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US20150017024A1 - Method of controlling an electric submersible pump - Google Patents

Method of controlling an electric submersible pump Download PDF

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Publication number
US20150017024A1
US20150017024A1 US14/381,759 US201314381759A US2015017024A1 US 20150017024 A1 US20150017024 A1 US 20150017024A1 US 201314381759 A US201314381759 A US 201314381759A US 2015017024 A1 US2015017024 A1 US 2015017024A1
Authority
US
United States
Prior art keywords
pressure
pump
electric submersible
controlling
discharge
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.)
Abandoned
Application number
US14/381,759
Inventor
Lissett Josefina Barrios
David Earl Hugg
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.)
Shell USA Inc
Original Assignee
Shell Oil Co
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 Shell Oil Co filed Critical Shell Oil Co
Priority to US14/381,759 priority Critical patent/US20150017024A1/en
Assigned to SHELL OIL COMPANY reassignment SHELL OIL COMPANY ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: BARRIOS, LISSETT JOSEFINA, HUGG, David Earl
Publication of US20150017024A1 publication Critical patent/US20150017024A1/en
Abandoned legal-status Critical Current

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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
    • F04B35/00—Piston pumps specially adapted for elastic fluids and characterised by the driving means to their working members, or by combination with, or adaptation to, specific driving engines or motors, not otherwise provided for
    • F04B35/04—Piston pumps specially adapted for elastic fluids and characterised by the driving means to their working members, or by combination with, or adaptation to, specific driving engines or motors, not otherwise provided for the means being electric
    • 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
    • E21B43/128—Adaptation of pump systems with down-hole electric drives
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/008—Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
    • 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
    • F04D15/00—Control, e.g. regulation, of pumps, pumping installations or systems
    • F04D15/0066—Control, e.g. regulation, of pumps, pumping installations or systems by changing the speed, e.g. of the driving engine
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
    • F04D31/00—Pumping liquids and elastic fluids at the same time

Definitions

  • the invention relates to a method of controlling an electric submersible pump located in a subsea caisson.
  • the invention further provides a method of starting up an electric submersible pump, comprising: a) starting the pump on differential pressure control, comprising: i) monitoring the pressure at the suction and discharge of the pump; ii) calculating the pressure difference between the discharge and suction pressure; and iii) controlling the pump to maintain a constant pressure difference between the discharge and suction pressure; and b) switching the pump control to pressure control, comprising: i) monitoring the pressure at the top of the caisson; and ii) controlling the pump to maintain a constant pressure at the caisson.
  • the invention also provides a method of controlling an electric submersible pump, comprising: a) monitoring the pressure at the caisson top; b) switching the pump control to differential pressure control during the start-up phase when fluid density inside the pump is changing; and c) switching the pump control to pressure control when the system has stabilized in a specified operational pressure range.
  • the method may further comprise: d) during steady operation, switching to constant pressure difference control automatically when an instability is detected, comprising: i) monitoring a performance variable that indicates the stability of the caisson operation; and ii) switching the control automatically to constant pressure difference control when the performance variable exceeds a threshold value.
  • FIG. 1 depicts an embodiment of the electric submersible pump showing the different fluid phases present on startup.
  • Electric submersible pumps are designed to operate in a range of conditions, but they are not designed for large pressure swings that can occur when the fluids passing through the pump change significantly. For example, slugs of water, changing oil/gas ratios and rapid changing of distinct fluid phases passing through the pump cause rapid swings in pressure as the pump operation characteristics vary with different fluid densities. These pressure swings can cause damage to pump components and is believed to be at least a contributing factor of current electrical failures of electric submersible pumps in the field.
  • the speed of an electrical submersible pump may be set via a Variable Frequency Drive (VFD); the speed of the pump may be directly-related to the frequency.
  • Caisson pressure may be controlled by manipulation of the demand to the VFD. Manipulating the electric submersible pump based on caisson pressure is normally satisfactory, but does not provide a rapid response during changing fluid conditions.
  • the invention provides an alternate process control scheme that can be used to more effectively manipulate the electric submersible pump during startup and when fluid properties are rapidly changing.
  • This process control scheme is referred to as constant boost mode because it manipulates the pump speed based on the differential pressure across the pump.
  • the differential pressure is calculated as the difference between the discharge pressure and the suction pressure of the pump.
  • Manipulating the pump in constant boost mode provides a more rapid response to fluctuations in fluid density to avoid instabilities on the system.
  • the fluid phase that is typically in the pump is an oil/gas mixture.
  • the oil/gas mixture is pumped out the discharge and after some time, a water phase that has separated from the oil/gas mixture reaches the pump suction. The water is pumped and then another oil/gas phase is encountered. Then a hot oil phase is passed through the pump while the wells are ramped up and start producing and this is followed by the oil/gas mixture being produced from the field.
  • the density changes; increases with water, decreases with oil/gas, increases with hot oil and decreases with field oil.
  • FIG. 1 depicts electric submersible pump system 100 .
  • Electric submersible pump system 100 may comprise a pump 110 and a shroud 120 surrounded by a caisson 130 .
  • Electric submersible pump system 100 may further comprise an inlet 101 , a gas outlet 102 , and a liquid outlet 103 .
  • fluid within the pump may be an oil/gas mixture.
  • a separate water phase may be located at the bottom of the caisson and an additional oil/gas phase is floating on the water phase outside of the shroud. After these phases have been pumped out, a new oil/gas mixture from the formation is pumped through the pump. Once the pump has started up manually, the system is switched to caisson pressure control.
  • the pump can be switched to constant boost control if slugs of water or other distinct phases are encountered as observed by pressure swings in the pump during operation.
  • the constant boost mode will help the pump through the phase changes and the pump can then be returned to caisson pressure control when system is in stable operation.
  • the differential pressure control is used to manipulate the electric submersible pump during startup and at any time during operation when the fluid density in the Caisson changes abruptly. As the caisson pressure is brought back into a more stable condition by controlling the differential pressure control, the pump can be switched back to manipulation via caisson pressure control.
  • the stability of the pressure can be detected by comparing the differential pressure in the Caisson to the last measured differential pressure or to a running average of a series of differential pressure measurements.
  • the specific characteristics of a stable system with regards to differential pressure should be determined based on the specific characteristics of the formation and the performance characteristics of the electric submersible pump.
  • differential pressure control scheme described herein provides a more rapid response to fluctuations in pressure caused by changing fluid density, especially those encountered during startup.

