WO2012143392A2 - Système de pompe, procédé et leurs utilisations pour transporter de l'eau d'injection dans un puits d'injection sous-marin - Google Patents

Système de pompe, procédé et leurs utilisations pour transporter de l'eau d'injection dans un puits d'injection sous-marin Download PDF

Info

Publication number
WO2012143392A2
WO2012143392A2 PCT/EP2012/057076 EP2012057076W WO2012143392A2 WO 2012143392 A2 WO2012143392 A2 WO 2012143392A2 EP 2012057076 W EP2012057076 W EP 2012057076W WO 2012143392 A2 WO2012143392 A2 WO 2012143392A2
Authority
WO
WIPO (PCT)
Prior art keywords
enclosure
arrangement
water
pump system
pump
Prior art date
Application number
PCT/EP2012/057076
Other languages
English (en)
Other versions
WO2012143392A3 (fr
Inventor
Jan Olav Hallset
Original Assignee
Siemens Aktiengesellschaft
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 Siemens Aktiengesellschaft filed Critical Siemens Aktiengesellschaft
Priority to US14/112,536 priority Critical patent/US20140112803A1/en
Priority to GB1313758.3A priority patent/GB2504008A/en
Publication of WO2012143392A2 publication Critical patent/WO2012143392A2/fr
Publication of WO2012143392A3 publication Critical patent/WO2012143392A3/fr

Links

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
    • F04D13/00—Pumping installations or systems
    • 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
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/0007—Equipment or details not covered by groups E21B15/00 - E21B40/00 for underwater installations
    • 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
    • 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
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/20—Displacing by water
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
    • Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
    • Y10T29/00—Metal working
    • Y10T29/49—Method of mechanical manufacture
    • Y10T29/49826—Assembling or joining

