WO2015123736A1 - Système sous-marin d'injection d'eau de mer au moyen d'une pompe centrifuge immergée - Google Patents

Système sous-marin d'injection d'eau de mer au moyen d'une pompe centrifuge immergée Download PDF

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Publication number
WO2015123736A1
WO2015123736A1 PCT/BR2014/000052 BR2014000052W WO2015123736A1 WO 2015123736 A1 WO2015123736 A1 WO 2015123736A1 BR 2014000052 W BR2014000052 W BR 2014000052W WO 2015123736 A1 WO2015123736 A1 WO 2015123736A1
Authority
WO
WIPO (PCT)
Prior art keywords
injection
pump
water
flow
pickup tube
Prior art date
Application number
PCT/BR2014/000052
Other languages
English (en)
Portuguese (pt)
Inventor
Carlos Eduardo MAIA DE SOUZA
Rene Thiago CAPELARI ORLOWSK
Original Assignee
Petróleo Brasileiro S.A. - Petrobras
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 Petróleo Brasileiro S.A. - Petrobras filed Critical Petróleo Brasileiro S.A. - Petrobras
Priority to PCT/BR2014/000052 priority Critical patent/WO2015123736A1/fr
Publication of WO2015123736A1 publication Critical patent/WO2015123736A1/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
    • F04D29/00—Details, component parts, or accessories
    • F04D29/70—Suction grids; Strainers; Dust separation; Cleaning
    • F04D29/708—Suction grids; Strainers; Dust separation; Cleaning specially for liquid pumps
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • 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
    • F04D13/066—Floating-units
    • 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