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

Abstract

A method of controlling an electric submersible pump, comprising: a) monitoring the pressure at the suction and discharge of the pump; b) calculating the pressure difference between the discharge and suction pressure; and c) controlling the pump to maintain a constant pressure difference between the discharge and suction pressure.

Description

    CROSS-REFERENCE TO RELATED APPLICATION
  • This application claims the benefit of U.S. Provisional Application No. 61/605,795, filed Mar. 2, 2012, which is incorporated herein by reference.
    • FIELD OF THE INVENTION
  • The invention relates to a method of controlling an electric submersible pump located in a subsea caisson.
    • BACKGROUND
  • Electric submersible pumps are used in deepwater oil and gas production settings to provide artificial lift such that the oil and gas can be raised to the surface for further processing, storage and/or transport. During fluid property changes of the oil/gas mixture and/or introduction of water into the pump, large swings in pump operation can occur.
  • These swings in pump operation can result in increased downtime, damage to the pump components, seals and motor and decreased pump longevity. These problems are often encountered during startup of the pump when the fluids in and around the pump suction side have been allowed time to separate into distinct phases. For example, a separate water phase, gas/liquid phase and hot oil phase may be encountered in the electric submersible pump during startup.
    • SUMMARY OF THE INVENTION
  • The invention provides a method of controlling an electric submersible pump, comprising: a) monitoring the pressure at the suction and discharge of the pump; b) calculating the pressure difference between the discharge and suction pressure; and c) controlling the pump to maintain a constant pressure difference between the discharge and suction pressure.
  • The invention further provides a method of starting up an electric submersible pump, comprising: a) starting the pump on differential pressure control, comprising: i) monitoring the pressure at the suction and discharge of the pump; ii) calculating the pressure difference between the discharge and suction pressure; and iii) controlling the pump to maintain a constant pressure difference between the discharge and suction pressure; and b) switching the pump control to pressure control, comprising: i) monitoring the pressure at the top of the caisson; and ii) controlling the pump to maintain a constant pressure at the caisson.
  • The invention also provides a method of controlling an electric submersible pump, comprising: a) monitoring the pressure at the caisson top; b) switching the pump control to differential pressure control during the start-up phase when fluid density inside the pump is changing; and c) switching the pump control to pressure control when the system has stabilized in a specified operational pressure range. In certain embodiments, the method may further comprise: d) during steady operation, switching to constant pressure difference control automatically when an instability is detected, comprising: i) monitoring a performance variable that indicates the stability of the caisson operation; and ii) switching the control automatically to constant pressure difference control when the performance variable exceeds a threshold value.
    • BRIEF DESCRIPTION OF THE DRAWINGS
  • FIG. 1 depicts an embodiment of the electric submersible pump showing the different fluid phases present on startup.
    •  DETAILED DESCRIPTION
  • Electric submersible pumps are designed to operate in a range of conditions, but they are not designed for large pressure swings that can occur when the fluids passing through the pump change significantly. For example, slugs of water, changing oil/gas ratios and rapid changing of distinct fluid phases passing through the pump cause rapid swings in pressure as the pump operation characteristics vary with different fluid densities. These pressure swings can cause damage to pump components and is believed to be at least a contributing factor of current electrical failures of electric submersible pumps in the field.
  • The speed of an electrical submersible pump may be set via a Variable Frequency Drive (VFD); the speed of the pump may be directly-related to the frequency. Caisson pressure may be controlled by manipulation of the demand to the VFD. Manipulating the electric submersible pump based on caisson pressure is normally satisfactory, but does not provide a rapid response during changing fluid conditions.
  • The invention provides an alternate process control scheme that can be used to more effectively manipulate the electric submersible pump during startup and when fluid properties are rapidly changing. This process control scheme is referred to as constant boost mode because it manipulates the pump speed based on the differential pressure across the pump. The differential pressure is calculated as the difference between the discharge pressure and the suction pressure of the pump.
  • Manipulating the pump in constant boost mode provides a more rapid response to fluctuations in fluid density to avoid instabilities on the system.
