above phase separation is preferably done inside the second volume of the second dome 20 2 .
  • the dome 20 may comprise: - a first output opening for extracting a first phase from the cavity, said first phase being for example an oil phase of the hydrocarbon fluid, and
  • a second output opening for extracting a second phase from the cavity , said second output opening being positioned on the dome at a level proximal to a highest level of the dome, said second phase being lighter than the first phase, and being for example a gas phase of the hydrocarbon fluid.
  • Each output opening (first and second) is connected to a pipe: an oil pipe 51b for extracting oil and a gas pipe 51a for extracting gas.
  • quantities of each phase can be limited inside the cavity 21 to predetermined values.
  • An Archimedes force maximum that applies on the containment system 1 can be predetermined, and the weights of the foot 20c can therefore be predetermined for maintaining the containment system 1 landed at the seafloor 5.
  • the first output opening is positioned at a predetermined level inside the dome. So as the phase separation works properly, an oil-gas interface must be above said predetermined level.
  • the level sensor 60 may provide the level of said oil-gas interface.
  • the containment system 1 comprises a mixer device 80 that mixes the hydrocarbon fluid, and mixes the various phases and components of the hydrocarbon fluid.
  • the mixed fluid is therefore more homogeneous, and more easily transferred or extracted via a pipe, as the flow of said mixed fluid is more constant and continuous.
  • the mixer device 80 is preferably outside the second dome 20 2 as illustrated on the figures.
  • the mixer device 80 is integrated inside the dome 20, and preferably integrated inside the second dome 20 2 .
  • the oil pipe 51b and the gas pipe 51a are connected to the mixer device 80, said mixer device 80 being located outside of the second dome 20 2 . Then, the fluids from each pipe are mixed by the mixer device.
  • the containment system 1 may comprise a plurality of outputs, each of them mixed with a quantity of gas from a gas output via a plurality of mixer devices.
  • the above mixer device 80 can be used in any containment system: in a containment system having only one dome as illustrated on figure 5 and in prior patent applications of the applicant, i.e. patent applications PCT/EP2012/075675, PCT/EP2012 / 075676 , PCT/EP2013/065359, PCT/EP2013/068644 herewith enclosed by reference.
  • the oil pipe 51b is equipped with an oil valve 80b to control the flow of oil fluid, and therefore the mix and its ratio.
  • the oil pipe 51b is equipped with an oil valve 80b
  • the gas pipe 51a is equipped with a gas valve 80a.
  • These valves are manually controlled or remotely controlled (via a Remotely Operated Vehicle) or automatically controlled via the control unit 61 (closed loop control), for example, on the bases of interface level measurements provided by a level sensor 60.
  • the dome 20 may comprises thermal insulating material, so as to thermally insulate the cavity 21 from the cold environment of sea water.
  • the dome 20 may be manufactured with at least a thermally insulating material, said thermally insulating material preferably having a thermal conductivity lower than 0.1 W.m ⁇ .KT 1 .
  • the dome 20 may have an overall heat transfer coefficient lower than 2 W.m ⁇ .KT 1 , and more preferably lower than 1 W.m ⁇ .KT 1 based on the overall internal dome wall surface.
  • the above insulating improvements may apply to all the dome (first and second dome), or the first dome only, or the second dome only, or a portion of them.
  • the first dome 2 0 1 is however preferably thermally insulated so as to keep its huge first volume to a highest temperature as possible, said first volume being heated by the heat of the hydrocarbon fluid outputting from the leaking device 2.
  • thermal insulating materials may be used: synthetic material such as Polyurethane (PU) or polystyrene material, or a fibre textile with Polyvinyl chloride (PVC) coating or PU coating, or Alcryn ®.
  • the thermal insulating material may be foam, or a gel contained inside a double wall structure.
  • the thermal insulation of the dome 20 passively insulates the cavity 21, while the injection system 30 actively insulates the cavity 21. Both effects prevent the formation of hydrates inside the cavity 21.
  • the cavity 21 is a volume storing a quantity of hydrocarbon fluid and absorbing the fluctuations of hydrocarbon fluid flows.
  • the dome 20 comprises an over pressure valve 23 that extract fluid out of the cavity and into the environment if a pressure difference between the cavity 21 and the environment exceeds a predetermined pressure limit.
  • the predetermined pressure limit is for example of
  • the over pressure valve is for example a ball check valve.
  • the ball check valve comprises a support element, a ball, and a spring that loads the ball to the support element so as to close an opening.
  • the tuning of the spring load is adapted to the predetermined pressure limit.
  • the cavity 21 is closed, and if hydrates formation is prevented, the fluid inside the cavity is rapidly heated by the hydrocarbon fluid itself outputting from the leaking device 2.
  • the over pressure valve 23 insures that the pressure inside the cavity is not increasing, and then insuring that the containment system is not destroyed.
  • the predetermined pressure limit may insure that hydrates formation is prevented.
  • FIG. 2 is a second embodiment of a containment system 1 according to the invention.
  • This containment system 1 is similar to the first embodiment. It comprises the same elements as the first embodiment, and can have the same variants as disclosed above.
  • the second embodiment of the containment system 1 differs in that:
  • the first dome 2 0 1 comprises a lower output opening 23 that is situated on the lateral portion 25 of the dome so as the first dome is opened to the sea at a low level DL near the seafloor, and
  • the wall 10 extends from a lower end 10a at the base level to an upper end 10b at a first level LI, said wall 10 being substantially sealed to the seafloor around the leaking device 2.
  • the wall 10 and the dome 20 are preferably independent parts or members, each of them installed at the seafloor independently from the other, and each of them being fixed preferably to the seafloor.
  • the wall 10 is installed on the seafloor before the dome 20, so as to cancel the convection of cold sea water before the installation of the dome 20.
  • the wall 10 comprises foot 10c having heavy weights for sealing and securing the wall 10 to the seafloor.
  • the dome 20 may have similarly foot 20c for securing it to the seafloor.
  • the wall 10 completely surrounds the leaking device 2.
  • the wall 10 In a horizontal plane (XY) , the wall 10 has a closed loop shape encompassing the leaking device 2.
  • Said shape may be for example a circle shape, a square shape or any polygonal shape.
  • the wall 10 has an outer diameter D10. This outer diameter corresponds to a maximum distance between two external points of the wall, taken in an horizontal plane at a level near the first level LI.
  • the outer diameter D10 is for example of 6 meters or more.
  • the wall 10 then extends upwardly from a lower end 10a at the base level BL to an upper end 10b at the first level LI.
  • the first level LI is preferably higher than a total height of the leaking device 2.
  • the wall 10 defines an inner wall volume 11. This volume 11 is substantially isolated (not in direct communication) with the environment sea water, according to a horizontal direction (XY) .
  • the volume 11 is opened upwardly, according to a vertical direction (Z) .
  • Such wall 10 cancels any horizontal flow of sea water that is usually sucked by the flow of hydrocarbon fluid outputting from the leaking device 2. This dramatically reduces the thermal convection exchange between the cold sea water and the hydrocarbon fluid. This first effect cancels the hydrate formation.
  • the first level LI is preferably at least twice the total height of the leaking device 2, and more preferably three times higher than it.
  • the wall 10 can cancel efficiently the convection effect of cold sea water.
  • Figures 3a to 3e are an exemplary of a containment system according to the schematic of figure 1 and also showing a method for using or installing said containment system.
  • the dome 20 is composed of a base tubular structure represented on figure 3a, said base tubular structure comprising the foot 20c for securing the dome to the seafloor, and a tubular structure extending upwardly from the lower end 25b (attached to said foot 20c) to the upper end 25a and extending in a radial direction from said upper end 25a.
  • the tubular structure is a rigid frame giving a general shape to the first dome 2 0 1 . But, it does not close the volume of the cavity 21.
  • the tubular structure supports a first cover 27 for covering laterally said tubular structure and forming the lateral portion of the first dome 2 0 1 .
  • the first cover 27 is a cylindrical tube that covers and closes the lateral portion 25 of the first dome 2 0 1 .
  • the first cover shape is adapted to the lateral shape of the tubular structure.
  • the first cover is attached to (secured to) said tubular structure by any securing means.
  • the tubular structure also supports a second cover 28 for covering upwardly the tubular structure and forming the upper portion of the first dome 2 0 1 .
  • the second cover 28 is an annular part, having a lower ring 28a that fits to the upper end 25a of the first cover 27, a intermediate ring 28b having an annular and conical shape extending from said lower ring 28a, and an upper ring 28c extending from the centre of the intermediate ring.
  • the upper ring 28c is a cylindrical tube that keeps the dome opening 26 opened and that is adapted for receiving the second dome 20 2 .
  • the second cover shape is adapted to the upper shape of the tubular structure. The second cover is attached to (secured to) said tubular structure by any securing means .
  • the fist and/or second covers 27, 28 may be rigid elements, for example made of welded metal sheets.
  • the first and/or second covers 27, 28 may be flexible elements, for example made of textile. They may be extendable, or deployable, or telescopic from a retracted position to a deployed position that covers the surface of the lateral portion 25 or upper portion 24 of the first dome 2 0 1 .
  • the second dome 20 2 is a smaller, and may be a rigid box adapted to be attached above the upper ring 28c of the second cover 28.
  • the method for using or installing the containment system 1 according to the invention is now explained with the figures 3a to 3e.
  • a base tubular structure is landed and sealed around the leaking device 2, said leaking device being substantially situated at the centre of the base tubular structure (according to a horizontal XY direction) .
  • the leaking device 2 is completely inside the volume of the base tubular structure, said volume being the first volume of the first dome 2 0 1 .
  • the first cover 27 is mounted on and secured to the base tubular structure so as to close the lateral portion 25 of the dome.
  • the second cover 28 is mounted on and secured to the base tubular structure and above the first cover 27 so as to close the upper portion of the dome 24, a dome opening 26 being kept opened.
  • the second dome 202 is moved downwardly towards the first dome 20a.
  • the injection system 30 may inject the injection fluid IF into the second volume of the second dome 20 2 .
  • This second volume is rapidly filled with the injection fluid. Hydrates formation is then prevented inside this second volume.
  • the quantity of injection fluid needed to fill said second volume is much smaller than the one that would be necessary to fill the first volume or to prevent hydrates formation inside a dome having the first volume .
  • the second dome 20 2 is secured to the first dome 2 0 1 .
  • the containment system 1 comprises:
  • dome 20 forming a cavity 21 under said dome to accumulate hydrocarbon fluid coming upwardly from the leaking device, said dome comprising at least one upper output opening 22 adapted to extract the hydrocarbon fluid for recovering, and
  • an injection system 30 that inputs an injection fluid IF into the cavity for preventing or remediating hydrates inside the cavity.
  • the dome 20 further comprises a first dome 2 0 1 having a first volume, and a second dome 20 2 having a second volume smaller than the first volume, the second dome 20 2 being situated upper the first dome 2 0 1 .
  • the method according to the invention for using or installing the containment system 1 comprises the following successive steps:
  • the volume the quantity of needed injection fluid to prevent hydrates formation is smaller.
  • the flow of this injection fluid is highly reduced.
  • the time delay for installing the second dome 20 2 above the first dome 2 0 1 is shorter than the time delay for installing the first dome on the seafloor. The risk of hydrates formation is then reduced.
  • the injection system 30 preferably injects the injection fluid IF into the second volume of the second dome 20 2 before the second dome is installed upper the first dome 2 0 1 .
  • the second volume is completely filled with injection fluid before said installation of the second dome .
  • the containment system 1 further comprises a sensor 60 and an output valve 62 connected to the upper output opening 22.
  • a sensor 60 and an output valve 62 connected to the upper output opening 22.
  • the quantity of hydrocarbon fluid can be kept high. This fluid is relatively hot, and hydrates formation is prevented .
  • the output valve 62 is controlled so as to keep the interface level IL lower or equal to a level LL of output of the hydrocarbon fluid from the leaking device.
  • the jet of hydrocarbon fluid from the leaking device 2 is directly entering the hydrocarbon fluid accumulated inside the dome.
  • the hydrocarbon fluid is relatively hot, and cold water mixture is also prevented. Hydrates formation is therefore prevented.

