EP2906780A1 - Système de commande d'une pompe immergée à commande hydraulique - Google Patents

Système de commande d'une pompe immergée à commande hydraulique

Info

Publication number
EP2906780A1
EP2906780A1 EP12780971.3A EP12780971A EP2906780A1 EP 2906780 A1 EP2906780 A1 EP 2906780A1 EP 12780971 A EP12780971 A EP 12780971A EP 2906780 A1 EP2906780 A1 EP 2906780A1
Authority
EP
European Patent Office
Prior art keywords
pump
fluid
hydraulic motor
pressurized
outlet
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.)
Granted
Application number
EP12780971.3A
Other languages
German (de)
English (en)
Other versions
EP2906780B1 (fr
Inventor
Christopher K. Shaw
Howard J. HARTLEY
Wensen Wang
Eric R. SMEDSTAD
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.)
FMC Technologies Inc
Original Assignee
FMC Technologies Inc
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 FMC Technologies Inc filed Critical FMC Technologies Inc
Publication of EP2906780A1 publication Critical patent/EP2906780A1/fr
Application granted granted Critical
Publication of EP2906780B1 publication Critical patent/EP2906780B1/fr
Not-in-force legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
    • F04B47/00—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
    • F04B47/06—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
    • F04B47/08—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth the motors being actuated by fluid
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/129—Adaptations of down-hole pump systems powered by fluid supplied from outside the borehole
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
    • F04B23/00—Pumping installations or systems
    • F04B23/04—Combinations of two or more pumps
    • F04B23/08—Combinations of two or more pumps the pumps being of different types
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
    • F04B47/00—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
    • F04B47/06—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
    • F04B47/08—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth the motors being actuated by fluid
    • F04B47/10—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth the motors being actuated by fluid the units or parts thereof being liftable to ground level by fluid pressure
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
    • F04B9/00—Piston machines or pumps characterised by the driving or driven means to or from their working members
    • F04B9/08—Piston machines or pumps characterised by the driving or driven means to or from their working members the means being fluid
    • F04B9/10—Piston machines or pumps characterised by the driving or driven means to or from their working members the means being fluid the fluid being liquid
    • F04B9/109—Piston machines or pumps characterised by the driving or driven means to or from their working members the means being fluid the fluid being liquid having plural pumping chambers
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
    • F04D1/00—Radial-flow pumps, e.g. centrifugal pumps; Helico-centrifugal pumps
    • F04D1/06—Multi-stage pumps
    • 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
    • F04D13/02—Units comprising pumps and their driving means
    • F04D13/04—Units comprising pumps and their driving means the pump being fluid driven
    • 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
    • F04D13/02—Units comprising pumps and their driving means
    • F04D13/04—Units comprising pumps and their driving means the pump being fluid driven
    • F04D13/046—Units comprising pumps and their driving means the pump being fluid driven the fluid driving means being a hydraulic motor of the positive displacement type
    • 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
    • F04D13/02—Units comprising pumps and their driving means
    • F04D13/06—Units comprising pumps and their driving means the pump being electrically driven
    • F04D13/08—Units comprising pumps and their driving means the pump being electrically driven for submerged use
    • F04D13/10—Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
    • 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
    • F04D13/12—Combinations of two or more pumps

