CA2684292A1 - System and method for monitoring physical condition of production well equipment and controlling well production - Google Patents
System and method for monitoring physical condition of production well equipment and controlling well production Download PDFInfo
- Publication number
- CA2684292A1 CA2684292A1 CA002684292A CA2684292A CA2684292A1 CA 2684292 A1 CA2684292 A1 CA 2684292A1 CA 002684292 A CA002684292 A CA 002684292A CA 2684292 A CA2684292 A CA 2684292A CA 2684292 A1 CA2684292 A1 CA 2684292A1
- Authority
- CA
- Canada
- Prior art keywords
- well
- submersible pump
- electrical submersible
- setting
- flow rate
- 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
Links
- 238000000034 method Methods 0.000 title claims abstract 15
- 238000004519 manufacturing process Methods 0.000 title claims abstract 4
- 238000012544 monitoring process Methods 0.000 title 1
- 239000012530 fluid Substances 0.000 claims abstract 18
- 239000000126 substance Substances 0.000 claims abstract 9
- 238000002347 injection Methods 0.000 claims abstract 6
- 239000007924 injection Substances 0.000 claims abstract 6
- 239000004576 sand Substances 0.000 claims abstract 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract 5
- 238000005094 computer simulation Methods 0.000 claims abstract 2
- 238000005259 measurement Methods 0.000 claims 6
- 238000004590 computer program Methods 0.000 claims 5
- 238000005260 corrosion Methods 0.000 claims 3
- 230000007797 corrosion Effects 0.000 claims 3
- 239000012188 paraffin wax Substances 0.000 claims 3
- 230000015572 biosynthetic process Effects 0.000 claims 2
- 230000015556 catabolic process Effects 0.000 claims 1
- 239000000203 mixture Substances 0.000 claims 1
- 230000001052 transient effect Effects 0.000 claims 1
Classifications
-
- 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
- E21B47/00—Survey of boreholes or wells
- E21B47/008—Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
-
- 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
- E21B43/12—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
Landscapes
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Geochemistry & Mineralogy (AREA)
- Geophysics (AREA)
- Flow Control (AREA)
- Testing And Monitoring For Control Systems (AREA)
- Pipeline Systems (AREA)
- Control Of Non-Positive-Displacement Pumps (AREA)
- Structures Of Non-Positive Displacement Pumps (AREA)
- Multi-Process Working Machines And Systems (AREA)
- Testing Or Calibration Of Command Recording Devices (AREA)
Abstract
A system and method for producing fluid from a completed well is provided wherein the method in one aspect includes determining a first setting of at least one first device under use for producing the fluid from the well; selecting a first set of input parameters that includes at least one parameter relating to health of at least one second device and a plurality of parameters selected from a group consisting of information relating to flow rate, pressure, temperature, presence of a selected chemical, water content, sand content, and chemical injection rate; and using the selected first set of parameters as an input to a computer model, determining a second setting for the at least one first device that will provide at least one of an increased life of at least one second device and enhanced flow rate for the fluid from the completed well.
Claims (25)
1. A method of producing fluid from a well, comprising:
determining a first setting of at least one first device that is under use for producing the fluid from the well;
selecting a set of parameters that includes at least one parameter relating to health of at least one second device and a plurality of parameters selected from a group comprising flow rate, pressure, temperature, presence of a selected chemical, water content, sand content, and chemical injection rate; and using the selected set of parameters as an input to a computer model to determine a second setting for the at least one first device that will provide an increased life of the at least one second device and enhanced flow rate for the fluid from the completed well.
determining a first setting of at least one first device that is under use for producing the fluid from the well;
selecting a set of parameters that includes at least one parameter relating to health of at least one second device and a plurality of parameters selected from a group comprising flow rate, pressure, temperature, presence of a selected chemical, water content, sand content, and chemical injection rate; and using the selected set of parameters as an input to a computer model to determine a second setting for the at least one first device that will provide an increased life of the at least one second device and enhanced flow rate for the fluid from the completed well.
2. The method of claim 1 further comprising operating the well corresponding to the second setting of the at least one first device and determining a performance of the well based on the second setting.
3. The method of claim 1, wherein the at least one parameter relating to the health of the at least one second device relates to at least one of: an electrical submersible pump; a valve; a choke; a casing lining the well; a pipe carrying the fluid from the well toward the surface; and a sand screen.
4. The method of claim 1 or 2 further comprising:
estimating a flow rate from the well over an extended time period based on the second setting; and estimating a net present value for the well corresponding to the estimated flow rate for the extended time period.
estimating a flow rate from the well over an extended time period based on the second setting; and estimating a net present value for the well corresponding to the estimated flow rate for the extended time period.
5. The method of claim 1, wherein the group further consists of information relating to: resistivity; density of the fluid; fluid composition; a capacitance measurement relating to the fluid; vibration; acoustic measurements in the well;
differential pressure across a device in the well; oil-water ratio; and gas-oil ratio.
differential pressure across a device in the well; oil-water ratio; and gas-oil ratio.