Landscapes

  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Chemical & Material Sciences (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Structural Engineering (AREA)
  • Civil Engineering (AREA)
  • Mechanical Engineering (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

A containment system (1) for recovering hydrocarbon fluid from a leaking device (2) comprising a dome (20) sealed to the seafloor around the leaking device and forming a cavity (21) for accumulating hydrocarbon fluid. The dome (20) comprises a first dome (201) and a second dome (202) connected upper to the first dome. The second volume of the second dome is smaller than the first volume of the first dome.

Description

A containment system and
a method for using said containment system.
FIELD OF THE INVENTION
The present invention concerns a containment system for recovering spilled oil that is leaking under water.
BACKGROUND OF THE INVENTION
The present invention concerns more precisely a containment system for recovering a hydrocarbon fluid from a leaking device that is situated at the seafloor and that is leaking the hydrocarbon fluid from a well.
Recovering oil that is leaking from an under water oil device is a great problem, especially for oil device that are installed at deep sea floor.
The explosion on the "Deepwater Horizon" platform in the Gulf of Mexico demonstrated how much such a containment system is difficult to control.
One of the main problems was the formation of hydrates that clogged the used containment system.
For example, at a depth of around 1500 meters, the sea water is cold (for example around only 5°C) and at a high pressure. These environment conditions may transform the sea water and hydrocarbon fluid into hydrates having a quasi-solid phase and which can fill and clogged any cavity .
Hydrates inhibitors like methanol could be injected to avoid hydrate formation. But, the needed quantity of such chemical is huge and inhibitors are also pollution for the environment.
Heating of the containment system could be used to avoid hydrate formation. But, as the volume of cavity of the containment system is great, the heating is slow and amount of heat is too important. OBJECTS AND SUMMARY OF THE INVENTION
One object of the present invention is to provide a containment system that avoids the formation of hydrates inside the dome. More specifically, the aim of the invention is to provide a containment system having a large cavity volume, but that needs a reduced quantity of inhibitors or a reduced amount of heat to avoid hydrates formation and clogging of the containment system.
To this effect, the containment system of present invention is adapted to be landed at the seafloor corresponding to a base level of the containment system. It comprises :
- a dome intended to be secured to the seafloor around the leaking device and forming a cavity under said dome, said cavity being adapted to completely surround and include the leaking device, and to accumulate hydrocarbon fluid coming upwardly from the leaking device, said dome comprising at least one upper output opening adapted to extract the hydrocarbon fluid for recovering, and
- an anti hydrates system that actively prevents or remediates hydrates inside the cavity.
The dome of the invention is composed at least of a first dome having a first volume adapted to receive the leaking device, and a second dome having a second volume smaller than the first volume, the second dome being situated upper the first dome, and the first and second volumes being in communication via a dome opening.
Thanks to these features, the second volume can be more easily controlled for preventing or remediating hydrates formation. The containment system can be installed more easily without the annoying hydrates.
The anti hydrates system may be an injection system that injects injection fluid inside the cavity for preventing or remediating hydrates formation. Then, the second volume can be filled with the injection fluid, and hydrates formation can be prevented inside said second volume .
The quantity of injection fluid is reduced compared to the quantity that would be needed to avoid hydrates formation inside the volume of the first dome.
The anti hydrates system may be a heating system that heats at least a portion of the cavity, and more particularly the second volume. Then, the second volume is heated to a temperature so as hydrates formation can be prevented inside said second volume.
Therefore, the hydrocarbon fluid can be extracted from the second volume by the output opening situated on the upper portion of the second dome.
In various embodiments of the containment system, one and/or other of the following features may optionally be incorporated.
According to an aspect of the containment system, the second volume is smaller than a l/4th of the first volume, and preferably smaller than a l/10th of the first volume.
According to an aspect of the containment system, the second volume is higher than a l/20th of the first volume .
According to an aspect of the containment system, the dome opening is between 2 and 4 meters wide.
According to an aspect of the containment system, the first dome is thermally insulated with an insulating material for having an overall heat transfer coefficient of the first dome lower than 1 W.m^.KT1.
According to an aspect of the containment system, the anti hydrates system is only situated into or onto the second dome.
According to an aspect of the containment system, the anti hydrates system is a heating system for heating at least a portion of the cavity.
According to an aspect of the containment system, the anti hydrates system is an injection systems that inputs an injection fluid into the cavity.
According to an aspect of the containment system, the injection system comprises a plurality of output ports spread only inside the second volume or at the dome opening, said output ports being fed with the injection fluid .
According to an aspect of the containment system, the containment system further comprises a fluid heater for heating the injection fluid before injection into the cavity .
According to an aspect of the containment system, the injection fluid comprises one or a combination of the fluid components chosen in the list of water, salted water, dead oil, an alcohol, an ethanol, a methanol, a glycol, an ethylene glycol, a diethylene glycol, and a low-dosage hydrate inhibitor (LDHI) .
According to an aspect of the containment system, the containment system further comprises a pipe having an inner tube forming an inner channel, and an outer tube surrounding said inner tube and forming an annular channel, and wherein the inner channel is used to extract the hydrocarbon fluid from the upper output opening and the annular channel is used to feed the injection system with at least an injection fluid, or inversely.
Another object of the invention is to provide a method for using a containment system for recovering hydrocarbon fluid from a leaking device that is situated at the seafloor and that is leaking hydrocarbon fluid from a well. The containment system comprises at least:
- a dome forming a cavity under said dome to accumulate hydrocarbon fluid coming upwardly from the leaking device, said dome comprising at least one upper output opening adapted to extract the hydrocarbon fluid for recovering, and - an anti hydrate system that actively prevents or remediates hydrates inside the cavity, and
- the dome comprises a first dome having a first volume, and a second dome having a second volume smaller than the first volume, the second dome being situated upper the first dome.
The method of the invention comprises the following successive steps:
a) installing the first dome (20i) on the seafloor around the leaking device, the cavity completely surrounding and including the leaking device,
b) installing the second dome (202) upper the first dome (20i) so as the first and second volumes are in communication via a dome opening (26) .
Thanks to the above method, the dome can be installed above the leaking device without hydrates formation inside the cavity, and the quantity of injection fluid is lower.
In preferred embodiments of the method proposed by the invention, one and/or the other of the following features may optionally be incorporated.
According to an aspect of the method, the anti hydrates system is a heating system for heating at least a portion of the cavity.
According to an aspect of the method, the anti hydrates system is an injection systems that inputs an injection fluid into the cavity.
According to an aspect of the method, the injection system injects the injection fluid into the second volume of the second dome before step b) .
According to an aspect of the method, the containment system further comprises a level sensor and an output valve connected to the upper output opening, and the method further comprises after step b) the following steps:
c) measuring by the level sensor an interface level of a fluid interface between hydrocarbon fluid and any other fluid inside the dome,