Definitions

  • the present disclosure relates to a system that may be employed in recovering hydrocarbons from oil and gas wells. More specifically, the present disclosure is directed to various embodiments of a system for operating a hydraulically-powered submersible pump that uses a pump positioned subsea to supply the pressurized fluid to drive the submersible pump.
  • submersible pumps positioned in the well is one common technique that is employed to increase the flow rate of hydrocarbons to economically acceptable levels.
  • Such pumps may take a variety of forms, e.g., an electrical submersible pump (ESP), a hydraulic submersible pump (HSP), a progressing cavity pump, a jet pump, etc.
  • An ESP or an HSP typically includes a multistage centrifugal pump.
  • An ESP is operatively coupled to and driven by an electric motor.
  • An HSP is operatively coupled to a hydraulic motor.
  • the ESP or HSP may be installed inside the well in a tubing string, and it is typically situated at a certain depth within the well.
  • An ESP is powered via an electrical umbilical that includes an electric cable that is connected to a source of electrical power, e.g., a generator, positioned on a topside facility, e.g., a platform, a ship, etc.
  • An HSP is powered via a hydraulic umbilical, a tubing or pressurized fluid in an annular space that includes a conduit for the supply of pressurized fluid to the HSP, wherein the conduit is connected to a source of pressurized hydraulic fluid, e.g., a pump that is positioned on a topside facility, e.g., a platform, a ship, etc.
  • a source of pressurized hydraulic fluid e.g., a pump that is positioned on a topside facility, e.g., a platform, a ship, etc.
  • the HSP may be powered via pressurized fluid supplied via a tubing or via pressurized fluid supplied via an annular space.
  • An ESP is typically positioned within a well or a Christmas tree by suspending it on the production tubing and strapping an electrical cable on the outside of the production tubing from the ESP to the wellhead or Christmas tree.
  • the electrical cable is operatively coupled to the electrical motor portion of the ESP.
  • Electrical connectors or penetrators are coupled to the opposite end of the electrical cable within the wellhead of Christmas tree production tubing hanger. Multiple electrical connections will be made to thereby establish electrical conductivity with the electrical umbilical so as to provide electrical power to the electrical motor portion of the ESP.
  • a similar arrangement is made for HSPs except that a conduit, such as the annular space between the outside diameter of the production tubing and the inside diameter of the casing, extends between the HSP hanger and the HSP positioned down-hole.
  • the conduit is operatively coupled to the hydraulic motor portion of the HSP, and high-pressure fluid is supplied to the hydraulic motor via the conduit so as to drive the pump portion of the HSP.
  • a hydraulic connector that is in fluid communication with the conduit will be coupled to another hydraulic connector to thereby establish fluid communication with the hydraulic umbilical so as to provide a pressurized fluid to the hydraulic motor portion of the HSP.
  • the working fluid for an HSP motor can be either a component of the fluid the HSP is pumping, or a separate working fluid dedicated to driving the HSP may be used.
  • a typical problem encountered with the use of ESPs relates to reliability or longevity of electrical connectors and other electric components, e.g., electric motors. It is frequently the case that the electrical components that are responsible for powering the pump in an ESP fail for one reason or another leading to well downtime and/or expensive repairs.
  • a hydraulic powered submersible pump utilizes a more robust power delivery system which has a significantly longer mean time to failure than electrically powered submersible pump systems.
  • the use of a hydraulic umbilical to supply pressurized fluid from a pump positioned on a topside facility to drive an HSP becomes more problematic. For example, in a closed-loop system, as the water depth increases, the liquid head that must be overcome when the drive fluid is returned to the surface is becoming a very significant factor as it relates to system design and quality.