Definitions

  • the invention relates to a pump system and a method for trans ⁇ porting injection water to an underwater injection well.
  • the invention also relates to the use of the pump system and to the use of said method.
  • a relatively common method for increasing the degree of extrac ⁇ tion of hydrocarbons from an undersea reservoir is to pump wa ⁇ ter into the reservoir via an underwater injection well, so-called secondary extraction.
  • the injection water may also be subjected to various treatment un ⁇ derwater, for example filtering and/or chemical treatment, by means of associated equipment located on or near the seabed.
  • the use of such underwater equipment is typically undertaken in connection with secondary extraction from smaller and/or complex oil fields, and/or in secondary extraction at greater water depths than is usual for surface installations.
  • the well head of the injection well is located on the seabed, and said underwater equipment is flow-connected to the well head.
  • an underwater injection pump will typically be of a design which, technically speaking, is substantially more complex, more extensive and more robust, and thereby substantially more costly than a cor ⁇ responding well-known, well-tried and effectively functioning surface pump.
  • such an underwater injection pump is often exposed to very demanding and harsh operating conditions underwater. Such operating conditions often reduce the operating reliability and service life of the underwater pump. This may therefore lead to shorter maintenance intervals and thereby more frequent intervention operations, and increased operating costs associated with operation of the underwater pump. In the worst case, such operating conditions and associated disadvan ⁇ tages may render seabed-based water injection into an injection well impossible.
  • 2008/0190291 Al is used for the processing of a hydrocarbon stream from an underwater well.
  • a pump system for transporting injection water to an underwater injection well, wherein the pump system comprises a pressure- tight enclosure located underwater and containing:
  • enclosure also comprises:
  • the inlet of the enclosure is flow-connected to a body of water in which the enclosure is located, water from this body of water being used as injection water to said underwater injection well;
  • the pump system in question might therefore represent a sub ⁇ stantial technical contribution in being able to undertake eco ⁇ nomically viable, secondary extraction from smaller and/or complex oil fields, and from oil fields at greater water depths than is usual for surface installations.
  • At least one control unit of the pump system may comprise various electronic components, including elec ⁇ tronic circuit boards, programs, transmitter units, receiver units, circuit breakers, couplings, power connections and the like, for controlling and possibly monitoring the operation of the pump system when installed in its position of use underwa ⁇ ter.
  • the scope of the components in the control unit is deter ⁇ mined by the actual design of the pump system.
  • the control unit may therefore at least comprise components/equipment enabling it to communicate signals with said drive arrangement, and pos ⁇ sibly also with said cooling arrangement and/or other equipment in the pump system.
  • the pump system may also comprise various coupling equipment, for example valves, couplings, flanges, packings, connecting lines and hoses, for connecting various components which are included in or which are associated with the pressure-tight en ⁇ closure .
  • various coupling equipment for example valves, couplings, flanges, packings, connecting lines and hoses, for connecting various components which are included in or which are associated with the pressure-tight en ⁇ closure .
  • the pump system may furthermore comprise various regulating equipment for regulating and thereby controlling the operation of various components in the pump system.
  • the pump system may be designed for connection to various auxiliary equipment, which among other things is used to carry out servicing operations on the pump system, or on equipment which is associated with the pump system, possibly for coupling various equipment to the pump system.
  • auxil ⁇ iary equipment may therefore include ROV-based equipment, where an unmanned and remotely controlled underwater vessel (“ROV”) carries out the relevant servicing operations by means of re ⁇ mote control from a host vessel on the surface.
  • ROV unmanned and remotely controlled underwater vessel
  • Said enclosure in the pump system may advantageously be located on or near the bottom of a body of water, for example on a seabed or on the bed of a lake, river or delta.
  • the enclosure may possibly be located on a suitable foundation.
  • the pump arrangement in the enclosure may comprise or consist of any suitable pump arrangement, for example a cen ⁇ trifugal pump.
  • the drive arrangement of the pump arrangement may comprise or consist of any suitable drive ar ⁇ rangement, for example an electric motor or a hydraulic motor.
  • the pressure-tight enclosure of the pump system may also con ⁇ tain a lubrication arrangement for lubricating at least one moving part in the pump arrangement or the drive arrangement.
  • the pump ar ⁇ rangement and/or the drive arrangement may be provided with magnetic bearings for the operating support of at least one ro ⁇ tating part in the pump arrangement and/or in the drive ar ⁇ rangement.
  • the magnetic bearings may be con ⁇ nected to at least one control unit for operating control of the bearings.
  • the magnetic bearings may also be connected to at least one source (e.g. electric power source) for supplying drive power to the bearings .
  • the pressure-tight enclosure may also contain monitoring equip ⁇ ment for operational monitoring of at least said pump arrange ⁇ ment, drive arrangement and cooling arrangement.
  • the monitoring equipment is connected to at least one said control unit for operating control of the monitoring equipment and the transmission of monitoring data to a remote host device.
  • the monitoring equipment is also connected to at least one source (e.g. electric power source) for supplying drive power to the monitoring equipment.
  • the pressure-tight enclosure may contain a gas, for example air, at atmospheric or virtually atmospheric pres ⁇ sure, that is to say an internal pressure of approximately 1 atmosphere.
  • the pressure inside the enclosure may for example lie within a range of about 1 to about 2 bar. This assumes that the enclosure is designed to be capable of withstanding pres ⁇ sure differences between the water pressure that prevails out ⁇ side the enclosure at the water depth in question, and the at ⁇ mospheric or virtually atmospheric pressure inside the enclo ⁇ sure.
  • the enclosure can be raised to the surface and opened for servicing, modification or the like, without dangerous situations arising as a result of a pressure difference between the interior of the enclosure and the surrounding atmospheric pressure at the surface.
  • the gas in the enclosure may also consist of an inert gas, for example nitrogen or argon. This may pro ⁇ vide improved electric isolation and/or reduce corrosion.
  • the enclosure may be connected via a cabled con ⁇ nection to a remote host device for transferring contaminated gas from the enclosure and for returning uncontaminated gas to the enclosure.
