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
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) |
Families Citing this family (80)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
AU2008290585B2 (en) * | 2007-08-17 | 2011-10-06 | Shell Internationale Research Maatschappij B.V. | Method for controlling production and downhole pressures of a well with multiple subsurface zones and/or branches |
US8612154B2 (en) * | 2007-10-23 | 2013-12-17 | Schlumberger Technology Corporation | Measurement of sound speed of downhole fluid by helmholtz resonator |
US7822554B2 (en) * | 2008-01-24 | 2010-10-26 | Schlumberger Technology Corporation | Methods and apparatus for analysis of downhole compositional gradients and applications thereof |
US8214186B2 (en) * | 2008-02-04 | 2012-07-03 | Schlumberger Technology Corporation | Oilfield emulator |
FR2942265B1 (en) * | 2009-02-13 | 2011-04-22 | Total Sa | HYDROCARBON PRODUCTION FACILITY DRIVING METHOD |
US20100312401A1 (en) | 2009-06-08 | 2010-12-09 | Dresser, Inc. | Chemical Injection System |
GB0910978D0 (en) * | 2009-06-25 | 2009-08-05 | Wellmack Resources Ltd | Method and apparatus for monitoring fluids |
US8347957B2 (en) * | 2009-07-14 | 2013-01-08 | Halliburton Energy Services, Inc. | System and method for servicing a wellbore |
US9388686B2 (en) * | 2010-01-13 | 2016-07-12 | Halliburton Energy Services, Inc. | Maximizing hydrocarbon production while controlling phase behavior or precipitation of reservoir impairing liquids or solids |
CA2693640C (en) | 2010-02-17 | 2013-10-01 | Exxonmobil Upstream Research Company | Solvent separation in a solvent-dominated recovery process |
CA2696638C (en) | 2010-03-16 | 2012-08-07 | Exxonmobil Upstream Research Company | Use of a solvent-external emulsion for in situ oil recovery |
CA2701422A1 (en) * | 2010-04-26 | 2011-10-26 | Exxonmobil Upstream Research Company | A method for the management of oilfields undergoing solvent injection |
CA2705643C (en) | 2010-05-26 | 2016-11-01 | Imperial Oil Resources Limited | Optimization of solvent-dominated recovery |
US8988237B2 (en) | 2010-05-27 | 2015-03-24 | University Of Southern California | System and method for failure prediction for artificial lift systems |
US8988236B2 (en) | 2010-05-27 | 2015-03-24 | University Of Southern California | System and method for failure prediction for rod pump artificial lift systems |
US8684078B2 (en) | 2010-09-08 | 2014-04-01 | Direct Drivehead, Inc. | System and method for controlling fluid pumps to achieve desired levels |
US20120089335A1 (en) * | 2010-10-11 | 2012-04-12 | Baker Hughes Incorporated | Fluid pressure-viscosity analyzer for downhole fluid sampling pressure drop rate setting |
US9422793B2 (en) | 2010-10-19 | 2016-08-23 | Schlumberger Technology Corporation | Erosion tracer and monitoring system and methodology |
CN103221634B (en) * | 2010-10-21 | 2016-08-24 | 沙特阿拉伯石油公司 | There is the protection of clustered well head main line and the test system of ESP speed control and emergency isolation valve door |
US8727737B2 (en) | 2010-10-22 | 2014-05-20 | Grundfos Pumps Corporation | Submersible pump system |
US9347009B2 (en) | 2010-12-28 | 2016-05-24 | Chevron U.S.A. Inc. | Processes and systems for characterizing and blending refinery feedstocks |
US9140679B2 (en) | 2010-12-28 | 2015-09-22 | Chevron U.S.A. Inc. | Process for characterizing corrosivity of refinery feedstocks |
US9464242B2 (en) | 2010-12-28 | 2016-10-11 | Chevron U.S.A. Inc. | Processes and systems for characterizing and blending refinery feedstocks |
US9103813B2 (en) | 2010-12-28 | 2015-08-11 | Chevron U.S.A. Inc. | Processes and systems for characterizing and blending refinery feedstocks |