  • the present disclosure is directed to various embodiments of a system for operating a hydraulically-powered submersible pump that may solve or reduce one or more of the problems identified above.
  • the present disclosure is directed to various embodiments of a system for operating a hydraulically-powered submersible pump that uses a pump positioned subsea to supply the pressurized fluid to drive the submersible pump.
  • a hydraulically-powered submersible pump that uses a pump positioned subsea to supply the pressurized fluid to drive the submersible pump.
  • One illustrative system disclosed herein includes a submersible pump positioned in a well, a hydraulic motor that is operatively coupled to the submersible pump and a pressurized fluid supply pump that is positioned on or near a floor of the subsea environment and in fluid communication with the hydraulic motor.
  • Another illustrative system disclosed herein includes a production tree positioned above a well, a submersible pump positioned in the well, a hydraulic motor that is operatively coupled to the submersible pump, a booster pump that is adapted to receive a hydrocarbon fluid from a production outlet of the tree and a pressurized fluid supply pump that is positioned on or near a floor of the subsea environment, wherein the pressurized fluid supply pump is in fluid communication with the hydraulic motor.
  • the system may also include a separator that is adapted to receive a pressurized fluid from an outlet of the booster pump, and the pressurized fluid supply pump is in fluid communication with the hydraulic motor.
  • Yet another illustrative system disclosed herein includes a production tree positioned above a well, a submersible pump positioned in the well, a hydraulic motor that is operatively coupled to the submersible pump, a booster pump positioned on or near a floor of the subsea environment, wherein the booster pump is adapted to receive a hydrocarbon fluid from a production outlet of the tree, and a separator that is adapted to receive a pressurized fluid from an outlet of the booster pump, wherein the separator comprises a fluid outlet that is in fluid communication with the hydraulic motor.
  • Yet another illustrative system disclosed herein includes a production tree positioned above a well, a submersible pump positioned in the well, a hydraulic motor that is operatively coupled to the submersible pump, a booster pump positioned on or near a floor of the subsea environment, wherein the booster pump is adapted to receive a hydrocarbon fluid from a production outlet of the tree, and a valve that is in fluid communication with an outlet of the booster pump and adapted to receive a pressurized hydrocarbon fluid from the outlet of the booster pump and direct a portion of the pressurized hydrocarbon fluid to the hydraulic motor.
  • Yet another illustrative system disclosed herein includes a production tree positioned above a well, a submersible pump positioned in the well, a hydraulic motor that is operatively coupled to the submersible pump, a booster pump that is adapted to receive a hydrocarbon fluid from a production outlet of the tree, a pressurized fluid supply pump that is positioned on or near a floor of the subsea environment, wherein the pressurized fluid supply pump is in fluid communication with the hydraulic motor, and a turbine comprising a shaft that is operatively coupled to the pressurized fluid pump, the turbine being in fluid communication with an outlet of the booster pump and adapted to receive a pressurized hydrocarbon fluid from the outlet of the booster pump, wherein the shaft is adapted to be rotated by the pressurized hydrocarbon fluid, and wherein the shaft is further adapted to drive the pressurized fluid pump via rotation of the shaft.
  • Figures 1A-1G are various views of various illustrative embodiments of a system for operating a hydraulically-powered submersible pump that uses a pump positioned subsea to supply the pressurized fluid to drive the submersible pump.
  • FIGS. 1A-1B are simplistic and schematic depictions of one illustrative embodiment of a system 10 that includes a hydraulically- powered submersible pump 30 (HSP) that is positioned down-hole in a well 11.
  • HSP hydraulically- powered submersible pump 30
  • the HSP 30 is generally comprised of a pump 3 OP and a hydraulic motor 3 OHM that is operatively coupled to the pump 3 OP.