d) controlling the output valve on the bases of the interface level measured by the level sensor for outputting hydrocarbon fluid from the cavity.
According to an aspect of the method, the injection system injects the injection fluid at a velocity that is low, and preferably at a velocity that is lower than 0.5 meter per seconds.
According to an aspect of the method, at step d) , the output valve is controlled so as to keep the interface level lower or equal to a level of output of the hydrocarbon fluid from the leaking device.
BRIEF DESCRIPTION OF THE DRAWINGS
Other features and advantages of the invention will be apparent from the following detailed description of at least one of its embodiments given by way of non-limiting example, with reference to the accompanying drawings. In the drawings :
- Figure 1 is a schematic view of a vertical cut of a containment system according to a first embodiment of the invention;
- Figure 2 is a schematic view of a vertical cut of a containment system according to a second embodiment of the invention;
- Figures 3a to 3e are an exemplary of a containment system according to the schematic of figure 1, showing a method for using or installing a containment system according to the invention;
- Figure 4 is a schematic view of a vertical cut of a containment system according to the invention incorporating a separation and mixing function, and
- Figure 5 is a schematic view of a vertical cut of a containment system incorporating a separation and mixing function.
In the various figures, the same reference numbers indicate identical or similar elements. The direction Z is a vertical direction. A direction X or Y is a horizontal or lateral direction. These are indications for the understanding of the invention.
MORE DETAILLED DESCRIPTION
Figure 1 is a first embodiment of a containment system 1 according to the invention. This containment system 1 is adapted for recovering hydrocarbon fluid from a leaking device 2 that is situated at a seafloor 5 of a deep offshore installation. The leaking device 2 is for example the well itself, a pipeline, a blow out preventer device, a wellhead or any device connected to the wellhead. The leaking device 2 is therefore usually a large device. It may be larger than 5 m. The seafloor 5 is for example at more than 1500 meters deep below the sea surface 4. At this depth, the sea water is cold, for example around only 5°C and at high pressure.
The hydrocarbon fluid may be liquid oil, natural gas, or a mix of them.
The leaking device 2 is leaking a hydrocarbon fluid from an undersea well 3. The hydrocarbon fluid exiting from the undersea may be rather hot, for example above 50°C. However, the environment cold temperature and high pressure may transform the sea water and hydrocarbon fluid into hydrates having a quasi-solid or solid phase. These hydrates can fill and clogged any cavity.
The containment system 1 of present invention is landed and fixed to the seafloor by any means, such as anchoring or heavy weights 29 for compensating the upward Archimedes force applied on the containment system 1 by the hydrocarbon fluid that is lighter than the sea water (lower mass density) . The seafloor corresponds in the present description to a base level of the containment system 1. The other levels are defined going upwards, in the vertical direction Z towards the sea surface 4. The containment system 1 of present invention comprises at least:
- a dome 20 intended to be secured to the seafloor around the leaking device 2 and forming a cavity 21 under said dome 20, said cavity being adapted to completely surround and include the leaking device, and to accumulate the hydrocarbon fluid coming upwardly from the leaking device, said dome comprising at least one upper output opening 22 to extract the hydrocarbon fluid for recovering, and
- an anti hydrates system 30 that actively prevents or remediates hydrates inside the cavity.
The term "actively" means that the anti hydrates system 30 inputs some amount of energy inside the cavity to prevent the hydrates. The added energy may be of any type. It may be a chemical energy and/or a thermal energy. The anti hydrates system 30 is not a "passive" device, just thermally insulating the dome or doing a gravity separation of the components in the fluid inside the dome.
The dome 20 is preferably fixed and/or sealed to the seafloor.
For example, the dome 20 comprises foot 20c having heavy weights for sealing and securing the dome 20 to the seafloor .
The dome 20 completely surrounds the leaking device 2. In a horizontal plane (XY) , the dome 20 has a closed loop shape encompassing the leaking device 2. Said shape may be for example a circle shape, a square shape or any polygonal shape.
The dome 20 has a diameter D20. This outer diameter corresponds to a maximum distance between two internal points of the dome, taken in a horizontal plane at a level near the base level BL . The diameter D20 is for example of 6 meters or more.
The dome 20 is higher than a total height of the leaking device 2. It has a height H20 of approximately 3 meters or more. It completely includes the leaking device 2 (i.e. the part above the base level. All that is under the seafloor is not taken into account as the dome is sealed to the seafloor) .
The dome 20 defines an inner dome volume, called the cavity 21. This volume is isolated (not in communication) with the environment sea water. The thermal exchange between the cold sea water and the hydrocarbon fluid is cancelled. This first effect reduces the hydrate formation.
The dome 20 is a hollow structure.
The dome 20 according to the invention comprises at least two parts:
- a first dome (20i) having a first volume for receiving the leaking device, and
- a second dome (202) having a second volume smaller than the first volume, said second dome being situated upper the first dome (20i) , and the first and second volumes being in communication via a dome opening 26.
The term "dome" means here a general enclosure or container having a downwardly opened portion so as to be positioned above and to enclose a member. The dome has a lateral portion (like a vertical cylinder) that extends vertically from a base level to an upper level and an upper portion (like a cap) that extends horizontally from the upper end of the lateral portion so as to close the upper portion. The dome has an inner cavity with a volume adapted to receive the member. The lateral portion and/or upper portion may have some holes adapted for specific purposes (fluid exchange between the inner volume and the outside of the dome) .
The second volume may be smaller than one fourth (l/4th) of the first volume. Preferably, the second volume is smaller than one fifth (l/5th) of the first volume. Preferably, the second volume is smaller than one tenth (l/10th) of the first volume.
The second volume is therefore much smaller than the first volume, and hydrates formation can be more easily prevented inside the second volume than in the first volume.
The second volume is not null. Preferably, the second volume is higher than one thirtieth (l/30th) of the first volume, and more preferably the second volume is higher than one twentieth (l/20th) of the first volume.
The second volume corresponds to a buffer volume comprised between 3 minutes and 10 minutes of hydrocarbon fluids, when the flow of hydrocarbon fluids from the leaking device 2 is taken into account. Preferably, the second volume corresponds to a buffer volume higher than 5 minutes of the flow of hydrocarbon fluids from the leaking device 2.
In comparison, the first volume of the first dome 20i corresponds to between 30 minutes to 60 minutes (or more) of the flow of hydrocarbon fluids from the leaking device 2.
For example (first example) :
- the leaking device 2 may extend 6 meters in all directions ;
- the fist dome 2 01 may be 7 meters in all directions, having a first volume of approximately 350 m3;
- the dome opening is between 2 and 4 meters wide (preferably between 3 and 4 meters wide) ; and
- the second dome 202 may be less than 4 meters wide in all directions, or less than 3 meters in all directions, or having a second volume lower than 50 m3.
For example (second example), the leaking device is bigger (e.g. when it is a Christmas tree having a blowout preventer) :
- the leaking device 2 may extend 9 meters in all directions;
- the first dome 2 01 may be 10 meters in all directions, corresponding to a huge first volume of 1000 m3.
The other features may be similar or identical to first example.
The first dome 2 01 is landed on the seafloor and contains the leaking device 2. It is a hollow structure having :
- an upper portion 24 extending in a radial direction to an outer peripheral end 24a, said radial direction being perpendicular to the vertical direction AX (equal to direction Z on the figure) , and
- a lateral portion 25 extending from the upper portion 24 downwardly between an upper end 25a and a lower end 25b, said lower end 25b comprising for example the foot 20c.