US9324049B2 (en) | 2010-12-30 | 2016-04-26 | Schlumberger Technology Corporation | System and method for tracking wellsite equipment maintenance data |
US20120173299A1 (en) * | 2011-01-04 | 2012-07-05 | Mcmullin Dale Robert | Systems and methods for use in correcting a predicted failure in a production process |
US9121270B2 (en) | 2011-05-26 | 2015-09-01 | Grundfos Pumps Corporation | Pump system |
US9280517B2 (en) * | 2011-06-23 | 2016-03-08 | University Of Southern California | System and method for failure detection for artificial lift systems |
US8773948B2 (en) | 2011-09-27 | 2014-07-08 | Schlumberger Technology Corporation | Methods and apparatus to determine slowness of drilling fluid in an annulus |
US9157308B2 (en) * | 2011-12-29 | 2015-10-13 | Chevron U.S.A. Inc. | System and method for prioritizing artificial lift system failure alerts |
WO2014107113A1 (en) * | 2013-01-02 | 2014-07-10 | Scale Protection As | Scale indication device and method |
GB201304829D0 (en) * | 2013-03-15 | 2013-05-01 | Petrowell Ltd | Method and apparatus |
RU2525094C1 (en) * | 2013-04-05 | 2014-08-10 | Федеральное государственное бюджетное образовательное учреждение высшего профессионального образования "Уфимский государственный нефтяной технический университет" | Device for evaluation of centrifugal electric pump conditions under operating conditions |
US11055450B2 (en) * | 2013-06-10 | 2021-07-06 | Abb Power Grids Switzerland Ag | Industrial asset health model update |
US10534361B2 (en) * | 2013-06-10 | 2020-01-14 | Abb Schweiz Ag | Industrial asset health model update |
GB2515533A (en) * | 2013-06-27 | 2014-12-31 | Vetco Gray Controls Ltd | Monitoring a hydraulic fluid filter |
US10100594B2 (en) * | 2013-06-27 | 2018-10-16 | Ge Oil & Gas Uk Limited | Control system and a method for monitoring a filter in an underwater hydrocarbon well |
US9611731B2 (en) * | 2013-10-04 | 2017-04-04 | Halliburton Energy Services, Inc. | Determination of formation dip/azimuth with multicomponent induction data |
US10018020B2 (en) * | 2013-10-31 | 2018-07-10 | Halliburton Energy Services, Inc. | Decreasing pump lag time using process control |
CA2929943A1 (en) * | 2013-11-13 | 2015-05-21 | Schlumberger Canada Limited | Automatic pumping system commissioning |
WO2015070913A1 (en) * | 2013-11-14 | 2015-05-21 | Statoil Petroleum As | Well control system |
AU2015204064B2 (en) | 2014-01-02 | 2018-03-29 | Hydril USA Distribution LLC | Systems and methods to visualize component health and preventive maintenance needs for subsea control subsystem components |
US20150198038A1 (en) | 2014-01-15 | 2015-07-16 | Baker Hughes Incorporated | Methods and systems for monitoring well integrity and increasing the lifetime of a well in a subterranean formation |
WO2015112944A1 (en) * | 2014-01-27 | 2015-07-30 | Onsite Integrated Services Llc | Method for monitoring and controlling drilling fluids process |
US9650881B2 (en) * | 2014-05-07 | 2017-05-16 | Baker Hughes Incorporated | Real time tool erosion prediction monitoring |
CA2950843A1 (en) | 2014-06-03 | 2015-12-10 | Schlumberger Canada Limited | Monitoring an electric submersible pump for failures |
US10718200B2 (en) | 2014-06-03 | 2020-07-21 | Schlumberger Technology Corporation | Monitoring an electric submersible pump for failures |
CA2951279C (en) * | 2014-06-16 | 2022-07-12 | Schlumberger Canada Limited | Fault detection in electric submersible pumps |
US20170226842A1 (en) * | 2014-08-01 | 2017-08-10 | Schlumberger Technology Corporation | Monitoring health of additive systems |