Definitions

  • the present invention relates to subsea seawater injection system by means of specially developed equipment employing submerged centrifugal pump.
  • This technology is intended for the area of oil exploration and production and the like, specifically in the production of new fields, as a method of injecting water into oil or gas reservoir aquifers that require a secondary recovery method through water injection. Its full use is mainly intended for injection wells where the injection of untreated seawater does not cause undesired formation damage. Its application is directly linked to the reduction of water injection plants installed in floating units.
  • Water injection into the reservoir must be selectively so that water enters the intervals of different permeability which, in this case, is controlled by flow regulators acting independently by interval. In applying secondary recovery it is necessary to determine the injection flow rate of each interval as very high values may fracture the formation.
  • PI 0904009-9 refers to a downhole water injection regulator installed in a side pocket chuck to regulate fluid flow in a water injection completion.
  • the regulator is fitted with an internal piston and may be fitted with a retaining dart.
  • the piston and retention dart regulate the flow of fluid within the regulator housing.
  • the seals in the regulator housing block the spindle holes that communicate with a surrounding ring.
  • the blind plug on the regulator lock prevents fluid flow through the regulator so that the regulator acts as a fake valve and allows operators to adjust and test the shutters or perform other operations.
  • operators use a cable and winch to remove the blind plug disposed in the lock.
  • PI 0708920-1 (Shell) relates to a water injection system and method comprising a well drilled within a subsurface formation; a production facility on one end of the well; a water production facility connected with the production facility; wherein the water production facility produces water by removing some ions and adding an agent that increases water viscosity and / or enhances hydrocarbon recovery from formation and injects water into the well.
  • Document PI 0404603 deals with a system for capturing and injecting underground aquifer water into hydrocarbon reservoirs, specifically a system for capturing aquifer water wells and injector wells in oil reservoir (petroleum) and one or more bombs.
  • Document BR PI 0400926 comprises a well drilled in a subsurface formation, a production facility on the upper side of the well with a water production facility connected to the production facility, where the water production facility produces water. by removing some ions and adding an agent that increases water viscosity and / or enhances hydrocarbon recovery from formation by injecting water into the well.
  • Submerged centrifugal pumping systems - BCS - are not new and have been widely employed within dry completion wells, offshore and onshore, where they are very effective. In these In these cases, its replacement cost is considered cheap in the industry. But a defective pump at the bottom of a wet-completed well can be a production and logistical problem. In addition to pump replacement costs, reliance on resources such as a marine rig, which are not always readily available, can mean production shutdown. The challenge is to increase the reliability of these pumps and to seek alternative arrangements that facilitate intervention when they fail, such as installing the pumps in seabed hosts rather than the producing well.
  • the main difficulty is associated with the complexity of the system and the amount of equipment that needs to be installed.
  • the flowbase is designed to be accommodated on the seabed and therefore has a geometry foundation structure designed and constructed to maintain the correct leveling of all equipment regardless of the inclines or slopes of the ground.
  • the base structure will need to be modified to adjust to the new ground conditions. This causes major impacts on the project, with delays and increased costs.
  • Barrier fluid also requires a supply unit installed in the Floating Unit which also requires more stringent care with regard to the risk of water contamination.
  • the fluid when restricted to specification, can often be supplied by only one manufacturer, representing a supply problem.
  • Flowbase Positioned on the seabed, you can use a mud mat type structure designed to accommodate the slope of the ground or even be installed on a torpedo type subbase, which must be pre-nailed.
  • the flow base serves as a guide and housing for the other equipment that makes up the subsea pumping station. There are also pipes that connect the suction and discharge of the pump to the respective connectors of the water collection line to the flow base and the flow base injection line to the ANM.
  • Pump module - is the module in which the pump assembly resides, recoverable filter module with backwash system, ROV panel, receptacles with supply, valves, flowmeter and choke.
  • the pump used for water injection is a rotary type centrifugal pump.
  • Connection Modules - Lines that connect the pump station to the ANM and pickup utilize connection modules to connect to the flowbase. These modules can be horizontal or vertical.
  • PETROBRAS now requesting this application, uses hydraulic locking vertical connection modules.
  • the modules that make the line connection between the ANM and the flow base are the pump discharge modules.
  • the module installed at the end of the water intake line connects the latter to the pump suction through the flow base tubing.
  • Umbilical Termination Module To bring the power required to power the electric motor from the motor pump assembly, a power umbilical is required from the Floating Unit to the pump. This umbilical connects to the flowbase through an MTU. Likewise, to bring hydraulic power to actuate and control subsea valves, there is an umbilical that connects a Hydraulic Power Unit (UPH) installed in the Floating Unit to the flow base. This umbilical also has hydraulic lines for the transportation of barrier fluid needed to protect the electric motor. This umbilical is connected to the flowbase via an MTU.
  • UHP Hydraulic Power Unit
  • Water catchment line - This is a flexible line that has, at one end, a submerged buoy that elevates it and maintains it to a certain extent in relation to the seabed. At this end the capture is made through an inlet nozzle with sieve and support for fixing on the float. The line then descends and before touching the seabed makes a slight catenary. Part of the line is bottom and goes towards the pump suction connection module.
  • Hydraulic Power Units For seabed pumping systems currently used for water injection, two hydraulic power units are required. One control fluid and one barrier fluid UPH, both installed in the Floating Unit. The former is responsible for the supply of hydraulic fluid for actuation and control of subsea valves, while the latter is responsible for the supply of barrier fluid to the electric motor of the motorcycle pump assembly.
  • VSD Variable Speed Driver
  • Electrical panels - Surface equipment assemblies include the electrical panels required for pump control and operation.
  • Figure 1 represents, in perspective, one of the preferred constructivities for the equipment used in the innovative underwater seawater injection system, which employs a sustaining buoy;
  • FIGS. 2, 3 and 4 represent perspectives on alternative constructions of the equipment that employs a buoy