The lateral portion 25 has said diameter D20. Its inner diameter is wider than a total wide of the leaking device 2. For example, the inner diameter is of 6 meters or more .
The lateral portion 25 of the first dome is downwardly opened so as to surround the leaking device 2.
The upper portion 24 of the first dome 2 01 comprises the dome opening 26 having of small diameter compared to the dome diameter. The upper portion 24 and/or the dome opening 26 are adapted to be connected to the second dome 202. The dome opening 26 has for example a diameter of 3 meters or less.
The second dome 202 is secured to the upper portion 24 of the first dome 2 01 . It is a hollow structure having a similar general shape as the first dome, i.e. having :
- an upper portion, and
- a lateral portion extending from the upper portion downwardly between an upper end and a lower end.
The lateral portion of the second dome 202 has a diameter wider than the dome opening 26. For example, the diameter of the lateral portion is higher than 3 meters, and preferably lower than 5 meters.
The second dome 202 comprises downwardly a bottom opening having a width equal to the dome opening 26 or wider than said dome opening. When the second dome 202 is secured above the first dome 2 0 l r the bottom opening comes substantially into coincidence with the dome opening 26, and the second volume is in communication with the first volume via said dome opening 26 (and reciprocally) . The hydrocarbon fluid that exits from the leaking device 2 is going naturally upwardly from the first volume to the second volume via said dome opening 26.
The first and second domes 2 0 l r 202 may comprise fastening means so as the second dome 202 is automatically secured to the first dome 2 01 as soon as the second dome is set down on the first dome. Any known mechanical means can be used for said fastening means, such as pins, spring loaded pins, etc... The fastening means are locked automatically by the setting down of the second dome above the first dome. They might be unlocked manually or remotely or via any actuation mean.
The containment system 1 can be composed of a plurality of modules, each one being installed above the other. The modules are preferably automatically secured one to the other by fastening means that automatically lock themselves when a second module is set down above a first module .
The upper portion of the second dome 202 comprises the upper output opening 22 of the dome 20 and is adapted to be connected to a pipe 50 for extracting the hydrocarbon fluid from the containment system 1 to a recovery boat 6 at the sea surface 4, so as the hydrocarbon fluid is recovered .
In a vertical plane (XZ), the upper portion 24 of the first dome 2 01 may have a convergent shape from the lateral portion 25 up to the dome opening 26. The dome 20 is a cover that can have advantageously an inverted funnel shape .
The hollow structure of the dome 20 (first and second domes 2 0 l r 202) forms a largely opened cavity 21 in the direction to the seafloor. It is positioned above and around the leaking device 2 so as to accumulate the light hydrocarbon fluid.
The cavity 21 accumulates hydrocarbon fluid coming upwardly from the leaking device 2, i.e. oil and/or natural gas. The hydrocarbon fluid fills the upper volume of the cavity, down to an interface level IL.
According to a first variant, the anti hydrates system 30 is an injection system that injects an injection fluid IF into the cavity 21. The injection system 30 may inject the injection fluid inside the first volume of the first dome 2 01 and/or the second volume of the second dome 202.
The injection system inputs injection fluid having a chemical effect on the fluids inside the cavity to actively avoid hydrates formation or hydrates agglomeration that may increase fluid viscosity in forming a slurry fluid .
The injection system 30 may comprise a plurality of output ports spread only inside the second volume (the volume of the second dome 202) so as to ensure a treatment of the hydrocarbon inside said second volume. Hydrates formation is then prevented inside the second volume. Then, the containment system cannot be clogged. And, the hydrocarbon fluid can be extracted via the upper output opening 22 of the second dome 202.
The injection system 30 may injects injection fluid IF from the upper portion, the lateral portion or from both portions of the second dome 202.
The injection system 30 may comprise a plurality of output ports spread near or at the dome opening 26. The injection fluid IF may be sea water pumped near the sea surface 4 via a pump 63. The pumped sea water may be used as it, i.e. at the temperature of sea water at the sea surface 4, or heated by additional means.
The injection fluid may be water, salted water, sea water, oil, gas oil, dead oil, or crude oil.
The injection fluid may be an alcohol, an ethanol, a methanol, a glycol, an ethylene glycol, a diethylene glycol, or a low-dosage hydrate inhibitor (LDHI) .
The injection fluid may be additionally heated by a fluid heater or not, for preventing to form hydrates. In case of use water, the injection fluid is preferably heated. The fluid heater may by on a vessel at sea surface, or integrated in the injection system itself, or integrated in the second dome 202. The injection system 30 preferably injects the injection fluid at a velocity that is low, and preferably at a velocity that is lower than 0.5 meter per seconds. The injection fluid is better mixed to the fluid inside the cavity, and preferably better mixer to the fluid inside the second volume of the second dome 202.
According to a second variant, the anti hydrates system 30 is a heating system that heats at least a portion of the cavity for actively preventing or remediating hydrates formation inside the cavity and/or for preventing adhesion of hydrates on an inner surface of the first and/or second dome.
The heating device inputs heat energy having a thermal effect to actively avoid hydrates formation and/or hydrates adhesion.
The heating system is for example a fluid circuit fed with a heated or hot fluid, or a resistive electric circuit. The heating system is for example situated in or on the second dome 202. The second dome 202 and/or the second volume of the second dome and/or a portion of the second volume is heated. For example, only a boundary layer above the inner surface is heated. The boundary layer is eventually less than 10 mm thick, and for example less than 5 mm thick. Thanks to the heated boundary layer, hydrates do not adhere to the inner surface of the second dome 202 and can be extracted from the cavity via the flow of hydrocarbon fluid.
The term "heated" means having a temperature increase enough to obtain the anti hydrates effect (no formation or no adhesion) . For example, the temperature may be increased of at least 10°C, and preferably between 10°C and 15 °C above a hydrate formation temperature. The hydrate formation temperature is determined by hydrocarbon fluid and the pressure near the leaking device 2 (i.e. the depth) . Temperature-pressure curves for every hydrocarbon fluid are known, these curves identifying the phase changes, and more particularly conditions for hydrates formation .
The fluid inside the second dome 202 is prevented of hydrates formation and/or hydrates adhesion on inner surface. The hydrocarbon fluid accumulated inside said second dome can be extracted via the upper output opening.
The fluid inside the first dome 2 01 is itself prevented of hydrates formation by the heat from the hydrocarbon fluid itself, and filling a great portion of the first volume inside the first dome 2 01 .
In all the variants, the containment system 1 advantageously comprises at least one level sensor 60 for measuring the interface level IL of the fluid interface between sea water and the hydrocarbon fluid inside the dome 20.
The level sensor 60 may give a first measurement of a liquid level corresponding to the interface level IL between the liquid component of the hydrocarbon fluid (e.g. oil) and the sea water, and a second measurement of a gas level corresponding to an interface between the liquid component and a gas component (e.g. natural gas ) of the hydrocarbon fluid.
The containment system 1 may also comprise a temperature sensor 70 for measuring a temperature of the fluid inside cavity 21. The temperature sensor 70 may provide a local temperature value, a mean temperature value of a plurality of locations inside the cavity, or a plurality of temperature values inside the cavity.
The containment system 1 may also comprise a pressure sensor for measuring a pressure of the fluid inside cavity 21.
The containment system 1 additionally comprises an output valve 62 connected to the upper output opening 22 and/or pipe 50 for outputting the recovered hydrocarbon fluid to the recovery boat 6. The output valve 62 is located in a vessel (as illustrated on figure 1) or just above the dome 20 or integrated in the dome at the upper output opening 22 (as illustrated on figure 2) .