  • One example of the issues encountered during startup is described further. When starting up an electric submersible pump located in a subsea caisson, the fluid phase that is typically in the pump is an oil/gas mixture. As the pump starts up, the oil/gas mixture is pumped out the discharge and after some time, a water phase that has separated from the oil/gas mixture reaches the pump suction. The water is pumped and then another oil/gas phase is encountered. Then a hot oil phase is passed through the pump while the wells are ramped up and start producing and this is followed by the oil/gas mixture being produced from the field. With each change in phases, the density changes; increases with water, decreases with oil/gas, increases with hot oil and decreases with field oil.
  • FIG. 1 depicts electric submersible pump system 100. Electric submersible pump system 100 may comprise a pump 110 and a shroud 120 surrounded by a caisson 130. Electric submersible pump system 100 may further comprise an inlet 101, a gas outlet 102, and a liquid outlet 103.
  • In certain embodiments, fluid within the pump may be an oil/gas mixture. A separate water phase may be located at the bottom of the caisson and an additional oil/gas phase is floating on the water phase outside of the shroud. After these phases have been pumped out, a new oil/gas mixture from the formation is pumped through the pump. Once the pump has started up manually, the system is switched to caisson pressure control.
  • In the alternative, the pump can be switched to constant boost control if slugs of water or other distinct phases are encountered as observed by pressure swings in the pump during operation. The constant boost mode will help the pump through the phase changes and the pump can then be returned to caisson pressure control when system is in stable operation.
  • In one embodiment, the differential pressure control is used to manipulate the electric submersible pump during startup and at any time during operation when the fluid density in the Caisson changes abruptly. As the caisson pressure is brought back into a more stable condition by controlling the differential pressure control, the pump can be switched back to manipulation via caisson pressure control.
  • The stability of the pressure can be detected by comparing the differential pressure in the Caisson to the last measured differential pressure or to a running average of a series of differential pressure measurements. The specific characteristics of a stable system with regards to differential pressure should be determined based on the specific characteristics of the formation and the performance characteristics of the electric submersible pump.
  • The differential pressure control scheme described herein provides a more rapid response to fluctuations in pressure caused by changing fluid density, especially those encountered during startup.

Claims (8)

1. A method of controlling an electric submersible pump, comprising:
a. monitoring the pressure at the suction and discharge of the pump;
b. calculating the pressure difference between the discharge and suction pressure; and
c. controlling the pump to maintain a constant pressure difference between the discharge and suction pressure.
2. The method of claim 1 wherein the electric submersible pump is located in a subsea caisson below the seafloor.
3. The method of claim 1 wherein the electric submersible pump comprises a pump and a shroud.
4. A method of starting up an electric submersible pump during start up, comprising:
a. starting the pump on constant boost control, comprising:
i. monitoring the pressure at the suction and discharge of the pump;
ii. calculating the pressure difference between the discharge and suction pressure; and
iii. controlling the pump to maintain a constant pressure difference between the discharge and suction pressure; and
b. switching the constant boost control to pressure control, comprising:
i. monitoring the pressure at the caisson top; and
ii. controlling the pump to maintain a constant pressure at the caisson top.
5. The method of claim 4 wherein the switching the constant boost control to pressure control is carried out by operator intervention.
6. A method of controlling an electric submersible pump during operation, comprising:
a. monitoring the pressure at the caisson top;
b. switching the pressure control to constant boost control when the pressure goes outside of a determined operational pressure range during operation; and
c. switching the constant boost control to pressure control when the pressure has stabilized inside of the determined operational pressure range.
7. The method of claim 6 wherein the switching the constant boost control to pressure control is carried out by operator intervention.
8. The method of claim 6 further comprising carrying out steps b) and c) repeatedly as the pressure goes outside of the range and then is stabilized inside of the range.
US14/381,759 2012-03-02 2013-02-27 Method of controlling an electric submersible pump Abandoned US20150017024A1 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
US14/381,759 US20150017024A1 (en) 2012-03-02 2013-02-27 Method of controlling an electric submersible pump