6. The method of claim 1, wherein the group further consists of: microseismic measurements; pressure transient test measurements; well log measurements; a measurement relating to presence of one of scale, hydrate, corrosion, paraffin, and asphaltene.
7. The method of claim 1 or 2 further comprising:
predicting an occurrence of one of: water breakthrough; cross-flow condition;
breakdown of a device installed in the well; and determining the second setting based on such prediction.
predicting an occurrence of one of: water breakthrough; cross-flow condition;
breakdown of a device installed in the well; and determining the second setting based on such prediction.
8. The method of claim 1 or 2, wherein the second setting constitutes at least one of: altering the chemical injection rate; altering an operation of an electrical submersible pump; shutting in a selected production zone; altering position of a choke; altering position of a valve; and altering flow through an artificial lift mechanism.
9. The method of claim 1 or 2 further comprising sending a message relating to the second setting to at least one of: an operator; and a remote location from the well.
10. The method of claim 1 or 2 further comprising using a processor that automatically sets the at least one first device to the second setting.
11. A computer system for controlling an operation of an electrical submersible pump placed in a well for producing a fluid from the well, comprising:
a database that stores information corresponding to one of : an operating envelope for the electrical submersible pump that is based on a relationship among fluid flow rate, frequency and head over the electrical submersible pump; and a maximum flow rate for the electrical submersible pump corresponding to the frequency and head; and a processor that utilizes at least one measured operating parameter of the electrical submersible pump and the information stored in the database and determines a setting for at least the electrical submersible pump and another downhole device that will cause the electrical submersible pump to operate according to one of:
within the envelope; and proximate the maximum flow rate.
a database that stores information corresponding to one of : an operating envelope for the electrical submersible pump that is based on a relationship among fluid flow rate, frequency and head over the electrical submersible pump; and a maximum flow rate for the electrical submersible pump corresponding to the frequency and head; and a processor that utilizes at least one measured operating parameter of the electrical submersible pump and the information stored in the database and determines a setting for at least the electrical submersible pump and another downhole device that will cause the electrical submersible pump to operate according to one of:
within the envelope; and proximate the maximum flow rate.
12. The computer system of claim 11, wherein the measured operating parameter of the electrical submersible pump is one of a: flow rate; frequency;
temperature;
pressure proximate the electrical submersible pump; and differential pressure across a wellbore segment proximate the electrical submersible pump.
temperature;
pressure proximate the electrical submersible pump; and differential pressure across a wellbore segment proximate the electrical submersible pump.
13. The system of claim 11, wherein the processor determines the setting such that the determined setting maintains one of temperature, pressure and differential pressure associated with the electrical submersible pump within a selected limit.
14. The system of claim 11 or 13, wherein the setting is one of altering:
frequency of the electrical submersible pump; power to the electrical submersible pump;
position of a choke; position of a valve; and flow from a selected zone.
frequency of the electrical submersible pump; power to the electrical submersible pump;
position of a choke; position of a valve; and flow from a selected zone.
15. The system of claim 11, wherein the processor further determines a chemical injection rate that will inhibit formation of one of scale, corrosion, paraffin, hydrate and asphaltene in the fluid in the well.
16. The system of claim 11 or 12 further comprising a display and wherein the processor displays messages relating to operation of the well and the electrical submersible pump.
17. The system of claim 11 or 13, wherein the processor sends command signals to cause the electrical submersible pump and the other downhole device to operate according to the determined setting.
18. The system of claim 11, wherein the processor estimates the expected life of the electrical submersible pump based on its current operation parameters and a plurality of parameters relating to the well.
19 A method of controlling operation of an electrical submersible pump in a well that is producing fluids, comprising:
determining an operating envelope for the electrical submersible pump that is based on a relationship among fluid flow rate, frequency and head over the electrical submersible pump and includes a maximum flow rate for the electrical submersible pump corresponding to the frequency and head; and measuring an operating parameter of the electrical submersible pump using a sensor in the well; and altering an operation of one of the electrical submersible pump and a downhole device to operate the electrical submersible pump according to one of:
within the operating envelope; and proximate the maximum flow rate.
determining an operating envelope for the electrical submersible pump that is based on a relationship among fluid flow rate, frequency and head over the electrical submersible pump and includes a maximum flow rate for the electrical submersible pump corresponding to the frequency and head; and measuring an operating parameter of the electrical submersible pump using a sensor in the well; and altering an operation of one of the electrical submersible pump and a downhole device to operate the electrical submersible pump according to one of:
within the operating envelope; and proximate the maximum flow rate.
20 The method of claim 19 further comprising operating the electrical submersible pump within the operating envelope and below one of a selected:
temperature; pressure; and differential pressure.
temperature; pressure; and differential pressure.