Then, a user or a control unit 61 determines or calculates a control value on the bases of a measured value of the interface level IL and/or the temperature inside the cavity and/or a pressure value, and operates the output valve on the bases of the control value for outputting hydrocarbon fluid from the cavity. The user or the control unit 61 may determine the control value to keep the interface level at a constant level inside the cavity 21.
The containment system 1 may also comprise a exhaust output valve 64 for example situated above the dome 20 near the upper output opening 22. The exhaust output valve 64 is adapted for opening and/or closing the cavity to the sea environment.
The sea output valve 64 is advantageously operated on the bases of an exhaust control value that is opposite to the control value of the output valve 62: the output valve 62 is closed when the exhaust output valve is opened, and the output valve 62 is opened when the exhaust output valve is closed.
The pipe 50 is advantageously a two concentric tubes pipe, having an inner pipe 51 forming an inner channel, and an outer tube 52 surrounding said inner pipe 51 and forming an annular channel between the inner tube and the outer tube. The inner channel may be connected to the upper output opening 22 and used to extract the hydrocarbon fluid from the cavity 21. The annular channel may be therefore connected to the injection system 30, and used to feed it with the injection fluid from the surface. However, it is apparent that the two channel of such pipe can be connected to the dome according to the other inverse possibility without any change.
The containment system 1 may also comprise independent pipes: A first pipe 51 connected to the upper output opening 22 and used to extract the hydrocarbon fluid from the cavity 21, and a second pipe 52 connected to the injection system 30 and used to feed it with the injection fluid from the surface.
The containment system 1 may comprise other output openings and/or pipes for feeding additionally fluids, or for extracting other fluids, liquid or gases from the cavity .
For example, the containment system 1 may comprise a drain valve for purging or limiting the quantity of water inside the cavity 21. Said drain valve might be positioned proximal to the base level BL (seafloor) .
Advantageously, the cavity 21 can be used as a phase separator for separating the water and the hydrocarbon fluid, and for separating each phase of the hydrocarbon fluid (oil, gas) so as to extract them separately .
The above phase separation is preferably done inside the second volume of the second dome 202.
To this end, the dome 20 may comprise: - a first output opening for extracting a first phase from the cavity, said first phase being for example an oil phase of the hydrocarbon fluid, and
- a second output opening for extracting a second phase from the cavity , said second output opening being positioned on the dome at a level proximal to a highest level of the dome, said second phase being lighter than the first phase, and being for example a gas phase of the hydrocarbon fluid.
Each output opening (first and second) is connected to a pipe: an oil pipe 51b for extracting oil and a gas pipe 51a for extracting gas.
Thanks to the above first and second output openings, quantities of each phase (oil, gas) can be limited inside the cavity 21 to predetermined values. An Archimedes force maximum that applies on the containment system 1 can be predetermined, and the weights of the foot 20c can therefore be predetermined for maintaining the containment system 1 landed at the seafloor 5.
The first output opening is positioned at a predetermined level inside the dome. So as the phase separation works properly, an oil-gas interface must be above said predetermined level. The level sensor 60 may provide the level of said oil-gas interface.
Eventually, as illustrated on figure 4, the containment system 1 comprises a mixer device 80 that mixes the hydrocarbon fluid, and mixes the various phases and components of the hydrocarbon fluid. The mixed fluid is therefore more homogeneous, and more easily transferred or extracted via a pipe, as the flow of said mixed fluid is more constant and continuous.
The mixer device 80 is preferably outside the second dome 202 as illustrated on the figures.
Eventually the mixer device 80 is integrated inside the dome 20, and preferably integrated inside the second dome 202. Eventually, the oil pipe 51b and the gas pipe 51a are connected to the mixer device 80, said mixer device 80 being located outside of the second dome 202. Then, the fluids from each pipe are mixed by the mixer device.
In both cases, thanks to the mixer device 80, only one pipe is needed to extract all the components of the hydrocarbon fluid from the seafloor to the sea surface. It is therefore less expensive and the installation is more rapidly installed above the leaking device 2.
The containment system 1 may comprise a plurality of outputs, each of them mixed with a quantity of gas from a gas output via a plurality of mixer devices.
Then, the above mixer device 80 can be used in any containment system: in a containment system having only one dome as illustrated on figure 5 and in prior patent applications of the applicant, i.e. patent applications PCT/EP2012/075675, PCT/EP2012 / 075676 , PCT/EP2013/065359, PCT/EP2013/068644 herewith enclosed by reference.
According to a first variant illustrated on figure 4, the oil pipe 51b is equipped with an oil valve 80b to control the flow of oil fluid, and therefore the mix and its ratio.
According to a second variant illustrated on figure 5, the oil pipe 51b is equipped with an oil valve 80b, and the gas pipe 51a is equipped with a gas valve 80a. These valves are manually controlled or remotely controlled (via a Remotely Operated Vehicle) or automatically controlled via the control unit 61 (closed loop control), for example, on the bases of interface level measurements provided by a level sensor 60.
Moreover, the dome 20 may comprises thermal insulating material, so as to thermally insulate the cavity 21 from the cold environment of sea water. Ideally, the dome 20 may be manufactured with at least a thermally insulating material, said thermally insulating material preferably having a thermal conductivity lower than 0.1 W.m^.KT1. The dome 20 may have an overall heat transfer coefficient lower than 2 W.m^.KT1, and more preferably lower than 1 W.m^.KT1 based on the overall internal dome wall surface.
The above insulating improvements may apply to all the dome (first and second dome), or the first dome only, or the second dome only, or a portion of them.
The first dome 2 01 is however preferably thermally insulated so as to keep its huge first volume to a highest temperature as possible, said first volume being heated by the heat of the hydrocarbon fluid outputting from the leaking device 2.
The following thermal insulating materials may be used: synthetic material such as Polyurethane (PU) or polystyrene material, or a fibre textile with Polyvinyl chloride (PVC) coating or PU coating, or Alcryn ®. The thermal insulating material may be foam, or a gel contained inside a double wall structure.
The thermal insulation of the dome 20 passively insulates the cavity 21, while the injection system 30 actively insulates the cavity 21. Both effects prevent the formation of hydrates inside the cavity 21.
The cavity 21 is a volume storing a quantity of hydrocarbon fluid and absorbing the fluctuations of hydrocarbon fluid flows.
The dome 20 comprises an over pressure valve 23 that extract fluid out of the cavity and into the environment if a pressure difference between the cavity 21 and the environment exceeds a predetermined pressure limit.
The predetermined pressure limit is for example of
10 bars, 20 bars, or 50 bars. This limit has to be determined accordingly with the cavity size and the leaking device flow.
The over pressure valve is for example a ball check valve. The ball check valve comprises a support element, a ball, and a spring that loads the ball to the support element so as to close an opening. The tuning of the spring load is adapted to the predetermined pressure limit.
The cavity 21 is closed, and if hydrates formation is prevented, the fluid inside the cavity is rapidly heated by the hydrocarbon fluid itself outputting from the leaking device 2.
The over pressure valve 23 insures that the pressure inside the cavity is not increasing, and then insuring that the containment system is not destroyed.
The predetermined pressure limit may insure that hydrates formation is prevented.
Figure 2 is a second embodiment of a containment system 1 according to the invention. This containment system 1 is similar to the first embodiment. It comprises the same elements as the first embodiment, and can have the same variants as disclosed above. The second embodiment of the containment system 1 differs in that:
- the first dome 2 01 comprises a lower output opening 23 that is situated on the lateral portion 25 of the dome so as the first dome is opened to the sea at a low level DL near the seafloor, and
- it further comprises a wall 10 inside the first dome 2 01.
The wall 10 extends from a lower end 10a at the base level to an upper end 10b at a first level LI, said wall 10 being substantially sealed to the seafloor around the leaking device 2.
The wall 10 and the dome 20 are preferably independent parts or members, each of them installed at the seafloor independently from the other, and each of them being fixed preferably to the seafloor. The wall 10 is installed on the seafloor before the dome 20, so as to cancel the convection of cold sea water before the installation of the dome 20.
For example, the wall 10 comprises foot 10c having heavy weights for sealing and securing the wall 10 to the seafloor. The dome 20 may have similarly foot 20c for securing it to the seafloor.
The wall 10 completely surrounds the leaking device 2. In a horizontal plane (XY) , the wall 10 has a closed loop shape encompassing the leaking device 2. Said shape may be for example a circle shape, a square shape or any polygonal shape.
The wall 10 has an outer diameter D10. This outer diameter corresponds to a maximum distance between two external points of the wall, taken in an horizontal plane at a level near the first level LI. The outer diameter D10 is for example of 6 meters or more.
The wall 10 then extends upwardly from a lower end 10a at the base level BL to an upper end 10b at the first level LI. The first level LI is preferably higher than a total height of the leaking device 2.
The wall 10 defines an inner wall volume 11. This volume 11 is substantially isolated (not in direct communication) with the environment sea water, according to a horizontal direction (XY) . The volume 11 is opened upwardly, according to a vertical direction (Z) . Such wall 10 cancels any horizontal flow of sea water that is usually sucked by the flow of hydrocarbon fluid outputting from the leaking device 2. This dramatically reduces the thermal convection exchange between the cold sea water and the hydrocarbon fluid. This first effect cancels the hydrate formation.
The first level LI is preferably at least twice the total height of the leaking device 2, and more preferably three times higher than it. The wall 10 can cancel efficiently the convection effect of cold sea water.
Figures 3a to 3e are an exemplary of a containment system according to the schematic of figure 1 and also showing a method for using or installing said containment system.
In this exemplary, the dome 20 is composed of a base tubular structure represented on figure 3a, said base tubular structure comprising the foot 20c for securing the dome to the seafloor, and a tubular structure extending upwardly from the lower end 25b (attached to said foot 20c) to the upper end 25a and extending in a radial direction from said upper end 25a.
The tubular structure is a rigid frame giving a general shape to the first dome 2 01 . But, it does not close the volume of the cavity 21.
The tubular structure supports a first cover 27 for covering laterally said tubular structure and forming the lateral portion of the first dome 2 01 . The first cover 27 is a cylindrical tube that covers and closes the lateral portion 25 of the first dome 2 01 . The first cover shape is adapted to the lateral shape of the tubular structure. The first cover is attached to (secured to) said tubular structure by any securing means.
The tubular structure also supports a second cover 28 for covering upwardly the tubular structure and forming the upper portion of the first dome 2 01 . The second cover 28 is an annular part, having a lower ring 28a that fits to the upper end 25a of the first cover 27, a intermediate ring 28b having an annular and conical shape extending from said lower ring 28a, and an upper ring 28c extending from the centre of the intermediate ring. The upper ring 28c is a cylindrical tube that keeps the dome opening 26 opened and that is adapted for receiving the second dome 202. The second cover shape is adapted to the upper shape of the tubular structure. The second cover is attached to (secured to) said tubular structure by any securing means .
The fist and/or second covers 27, 28 may be rigid elements, for example made of welded metal sheets.
The first and/or second covers 27, 28 may be flexible elements, for example made of textile. They may be extendable, or deployable, or telescopic from a retracted position to a deployed position that covers the surface of the lateral portion 25 or upper portion 24 of the first dome 2 01 .
The second dome 202 is a smaller, and may be a rigid box adapted to be attached above the upper ring 28c of the second cover 28. The method for using or installing the containment system 1 according to the invention is now explained with the figures 3a to 3e.
At figure 3a, a base tubular structure is landed and sealed around the leaking device 2, said leaking device being substantially situated at the centre of the base tubular structure (according to a horizontal XY direction) .
The leaking device 2 is completely inside the volume of the base tubular structure, said volume being the first volume of the first dome 2 01 .
At figure 3b, the first cover 27 is mounted on and secured to the base tubular structure so as to close the lateral portion 25 of the dome.
At figure 3c, the second cover 28 is mounted on and secured to the base tubular structure and above the first cover 27 so as to close the upper portion of the dome 24, a dome opening 26 being kept opened.
At figure 3d, the second dome 202 is moved downwardly towards the first dome 20a.
During this step, the injection system 30 may inject the injection fluid IF into the second volume of the second dome 202. This second volume is rapidly filled with the injection fluid. Hydrates formation is then prevented inside this second volume. The quantity of injection fluid needed to fill said second volume is much smaller than the one that would be necessary to fill the first volume or to prevent hydrates formation inside a dome having the first volume .
At figure 3e, the second dome 202 is secured to the first dome 2 01 .
Therefore, the containment system 1 according to the invention comprises:
- a dome 20 forming a cavity 21 under said dome to accumulate hydrocarbon fluid coming upwardly from the leaking device, said dome comprising at least one upper output opening 22 adapted to extract the hydrocarbon fluid for recovering, and
- an injection system 30 that inputs an injection fluid IF into the cavity for preventing or remediating hydrates inside the cavity.
The dome 20 further comprises a first dome 2 01 having a first volume, and a second dome 202 having a second volume smaller than the first volume, the second dome 202 being situated upper the first dome 2 01 .
The method according to the invention for using or installing the containment system 1 comprises the following successive steps:
a) installing the first dome (20i) on the seafloor around the leaking device, the cavity completely surrounding and including the leaking device,
b) installing the second dome (202) upper the first dome (20i) so as the first and second volumes are in communication via a dome opening (26) .
Thanks to the above method, the volume the quantity of needed injection fluid to prevent hydrates formation is smaller. The flow of this injection fluid is highly reduced.
The time delay for installing the second dome 202 above the first dome 2 01 is shorter than the time delay for installing the first dome on the seafloor. The risk of hydrates formation is then reduced.
The injection system 30 preferably injects the injection fluid IF into the second volume of the second dome 202 before the second dome is installed upper the first dome 2 01 .
Preferably, the second volume is completely filled with injection fluid before said installation of the second dome .
Additionally, the containment system 1 further comprises a sensor 60 and an output valve 62 connected to the upper output opening 22. In the method, we are:
c) measuring by the sensor 60 an interface level IL of a fluid interface between hydrocarbon fluid and any other fluid inside the dome, and
d) controlling the output valve 62 on the bases of the interface level IL measured by the sensor 60 for outputting hydrocarbon fluid from the cavity 21.
The quantity of hydrocarbon fluid can be kept high. This fluid is relatively hot, and hydrates formation is prevented .
The output valve 62 is controlled so as to keep the interface level IL lower or equal to a level LL of output of the hydrocarbon fluid from the leaking device.
The jet of hydrocarbon fluid from the leaking device 2 is directly entering the hydrocarbon fluid accumulated inside the dome. The hydrocarbon fluid is relatively hot, and cold water mixture is also prevented. Hydrates formation is therefore prevented.