GB201420752D0 (en) * | 2014-11-21 | 2015-01-07 | Anderson Scott C And Doherty Benjamin D | Pump |
WO2016084054A1 (en) * | 2014-11-30 | 2016-06-02 | Abb Technology Ltd. | Method and system for maximizing production of a well with a gas assisted plunger lift |
US20170350221A1 (en) * | 2014-12-17 | 2017-12-07 | Galexum Technologies Ag | Method of simultaneous introducing of two or more than two chemical substances and/or water into a subterraneous hydrocarbon formation and/or control of the rate of chemical reactions of these substances, and a device for implementation of this method |
RU2585345C1 (en) * | 2015-03-23 | 2016-05-27 | Закрытое акционерное общество "Энергосервис" | Method for integrated assessment of energy efficiency of process plant for pumping liquid media during operation thereof |
WO2016153895A1 (en) * | 2015-03-25 | 2016-09-29 | Schlumberger Technology Corporation | System and method for monitoring an electric submersible pump |
GB2553467B (en) * | 2015-04-27 | 2021-03-17 | Equinor Energy As | Method for inverting oil continuous flow to water continuous flow |
RU2608838C2 (en) * | 2015-06-09 | 2017-01-25 | Общество С Ограниченной Ответственностью "Газпром Трансгаз Краснодар" | Method of determining moment of assigning well repair |
US10107932B2 (en) | 2015-07-09 | 2018-10-23 | Saudi Arabian Oil Company | Statistical methods for assessing downhole casing integrity and predicting casing leaks |
RU2602774C1 (en) * | 2015-08-04 | 2016-11-20 | Общество с ограниченной ответственностью "ТатАСУ" | System for monitoring operation of submersible pump equipment |
GB2543048B (en) * | 2015-10-05 | 2022-06-08 | Equinor Energy As | Estimating flow rate at a pump |
EP3516161B1 (en) * | 2016-09-26 | 2023-06-28 | Bristol, Inc., D/B/A Remote Automation Solutions | Automated wash system and method for a progressing cavity pump system |
US10364655B2 (en) | 2017-01-20 | 2019-07-30 | Saudi Arabian Oil Company | Automatic control of production and injection wells in a hydrocarbon field |
WO2018165352A1 (en) | 2017-03-08 | 2018-09-13 | Schlumberger Technology Corporation | Dynamic artificial lift |
US10697293B2 (en) | 2017-05-26 | 2020-06-30 | Baker Hughes Oilfield Operations, Llc | Methods of optimal selection and sizing of electric submersible pumps |
US11649705B2 (en) * | 2017-08-23 | 2023-05-16 | Robert J Berland | Oil and gas well carbon capture system and method |
US10947821B2 (en) * | 2017-08-23 | 2021-03-16 | Robert J. Berland | Oil and gas production well control system and method |
EP3887648B1 (en) * | 2018-11-29 | 2024-01-03 | BP Exploration Operating Company Limited | Das data processing to identify fluid inflow locations and fluid type |
US11180976B2 (en) | 2018-12-21 | 2021-11-23 | Exxonmobil Upstream Research Company | Method and system for unconventional gas lift optimization |
CN109696360B (en) * | 2019-01-28 | 2023-10-31 | 中国地质大学(武汉) | Hydrate exploitation reservoir response and sand production simulation multifunctional reaction kettle |
AU2019279953B2 (en) | 2019-02-12 | 2023-02-02 | Halliburton Energy Services, Inc. | Bias correction for a gas extractor and fluid sampling system |
RU2730252C1 (en) * | 2019-06-14 | 2020-08-19 | Дмитрий Валерьевич Хачатуров | Method of maximizing fluid extraction using electric submersible pump |
US11326440B2 (en) | 2019-09-18 | 2022-05-10 | Exxonmobil Upstream Research Company | Instrumented couplings |
WO2021080622A1 (en) * | 2019-10-25 | 2021-04-29 | Halliburton Energy Services, Inc. | Wax removal in a production line |
WO2021102037A1 (en) * | 2019-11-21 | 2021-05-27 | Conocophillips Company | Well annulus pressure monitoring |