21. The method of claim 20 further comprising altering injection of a chemical from a surface location that inhibits formation of one of corrosion, scale, hydrate, paraffin and asphaltene proximate the electrical submersible pump.
22. A computer-readable medium that has embedded therein a computer program that is accessible to a processor for executing instructions contains in the computer program, the computer program comprising:
instructions to determine a first setting of at least one first device while in use for producing the fluid from the well;
instructions to select a first set of input parameters that includes at least one parameter relating to health of at least one second device and a plurality of parameters selected from a group consisting of information relating to flow rate, pressure, temperature, presence of a selected chemical, water content, sand content, and chemical injection rate; and instructions to use the selected first set of parameters as an input to determine `23 a second setting for at least one first device that will provide at least one of an increased life of the at least one second device and enhanced flow rate for the fluid from the completed well.
instructions to determine a first setting of at least one first device while in use for producing the fluid from the well;
instructions to select a first set of input parameters that includes at least one parameter relating to health of at least one second device and a plurality of parameters selected from a group consisting of information relating to flow rate, pressure, temperature, presence of a selected chemical, water content, sand content, and chemical injection rate; and instructions to use the selected first set of parameters as an input to determine `23 a second setting for at least one first device that will provide at least one of an increased life of the at least one second device and enhanced flow rate for the fluid from the completed well.
23. The computer-readable medium of claim 22 wherein the computer program further comprises:
instructions to send signals to operate the well corresponding to the second setting of the at least one first device; and instructions to estimate performance of the well based on the second setting.
instructions to send signals to operate the well corresponding to the second setting of the at least one first device; and instructions to estimate performance of the well based on the second setting.
24. The computer-readable medium of claim 22, wherein the at least one parameter relating to the health of the at least one second device relates to at least one of: an electrical submersible pump; a valve; a choke; a casing lining the well; a pipe carrying the fluid from the well toward the surface; and a sand screen.
25. The computer-readable medium of claim 22 or 23, wherein the computer program further comprises:
instructions to estimate a flow rate from the well over an extended time period based on the second setting; and instructions to estimate a net present value for the well corresponding to the estimated flow rate for the extended time period.
instructions to estimate a flow rate from the well over an extended time period based on the second setting; and instructions to estimate a net present value for the well corresponding to the estimated flow rate for the extended time period.
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US11/737,313 US7711486B2 (en) | 2007-04-19 | 2007-04-19 | System and method for monitoring physical condition of production well equipment and controlling well production |
| US11/737,313 | 2007-04-19 | ||
| PCT/US2008/060797 WO2009009196A2 (en) | 2007-04-19 | 2008-04-18 | System and method for monitoring physical condition of production well equipment and controlling well production |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2684292A1 true CA2684292A1 (en) | 2009-01-15 |
| CA2684292C CA2684292C (en) | 2012-12-11 |
Family
ID=39873089
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2684292A Active CA2684292C (en) | 2007-04-19 | 2008-04-18 | System and method for monitoring physical condition of production well equipment and controlling well production |
Country Status (9)
| Country | Link |
|---|---|
| US (1) | US7711486B2 (en) |
| AU (1) | AU2008275494B2 (en) |
| BR (1) | BRPI0810228B1 (en) |
| CA (1) | CA2684292C (en) |
| GB (1) | GB2461445B (en) |
| MY (1) | MY153025A (en) |
| NO (1) | NO341444B1 (en) |
| RU (1) | RU2468191C2 (en) |
| WO (1) | WO2009009196A2 (en) |
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2007
- 2007-04-19 US US11/737,313 patent/US7711486B2/en active Active
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2008
- 2008-04-18 MY MYPI20094371 patent/MY153025A/en unknown
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- 2008-04-18 GB GB0918124.9A patent/GB2461445B/en active Active
- 2008-04-18 AU AU2008275494A patent/AU2008275494B2/en active Active
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- 2008-04-18 RU RU2009142438/03A patent/RU2468191C2/en active IP Right Revival
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| Publication number | Publication date |
|---|---|
| NO20093166L (en) | 2010-01-18 |
| BRPI0810228B1 (en) | 2018-05-22 |
| CA2684292C (en) | 2012-12-11 |
| RU2009142438A (en) | 2011-05-27 |
| GB0918124D0 (en) | 2009-12-02 |
| WO2009009196A3 (en) | 2009-03-19 |
| GB2461445B (en) | 2012-04-25 |
| AU2008275494A1 (en) | 2009-01-15 |
| BRPI0810228A2 (en) | 2014-10-29 |
| GB2461445A (en) | 2010-01-06 |
| AU2008275494B2 (en) | 2013-08-29 |
| MY153025A (en) | 2014-12-31 |
| NO341444B1 (en) | 2017-11-13 |
| WO2009009196A2 (en) | 2009-01-15 |
| US7711486B2 (en) | 2010-05-04 |
| US20080262736A1 (en) | 2008-10-23 |
| RU2468191C2 (en) | 2012-11-27 |
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