  • a remote host device for transferring contaminated gas from the enclosure and for returning uncontaminated gas to the enclosure.
  • a solution may be appropriate, for example, if it is desirable to remove water vapor from the injection wa ⁇ ter and/or vapor for a coolant and/or a fluid lubricant, for example oil vapor, from the interior of the enclosure.
  • the con ⁇ taminated gas can thereby be transported from the enclosure and to the host device, where the contaminated gas is either cleaned or replaced.
  • the uncontaminated gas may then be re ⁇ turned to the enclosure via the cabled connection.
  • equipment, modules and units that are to be lo ⁇ cated underwater offshore can often be large, heavy and bulky, possibly with a relatively large lateral extent.
  • a floating vessel for example a boat
  • the vessel is also provided with a working aperture ("moon pool") in the deck of the vessel, it may also be difficult to lower such equipment down through the working aperture in the deck, and possibly also to retrieve the equipment though this working aperture.
  • bulky equipment must be transported sus ⁇ pended under or behind the vessel during transport offshore.
  • Such transport of awkward equipment is shown, for example, in the publication WO 03/074353 Al, which corresponds to NO 316168 Bl, and in publication WO 2009/070034 A2.
  • such equipment may be located on a deck of a large transport vessel, for example a lighter, and transported to the relevant location offshore. The equipment is then hoisted over the side of the vessel and lowered down into the water.
  • Such a working opera ⁇ tion may also be awkward with an associated uncertainty and risk .
  • the pump arrangement and drive arrange ⁇ ment of the enclosure may advantageously be vertically aligned in relation to one another.
  • the enclosure may be designed with an outer perimeter or circumference that fits in ⁇ side or is specially adapted to such a working aperture in a deck of a floating vessel.
  • the vessel is designed to be capable of lowering the enclosure down into the water, and where necessary retriev ⁇ ing the enclosure from the water through the working aperture in the deck of the vessel. It is thereby possible to transport the enclosure and its contents on the deck of the vessel when shipping the enclosure out to the relevant location offshore, following which the enclosure is lowered down into the water via said working aperture in the deck of the vessel.
  • the en ⁇ closure may for example comprise or consist of a vertically up ⁇ right, cylindrical container of a height that is greater than the diameter of the container.
  • the pump arrangement can be arranged vertically beneath the drive arrange- ment, or the pump arrangement can be arranged vertically above the drive arrangement.
  • said control unit may comprise at least one remotely controlled control unit, which, via a cabled connec ⁇ tion, is connected to a remote host device for transmitting at least control signals to the control unit.
  • a cabled con ⁇ nection may consist, for example, of a control cable ("umbili ⁇ cal line") .
  • the enclosure may be connected via a cabled connection to a remote host device for transmit ⁇ ting drive power to powered equipment in the pump system.
  • a cabled connection may consist, for example, of a suitable power transmission cable.
  • the enclosure may be connected via a ca ⁇ bled connection to a remote host device for transmitting both control signals to the control unit and drive power to powered equipment in the pump system.
  • said control system may also comprise at least one remotely controlled backup control unit, which is connected via a wireless connection to a remote host device for transmitting at least control signals to the control unit.
  • the backup control unit is connected to a transceiver for wire ⁇ less communication with the remote host device.
  • the wireless connection may consist, for example, of an acoustic connection or a radio frequency connection.
  • the enclosure may be provided with a power supply for operation of the remotely controlled backup control unit.
  • Said power sup ⁇ ply may consist, for example, of at least one battery.
  • the cooling arrangement of the enclosure may com ⁇ prise at least one closed flow circuit, for example a pipe loop, containing a coolant, where the closed flow circuit is connected to the internal atmosphere of the enclosure for ab- sorbing heat therefrom, and where the closed flow circuit com ⁇ prises a heat exchanger, which is connected to said body of wa ⁇ ter on the outside of the enclosure for removing heat transmit ⁇ ted from the internal atmosphere of the enclosure by way of the coolant of the flow circuit.
  • This cooling arrangement also com ⁇ prises a means of delivery for the coolant, for example a suit ⁇ able pump.
  • the heat exchanger may advantageously be arranged on the outside of the enclosure and may therefore be in direct contact with the cooling body of water.
  • the heat exchanger may be arranged inside the enclosure and may comprise an open flow circuit, which via at least one liquid-tight bush ⁇ ing through the wall of the enclosure is in direct contact with the cooling body of water outside the enclosure.
  • the cooling arrangement of the enclosure may comprise an open flow circuit, for example a pipe connec ⁇ tion/hose connection, including a control cable ("umbilical line") , containing a coolant, where the open flow circuit is connected to the internal atmosphere of the enclosure for ab ⁇ sorbing heat therefrom, and where the open flow circuit is connected to a remote host device for at least the circulation and possibly also the replenishing of coolant, and for removing heat transmitted from the internal atmosphere of the enclosure by means of the coolant of the flow circuit.
  • an open flow circuit for example a pipe connec ⁇ tion/hose connection, including a control cable ("umbilical line") , containing a coolant, where the open flow circuit is connected to the internal atmosphere of the enclosure for ab ⁇ sorbing heat therefrom, and where the open flow circuit is connected to a remote host device for at least the circulation and possibly also the replenishing of coolant, and for removing heat transmitted from the internal atmosphere of the enclosure by means of the coolant of the flow circuit.
  • the lubrication arrangement of the enclosure may comprise at least one closed flow circuit, for example a pipe loop, containing a fluid lubricant, where the closed flow cir ⁇ cuit is connected to lubricated equipment in the pump system.
  • This lubrication arrangement also comprises a means of delivery for the fluid lubricant, for example a suitable pump.
  • the lubrication arrangement of the enclosure may comprise an open flow circuit, for example a pipe connec ⁇ tion/hose connection, including a control cable ("umbilical line") , containing a fluid lubricant, where the open flow cir ⁇ cuit is connected to lubricated equipment in the pump system, and where the open flow circuit is connected to a remote host device for at least the circulation and possibly also the re ⁇ plenishing of fluid lubricant, and for lubricating the lubricated equipment in the pump system.
  • an open flow circuit for example a pipe connec ⁇ tion/hose connection, including a control cable ("umbilical line") , containing a fluid lubricant, where the open flow cir ⁇ cuit is connected to lubricated equipment in the pump system, and where the open flow circuit is connected to a remote host device for at least the circulation and possibly also the re ⁇ plenishing of fluid lubricant, and for lubricating the lubricated equipment in