CN113123761B (en) * | 2020-01-15 | 2023-08-22 | 中国石油天然气股份有限公司 | Method and device for controlling start and stop of electric submersible pump |
US11333010B2 (en) * | 2020-05-13 | 2022-05-17 | Saudi Arabian Oil Company | Smart choke valve to regulate well sand production |
US11414954B2 (en) * | 2020-07-06 | 2022-08-16 | Saudi Arabian Oil Company | Smart choke valve to assess and regulate production flow |
US11293268B2 (en) | 2020-07-07 | 2022-04-05 | Saudi Arabian Oil Company | Downhole scale and corrosion mitigation |
US11933162B2 (en) * | 2021-05-06 | 2024-03-19 | Landmark Graphics Corporation | Calibrating erosional sand prediction |
US11686177B2 (en) | 2021-10-08 | 2023-06-27 | Saudi Arabian Oil Company | Subsurface safety valve system and method |
CN115492558B (en) * | 2022-09-14 | 2023-04-14 | 中国石油大学(华东) | Device and method for preventing secondary generation of hydrate in pressure-reducing exploitation shaft of sea natural gas hydrate |
Family Cites Families (73)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3211225A (en) * | 1963-05-28 | 1965-10-12 | Signal Oil & Gas Co | Well treating apparatus |
US3710867A (en) * | 1971-01-05 | 1973-01-16 | Petrolite Corp | Apparatus and process for adding chemicals |
US3954006A (en) * | 1975-01-31 | 1976-05-04 | Schlumberger Technology Corporation | Methods for determining velocities and flow rates of fluids flowing in well bore |
US3991827A (en) * | 1975-12-22 | 1976-11-16 | Atlantic Richfield Company | Well consolidation method |
US4064936A (en) * | 1976-07-09 | 1977-12-27 | Mcclure L C | Chemical treating system for oil wells |
FR2421272A1 (en) * | 1978-03-28 | 1979-10-26 | Europ Propulsion | SYSTEM FOR REMOTE CONTROL AND MAINTENANCE OF A SUBMERSIBLE WELL HEAD |
US4354553A (en) * | 1980-10-14 | 1982-10-19 | Hensley Clifford J | Corrosion control downhole in a borehole |
US4436148A (en) * | 1981-04-27 | 1984-03-13 | Richard Maxwell | Chemical treatment for oil wells |
US4375833A (en) * | 1981-09-04 | 1983-03-08 | Meadows Floyd G | Automatic well treatment system |
US4635723A (en) * | 1983-07-07 | 1987-01-13 | Spivey Melvin F | Continuous injection of corrosion-inhibiting liquids |
US4582131A (en) * | 1984-09-26 | 1986-04-15 | Hughes Tool Company | Submersible chemical injection pump |
US4665981A (en) * | 1985-03-05 | 1987-05-19 | Asadollah Hayatdavoudi | Method and apparatus for inhibiting corrosion of well tubing |
US4589434A (en) * | 1985-06-10 | 1986-05-20 | Exxon Production Research Co. | Method and apparatus to prevent hydrate formation in full wellstream pipelines |
JPS62110135A (en) * | 1985-11-08 | 1987-05-21 | Cosmo Co Ltd | Method and apparatus for quantifying concentration of asphaltene |
US4721158A (en) * | 1986-08-15 | 1988-01-26 | Amoco Corporation | Fluid injection control system |
US4830112A (en) * | 1987-12-14 | 1989-05-16 | Erickson Don J | Method and apparatus for treating wellbores |
US4901563A (en) * | 1988-09-13 | 1990-02-20 | Atlantic Richfield Company | System for monitoring fluids during well stimulation processes |
US4926942A (en) * | 1989-02-22 | 1990-05-22 | Profrock Jr William P | Method for reducing sand production in submersible-pump wells |
US5006845A (en) * | 1989-06-13 | 1991-04-09 | Honeywell Inc. | Gas kick detector |
US5172717A (en) * | 1989-12-27 | 1992-12-22 | Otis Engineering Corporation | Well control system |
US5517593A (en) * | 1990-10-01 | 1996-05-14 | John Nenniger | Control system for well stimulation apparatus with response time temperature rise used in determining heater control temperature setpoint |
US5305209A (en) * | 1991-01-31 | 1994-04-19 | Amoco Corporation | Method for characterizing subterranean reservoirs |