  • the pump 3 OP is intended to be representative of any type of pump that may be used to pump hydrocarbon fluids, e.g., a centrifugal pump, a progressing cavity pump, a jet pump, etc.
  • the present invention should not be considered to be limited to any particular type or form of the pump 3 OP that may be used as part of the HSP 30.
  • a pressurized fluid 70 that is used to actuate the HSP 30 to pump hydrocarbons out of the well 11 is supplied by an illustrative pressurized fluid supply pump 60 (PFS pump 60) that is positioned subsea, i.e., in the water.
  • PFS pump 60 pressurized fluid supply pump 60
  • the system 10 is comprised of production casing 12, production tubing 14 positioned within the production casing 12, a well head 16 that is coupled to the production casing 12, a tubing head 18, a production or Christmas tree 20 and a tree cap 22.
  • the system 10 is further comprised of a sealing member 24, several sections of tubing that are generally designated with the reference numbers 32A, 32B and 32C, a production tubing hanger 34, a HSP hanger 35, and a plurality of hydraulic connectors 36, 38, 40, 42, 44 and 46.
  • the illustrative PFS pump 60 is positioned on a schematically depicted skid 62 that is positioned on or near the sea floor 64.
  • Figure IB is an enlarged view of the area of the system adjacent the HSP hanger 35.
  • a schematically depicted isolation valve 48 (not shown in Figure 1A), e.g., a ball valve or a gate valve, is incorporated in the production tree 20.
  • the isolation valve 48 is large enough to allow the HSP hanger 35 and the hydraulic connectors 36, 38 to pass therethrough during the installation of the HSP system in the well 11 and production tree 20, as will be described more fully below.
  • the hydraulic connectors 36, 38 are depicted in a spaced-apart, un-mated condition. Additional details of the various aspects of the various systems disclosed herein will be discussed further below.
  • the various components of the system 10 disclosed herein may be of traditional construction that may be made using traditional materials.
  • the system 10 includes numerous clamps, bolts and seals for assembling the various components depicted in the attached figures to one another, but such details are not included in the attached drawings so as not to obscure the presently disclosed invention and because such details of construction are well known to those skilled in the art.
  • the subsea PFS pump 60 is adapted to supply a pressurized fluid 70 to the hydraulic motor 30HM via the tubing 32, e.g., coiled tubing.
  • the HSP 30 is positioned below the level of hydrocarbons (liquid and/or gas) in the well 11.
  • the pump 3 OP of the HSP 30 has an intake 30A where hydrocarbons enter the pump
  • the pressurized fluid 70 causes the hydraulic motor 3 OHM to rotate, which in turn, in the case where the submersible pump 3 OP is a centrifugal pump, causes the submersible pump 30P to rotate and thereby increases the pressure of the hydrocarbon fluids as they pass through the pump 3 OP. More specifically, hydrocarbons enter the pump 30P, as schematically depicted by the arrow 80, and leave the pump 3 OP as a pressurized hydrocarbon fluid 82 via various outlets (not shown) in the pump 3 OP. The pressurized hydrocarbon fluid 82 is discharged into the annular space 13 between the production tubing 14 and the tubing 32.
  • the discharged fluid 70R from the hydraulic motor 3 OHM which is now at a relatively lower pressure, leaves the hydraulic motor 3 OHM via various outlets (not shown), and, in this embodiment of the system 10, is also discharged into the annular space 13 between the production tubing 14 and the tubing 32 where it co- mingles with the pressurized hydrocarbon fluid 82 that passed through the pump 30P.
  • the production tree 20 includes a production outlet 20A where a production fluid 90 (a combination of the pressurized hydrocarbon fluid 82 and the discharged fluid 70R) exits the tree 20 and flows to other processing equipment, described more fully below, for further processing.
  • the various systems 10 disclosed herein may be implemented using either open- loop or closed- loop type pumping systems.
  • the PFS pump 60 depicted herein is intended to be representative in nature in that it represents any type of pump that may be used to increase the pressure of a fluid (gas or liquid, or a combination thereof) as it passes through the PFS pump 60.