  • Figures 5 and 6 illustrate models of the innovative underwater seawater injection system equipment utilizing, instead of the float, a filter applied to the upper end of the intake tube;
  • Figure 7 illustrates, through perspective, the first option for installing innovative equipment on top of the ANM;
  • Figure 8 represents a second configuration option, where the equipment is installed in the injection chuck.
  • Figures 9 and 9A illustrate a third installation configuration where the apparatus is located on a torpedo sub-base with an injection line interconnecting it with the ANM; Figures 9 and 9A illustrate two positioning versions of equipment in the form of a pump set pickup tube used in the present system.
  • This technology is intended for the oil exploration and production area and the like, specifically in the production of new fields, as a method of injecting water into oil or gas reservoir aquifers that require a secondary recovery method by injection of Water. Its full use is mainly intended for injection wells where the injection of untreated seawater does not cause undesired formation damage. Its application is directly linked to the reduction of water injection plants installed in floating units.
  • the innovative submersible centrifugal pump pumping water injection system - BCS is formed by an equipment (E1) consisting of a pickup tube (2), consisting of a steel tube of up to 50m and with sufficient diameter to accommodate the main components of the pumping system inserted inside it, which also has a structural function.
  • the pickup tube (2) is fully open at the upper end (2a) and is partially closed at the lower end (2b) and further receives a guide funnel (2c) surrounding the connector (2d) designed for various assemblies, such as on ANM (22) (figure 7) or base (24) arranged on the sea floor (figures 8 and 9); at the upper end (2a) of the pickup tube and outside it a first filter device is installed which, in one option may be configured by sieve (3) associated with a float (4) (figures 1 to 4) or may be a module (5) provided with a sieve (6) and filter (8) or (9) installed therein (figures 5 and 6), each of which is responsible for trapping larger particles and preventing marine life from entering the interior. pickup tube (2).
  • the float (4) is responsible for the tensioning of the structure or suspension of all equipment (E1) in certain assembly configurations, dealt with below, which tensioning is allowed by means of mooring cables (7).
  • the float (4) is optional as it depends on the arrangement or installation chosen.
  • Submerged Centrifuge or BCS (1) may be only one BCS or several mounted in series with the first discharge directed to the second suction, and so on. Mentioned BCS pump (1) is responsible for increasing the pressure and flow required for injection. BCS or the various Mounted in series are aligned, centered or arranged within the pickup tube via pump bracket (W) which has the function of centering, sustaining and absorbing BCS vibration as well as aligning and arranging for multiple pumps.
  • W pump bracket
  • a shroud or shroud (10) is coupled at one end of the BCS pump (1), required in some equipment mounting configurations (E1), which is responsible for conducting water entering the pickup (2) until the suction of the BCS (1) causing captured water flow (F1) to pass outside the engine (1 1) to help cool it.
  • E1 equipment mounting configurations
  • F1 captured water flow
  • the discharge of one pump is connected with the suction of the other.
  • discharge piping (12) which directs the discharge flow (F2) from pump (1) directly to the flow meter (13).
  • This tubing is not present in some configurations.
  • Said flow meter (13) is responsible for measuring the pump discharge discharge value (1) required for injection control and pump operation.
  • the equipment (E1) still employs a choke valve (14) responsible for injection flow control.
  • At least one backwash line (15) is equipped with at least one check valve (16) that prevents reverse flows.
  • the backwash tubing (15) is required to backwash the filter (8) or (9) and also acts as a recirculation line.
  • Backwash valve (17) is provided which controls the backwash flow.
  • Electrical cables (18) required to supply power to the BCS pump motor (1) are also employed, as well as electric valve actuators, all interconnected with a ROV panel (19). In the mentioned panel (19), besides the power cables (18) are installed product injection hoses when necessary, and have valve operation interfaces.
  • the equipment (E1) is connected to a VSD (Variable Speed Driver) panel (20), which comprises the speed variator used to control the motor speed (11) and consequently its flow and discharge pressure.
  • VSD Very Speed Driver
  • All equipment that makes up the injection system is installed inside the pickup tube (2) in series, except for the VSD (20), which is installed on the surface of a floating production unit.
  • the pump (1) is mounted and coupled to the jacket (10) surrounding the pump suction and the motor (11), forcing the water flow (F1), which goes towards the suction of the pump. outside the motor (1 1), aiding its cooling.
  • the jacket 10 in the assembly of figure 1 is opened at the lower end.
  • FIG. 1 shows the sleeve (10), with the pump (1) mounted upside down, with the motor (1 1) mounted above the suction and the discharge flow. directly to the flowmeter (13).
  • Figure 2 further shows the pump holder (W) which centralizes and absorbs pump vibrations. This device will vary according to the type of mounting, but its function remains the same.
  • the flow (F1) after exiting the sieve (3), passes through the filter (8) or (9) and enters directly into the jacket (10) and, after exiting through the discharge pipe (12) of the pump. (1), goes into the space between the jacket (10) and the inside of the pickup tube (2).
  • the flow always passes first through the sieve (3), then through the filter (8) or (9) and goes towards the suction of the BCS pump (1), which will always be isolated from the discharge, or through from a discharge pipe (12) or by means of a jacket (10) which isolates the suction from the discharge.
  • Figures 5 and 6 show a mounting alternative in which the filter (8) or (9) is placed in a retrievable module coupled to the end of the pickup tube (2) and can be retracted and replaced without the need for decoupling or retrieval of the filter. rest of the system.
  • the backwash line connection (21) it can be made directly through an interface between the module and the pickup tube (X), or through a hose (Y) installed by ROV (Remote Operated Vehicle).
  • figures 7, 8, 9 and 9A represent that the pickup tube (2) can be installed according to three different configurations: (i) The first configuration, figure 7, is the top installation of the ANM (22) in place. from Treecap.
  • the injection is made with ANM valves that allow open injection for access to the injection column;
  • the second configuration, figure 8 is the installation of the system with equipment (E1) in the injection chuck (23).
  • the injection is made with ANM valves that allow open injection;
  • the third configuration is the installation of this system and equipment (E1) in a foundation equipment or system, which may be, inter alia, a torpedo mini pile (24), connected to equipment (E1) floating to the preset depth; secured via tendon (Z) with an injection line (25) interconnecting it with the ANM (22), or mounted to the seabed directly on a torpedo subfloor (24) or other foundation system.