US5209301A (en) * | 1992-02-04 | 1993-05-11 | Ayres Robert N | Multiple phase chemical injection system |
US5353237A (en) * | 1992-06-25 | 1994-10-04 | Oryx Energy Company | System for increasing efficiency of chemical treatment |
US5706896A (en) * | 1995-02-09 | 1998-01-13 | Baker Hughes Incorporated | Method and apparatus for the remote control and monitoring of production wells |
US6006832A (en) * | 1995-02-09 | 1999-12-28 | Baker Hughes Incorporated | Method and system for monitoring and controlling production and injection wells having permanent downhole formation evaluation sensors |
US5829520A (en) * | 1995-02-14 | 1998-11-03 | Baker Hughes Incorporated | Method and apparatus for testing, completion and/or maintaining wellbores using a sensor device |
US5647435A (en) * | 1995-09-25 | 1997-07-15 | Pes, Inc. | Containment of downhole electronic systems |
US5767680A (en) * | 1996-06-11 | 1998-06-16 | Schlumberger Technology Corporation | Method for sensing and estimating the shape and location of oil-water interfaces in a well |
US6061634A (en) * | 1997-04-14 | 2000-05-09 | Schlumberger Technology Corporation | Method and apparatus for characterizing earth formation properties through joint pressure-resistivity inversion |
US6281489B1 (en) * | 1997-05-02 | 2001-08-28 | Baker Hughes Incorporated | Monitoring of downhole parameters and tools utilizing fiber optics |
DE69808759D1 (en) | 1997-06-09 | 2002-11-21 | Baker Hughes Inc | MONITORING AND CONTROL SYSTEM FOR CHEMICAL TREATMENT OF AN OIL HOLE |
US6070663A (en) * | 1997-06-16 | 2000-06-06 | Shell Oil Company | Multi-zone profile control |
RU2140523C1 (en) * | 1997-06-24 | 1999-10-27 | Самарская государственная архитектурно-строительная академия | Method of automatic control of operating conditions of well equipped with submersible electrical centrifugal pump |
US6192480B1 (en) * | 1997-07-18 | 2001-02-20 | Micron Electronics, Inc. | Method of managing power for a computer system and generating application threshold warnings |
US5937946A (en) * | 1998-04-08 | 1999-08-17 | Streetman; Foy | Apparatus and method for enhancing fluid and gas flow in a well |
CA2296108C (en) | 1998-05-05 | 2008-10-14 | Baker Hughes Incorporated | Actuation system for a downhole tool |
NO982823D0 (en) | 1998-06-18 | 1998-06-18 | Kongsberg Offshore As | Control of fluid flow in oil or gas wells |
RU2165037C2 (en) * | 1998-11-30 | 2001-04-10 | Самарская государственная архитектурно-строительная академия | Method of operation of well with submersible centrifugal pump and device for realization of this method |
CA2353900C (en) * | 1998-12-21 | 2005-03-08 | Baker Hughes Incorporated | Closed loop chemical injection and monitoring system for oilfield operations |
US20080262737A1 (en) * | 2007-04-19 | 2008-10-23 | Baker Hughes Incorporated | System and Method for Monitoring and Controlling Production from Wells |
US7389787B2 (en) * | 1998-12-21 | 2008-06-24 | Baker Hughes Incorporated | Closed loop additive injection and monitoring system for oilfield operations |
US8682589B2 (en) * | 1998-12-21 | 2014-03-25 | Baker Hughes Incorporated | Apparatus and method for managing supply of additive at wellsites |
US6196314B1 (en) * | 1999-02-15 | 2001-03-06 | Baker Hughes Incorporated | Insoluble salt control system and method |
US6467340B1 (en) * | 1999-10-21 | 2002-10-22 | Baker Hughes Incorporated | Asphaltenes monitoring and control system |
US6543540B2 (en) * | 2000-01-06 | 2003-04-08 | Baker Hughes Incorporated | Method and apparatus for downhole production zone |
NO309884B1 (en) * | 2000-04-26 | 2001-04-09 | Sinvent As | Reservoir monitoring using chemically intelligent release of tracers |