  • the PFS pump 60 may have any type of configuration, e.g., a centrifugal type pump, a positive displacement type pump, etc., it may be of any size or horsepower, and it may be adapted to pump a single phase fluid or a multi-phase fluid.
  • the PFS pump 60 may be an electrical pump that is powered and controlled via an electrical umbilical (not shown) that is connected to an electrical power supply source positioned on a topside facility, e.g., a platform.
  • the PFS pump 60 should not be considered as limited to any particular type or form of pump.
  • the PFS pump 60 is of a size such that it alone is adapted to increase a pressure of a hydrocarbon fluid so that hydrocarbon fluid may flow from a floor of the subsea environment to a surface of the subsea environment without the need to further increase the pressure on the hydrocarbon fluids.
  • the tubing 32 is also intended to be representative of any type of conduit, e.g., coiled tubing, that may be employed in a well to conduct and contain a pressurized fluid from one location to another location.
  • Figures 1C-1G are process flow diagrams that schematically depict various illustrative examples of specific implementations of the system 10 as it relates to producing hydrocarbons from the well 11.
  • Figure 1C depicts one illustrative system 10A that includes a plurality of subsea pumps 102, 104 and a schematically depicted liquid/gas separator 106.
  • the production fluid 90 (a combination of the pressurized hydrocarbon fluid 82 and the discharged fluid 70R) may be a multi-phase fluid containing liquid and gaseous hydrocarbon components.
  • the production fluid 90 exits the tree 20 via production outlet 20A (see Figure 1A) and flows to the pump 102 where its pressure is increased and where it thereafter leaves the pump 102 as a pressurized production or pressurized hydrocarbon fluid
  • the pressurized production fluid 90P flows to the separator 106 where its liquid and gas components are separated.
  • the separated production liquid 90PL may be transmitted to a topside facility or a pipeline for collection and/or transmission.
  • the separated gas 90G may be transmitted to the surface for collection and/or transmission via a separate pipeline and riser.
  • a portion of the separated production liquid 90PL is supplied to the pump 104 where its pressure is increased to the desired pressure level for driving the HSP 30 in the well 11. i.e., the output from the pump 104 is the pressurized fluid 70 that is used to drive the HSP 30.
  • This pressurized fluid 90PL generally will have been treated with various types of flow assurance chemicals to prevent the formation of hydrates, scale, asphaltenes, etc.
  • the pump 104 is the PFS pump 60.
  • a choke may be positioned between the separator 106 and the pump 104 to regulate the flow of the production liquid 90PL to the pump 104.
  • Various valves and flanged connections that would normally be provided to allow assembly of the components of the system 10A are not depicted so as not to obscure the presently disclosed inventions.
  • the pump 102 may be booster pump that is adapted to pump a multi-phase fluid. Such booster pumps are typically employed to increase the pressure of the production fluid 90 so that it may be transmitted via a pipeline over relatively long distances.
  • the pump 104 may be a pump that is adapted to pump a single phase fluid, e.g., the production liquid 90PL from the separator 106.
  • the pumps 102, 104 are sometimes generically referred to as "mud-line" pumps as they are often positioned in one or more skids that are positioned on or near the sea floor.
  • the pumps 102, 104 need not be positioned on the same skid.
  • the sizing of the pumps 102, 104 may vary depending upon the particular application.
  • FIG. 10B depicts another system 10B that employs the novel concepts disclosed herein.
  • System 10B is substantially identical to system 10A described above except that, in system 10B, the pump 104 has been removed.
  • a portion of the separated production liquid 90PL is at a sufficient pressure within the separator 106 such that it may be used to drive the HSP 30 in the well 11 without further increasing its pressure, i.e., the production liquid 90PL from the separator 106 is the pressurized fluid 70 that is used to drive the HSP 30.
  • a choke may be positioned between the separator 106 and the HSP 30 to regulate the flow or pressure of the production liquid 90PL as it is supplied to the HSP 30.
