EP2494144B1 - Subsea pumping system - Google Patents

Subsea pumping system Download PDF

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Publication number
EP2494144B1
EP2494144B1 EP10771147.5A EP10771147A EP2494144B1 EP 2494144 B1 EP2494144 B1 EP 2494144B1 EP 10771147 A EP10771147 A EP 10771147A EP 2494144 B1 EP2494144 B1 EP 2494144B1
Authority
EP
European Patent Office
Prior art keywords
pump
valve
fluid
pumping system
pressure
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.)
Active
Application number
EP10771147.5A
Other languages
German (de)
English (en)
French (fr)
Other versions
EP2494144A2 (en
Inventor
Leif Arne TØNNESEN
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 Kongsberg Subsea AS
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FMC Kongsberg Subsea AS
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Publication of EP2494144A2 publication Critical patent/EP2494144A2/en
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Publication of EP2494144B1 publication Critical patent/EP2494144B1/en
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/01—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
    • 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
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/36—Underwater separating arrangements
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D1/00—Pipe-line systems
    • F17D1/08—Pipe-line systems for liquids or viscous products
    • F17D1/14—Conveying liquids or viscous products by pumping

Definitions

  • the present invention relates to a pumping system for use in a remote location such as a subsea hydrocarbon extraction facility, comprising a source for high pressure fluid and a fluid driven pump.
  • subsea process plants with process boosting require more pumps in addition to a main booster.
  • subsea pumps are large, heavy and complex units that also require electric power supply and barrier oil supply provided over a long distance.
  • the electric system itself is highly complicated and costly, including for example penetrators, connectors, cable, transformers and motor control systems. If the host for electric power and barrier oil is a vessel or a platform, the pump supply systems will occupy highly valuable deck-area
  • Hydrocarbons coming from wells can be divided into several types, having mainly gas with some water or oil, having mainly oil with some water. In some instances there may be three phases, gas, oil and water.
  • the well stream is separated into separate phases in a separator.
  • the water may preferably be injected back into the formation.
  • the separated process medium at the later stages must be commingled with the separated process medium at first stage. Since the process medium looses pressure throughout the separation stages, the later stages separated process medium must be boosted to reach the pressure of the first stage separated process medium.
  • One current solution for boosting the pressure of the later stage separated process medium is to use an ejector that uses another pressurized medium as motion fluid.
  • the ejector solution has the disadvantages of low efficiency and mixing of motion fluid with the driven medium.
  • WO 99/50524 A2 describes a positive displacement pump which includes multiple pumping elements, each element having a pressure vessel with a first and second chamber and a separating member disposed between the first and second chambers.
  • the first chambers and the second chambers are hydraulically connected to receive and discharge fluid, wherein the separating members move within the pressure vessels in response to pressure differential between the first and second chambers.
  • a valve assembly having suction and discharge valves communicates with the first chambers.
  • the suction and discharge valves are operable to permit fluid to alternately flow into and out of the first chambers.
  • a hydraulic drive alternately supplies hydraulic fluid to and withdraws hydraulic fluid from the second chambers such that the fluid discharged from the first chambers is free of pulsation.
  • US 2004/007392 A1 relates to a sub-sea mud pump system that includes a plurality of pump units, and each pumping unit includes a plurality of pumping elements.
  • Each pumping element includes a pressure vessel with a first and a second chamber, a separating member between the first and second chambers, a measurement device adapted to measure the volume of at least one of the first and second chambers, a hydraulic inlet control valve and a hydraulic outlet control valve coupled to the first chamber, a mud suction valve and a mud discharge valve coupled to the second chamber.
  • the first chamber is hydraulically coupled to receive and discharge a hydraulic fluid
  • the second chamber is hydraulically coupled to receive and discharge a drilling fluid.
  • the separating member is adapted to move within its the pressure vessel in response to a pressure differential between the first and second chambers.
  • WO 2006/027562 A1 relates to a wellbore-external underwater pumping system for pumping process fluid into or out of a wellbore is described.
  • the pumping system comprises a piston pump that is driveable by a drive fluid.
  • the pressure driven pumping system may include at least one pumping element.
  • Each pumping element includes a housing having a bore at least partially bounded by first and second outer walls.
  • a first piston is disposed between the first outer wall and the inner wall, to define a first outer chamber and a first inner chamber.
  • a second piston is disposed between the second outer wall and the inner wall, to define a second outer chamber and a second inner chamber.
  • a coupling member couples the first and second pistons.