US6408943B1 (en) * | 2000-07-17 | 2002-06-25 | Halliburton Energy Services, Inc. | Method and apparatus for placing and interrogating downhole sensors |
AU2001293809A1 (en) * | 2000-09-12 | 2002-03-26 | Sofitech N.V. | Evaluation of multilayer reservoirs |
US20020112888A1 (en) * | 2000-12-18 | 2002-08-22 | Christian Leuchtenberg | Drilling system and method |
EA005604B1 (en) * | 2001-02-05 | 2005-04-28 | Шлумбергер Холдингс Лимитид | Optimization of reservoir, well and surface network systems |
US6795773B2 (en) * | 2001-09-07 | 2004-09-21 | Halliburton Energy Services, Inc. | Well completion method, including integrated approach for fracture optimization |
US7111179B1 (en) * | 2001-10-11 | 2006-09-19 | In-Hand Electronics, Inc. | Method and apparatus for optimizing performance and battery life of electronic devices based on system and application parameters |
US7178591B2 (en) * | 2004-08-31 | 2007-02-20 | Schlumberger Technology Corporation | Apparatus and method for formation evaluation |
DE60315304D1 (en) * | 2002-08-14 | 2007-09-13 | Baker Hughes Inc | UNDERWATER INJECTION UNIT FOR INJECTION OF CHEMICAL ADDITIVES AND MONITORING SYSTEM FOR OIL CONVEYORS |
US7725301B2 (en) * | 2002-11-04 | 2010-05-25 | Welldynamics, B.V. | System and method for estimating multi-phase fluid rates in a subterranean well |
JP2007533969A (en) * | 2003-03-17 | 2007-11-22 | ジュール マイクロシステムズ カナダ インコーポレイテッド | System that enables remote analysis of fluids |
US7261162B2 (en) * | 2003-06-25 | 2007-08-28 | Schlumberger Technology Corporation | Subsea communications system |
NO322167B1 (en) | 2003-11-05 | 2006-08-21 | Abb As | Method and apparatus for detecting water breakthroughs in well production of oil and gas, as well as using the method in an oil and gas production process |
US20050149264A1 (en) * | 2003-12-30 | 2005-07-07 | Schlumberger Technology Corporation | System and Method to Interpret Distributed Temperature Sensor Data and to Determine a Flow Rate in a Well |
US6874361B1 (en) * | 2004-01-08 | 2005-04-05 | Halliburton Energy Services, Inc. | Distributed flow properties wellbore measurement system |
RU2256065C1 (en) * | 2004-01-22 | 2005-07-10 | Общество с ограниченной ответственностью "ЮКСиб" | Device for operation of electric down-pump in oil-gas well |
US7114557B2 (en) * | 2004-02-03 | 2006-10-03 | Schlumberger Technology Corporation | System and method for optimizing production in an artificially lifted well |
GB2416871A (en) | 2004-07-29 | 2006-02-08 | Schlumberger Holdings | Well characterisation using distributed temperature sensor data |
RU2280151C1 (en) * | 2004-12-06 | 2006-07-20 | Закрытое Акционерное Общество "Промышленная группа "Инженерные технологии", ЗАО ПГ "Инженерные технологии" | Automatic control method and device for oil production process |
RU46889U1 (en) * | 2005-01-25 | 2005-07-27 | Центр Разработки Нефтедобывающего Оборудования | SUBMERSIBLE UNIT FOR SYSTEM OF TELEMETRY INSTALLATION OF SUBMERSIBLE CENTRIFUGAL PUMP FOR OIL PRODUCTION |
US20060266913A1 (en) | 2005-05-26 | 2006-11-30 | Baker Hughes Incororated | System, method, and apparatus for nodal vibration analysis of a device at different operational frequencies |
RU2293176C1 (en) * | 2005-09-02 | 2007-02-10 | Николай Петрович Кузьмичев | Method for short-term operation of well using immersed pump device with electric drive |
US7654318B2 (en) * | 2006-06-19 | 2010-02-02 | Schlumberger Technology Corporation | Fluid diversion measurement methods and systems |
US7715742B2 (en) * | 2006-12-22 | 2010-05-11 | Xerox Corporation | Photoconductor life through active control of charger settings |