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
US201261605795P 2012-03-02 2012-03-02
US14/381,759 US20150017024A1 (en) 2012-03-02 2013-02-27 Method of controlling an electric submersible pump
PCT/US2013/027908 WO2013130524A1 (en) 2012-03-02 2013-02-27 Method of controlling an electric submersible pump

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CN (1) CN104160156B (en)
AU (1) AU2013226203B2 (en)
GB (1) GB2512555A (en)
MY (1) MY175543A (en)
NO (1) NO20141029A1 (en)
WO (1) WO2013130524A1 (en)

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WO2017106592A1 (en) * 2015-12-18 2017-06-22 General Electric Company Deriving the gas volume fraction (gvf) of a multiphase flow from the motor parameters of a pump

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CN104847674B (en) * 2015-06-16 2017-01-18 合肥工业大学 Smart sensing type submersible electric pump
CN116412118A (en) * 2023-04-25 2023-07-11 东甲林集团有限公司 Device and method for monitoring working condition of foundation pit dewatering well water pump

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US8042612B2 (en) * 2009-06-15 2011-10-25 Baker Hughes Incorporated Method and device for maintaining sub-cooled fluid to ESP system
US9062684B2 (en) * 2005-02-02 2015-06-23 Edwards Limited Method of operating a pumping system

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US8397821B2 (en) * 2009-07-31 2013-03-19 Baker Hughes Incorporated Caisson two-phase emulsion reducer

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Publication number Priority date Publication date Assignee Title
US3772805A (en) * 1968-03-06 1973-11-20 Octrooien Spanstaal Ing Bureau Method and suction dredging installation for conveying dredging spoil
US5243828A (en) * 1992-12-28 1993-09-14 Carrier Corporation Control system for compressor protection in a manually operated refrigerant recovery apparatus
US5580221A (en) * 1994-10-05 1996-12-03 Franklin Electric Co., Inc. Motor drive circuit for pressure control of a pumping system
US9062684B2 (en) * 2005-02-02 2015-06-23 Edwards Limited Method of operating a pumping system
US8042612B2 (en) * 2009-06-15 2011-10-25 Baker Hughes Incorporated Method and device for maintaining sub-cooled fluid to ESP system
US20110223038A1 (en) * 2010-03-10 2011-09-15 Ogawa Takahiko Controller-integrated motor pump

Cited By (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2017106592A1 (en) * 2015-12-18 2017-06-22 General Electric Company Deriving the gas volume fraction (gvf) of a multiphase flow from the motor parameters of a pump
GB2560140A (en) * 2015-12-18 2018-08-29 Gen Electric Deriving the gas volume fraction (GVF) of a multiphase flow from the motor parameters of a pump
US10208745B2 (en) 2015-12-18 2019-02-19 General Electric Company System and method for controlling a fluid transport system
GB2560140B (en) * 2015-12-18 2021-07-07 Gen Electric Deriving the gas volume fraction (GVF) of a multiphase flow from the motor parameters of a pump

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Publication number Publication date
CN104160156A (en) 2014-11-19
WO2013130524A1 (en) 2013-09-06
AU2013226203A1 (en) 2014-08-21
MY175543A (en) 2020-07-01
CN104160156B (en) 2016-07-13
AU2013226203B2 (en) 2016-04-07
GB2512555A (en) 2014-10-01
NO20141029A1 (en) 2014-08-22
GB201413294D0 (en) 2014-09-10

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Owner name: SHELL OIL COMPANY, TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:HUGG, DAVID EARL;BARRIOS, LISSETT JOSEFINA;SIGNING DATES FROM 20131008 TO 20140326;REEL/FRAME:033630/0732

STCB Information on status: application discontinuation

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