  • a plurality of valves control flow of seawater to the first and second outer chambers, and control flow of well fluid to the first inner chamber of each pumping element.
  • the aim of the invention is to provide a simpler system that does not require dedicated supply of utilities (e.g. electric power and barrier fluid) from an external host, and hence will be more or less autonomous. It is also an aim of the invention to provide a system that is robust to sand and capable of pumping viscous sand slurries. This is achieved by using a subsea available pressurized fluid as a motive fluid for the pump, that the pump is a reciprocating pump and that it comprises means for creating pressure pulses in the motive fluid for operation of the pump.
  • utilities e.g. electric power and barrier fluid
  • the working principle of the autonomous pump invention is to bleed off some process fluid from a high pressure space to a low pressure space.
  • a valve, or arrangement of valves hereafter named sequencing valve which working task is to transform a steady fluid pressure to a pulsating fluid pressure for excitation of a reciprocating or oscillating pump.
  • the reciprocating pump is a piston type, diaphragm type or hose diaphragm type.
  • diaphragm pumps and hose diaphragm pumps are robust to sand and particles.
  • the means for providing the reciprocating driving fluid is a sequential valve, preferably a rotating valve or a shuttle valve. It can also be an arrangement of several valves. One sequencing valve (or valve arrangement) can be made to operate one single pump or multiple pumps.
  • the sand is separated out in a de-sander and pumped using the reciprocating pump while the clean fluid is used as the motive fluid for the pump.
  • the motive fluid is gas that is pressurized in a compress or and the compressed gas is used as the motive fluid to power the pump for the liquid phase
  • the hydrocarbons are mainly liquids.
  • the hydrocarbons are separated into an oil phase and a water phase.
  • the oil phase can then be used as the motive fluid to increase the pressure in the water line to enable reinjection of water into the formation.
  • pressurized water for water injection can be used as motive fluid for increasing the oil pressure for transport to an oil-reception facility.
  • a pump 12 is connected to a pipeline 13 to receive a fluid to be pressurized, for instance hydrocarbon stream from one or more wells (not shown).
  • the pump is a reciprocating pump preferably a hose diaphragm pump, a diaphragm pump or a piston pump.
  • the pumped fluid is led to a pipeline 14 which transports the hydrocarbons to a receiving facility (not shown).
  • Another pipeline 16 conveys a fluid of higher pressure than line 13.
  • the fluid is led through a sequential valve 17 which in turn is connected to the pump 12 and delivers pulsed fluid to be the motive fluid for the pump 12.
  • the high pressure fluid can be served from a remote facility.
  • the high pressure fluid may be an injection fluid that is transported from a land based facility that pressurizes the fluid to a higher pressure than what is needed for the well and the excess energy/pressure is drawn from this fluid.
  • Fig. 2 there is shown a first embodiment of a practical use of the invention where the fluids produced from one or several subsea wells are separated into a first and second fluid phase, where the first phase may be a gas and the second phase may be a liquid such a condensate, oil or water or combination of those.
  • the hydrocarbons are transported through pipeline 20 to a separator 22.
  • the separator 22 the first phase is separated from the second phase and the first phase is led through pipeline 23 to a compressor 24.
  • the second phase is led through pipeline 30 to the reciprocating pump 32.
  • pump 32 the liquid is pressurized up and led into export pipeline 34.
  • the compressor outlet is connected to a pipeline 25 for the high pressure first phase.
  • a pipeline 26 branches off pipeline 25 to carry some of the first phase through sequential valve 27 and then back to the inlet pipe 23 upstream compressor 24. Alternatively the light fluid could after sequential valve 27 be led back to pipeline 20 or separator 22.
  • the valve is arranged to set up an alternating high and low pressure pulse to drive the reciprocating pump.
  • a reciprocating pump works by pulsing the pressure outside of a diaphragm or piston to set up the pumping action. This arrangement is not describes further as such pumps are well known in the art. Examples of sequential valves will be shown later with reference to Figs. 6-8 .
  • the first and second phases may be recombined downstream of the pump(s). In this case it is advantageous to pressurize the second phase to a higher pressure than the first phase, to facilitate recombination.
  • Fig. 3 there is shown a second embodiment of the invention.
  • the produced fluids from the well are three phase fluids, i.e. gas oil and water.
  • the hydrocarbons stream is led through pipeline 20 to a first separator 22 that separates the fluids into a gaseous phase that is led to pipeline 23 and a liquid phase that is led through pipeline 30.
  • the gas is led through a compressor 24 and to the gas export pipeline 25.
  • a branch leads the high pressure gas through sequential valve 27 that sets up the pressure pulses for driving the reciprocating pump 32.
  • the liquids that are separated out in first separator 22 is led to a second separator 40. This separates the oil from the water.
  • the oil is led through pipeline 41 to reciprocating pump 32 which pressurizes up the oil and then through pipeline 42 and recombines the oil with the gas.
  • the water is led through pipeline 44 to another pump 46 that pressurizes the water so that it can be injected into the formation.