  • the pump 102 is the PFS pump 60.
  • Figure IE depicts another illustrative system IOC that employs the novel concepts disclosed herein.
  • System IOC is substantially identical to system 10B described above except that, in system IOC, the separator 106 has been removed.
  • the pressurized production fluid 90P (after it leaves the pump 102) is at a sufficient pressure such that a portion of the pressurized production fluid 90P may be used to drive the HSP 30 in the well
  • the pressurized production fluid 90P is the pressurized fluid 70 that is used to drive the HSP 30.
  • a schematically depicted valve 112 may be positioned between the outlet of the pump 102 and the HSP 30 to direct a portion 90PA of the pressurized hydrocarbon fluid 90P to the HSP 30.
  • a choke may be positioned between the valve 112 and the HSP 30 to regulate the flow or pressure of the liquid 90PA as it is supplied to the HSP 30.
  • the portion of the pressurized production fluid 90P that is not used to drive the HSP 30 may be transmitted to a topside facility or a pipeline for collection and/or transmission.
  • the pump 102 is the PFS pump 60.
  • FIG. IF depicts yet another illustrative system 10D that employs the novel concepts disclosed herein.
  • the system 10D includes the pump 102, a schematically depicted turbine 116 with an output shaft 116S that is operatively coupled to a pump 118.
  • the turbine 116 is adapted to drive the pump 118.
  • a separate fluid 120 is supplied to the intake of pump 118 from other sources, i.e., dead oil or other fluid from topsides that does not pose any flow assurance risks.
  • the output from the pump 118 is the pressurized fluid 70 that is used to drive the HSP 30.
  • the pump 118 is the PFS pump 60.
  • FIG. 1G depicts yet another illustrative system 10E that employs the novel concepts disclosed herein.
  • the system 10E includes a closed loop system 130 that includes the HSP 30, a fluid reservoir 134 and a pump 138.
  • the system 10E includes a schematically depicted turbine 116 with an output shaft 116S that is adapted to drive the pump 138.
  • the system 130 is a closed system, only pressurized hydrocarbon fluid 82 exits the production outlet 20A of the tree 20 (see
  • the hydrocarbon fluid 82 is not co-mingled with discharged fluid from the HSP 30.
  • the pressure of the hydrocarbon fluid 82 is increased as it passes through the pump 102 where it exits as hydrocarbon fluid 82P.
  • the output from the pump 138 is the pressurized fluid 70 that is used to drive the HSP 30.
  • the system 130 includes a feed or supply line 131 and a return line 132 whereby, after the pressurized fluid 70 passes through the HSP 30, it is returned to the reservoir 134.
  • the liquid within the reservoir 134 is supplied to the intake of the pump 138 via line 136.
  • the pump 138 is the PFS pump 60.
  • the hydrocarbon fluid 82P that passes through the turbine 116 may be transmitted to a topside facility or a pipeline for collection and/or transmission.
  • the system 10 may be assembled as follows. Initially, after the production tubing 14 is secured in the tubing hanger 34, the HSP hanger 35 is positioned and secured in the tree 20 via known locking or clamping mechanisms. The HSP 30 is secured to the HSP hanger 35 using a coiled tubing or similar conductor and run into the well 1 1 during the installation of the HSP hanger 35. The isolation valve 48 is closed after the process of running the HSP 30 into the well is complete and provides a pressure- barrier while the blow-out preventer (not shown) is removed from the tree 20. The seal member 24 provides a barrier seal between the production tubing 14 and the intake to the pump 30A of the HSP 30.
  • the tree cap 22 is lowered into position and secured to the tree 20.
  • the hydraulic connector 36 is not operatively coupled to the hydraulic connector 38.
  • the isolation valve 48 is opened and the hydraulic connectors 36, 38 are operatively coupled to one another, using any of a variety of known techniques.
  • a screw type assembly (not shown) may be provided in the tree cap 22 that, when actuated, causes the connector 38 to move downward through the open isolation valve 48 and into engagement with the connector 36.
  • a piston-type assembly that, when actuated, also causes the connector 38 to move downward through the open isolation valve 48 and into engagement with the connector 36.