US7890273B2 (en) * | 2007-02-20 | 2011-02-15 | Schlumberger Technology Corporation | Determining fluid and/or reservoir information using an instrumented completion |
US7805248B2 (en) * | 2007-04-19 | 2010-09-28 | Baker Hughes Incorporated | System and method for water breakthrough detection and intervention in a production well |
US20080257544A1 (en) * | 2007-04-19 | 2008-10-23 | Baker Hughes Incorporated | System and Method for Crossflow Detection and Intervention in Production Wellbores |
-
2007
- 2007-04-19 US US11/737,313 patent/US7711486B2/en active Active
-
2008
- 2008-04-18 MY MYPI20094371 patent/MY153025A/en unknown
- 2008-04-18 AU AU2008275494A patent/AU2008275494B2/en active Active
- 2008-04-18 WO PCT/US2008/060797 patent/WO2009009196A2/en active Application Filing
- 2008-04-18 CA CA2684292A patent/CA2684292C/en active Active
- 2008-04-18 GB GB0918124.9A patent/GB2461445B/en active Active
- 2008-04-18 RU RU2009142438/03A patent/RU2468191C2/en active IP Right Revival
- 2008-04-18 BR BRPI0810228-7A patent/BRPI0810228B1/en active IP Right Grant
-
2009
- 2009-10-19 NO NO20093166A patent/NO341444B1/en unknown
Also Published As
Publication number | Publication date |
---|---|
BRPI0810228B1 (en) | 2018-05-22 |
AU2008275494B2 (en) | 2013-08-29 |
CA2684292C (en) | 2012-12-11 |
RU2009142438A (en) | 2011-05-27 |
GB2461445A (en) | 2010-01-06 |
MY153025A (en) | 2014-12-31 |
AU2008275494A1 (en) | 2009-01-15 |
US7711486B2 (en) | 2010-05-04 |
GB0918124D0 (en) | 2009-12-02 |
WO2009009196A2 (en) | 2009-01-15 |
NO341444B1 (en) | 2017-11-13 |
RU2468191C2 (en) | 2012-11-27 |
WO2009009196A3 (en) | 2009-03-19 |
NO20093166L (en) | 2010-01-18 |
GB2461445B (en) | 2012-04-25 |
BRPI0810228A2 (en) | 2014-10-29 |
US20080262736A1 (en) | 2008-10-23 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
CA2684292A1 (en) | System and method for monitoring physical condition of production well equipment and controlling well production | |
AU2008270950B2 (en) | System and method for monitoring and controlling production from wells | |
AU2008242750B2 (en) | System and method for water breakthrough detection and intervention in a production well | |
KR102083816B1 (en) | Apparatuses and methods for determining wellbore influx condition using qualitative indications | |
US7246662B2 (en) | Systems and methods for controlling flow control devices | |
US20080262737A1 (en) | System and Method for Monitoring and Controlling Production from Wells | |
US10480315B2 (en) | Average/initial reservoir pressure and wellbore efficiency analysis from rates and downhole pressures | |
AU2012261505B2 (en) | Groundwater Management System | |
EP2041394A2 (en) | Method and system of diagnosing production changes | |
EA026278B1 (en) | Method for estimating reservoir pressure in a subsurface hydrocarbon reservoir and computer system and computer-readable medium used therein | |
CN110325705A (en) | System and method for operating blowout preventer system | |
US9970289B2 (en) | Methods and systems for assessing productivity of a beam pumped hydrocarbon producing well | |
CN108920795B (en) | Thermal recovery production well bottom steam cavity prediction method and device | |
Giangiacomo et al. | Optimizing pumping well efficiency with smart fluid-level controller technology | |
Denney | Well management: Use of permanent downhole flowmeters for pressure-transient analysis | |
Jackson et al. | Fluid flow monitoring in oilfields using downhole measurements of electrokinetic potential | |
Smith | Reducing Produced Water with Density and Conductivity Meters |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
EEER | Examination request |