  • control unit For transmitting at least control signals to the control unit, said control unit may be connected to at least one wet-mateable plug connection arranged in the wall of the enclosure and de ⁇ signed for coupling to a separate, cabled connection.
  • the wall of the enclosure may be provided with at least one wet-mateable plug connection designed for coupling to a separate, cabled connec ⁇ tion .
  • the wall of the enclosure may be provided with at least one wet-mateable plug connection designed for coupling to a separate, cabled connection.
  • All of these plug connections may for example comprise or con ⁇ sist of a plug and a socket, which afford a mating fit when coupled together.
  • a cabled con ⁇ nection for example a control cable and/or a power transmis ⁇ sion cable
  • ROV remotely controlled under ⁇ water vessel
  • Said remote host device may comprise or consist of a surface installation on land or offshore.
  • the surface installation may comprise, for example, of a building or the like, in which an operator of the pump system is situated.
  • the surface installation may comprise or consist of an anchored platform or a floating installation, for example a floating platform or a suitable vessel/ship.
  • the inlet of the enclosure may furthermore be designed to be closeable, for example by means of a suitable valve arrange ⁇ ment .
  • the outlet of the enclosure may be designed to be closeable, for example by means of a suitable valve arrangement.
  • the outlet of the enclo ⁇ sure may be connected to the injection well via an underwater line, for example a pipeline.
  • the outlet of the enclosure may be directly connected to the injection well, for example the outlet is connected to a well head for the injection well.
  • the enclosure may be flow-connected to at least one underwater installation for treatment of the injection water, where said underwater installation is located underwater in said body of water.
  • the enclosure can therefore be connected to said underwater installation via an underwater line, for example a pipeline.
  • Said underwater installation may comprise at least one arrange ⁇ ment for removing solid particles from the injection water without filtering.
  • the inlet of the enclosure is connected to one or more such ar ⁇ rangements. At least some solid particles will thereby be re ⁇ moved from the injection water before this reaches the enclo ⁇ sure and its pump arrangement.
  • An example of such an underwater arrangement is described in WO 2007/035106 Al, which is incorporated herein by reference in its entirety.
  • This underwater arrangement comprises a closed chamber, which is designed to allow the feed water to be fed directly into a lower part of the closed chamber, and which is also designed to allow the treated water to be fed out of an upper part of the closed chamber.
  • This closed chamber also has a cross sectional area which is designed to allow the water to flow from the lower part to the upper part with a rate of flow that is low enough for the unwanted solid particles to be precipitated out of the water under gravity.
  • the closed chamber may furthermore be de ⁇ signed as a container or module that is located on a seabed or the like, for example.
  • said underwater installation may comprise at least one arrangement for chemical treatment of the injection water.
  • at least one inlet and outlet of the enclosure may be flow-connected to one or more such ar ⁇ rangements for chemical treatment of the injection water.
  • An example of such a chemical treatment arrangement is described in WO 2004/090284 Al , which is incorporated herein by reference in its entirety.
  • This patent publication relates to a method and an apparatus for undersea chemical treatment of injection water, using a modular underwater apparatus that is connected to an injection well for injection of the water.
  • the apparatus comprises at least one container, which is provided with at least one type of water-soluble solid chemical.
  • the container can be changed, for example, by means of a remotely controlled underwater vessel ("ROV") .
  • ROV remotely controlled underwater vessel
  • the water is then brought into contact with the solid chemical, in such a way that it is gradu ⁇ ally dissolved and mixed with the water.
  • the ready-treated wa ⁇ ter is then injected into a reservoir connected to the well.
  • Chemical treatment and water injection can thereby be under ⁇ taken without having to use a directly superjacent surface in ⁇ stallation or vessel.
  • the water-soluble solid chemical may com ⁇ prise chlorine and/or biocide, but also various other chemi ⁇ cals, such as said oxygen-removal agents, corrosion inhibitors and settlement inhibitors.
  • This chemical treatment arrangement may consist of a separate unit or it may be incorporated into the aforesaid underwater arrangement for the removal of un ⁇ wanted solid particles from the feed water without filtering.
  • said underwater installation may comprise at least one arrangement for the de- struction of organic material in the injection water.
  • at least one inlet and outlet of the enclosure may be flow-connected to one or more such arrangements for the destruction of organic material in the injection water.
  • An example of such a destructive arrangement is described in WO 2007/073198 Al , which is incorporated herein by reference in its entirety.
  • This patent publication relates to a method and an arrangement for destroying organic material in injection wa ⁇ ter for an injection well. The arrangement uses at least one electrochemical cell with associated operating means for the in situ electrolytic production from water of at least short ⁇ lived, free hydroxyl radicals.
  • the electrochemical cell is designed to be capable of ducting the injection water through it as basic material for the in situ production of at least said free hydroxyl radicals from the injection water.
  • Such free hydroxyl radicals will immediately destroy organic material with which they come into contact in the injection water.
  • This destructive arrangement may consist of a separate unit or it may be incorporated into the aforesaid underwater arrangement for the removal of un ⁇ wanted solid particles from the feed water without filtering.
  • the destructive arrangement may be combined with the aforementioned chemical treatment arrange ⁇ ment .
  • At least said one underwater installation for treatment of the injection water may, like the enclosure, advantageously be lo ⁇ cated on or near the bottom of a body of water, for example on a seabed or on the bed of a lake, river or delta.
  • the underwater installation may, if necessary, be located on a suitable foundation.
  • a method is pro ⁇ vided for transporting injection water to an underwater injection well, where the method uses a pump system comprising a pressure-tight enclosure which contains:
  • enclosure also comprises:
  • method may also comprise the following steps :
  • the enclosure and its contents which may be large, heavy and bulky, can thereby be transported on the deck of a vessel when shipping the enclosure out to a location offshore, following which the enclosure is lowered down into the water via a work ⁇ ing aperture ("moon pool") in the deck of the vessel. At a later date the enclosure can thereby be retrieved from the wa ⁇ ter via this working aperture.