Landscapes

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

Abstract

Cette invention concerne un système disposé dans un environnement sous-marin, comprenant une pompe immergée positionnée dans un puits, un moteur hydraulique fonctionnellement couplé à la pompe immergée et une pompe d'alimentation en fluide pressurisé disposée sur ou à proximité d'un fond de l'environnement sous-marin et en communication fluidique avec le moteur hydraulique.
EP12780971.3A 2012-10-11 2012-10-11 Système de commande d'une pompe immergée à commande hydraulique Not-in-force EP2906780B1 (fr)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2012/059652 WO2014058426A1 (fr) 2012-10-11 2012-10-11 Système de commande d'une pompe immergée à commande hydraulique

Publications (2)

Publication Number Publication Date
EP2906780A1 true EP2906780A1 (fr) 2015-08-19
EP2906780B1 EP2906780B1 (fr) 2016-11-23

Family

ID=47116409

Family Applications (1)

Application Number Title Priority Date Filing Date
EP12780971.3A Not-in-force EP2906780B1 (fr) 2012-10-11 2012-10-11 Système de commande d'une pompe immergée à commande hydraulique

Country Status (6)

Country Link
US (1) US20150226208A1 (fr)
EP (1) EP2906780B1 (fr)
AU (1) AU2012392172B2 (fr)
BR (1) BR112015005332A2 (fr)
SG (1) SG11201502754WA (fr)
WO (1) WO2014058426A1 (fr)

Families Citing this family (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20110164999A1 (en) * 2010-01-04 2011-07-07 Dale Meek Power pumping system and method for a downhole tool
US10323494B2 (en) 2015-07-23 2019-06-18 General Electric Company Hydrocarbon production system and an associated method thereof
US10077646B2 (en) * 2015-07-23 2018-09-18 General Electric Company Closed loop hydrocarbon extraction system and a method for operating the same
US10047596B2 (en) 2015-07-23 2018-08-14 General Electric Company System and method for disposal of water produced from a plurality of wells of a well-pad
US10337302B2 (en) * 2017-03-06 2019-07-02 Saudi Arabian Oil Company In-situ replacement of fluids in a well tool
CN110821448B (zh) * 2019-11-14 2022-02-18 中国科学院广州能源研究所 一种海相天然气水合物的开采方法及开采装置
EP3964717A1 (fr) * 2020-09-03 2022-03-09 Sulzer Management AG Échangeur de pression sous-marin multiphase
CN112160910A (zh) * 2020-09-09 2021-01-01 广德元瑞生产力促进中心有限公司 一种液压渣浆泵
US11578534B2 (en) * 2021-02-25 2023-02-14 Saudi Arabian Oil Company Lifting hydrocarbons

Family Cites Families (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4233154A (en) * 1978-12-29 1980-11-11 Kobe, Inc. Method for treating petroleum well pumping power fluid
NO175020C (no) * 1986-08-04 1994-08-17 Norske Stats Oljeselskap Fremgangsmåte ved transport av ubehandlet brönnström
US4871302A (en) * 1988-01-26 1989-10-03 Milam/Clardy, Inc. Apparatus for removing fluid from the ground and method for same
BR9003370A (pt) * 1990-07-13 1992-01-21 Petroleo Brasileiro Sa Sistema de producao de oleo e gas em aguas profundas
BR0303129B1 (pt) * 2003-08-14 2013-08-06 mÉtodo e aparelhagem para produÇço de poÇos de petràleo
BR0303094A (pt) * 2003-08-14 2005-04-05 Petroleo Brasileiro Sa Aparelhagem para produção de poços de petróleo
BRPI0703726B1 (pt) * 2007-10-10 2018-06-12 Petróleo Brasileiro S.A. - Petrobras Módulo de bombeio e sistema para bombeio submarino de produção de hidrocarbonetos com alta fração de gás associado
US20110232912A1 (en) * 2010-03-25 2011-09-29 Chevron U.S.A. Inc. System and method for hydraulically powering a seafloor pump for delivering produced fluid from a subsea well
US8834133B2 (en) * 2010-08-05 2014-09-16 Bp Corporation North America Inc. Pumping device for fluids located at the bottom of a drilled well

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See references of WO2014058426A1 *

Also Published As

Publication number Publication date
SG11201502754WA (en) 2015-05-28
EP2906780B1 (fr) 2016-11-23
AU2012392172B2 (en) 2017-05-04
BR112015005332A2 (pt) 2017-07-04
AU2012392172A1 (en) 2015-02-26
WO2014058426A1 (fr) 2014-04-17
US20150226208A1 (en) 2015-08-13