Abstract

L'invention concerne un système sous-marin d'injection d'eau de mer au moyen d'une pompe centrifuge immergée, et notamment un système sous-marin d'injection d'eau dans des aquifères de réservoirs de pétrole ou de gaz, nécessitant un procédé de récupération secondaire par injection d'eau. Le système est formé par un tube collecteur (2) comportant et maintenant aligné longitudinalement l'ensemble de pompage formé par une pompe PCI (1), un moteur (11), un tamis (3) ou des filtres (6) et (8) ou (9) et un débitmètre (14). Le flux d'eau est filtré par le tamis (3) ou le filtre (6), puis par le filtre (8) ou (9), et continue en direction de l'aspiration par la pompe PCI (1). L'aspiration par la pompe PCI (1) est isolée de l'évacuation par une tubulure d'évacuation (12) ou par une chemise (10). Le tube collecteur (2) est rendu flottant au moyen d'une bouée (4) et d'attaches (7) ou est raccordé/monté directement sur l'arbre de Noël immergé (22). Un panneau ROV (19) de raccordement de câbles électriques et de tuyaux d'injection de chimiques est utilisé, si nécessaire, des interfaces pour le fonctionnement de valves étant en outre prévues. La vitesse du moteur (11), et par conséquent son débit et sa pression d'évacuation, est régulée par un variateur de vitesse (20) disposé à l'extérieur du tube collecteur (2). L'utilisation de la présente invention est principalement destinée à des puits d'injection où l'injection d'eau de mer non traitée n'endommage pas la formation. Son application est directement liée à la diminution des dispositifs d'injection d'eau installés sur des unités flottantes.
PCT/BR2014/000052 2014-02-19 2014-02-19 Système sous-marin d'injection d'eau de mer au moyen d'une pompe centrifuge immergée WO2015123736A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
PCT/BR2014/000052 WO2015123736A1 (fr) 2014-02-19 2014-02-19 Système sous-marin d'injection d'eau de mer au moyen d'une pompe centrifuge immergée