  • Aligning the pump arrangement and its drive arrangement vertically in relation to one another affords a relatively narrow enclosure, which fits both on the deck of the vessel and inside the working aperture in the deck. This obviates the need, for example, to transport such an en ⁇ closure with contents suspended beneath or behind the vessel when it is transported offshore, and possibly hoisting the equipment over the side of a vessel before lowering the equip ⁇ ment down into the water.
  • the method may also comprise the following steps:
  • said underwater installation may comprise at least one of the following types of underwater installations:
  • a pump system according to the first aspect of the invention is for transporting injection water to an underwater injection well.
  • the use of a method according to the second aspect of the invention is for transporting injection water to an underwater injection well.
  • Figure 1 shows a highly schematic vertical plan view, partly in section, of a pump system according to an embodiment of the invention, comprising, among other things, a pressure-tight enclosure, which contains a pump arrangement, etc., where the en ⁇ closure is located underwater on a seabed, and the enclosure is flow-connected to, among other things, a remote underwater in ⁇ jection well;
  • Figure 2 also highly schematic and to a smaller scale, shows a first embodiment of a pump system in question, comprising the enclosure according to figure 1, where the upstream side of the enclosure is flow-connected to an underwater installation for treatment of the injection water that is drawn directly from the sea which surrounds the enclosure and the underwater in ⁇ stallation, and where both the enclosure and the underwater installation are each connected to a remote and floating platform offshore for transmitting various signals, including control signals and monitoring data, and drive power to powered equip ⁇ ment in the enclosure and the underwater installation; and
  • Figure 3 also highly schematic, shows a second embodiment of a pump system in question and the underwater installation according to figure 2, where, however, both the enclosure and the un ⁇ derwater installation are each connected to a remote location offshore or on land for transmitting said signals and drive power to the enclosure and the underwater installation.
  • FIG 1 shows a pump system 2 according to an embodiment of the invention located in a body of water in the form of sea- water 4, where the pump system 2 is situated on a seabed 6 be ⁇ neath a sea surface 8 (shown only in figures 2 and 3) .
  • the pump system is designed for transporting injection water 10 to a remote injection well 12 on the seabed 6 (see figures 2 and 3) .
  • seawater 4 is used as untreated water for the injection water 10 to the injection well 12.
  • the injection water can consist of water/untreated water that is drawn from a body of water in which the pump system in question is located when the system is in its position of use underwater.
  • This body of water may consist of salt seawater, for example, or, when installed at a different location, of water from a lake, river, spring or groundwater deposit.
  • the pump system in question can furthermore be controlled and possibly monitored from a remote host device via one or more cabled and/or wireless communications connections.
  • the pump system may also be supplied with power from a remote host de ⁇ vice via at least one cabled power transmission connection.
  • a host device may include a surface installation on land or offshore.
  • the pump system in question may be linked to one or more underwater installations for various treatment of the injection water, for example fil ⁇ tering and/or various chemical treatment of the injection wa ⁇ ter .
  • the pump system 2 comprises a pressure-tight enclosure 14, which is located on a foundation 16 on the seabed 6.
  • the enclosure 14 consists of a vertically upright, cylindrical container of a height which is greater than the di ⁇ ameter of the container.
  • the enclosure 14 contains an inert gas 17, for example nitrogen or argon, which is set to an atmospheric or virtually atmospheric pressure.
  • the enclosure 14 also contains a pump arrangement for pumping the injection water 10, and a drive arrangement connected to the pump arrangement for operating the latter.
  • the pump arrangement is of a centrifugal pump 18, whilst the drive arrangement com ⁇ prises an electric motor 20, which is rotatably connected to the centrifugal pump 18 via a rotatable shaft 22.
  • the enclosure 14 further comprises an inlet in the form of an external, first flange coupling 24, which via a first connect ⁇ ing pipe 26 is flow-connected to an upstream side of the cen ⁇ trifugal pump 18.
  • the enclosure 14 also comprises an outlet in the form of an external, second flange coupling 28, which via a second connecting pipe 30 is flow-connected to a downstream side of the centrifugal pump 18.
  • the inlet and outlet of the enclosure 14 are also of closeable design, in that the first flange coupling 24 is coupled to a first valve 32, whilst the second flange coupling 28 is coupled to a second valve 34.
  • the valves 32, 34 can be opened or closed via associ ⁇ ated actuator arrangements (not shown) , which are connected to and driven and controlled by a remotely controlled control unit 48 in the enclosure 14.
  • the valves 32, 34 may be opened or closed by means of a remotely controlled underwater vessel (“ROV”) .
  • ROV remotely controlled underwater vessel
  • Each valve 32, 34 is also flow-connected to an injection pipe ⁇ line 36 for transporting the injection water 10.
  • An upstream end of the injection pipeline 36 is connected to an underwater installation 38 located on the seabed 6 and is designed for various treatment of the seawater 4, whilst a downstream end of the injection pipeline 36 is connected to a well head 40 cou ⁇ pled to said injection well 12 on the seabed 6 (see figures 2 and 3) .
  • the seawater 4 surrounding the underwater installation 38 is used as untreated water for the injection water 10.
  • the untreated water is drawn from a layer of water situated just above the seabed 6, and is introduced into the underwater in ⁇ stallation 38 via an intake pipe 42 coupled thereto.
  • the intake pipe 42 may also be provided with or connected to one or more suitable intake filters.
  • the enclosure 14 further contains a lubrication arrangement for lubricating various moving parts in the centrifugal pump 18 and the electric motor 20.
  • the enclosure 14 moreover contains a cooling arrangement for removing heat that is generated by equipment inside the enclosure 14 when in operation.
  • the enclo ⁇ sure 14 then also contains said remotely controlled control unit 48, which in addition to controlling said valves 32, 34 is designed for operating control of, among other things, the electric motor 20 and said lubrication arrangement and cooling arrangement.
  • the lubrication arrangement, the cooling arrangement and the control unit comprise respec ⁇ tive units (or modules), which are vertically aligned in rela ⁇ tion to one another, and which are also arranged side by side with the centrifugal pump 18 and the electric motor 20 (see figure 1) .
  • the enclosure 14 therefore contains a lower lubrica ⁇ tion unit 44, a middle cooling unit 46 and an upper, remotely controlled control unit 48, which has already been mentioned in connection with control of said valves 32, 34.