Claims

1. A containment system (1) for recovering hydrocarbon fluid from a leaking device that is situated at the seafloor and that is leaking hydrocarbon fluid from a well, wherein the containment system (1) is adapted to be landed at the seafloor corresponding to a base level of the containment system, and wherein the containment system comprises :
- a dome (20) intended to be secured to the seafloor around the leaking device and forming a cavity (21) under said dome, said cavity being adapted to completely surround and include the leaking device, and to accumulate hydrocarbon fluid coming upwardly from the leaking device, said dome comprising at least one upper output opening (22) adapted to extract the hydrocarbon fluid for recovering, and
- an anti hydrates system (30) that actively prevents or remediates hydrates inside the cavity, and
wherein the dome (20) comprises a first dome (20i) having a first volume adapted to receive the leaking device, and a second dome (202) having a second volume smaller than the first volume, the second dome (202) being situated upper the first dome (20i) , and the first and second volumes being in communication via a dome opening (26) .
2. The containment system according to claim 1, wherein the second volume is smaller than a l/4th of the first volume, and preferably smaller than a l/10th of the first volume.
3. The containment system according to claim 1 or claim 2, wherein the second volume is higher than a l/20th of the first volume.
4. The containment system according to any one of claims 1 to 3, wherein the dome opening is between 2 and 4 meters wide.
5. The containment system according to any one of claims 1 to 4, wherein the first dome (20i) is thermally insulated with an insulating material for having an overall heat transfer coefficient of the first dome lower than 1 W.m^.K"1.
6. The containment system according to any one of claims 1 to 5, wherein the anti hydrates system (30) is only situated into or onto the second dome (202) .
7. The containment system according to any one of claims 1 to 6, wherein the anti hydrates system (30) is a heating system for heating at least a portion of the cavity (21) .
8. The containment system according to any one of claims 1 to 6, wherein the anti hydrates system (30) is an injection systems that inputs an injection fluid (IF) into the cavity.
9. The containment system according to claim 8, wherein the injection system comprises a plurality of output ports spread only inside the second volume or at the dome opening (26), said output ports being fed with the injection fluid.
10. The containment system according to claim 8, further comprising a fluid heater for heating the injection fluid before injection into the cavity.
11. The containment system according to any one of the claims 8 to 9, wherein the injection fluid comprises one or a combination of the fluid components chosen in the list of water, salted water, dead oil, an alcohol, an ethanol, a methanol, a glycol, an ethylene glycol, a diethylene glycol, and a low-dosage hydrate inhibitor (LDHI) .
12. The containment system according to claim 8, further comprising a pipe (50) having an inner tube (51) forming an inner channel, and an outer tube (52) surrounding said inner tube and forming an annular channel, and wherein the inner channel is used to extract the hydrocarbon fluid from the upper output opening (22) and the annular channel is used to feed the injection system (30) with at least an injection fluid (IF), or inversely .
13. A method for using the containment system (1) for recovering hydrocarbon fluid from a leaking device that is situated at the seafloor and that is leaking hydrocarbon fluid from a well, and
wherein the containment system (1) comprises:
- a dome (20) forming a cavity (21) under said dome to accumulate hydrocarbon fluid coming upwardly from the leaking device, said dome comprising at least one upper output opening (22) adapted to extract the hydrocarbon fluid for recovering, and
- an anti hydrates system (30) that actively prevents or remediates hydrates inside the cavity, and
wherein the dome (20) comprises a first dome (20i) having a first volume, and a second dome (202) having a second volume smaller than the first volume, the second dome (202) being situated upper the first dome (20i) , and
wherein the method comprises the following successive steps :
a) installing the first dome (20i) on the seafloor around the leaking device, the cavity completely surrounding and including the leaking device,
b) installing the second dome (202) upper the first dome (20i) so as the first and second volumes are in communication via a dome opening (26) .
14. The method according to claim 13, wherein the anti hydrates system (30) is a heating system for heating at least a portion of the cavity (21) .
15. The method according to claim 13, wherein the anti hydrates system (30) is an injection systems that inputs an injection fluid (IF) into the cavity.
16. The method according to claim 15, wherein the injection system (30) injects the injection fluid into the second volume of the second dome before step b) .
17. The method according to claim 15 or claim 16, wherein the injection system (30) injects the injection fluid at a velocity that is low, and preferably at a velocity that is lower than 0.5 meter per seconds.
18. The method according to claim 13, wherein the containment system (1) further comprises a level sensor (60) and an output valve (62) connected to the upper output opening (22), and wherein the method further comprises after step b) the following steps:
c) measuring by the level sensor (60) an interface level (IL) of a fluid interface between hydrocarbon fluid and any other fluid inside the dome,
d) controlling the output valve (62) on the bases of the interface level (IL) measured by the level sensor (60) for outputting hydrocarbon fluid from the cavity (21) .
19. The method according to claim 18, wherein at step d) , the output valve (62) is controlled so as to keep the interface level (IL) lower or equal to a level (LL) of output of the hydrocarbon fluid from the leaking device.
20. The method according to claim 13, wherein the containment system (1) further comprises a temperature sensor (70) and an output valve (62) connected to the upper output opening (22), and wherein the method further comprises after step b) the following steps:
c) measuring by the temperature sensor (70) a temperature of the fluid inside the dome,
d) controlling the output valve (62) on the bases of the temperature measured by the temperature sensor (70) for outputting hydrocarbon fluid from the cavity (21) .
PCT/IB2014/000569 2013-10-21 2014-03-07 A containment system and a method for using said containment system Ceased WO2015059530A1 (en)

Priority Applications (2)

Application Number Priority Date Filing Date Title
BR112016006924A BR112016006924A2 (en) 2013-10-21 2014-03-07 containment system and method for using said containment system
US15/031,154 US20160265317A1 (en) 2013-10-21 2014-03-07 A containment system and a method for using said containment system

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
EP13306446 2013-10-21
EP13306446.9 2013-10-21

Publications (1)

Publication Number Publication Date
WO2015059530A1 true WO2015059530A1 (en) 2015-04-30

Family

ID=52992336

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/IB2014/000569 Ceased WO2015059530A1 (en) 2013-10-21 2014-03-07 A containment system and a method for using said containment system

Country Status (3)

Country Link
US (1) US20160265317A1 (en)
BR (1) BR112016006924A2 (en)
WO (1) WO2015059530A1 (en)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2017182837A1 (en) * 2016-04-20 2017-10-26 Total Sa A method for using a containment system and a containment system

Families Citing this family (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
RU2739664C2 (en) * 2019-06-21 2020-12-28 Публичное акционерное общество "Нефтяная компания "Роснефть" (ПАО "НК "Роснефть") Petroleum mixture transportation system for liquidation of underwater oil spills by "dome" type device
US11927078B1 (en) 2019-12-31 2024-03-12 Couvillion Group Underwater separator
US12188334B1 (en) * 2019-12-31 2025-01-07 Couvillion Group, Llc Mobile modular containment system
CN113624639B (en) * 2021-07-05 2022-10-14 青岛海洋地质研究所 Device and method for rapidly measuring instant flux of deep sea seabed gas leakage
CN117927855B (en) * 2024-01-24 2025-09-19 中山大学 Carbon dioxide seabed sealing injection device, method and terminal equipment