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/BR2014/000052 WO2015123736A1 (fr) 2014-02-19 2014-02-19 Système sous-marin d'injection d'eau de mer au moyen d'une pompe centrifuge immergée

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Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10160662B2 (en) 2016-03-15 2018-12-25 Onesubsea Ip Uk Limited Subsea fluid injection system
US10859084B2 (en) 2016-04-26 2020-12-08 Onesubsea Ip Uk Limited Subsea process lubricated water injection pump
WO2021142507A1 (fr) * 2020-01-17 2021-07-22 Blakemere Engineering Pty Ltd Filtre sous-marin

Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4009756A (en) * 1975-09-24 1977-03-01 Trw, Incorporated Method and apparatus for flooding of oil-bearing formations by downward inter-zone pumping
US4077428A (en) * 1976-01-29 1978-03-07 Dale Weaver, Inc. Transportable water injection plant
US6092600A (en) * 1997-08-22 2000-07-25 Texaco Inc. Dual injection and lifting system using a rod driven progressive cavity pump and an electrical submersible pump and associate a method
GB2361721A (en) * 1999-11-11 2001-10-31 Mentor Subsea Tech Serv Inc Sub sea pile-sump pumping arrangement
WO2008100592A1 (fr) * 2007-02-13 2008-08-21 Saudi Arabian Oil Company Procede et appareil de production, de transfert et d'injection d'eau souterraine
GB2457784A (en) * 2008-02-29 2009-09-02 Schlumberger Holdings Pumping systems
WO2011084769A2 (fr) * 2009-12-21 2011-07-14 Chevron U.S.A. Inc. Système et procédé pour inonder d'eau des réservoirs en mer
CN102966338A (zh) * 2012-11-27 2013-03-13 中国石油天然气集团公司 可测流量、压力的同井采注水工艺系统

Patent Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4009756A (en) * 1975-09-24 1977-03-01 Trw, Incorporated Method and apparatus for flooding of oil-bearing formations by downward inter-zone pumping
US4077428A (en) * 1976-01-29 1978-03-07 Dale Weaver, Inc. Transportable water injection plant
US6092600A (en) * 1997-08-22 2000-07-25 Texaco Inc. Dual injection and lifting system using a rod driven progressive cavity pump and an electrical submersible pump and associate a method
GB2361721A (en) * 1999-11-11 2001-10-31 Mentor Subsea Tech Serv Inc Sub sea pile-sump pumping arrangement
WO2008100592A1 (fr) * 2007-02-13 2008-08-21 Saudi Arabian Oil Company Procede et appareil de production, de transfert et d'injection d'eau souterraine
GB2457784A (en) * 2008-02-29 2009-09-02 Schlumberger Holdings Pumping systems
WO2011084769A2 (fr) * 2009-12-21 2011-07-14 Chevron U.S.A. Inc. Système et procédé pour inonder d'eau des réservoirs en mer
CN102966338A (zh) * 2012-11-27 2013-03-13 中国石油天然气集团公司 可测流量、压力的同井采注水工艺系统

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10160662B2 (en) 2016-03-15 2018-12-25 Onesubsea Ip Uk Limited Subsea fluid injection system
US10859084B2 (en) 2016-04-26 2020-12-08 Onesubsea Ip Uk Limited Subsea process lubricated water injection pump
WO2021142507A1 (fr) * 2020-01-17 2021-07-22 Blakemere Engineering Pty Ltd Filtre sous-marin

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