  • the enclosure 14 By aligning said equipment 18, 20, 44, 46, 48 vertically inside the vertically upright, cylindrical and relatively narrow enclosure 14 it is also possible to design the enclosure 14 with an outer circum ⁇ ference which fits inside a working aperture ("moon pool") in a deck of a floating vessel (not shown) .
  • the enclosure 14 and its contents can thereby be transported on the deck of the vessel when shipping out to the relevant offshore location, following which the enclosure 14 can be lowered down into the seawater 4, and if necessary also retrieved from the seawater 4 via the working aperture in the deck of the vessel.
  • the lower lubrication unit 44 contains, among other things, a fluid lubricant (not shown) and a suitable pump (not shown) for the lubricant.
  • Drive power and control signals to the lubricant pump are transmitted from the upper control unit 48 via a first connecting line 50.
  • Said lubrication arrangement also comprises a first lubricant pipe loop 52 and a second lubricant pipe loop 54, which connect the lubrication unit 44 to lubricated compo ⁇ nents of the centrifugal pump 18 and the electric motor 20 re ⁇ spectively.
  • the lubrication unit 44 is thereby capable of supplying such components with fluid lubricant.
  • the direction of flow of the lubricant is moreover indicated by black arrows in figure 1.
  • the middle cooling unit 46 furthermore contains, among other things, a suitable coolant (not shown) and a suitable compres ⁇ sor/pump (not shown) for the coolant.
  • Drive power and control signals to the coolant pump are transmitted from the upper con ⁇ trol unit 48 via a second connecting line 56.
  • Said cooling ar ⁇ rangement also comprises a coolant pipe loop 58, which via liq ⁇ uid-tight bushings (not shown) through the wall of the enclo ⁇ sure 14 connect the cooling unit 46 to a heat exchanger 60 ar ⁇ ranged on the outside of the enclosure 14.
  • the cooling unit 46 is thereby able to absorb heat that is gener ⁇ ated by equipment inside the enclosure 14 and to transmit this heat to the heat exchanger 60 on the outside of the enclosure 14.
  • the heat exchanger 60 exchanges the transmitted heat with colder seawater 4, which surrounds the enclosure 14.
  • a cooled coolant can thereby be returned to the cooling unit 46 for fresh absorption of heat generated in the enclosure 14.
  • the di ⁇ rection of flow of the coolant is also indicated by black ar ⁇ rows in figure 1.
  • the enclosure 14 also contains various monitoring equipment (not shown) , for example one or more cam ⁇ eras, associated light sources, various detectors including gas detectors, for operational monitoring of the centrifugal pump 18, the electric motor 20 and said cooling arrangement and lu ⁇ brication arrangement.
  • various monitoring equipment for example one or more cam ⁇ eras, associated light sources, various detectors including gas detectors, for operational monitoring of the centrifugal pump 18, the electric motor 20 and said cooling arrangement and lu ⁇ brication arrangement.
  • Drive power, control signals and moni ⁇ toring data to/from such monitoring equipment are also transmitted from/to the upper control unit 48.
  • the upper, remotely controlled control unit 48 furthermore con ⁇ tains various electronic components and equipment to the extent necessary in order to achieve the required functionality of the pump system 2 in question.
  • the control unit 48 may therefore contain various electronic processors and circuit boards, data programs, electronic circuit breakers and couplings, but also various data communications equipment, including transceivers and signal converters, and any smaller energy sources for the operation, control and/or signal transmission to/from various equipment and components in the enclosure 14, for example one or more batteries for the operation of monitoring equipment in the enclosure 14.
  • the equipment is as such generally known, however, and will therefore not be discussed in more detail here.
  • the control unit 48 also transmits control signals to the electric motor 20 via a third connecting line 62.
  • the wall of an upper part of the enclosure 14 is moreover pro ⁇ vided with a releasable and wet-mateable plug connection 64 of the plug 64a and socket 64b type.
  • the socket 64b is situated on the outside of the enclosure 14 and is connected to a liquid- tight bushing (not shown) through the wall of the enclosure 14, whilst the plug 64a is coupled to a separate control cable ("umbilical line") 66, which is connected to a remote host de ⁇ vice.
  • the plug 64a can thereby be coupled to or uncoupled from the socket 64b by means, for example of an unmanned and re ⁇ motely controlled underwater vessel (“ROV”) .
  • ROV unmanned and re ⁇ motely controlled underwater vessel
  • the control cable 66 is further designed to be capable of transmitting control signals and monitoring data between the host device and the control unit 48, and designed to be capable of transmitting drive power from the host device to powered equipment in the pump system 2.
  • the control cable 66 therefore constitutes both a signal transmission cable and a power transmission cable. Since the electric motor 20 requires a lot of electrical drive power, a power transmission cable 68 is arranged between the electric motor 20 and a power outlet (not shown) in the socket 64b.
  • a fourth connecting line 70 is also arranged between the socket 64b and the upper control unit 48 for transmitting con ⁇ trol signals, monitoring data and any drive power between the remote host device and the control unit 48.
  • FIG 2 shows an embodiment in which the control cable 66 is connected to a remote host device in the form of a floating platform 72 situated offshore.
  • Figure 3 shows another embodi ⁇ ment in which the control cable 66 is connected to a remote surface installation on land (not shown) .
  • figures 2 and 3 also show that the upstream end of the injection pipeline 36 is connected to said underwater in ⁇ stallation 38, which is located on the seabed 6 for various treatment of the untreated injection water, that is to say the seawater 4, which surrounds the underwater installation 38.
  • the seawater 4 is drawn from a layer of water situated just above the seabed 6 and is introduced into the underwater installation 38 via its intake pipe 42.
  • This underwater installation 38 comprises, among other things, at least one arrangement (not shown) for removing solid particles from the seawater 4 without filtering.
  • An example of such an underwater arrangement is described in said WO 2007/035106 Al, in which solid particles are precipitated out of the seawater 4 under gravity, so-called sedimentation .
  • the underwater installation 38 may comprise at least one arrangement (not shown) for chemical treatment of the water which runs out from the first aforementioned arrangement for the sedimentation of solid particles.
  • the water running out is brought into contact with at least one type of water-soluble solid chemical for gradually dissolving and mixing with the wa ⁇ ter.
  • water-soluble solid chemicals may consist of chlo ⁇ rine, biocide, oxygen-removal agents, corrosion inhibitors and/or settlement inhibitors.
  • An example of such a chemical treatment arrangement is described in the aforementioned WO 2004/090284 Al .
  • the underwater installation 38 comprises a discharge point for the injection water 10.