  • Fig. 4 there is shown yet another embodiment.
  • the fluids produced by the well(s) are also a three phase fluid but may be a two phase fluid, that is, oil and water.
  • hydrocarbons from the well are transported through pipeline 20 to a first separator 22.
  • This first separator 22 is only needed in the case where the well fluids contain gas.
  • the gas is led through an export pipeline 52 to a remote facility.
  • the liquids are led through pipeline 54 to a second separator 56 that separates the oil from water.
  • the water is led through pipeline 58 to a pump 60 and then through pipeline 62.
  • the pipeline 62 can lead to an injection well or to another facility.
  • the oil is led trough pipeline 64 to reciprocating pump 66 and then to export pipeline 68.
  • a pipe 70 branches off the pipeline 62 to convey pressurized fluid through sequential valve 27 and back through line 71 into pipeline 58 (the pump inlet). Similar to what is described earlier the high pressure fluids led through line 70 and sequential valve 27 sets up the pulses that make up the driving fluid for the reciprocating pump 66.
  • sand can be very abrasive and it is normally not desirable to have sand in contact with rotary equipment, such as rotary pumps, since it can wear out the pump impellers and dynamic seals and bearings very quickly.
  • Diaphragm pumps and hose diaphragm pumps are far more tolerant of particles since they do not have rotating parts, dynamic seals or bearings.
  • Fig. 5 there is therefore shown an embodiment where a well stream contains sand.
  • the well fluids are transported from the well in pipeline 20 to a de-sander 80.
  • the clean fluids are conveyed through pipeline 82 to pump 84 and to export pipeline 86.
  • the sand slurry is conveyed through line 90 to n reciprocating pump 92.
  • the pump 92 pressurizes the slurry to a pressure that is equal, or preferably a little higher, than in pipeline 86 and is recombined with the well fluids downstream of pump 84.
  • a line 87 branches off pipeline 86 downstream of the pump and, as in the previous embodiments, are led through sequential valve 27 and then through line 87 back into pipeline 82 upstream of the pump.
  • the sequential valve 27 sets up the pressure pulses that drive the reciprocating pump 92.
  • Figs. 6-8 show examples of a sequential valve that may be used in the invention.
  • a high pressure line 101 with a first valve 102.
  • a low pressure line 103 with valve 104.
  • a line 105 leads to the reciprocating pump.
  • the valves 102 and 104 are run in sequence corresponding with the pulsing of the reciprocating pump.
  • the valves may be controlled electrically or hydraulically but ideally they are controlled by the fluid to create a fully autonomous system.
  • the sequential valve is a rotating valve with its rotational axis parallel with the pipeline axis. As the valve rotates it will in sequence convey high pressure fluid through bore 106 to the reciprocating pump or exhaust spent fluid through bore 108.
  • the valve can be arranged with a fixed rotational speed that is synchronized with the oscillations of the pump or it can be mechanically linked to the pump.
  • the sequential valve is a rotating valve with its rotational axis perpendicular to the pipeline axis.
  • the valve has a rotating vane 110 that sequentially opens for high pressure fluid to the pump and exhausts the spent fluids.
  • the vane can be rotated with an electric motor but preferably is controlled either by the pump or by the pressurized fluid to create an autonomous system.
  • valves and valve-arrangements may be fit for purpose.
  • the maximum discharge pressure is set by the process pressure supplied to autonomous pump drive in displacing sequence. This pressure can be increased by increasing main booster discharge pressure, e.g. by means of a restriction at main booster discharge, downstream the branch-off to autonomous pump drive.
  • the pump charging sequence requires a positive differential pressure between pumped medium in pump chamber and pump drive medium.
  • This differential pressure can be increased either by increasing suction pressure to autonomous pump (e.g. by increasing liquid column upstream pump), or by decreasing drive medium pressure.
  • Pulsation pressure negative amplitude can also be increased by means of an ejector incorporated in the sequencing valve or sequencing valve arrangement.
  • a charging sequence may be determined by the pressure on the pump inlet. If flow should be regulated, initially the frequency on the valve must be regulated. However there is a possibility to achieve a self-regulating pump for compressor applications as the liquid column in the separator would determine how much the pump will be filled during a "charging" sequence.
  • the reciprocating pump can for example be used for in a circuit for supplying cooling fluid to a compressor. It can also be used to set up a high pressure stream to purge a separator of accumulated sand. Also, more than one pump can be installed in the system. In the case of having more than one pump it is preferable to control both pumps with one single sequential (rotating) valve.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Water Supply & Treatment (AREA)
  • Public Health (AREA)
  • Health & Medical Sciences (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Reciprocating Pumps (AREA)
  • Details Of Reciprocating Pumps (AREA)
  • Separation Using Semi-Permeable Membranes (AREA)
  • Structures Of Non-Positive Displacement Pumps (AREA)
EP10771147.5A 2009-10-30 2010-10-29 Subsea pumping system Active EP2494144B1 (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NO20093258A NO20093258A1 (no) 2009-10-30 2009-10-30 Undervannspumpesystem
PCT/EP2010/066477 WO2011051453A2 (en) 2009-10-30 2010-10-29 Subsea pumping system