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4358218A (en) * 1979-12-17 1982-11-09 Texaco Inc. Apparatus for confining the effluent of an offshore uncontrolled well
US7987903B1 (en) * 2010-06-22 2011-08-02 triumUSA Inc. Apparatus and method for containing oil from a deep water oil well
DE102010022650A1 (en) * 2010-06-04 2011-12-08 Uwe ROHDE Device for discharging a material that emerges from the seabed and method
US20110318107A1 (en) * 2010-06-23 2011-12-29 Dighe Technologies Corporation Apparatus and method for undersea oil leakage containment
WO2013085380A1 (en) * 2011-12-07 2013-06-13 Technische Universiteit Delft Method and system for capturing hydrocarbons from a leaking oilwell at a predetermined seabed location
WO2013126756A2 (en) * 2012-02-24 2013-08-29 Tessema Dosho Shifferaw Fluid leak containment system

Family Cites Families (22)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
NO153938C (en) * 1979-11-02 1986-06-18 Ostlund As PROCEDURE FOR THE COLLECTION AND SEPARATION OF OIL, WATER AND GAS FROM AN OIL WELL AND AN EQUAL COLUMN FOR EXECUTION OF THE PROCEDURE.
US5213444A (en) * 1992-04-17 1993-05-25 The United States Of America As Represented By The United States Department Of Energy Oil/gas collector/separator for underwater oil leaks
FR2852917B1 (en) * 2003-03-26 2005-06-24 Saipem Sa SEALED COMPARTMENT RECEPTACLE AND METHOD OF PLACING IT TO RECOVER POLLUTANT EFFLUENTS FROM A EPAVE
US8869880B2 (en) * 2007-02-12 2014-10-28 Gaumer Company, Inc. System for subsea extraction of gaseous materials from, and prevention, of hydrates
US8894325B2 (en) * 2010-05-04 2014-11-25 Oxus Recovery Solutions, Inc. Submerged hydrocarbon recovery apparatus
US20110274493A1 (en) * 2010-05-07 2011-11-10 Justin Bredar Cutts Moored Wellhead Effluent Capture and Concrete Application Apparatus
US8555980B1 (en) * 2010-06-09 2013-10-15 John Powell Oil well blowout containment device
NO334010B1 (en) * 2010-06-10 2013-11-18 Borealis Offshore Consultants As Discharge containment device for underwater blowing oil wells
IT1401465B1 (en) * 2010-06-17 2013-07-26 Eni Spa EQUIPMENT FOR CONVEYANCE AND RECOVERY OF HYDROCARBONS FROM A SUBMARINE WELL FOR THE EXTRACTION OF HYDROCARBONS IN UNCONTROLLED RELEASE CONDITION
US20110315395A1 (en) * 2010-06-24 2011-12-29 Subsea IP Holdings LLC Method and apparatus for containing a defective blowout preventer (bop) stack using bopstopper assemblies having remotely controlled valves and heating elements
WO2011163573A2 (en) * 2010-06-25 2011-12-29 Mjb Of Mississippi, Inc. Apparatus and method for isolating and securing an underwater oil wellhead and blowout preventer
US20120155964A1 (en) * 2010-06-25 2012-06-21 George Carter Universal Subsea Oil Containment System and Method
US20120027517A1 (en) * 2010-08-02 2012-02-02 Tessema Dosho Shifferaw Fluid leak containment system
US20120213588A1 (en) * 2010-08-02 2012-08-23 Tessema Dosho Shifferaw Fluid leak containment system
US8931562B2 (en) * 2010-09-20 2015-01-13 Wild Well Control, Inc. Collector for capturing flow discharged from a subsea blowout
US8444344B2 (en) * 2010-10-06 2013-05-21 Baker Hughes Incorporated Temporary containment of oil wells to prevent environmental damage
US8434558B2 (en) * 2010-11-15 2013-05-07 Baker Hughes Incorporated System and method for containing borehole fluid
US20120186822A1 (en) * 2011-01-20 2012-07-26 Research Foundation Of State University Of New York Modular pressure management oil spill containment system and method
US8789607B2 (en) * 2011-03-21 2014-07-29 Henk H. Jelsma Method and apparatus for subsea wellhead encapsulation
US8678708B2 (en) * 2011-04-26 2014-03-25 Bp Corporation North America Inc. Subsea hydrocarbon containment apparatus
US8522881B2 (en) * 2011-05-19 2013-09-03 Composite Technology Development, Inc. Thermal hydrate preventer
WO2013025644A1 (en) * 2011-08-12 2013-02-21 Mcalister Technologies, Llc Systems and methods for extracting and processing gases from submerged sources

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4358218A (en) * 1979-12-17 1982-11-09 Texaco Inc. Apparatus for confining the effluent of an offshore uncontrolled well
DE102010022650A1 (en) * 2010-06-04 2011-12-08 Uwe ROHDE Device for discharging a material that emerges from the seabed and method
US7987903B1 (en) * 2010-06-22 2011-08-02 triumUSA Inc. Apparatus and method for containing oil from a deep water oil well
US20110318107A1 (en) * 2010-06-23 2011-12-29 Dighe Technologies Corporation Apparatus and method for undersea oil leakage containment
WO2013085380A1 (en) * 2011-12-07 2013-06-13 Technische Universiteit Delft Method and system for capturing hydrocarbons from a leaking oilwell at a predetermined seabed location
WO2013126756A2 (en) * 2012-02-24 2013-08-29 Tessema Dosho Shifferaw Fluid leak containment system

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2017182837A1 (en) * 2016-04-20 2017-10-26 Total Sa A method for using a containment system and a containment system

Also Published As

Publication number Publication date
US20160265317A1 (en) 2016-09-15
BR112016006924A2 (en) 2017-08-01

Similar Documents

Publication Publication Date Title
US20160265317A1 (en) A containment system and a method for using said containment system
US7546880B2 (en) Extracting gas hydrates from marine sediments
US8894325B2 (en) Submerged hydrocarbon recovery apparatus
US9587467B2 (en) Containment system and a method for using said containment system
US11987443B2 (en) Subsea fluid storage unit
US9506327B2 (en) Containment system and a method for using such containment system
US20180016874A1 (en) Improved inlet-outlet system and method for subsea storage
NO20130485A1 (en) Fluid level control system and method of use
US20170321524A1 (en) A containment system and method for using said containment system
US20150226039A1 (en) Containment system and a method for using said containment system
US9416632B2 (en) Containment system
OA17744A (en) A containment system and a method for using said containment system.
NO20240308A1 (en) Subsea fluid storage unit
OA17374A (en) A containment system and a method for using said containment system.
OA17260A (en) A containment system and a method for using such containment system.
WO2017182837A1 (en) A method for using a containment system and a containment system
OA17373A (en) A containment system and a method for using said containment system.
US20120141213A1 (en) Oil reclamation apparatus
OA17259A (en) A containment system.
OA17261A (en) A containment system and a method for using said containment system.
GB2588326A (en) Assembly and maintenance of subsea fluid storage units

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 14729433

Country of ref document: EP

Kind code of ref document: A1

REG Reference to national code

Ref country code: BR

Ref legal event code: B01A

Ref document number: 112016006924

Country of ref document: BR

NENP Non-entry into the national phase

Ref country code: DE

WWE Wipo information: entry into national phase

Ref document number: 15031154

Country of ref document: US

122 Ep: pct application non-entry in european phase

Ref document number: 14729433

Country of ref document: EP

Kind code of ref document: A1

ENP Entry into the national phase

Ref document number: 112016006924

Country of ref document: BR

Kind code of ref document: A2

Effective date: 20160329