Landscapes

  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Structures Of Non-Positive Displacement Pumps (AREA)
  • Details Of Reciprocating Pumps (AREA)
  • Jet Pumps And Other Pumps (AREA)

Abstract

L'invention porte sur un système de pompe (2), sur un procédé et sur leurs utilisations pour transporter de l'eau d'injection (10) dans un puits d'injection sous-marin (12), le système de pompe (2) comprenant une enceinte (14) qui est étanche à la pression, située sous l'eau et qui renferme : - un agencement de pompe (18) servant à pomper l'eau d'injection (10) ; - un agencement d'entraînement (20) relié au agencement de pompe (18) pour faire travailler ce dernier ; un agencement de refroidissement (46) servant à évacuer la chaleur de l'intérieur de l'enceinte (14) ; et - au moins une unité de commande (48) destinée à actionner la commande d'au moins ledit agencement d'entraînement (20), dans lequel l'enceinte (14) comprend aussi : - une entrée (24) qui est reliée fluidiquement à un côté amont du agencement de pompe (18) ; et - une sortie (28) qui est reliée fluidiquement à un côté aval du agencement de pompe (18). La caractéristique du système de pompe (2) consiste en ce que l'entrée (24) de l'enceinte (14) est reliée fluidiquement à une nappe d'eau (4) dans laquelle l'enceinte (14) est située, l'eau de cette nappe d'eau (4) étant utilisée comme eau d'injection (10) dans le puits d'injection sous-marin (12) ; et - en ce que la sortie (28) de l'enceinte (14) est reliée fluidiquement au puits d'injection (12).
PCT/EP2012/057076 2011-04-18 2012-04-18 Système de pompe, procédé et leurs utilisations pour transporter de l'eau d'injection dans un puits d'injection sous-marin WO2012143392A2 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
US14/112,536 US20140112803A1 (en) 2011-04-18 2012-04-18 Pump system, method and uses for transporting injection water to an underwater injection well
GB1313758.3A GB2504008A (en) 2011-04-18 2012-04-18 Pump system method and uses for transporting injection water to an underwater injection well

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NO20110607 2011-04-18
NO20110607A NO333264B1 (no) 2011-04-18 2011-04-18 Pumpesystem, fremgangsmate og anvendelser for transport av injeksjonsvann til en undervanns injeksjonsbronn

Publications (2)

Publication Number Publication Date
WO2012143392A2 true WO2012143392A2 (fr) 2012-10-26
WO2012143392A3 WO2012143392A3 (fr) 2013-04-04

Family

ID=45998346

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/EP2012/057076 WO2012143392A2 (fr) 2011-04-18 2012-04-18 Système de pompe, procédé et leurs utilisations pour transporter de l'eau d'injection dans un puits d'injection sous-marin

Country Status (4)

Country Link
US (1) US20140112803A1 (fr)
GB (1) GB2504008A (fr)
NO (1) NO333264B1 (fr)
WO (1) WO2012143392A2 (fr)

Families Citing this family (14)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
RU2675833C2 (ru) * 2014-01-03 2018-12-25 Шелл Интернэшнл Рисерч Маатсхаппий Б.В. Способ и система для предотвращения замерзания воды с низкой соленостью в морском подводящем трубопроводе для нагнетания воды с низкой соленостью
CN106165347A (zh) * 2014-02-07 2016-11-23 英国电讯有限公司 通信接口
NO20160416A1 (en) * 2016-02-19 2017-08-21 Aker Solutions Inc Flexible subsea pump arrangement
US9915129B2 (en) * 2016-03-30 2018-03-13 Oceaneering International, Inc. Dual method subsea chemical delivery and pressure boosting
GB2549102A (en) * 2016-04-04 2017-10-11 Forsys Subsea Ltd Pipeline integrated manifold
CN106246644B (zh) * 2016-08-31 2018-06-15 长沙矿山研究院有限责任公司 一种深海钻机液压站
CA3039771C (fr) * 2016-10-11 2021-03-23 Baker Hughes, A Ge Company, Llc Injection chimique avec pompe de suralimentation sous-marine d'ecoulement de production
WO2018093456A1 (fr) * 2016-11-17 2018-05-24 Exxonmobil Upstream Research Company Système de maintien de pression de réservoir sous-marin
WO2018102008A1 (fr) * 2016-12-01 2018-06-07 Exxonmobil Upstream Research Company Système et procédé de manipulation de fluide non-vendable issu de production sous-marine
US20200018138A1 (en) * 2018-07-12 2020-01-16 Audubon Engineering Company, L.P. Offshore floating utility platform and tie-back system
CN109209309B (zh) * 2018-10-29 2021-03-02 中国石油集团渤海钻探工程有限公司 一种闭循环水力排液测试工艺系统
GB201901257D0 (en) * 2019-01-30 2019-03-20 Enpro Subsea Ltd Apparatus, systems and methods for oil and gas operations
US20220120166A1 (en) * 2020-09-30 2022-04-21 C-Innovation Llc Vessel-based water injection systems
WO2023201071A1 (fr) * 2022-04-14 2023-10-19 Chevron U.S.A. Inc. Amortissement structural pour atténuation de bruit sous-marin

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2003074353A1 (fr) 2002-03-06 2003-09-12 Aker Marine Contractors As Technique de transport sous-marin et mise en place ou retrait d'objets en mer
WO2004090284A1 (fr) 2003-04-08 2004-10-21 Sørco AS Procede et appareil pour traiter de l'eau utilisee dans un puits d'injection
WO2007035106A1 (fr) 2005-09-22 2007-03-29 Well Processing As Procede et dispositif de separation de particules de l'eau d'injection
WO2007073198A1 (fr) 2005-12-23 2007-06-28 Well Processing As Procédé et dispositif de destruction de matériau organique dans l’eau d’injection et utilisation de l’eau d’injection pour générer des radicaux hydroxyles destructeurs
US20080190291A1 (en) 2007-02-13 2008-08-14 Drew Linden Krehbiel Method and apparatus for sub-sea processing
WO2009070034A2 (fr) 2007-11-26 2009-06-04 Subsea 7 Norway Nuf Procédé permettant de saisir et de remorquer une structure sous l'eau