Similar Documents

Publication Publication Date Title
AU2012392172B2 (en) System for operating a hydraulically powered submersible pump
US10246972B2 (en) In-riser power generation
US9556710B2 (en) Apparatus and method for recovering fluids from a well and/or injecting fluids into a well
EP2198120B1 (fr) Système et module de pompage
US6688392B2 (en) System and method for flow/pressure boosting in a subsea environment
US8893775B2 (en) Multiple electric submersible pump system
EP3485136B1 (fr) Système d'installation de pompe électrique immergée sur un puits
EP2394018B1 (fr) Ensemble rame sous-marine
US20220290538A1 (en) Subsea pumping and booster system
MX2011004687A (es) Metodo para modificar un pozo de produccion de petroleo existente en una ubicacion submarina, y un pozo de produccion de petroleo modificado de tal manera.
US11970926B2 (en) Electric submersible pump completion with wet-mate receptacle, electrical coupling (stinger), and hydraulic anchor
US11913296B1 (en) Auto recycle system to maintain fluid level on ESP operation
US20170198582A1 (en) Well site pump with integrated driver and hydraulic motor and method of using same
NO20230976A1 (en) Subsea pumping and booster system
CN113646503A (zh) 用于井操作的管道系统

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

17P Request for examination filed

Effective date: 20150331

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

AX Request for extension of the european patent

Extension state: BA ME

DAX Request for extension of the european patent (deleted)
RIC1 Information provided on ipc code assigned before grant

Ipc: F04D 13/04 20060101ALI20160504BHEP

Ipc: F04B 47/08 20060101ALI20160504BHEP

Ipc: E21B 43/12 20060101AFI20160504BHEP

Ipc: F04D 13/10 20060101ALI20160504BHEP

Ipc: F04B 47/10 20060101ALI20160504BHEP

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

INTG Intention to grant announced

Effective date: 20160614

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: CH

Ref legal event code: EP

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: AT

Ref legal event code: REF

Ref document number: 848108

Country of ref document: AT

Kind code of ref document: T

Effective date: 20161215

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602012025793

Country of ref document: DE

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LV

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

REG Reference to a national code

Ref country code: LT

Ref legal event code: MG4D

REG Reference to a national code

Ref country code: NL

Ref legal event code: MP

Effective date: 20161123

REG Reference to a national code

Ref country code: AT

Ref legal event code: MK05

Ref document number: 848108

Country of ref document: AT

Kind code of ref document: T

Effective date: 20161123

REG Reference to a national code

Ref country code: NO

Ref legal event code: T2

Effective date: 20161123

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: SE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: GR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20170224

Ref country code: NL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: PL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: HR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: PT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20170323

Ref country code: RS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: FI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: AT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: ES

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: EE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: SK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: RO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: DK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: CZ

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

REG Reference to a national code

Ref country code: DE

Ref legal event code: R097

Ref document number: 602012025793

Country of ref document: DE

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: BG

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20170223

Ref country code: BE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: SM

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

REG Reference to a national code

Ref country code: FR

Ref legal event code: PLFP

Year of fee payment: 6

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: FR

Payment date: 20170918

Year of fee payment: 6

26N No opposition filed

Effective date: 20170824

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: NO

Payment date: 20171010

Year of fee payment: 6

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 20171011

Year of fee payment: 6

Ref country code: IT

Payment date: 20171024

Year of fee payment: 6

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 602012025793

Country of ref document: DE

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MC

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

REG Reference to a national code

Ref country code: IE

Ref legal event code: MM4A

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20180501

Ref country code: LU

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20171011

Ref country code: LI

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20171031

Ref country code: CH

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20171031

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MT

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20171011

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20171011

REG Reference to a national code

Ref country code: NO

Ref legal event code: MMEP

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 20181011

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: HU

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT; INVALID AB INITIO

Effective date: 20121011

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NO

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20181031

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: FR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20181031

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IT

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20181011

Ref country code: CY

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: GB

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20181011

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: TR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: AL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20161123

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20170323