Publications (2)

Publication Number Publication Date
EP2494144A2 EP2494144A2 (en) 2012-09-05
EP2494144B1 true EP2494144B1 (en) 2016-10-19

Family

ID=43855960

Family Applications (1)

Application Number Title Priority Date Filing Date
EP10771147.5A Active EP2494144B1 (en) 2009-10-30 2010-10-29 Subsea pumping system

Country Status (8)

Country Link
US (1) US20120282116A1 (no)
EP (1) EP2494144B1 (no)
AU (1) AU2010311379B2 (no)
BR (1) BR112012009946B1 (no)
DK (1) DK2494144T3 (no)
NO (1) NO20093258A1 (no)
RU (1) RU2571466C2 (no)
WO (1) WO2011051453A2 (no)

Families Citing this family (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2500873A (en) * 2012-03-22 2013-10-09 Corac Energy Technologies Ltd Pipeline compression system
US9175528B2 (en) 2013-03-15 2015-11-03 Hydril USA Distribution LLC Decompression to fill pressure
US20140262305A1 (en) * 2013-03-15 2014-09-18 Hydril Usa Manufacturing Llc Control valve timing
US9534458B2 (en) 2013-03-15 2017-01-03 Hydril USA Distribution LLC Hydraulic cushion
US10633961B2 (en) 2013-04-16 2020-04-28 Framo Engineering As Oil filtration system for subsea oil-filled machines
US10539141B2 (en) * 2016-12-01 2020-01-21 Exxonmobil Upstream Research Company Subsea produced non-sales fluid handling system and method
GB2561568A (en) 2017-04-18 2018-10-24 Subsea 7 Norway As Subsea processing of crude oil
GB2561570B (en) 2017-04-18 2020-09-09 Subsea 7 Norway As Subsea processing of crude oil
GB2573121B (en) 2018-04-24 2020-09-30 Subsea 7 Norway As Injecting fluid into a hydrocarbon production line or processing system
NO20200357A1 (en) 2020-03-26 2021-09-27 Fmc Kongsberg Subsea As Method and subsea system for phased installation of compressor trains
US12024962B1 (en) * 2023-02-13 2024-07-02 Caterpillar Inc. Operation of a recirculation circuit for a fluid pump of a hydraulic fracturing system

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US1623605A (en) * 1924-08-20 1927-04-05 Urlyn C Tainton Pump
US3589838A (en) * 1969-11-19 1971-06-29 Borg Warner Submersible multiple-acting floating piston deep well pump
SU885608A1 (ru) * 1976-08-16 1981-11-30 Mamedov Fikrat S Глубинна гидроприводна насосна установка
US6102673A (en) * 1998-03-27 2000-08-15 Hydril Company Subsea mud pump with reduced pulsation
US6904982B2 (en) * 1998-03-27 2005-06-14 Hydril Company Subsea mud pump and control system
US6167960B1 (en) * 1998-08-17 2001-01-02 Emmanuel G. Moya Protection of downwell pumps from sand entrained in pumped fluids
RU2165015C2 (ru) * 1999-06-25 2001-04-10 Гусев Анатолий Григорьевич Комплекс для добычи нефти
US6244836B1 (en) * 2000-02-04 2001-06-12 Robert A. Jordan Well pump actuated by natural gas
RU2190757C1 (ru) * 2001-02-05 2002-10-10 ЗАО Научно-исследовательский центр "Югранефтегаз" Способ добычи нефти
US20050175476A1 (en) * 2004-02-09 2005-08-11 Energy Xtraction Corporation Gas well liquid recovery
US7063517B2 (en) * 2004-06-16 2006-06-20 Ingersoll-Rand Company Valve apparatus and pneumatically driven diaphragm pump incorporating same
GB0419915D0 (en) * 2004-09-08 2004-10-13 Des Enhanced Recovery Ltd Apparatus and method
US8323003B2 (en) * 2005-03-10 2012-12-04 Hydril Usa Manufacturing Llc Pressure driven pumping system

Also Published As

Publication number Publication date
WO2011051453A3 (en) 2011-10-13
US20120282116A1 (en) 2012-11-08
RU2012121263A (ru) 2013-12-10
AU2010311379A1 (en) 2012-05-17
AU2010311379B2 (en) 2016-04-14
RU2571466C2 (ru) 2015-12-20
BR112012009946A2 (pt) 2016-03-08
WO2011051453A2 (en) 2011-05-05
EP2494144A2 (en) 2012-09-05
BR112012009946B1 (pt) 2020-12-08
NO20093258A1 (no) 2011-05-02
DK2494144T3 (en) 2017-01-30

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