Family Cites Families (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB8511468D0 (en) * 1985-05-07 1985-06-12 Mobil North Sea Ltd Waterflooding injection system
US6059539A (en) * 1995-12-05 2000-05-09 Westinghouse Government Services Company Llc Sub-sea pumping system and associated method including pressure compensating arrangement for cooling and lubricating
US20020050361A1 (en) * 2000-09-29 2002-05-02 Shaw Christopher K. Novel completion method for rigless intervention where power cable is permanently deployed
GB0124616D0 (en) * 2001-10-12 2001-12-05 Alpha Thames Ltd A system and method for injecting water into a hydrocarbon reservoir
CN2752436Y (zh) * 2004-12-29 2006-01-18 大庆油田装备制造集团 活动注水站
US7658843B2 (en) * 2005-05-31 2010-02-09 Dsh International, Inc. Deep sea water harvesting method, apparatus, and product
US7468679B2 (en) * 2005-11-28 2008-12-23 Paul Feluch Method and apparatus for mud pulse telemetry
NO330192B1 (no) * 2007-04-12 2011-03-07 Framo Eng As Fluidpumpesystem.
EP2103810A1 (fr) * 2008-03-19 2009-09-23 Siemens Aktiengesellschaft Unité de compresseur
US8696331B2 (en) * 2008-05-06 2014-04-15 Fmc Technologies, Inc. Pump with magnetic bearings
CN101328797A (zh) * 2008-06-26 2008-12-24 胜利油田胜利动力机械集团有限公司 天然气机注水系统远程监控装置
US8740586B2 (en) * 2009-06-29 2014-06-03 Baker Hughes Incorporated Heat exchanger for ESP motor

Patent Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2003074353A1 (fr) 2002-03-06 2003-09-12 Aker Marine Contractors As Technique de transport sous-marin et mise en place ou retrait d'objets en mer
NO316168B1 (no) 2002-03-06 2003-12-22 Aker Marine Contractors As Fremgangsmåte for transport og installasjon av objekter til havs
WO2004090284A1 (fr) 2003-04-08 2004-10-21 Sørco AS Procede et appareil pour traiter de l'eau utilisee dans un puits d'injection
WO2007035106A1 (fr) 2005-09-22 2007-03-29 Well Processing As Procede et dispositif de separation de particules de l'eau d'injection
WO2007073198A1 (fr) 2005-12-23 2007-06-28 Well Processing As Procédé et dispositif de destruction de matériau organique dans l’eau d’injection et utilisation de l’eau d’injection pour générer des radicaux hydroxyles destructeurs
US20080190291A1 (en) 2007-02-13 2008-08-14 Drew Linden Krehbiel Method and apparatus for sub-sea processing
WO2009070034A2 (fr) 2007-11-26 2009-06-04 Subsea 7 Norway Nuf Procédé permettant de saisir et de remorquer une structure sous l'eau

Also Published As

Publication number Publication date
WO2012143392A3 (fr) 2013-04-04
NO20110607A1 (no) 2012-10-19
NO333264B1 (no) 2013-04-22
GB201313758D0 (en) 2013-09-18
GB2504008A (en) 2014-01-15
US20140112803A1 (en) 2014-04-24

Similar Documents

Publication Publication Date Title
WO2012143392A2 (fr) Système de pompe, procédé et leurs utilisations pour transporter de l'eau d'injection dans un puits d'injection sous-marin
US10161238B2 (en) Subsea technique for promoting fluid flow
US20180187395A1 (en) Mineral lifting system and mineral lifting method
US20080282777A1 (en) Geometric universal pump platform
KR101579867B1 (ko) 해저에 인접한 한 위치로부터 해수면에 인접한 한 위치로 슬러리를 운송하기 위한 라이저 시스템
CN102561997A (zh) 水下采油树修井控制系统
CN1877181B (zh) 水下干式维修工作舱
EP2721246A2 (fr) Système déflecteur pour puits sous-marin
MX2013015210A (es) Sistema modular de exploracion y produccion que incluye una embarcacion extendida para servicio de prueba de pozo.
MX2013013599A (es) Metodo y dispositivo de abastecimiento de liquidos para la oxidacion y para matar un pozo submarino.
US20170026085A1 (en) Resident ROV Signal Distribution Hub
US20120315096A1 (en) Rigless intervention
CN2900987Y (zh) 水下干式维修工作舱
NO861798L (no) Fremgangsmaate for utvinning av olje.
US10814948B2 (en) Electric power generating submarine tool
CN112278196B (zh) 深海沉船应急处置协同作业施工系统及工艺
CN112771245B (zh) 用于对水下装置和线路进行减压的非驻留系统和方法
US20220120166A1 (en) Vessel-based water injection systems
CN1014265B (zh) 海底石油和石油气的输送设备
CN209838382U (zh) 深海天然气水合物无隔水管勘探系统
EP3429918B1 (fr) Rov autonomes rechargeables ayant une source d'alimentation en mer
CN103930644A (zh) 延长井口的使用寿命的方法及装置
NO20210561A1 (en) Subsea hydrate removal assembly
KR101701609B1 (ko) 방사능 오염수의 처리 방법 및 원자력 발전소의 밀봉 방법

Legal Events

Date Code Title Description
ENP Entry into the national phase

Ref document number: 1313758

Country of ref document: GB

Kind code of ref document: A

Free format text: PCT FILING DATE = 20120418

WWE Wipo information: entry into national phase

Ref document number: 1313758.3

Country of ref document: GB

NENP Non-entry into the national phase

Ref country code: DE

WWE Wipo information: entry into national phase

Ref document number: 14112536

Country of ref document: US

122 Ep: pct application non-entry in european phase

Ref document number: 12715982

Country of ref document: EP

Kind code of ref document: A2