Wireless downwhole measurement and control for optimizing gas lift well and field performance
원문보기
IPC분류정보
국가/구분
United States(US) Patent
등록
국제특허분류(IPC7판)
E21B-04700
E21B-04706
출원번호
US-0220455
(2001-03-02)
국제출원번호
PCT/US01/07003
(2002-08-29)
§371/§102 date
20020829
(20020829)
국제공개번호
WO01/65056
(2001-09-07)
발명자
/ 주소
Hirsch, John Michele
Stegemeier, George Leo
Hall, James William
Burnett, Robert Rex
Savage, William Mountjoy
Carl, Jr., Frederick Gordon
출원인 / 주소
Shell Oil Company
인용정보
피인용 횟수 :
20인용 특허 :
84
초록▼
A method for optimizing the production of a petroleum well is provided. The petroleum well includes a borehole, a piping structure positioned within the borehole, and a tubing string positioned within the borehole for conveying a production fluid. Production of the well is optimized by determining a
A method for optimizing the production of a petroleum well is provided. The petroleum well includes a borehole, a piping structure positioned within the borehole, and a tubing string positioned within the borehole for conveying a production fluid. Production of the well is optimized by determining a flow rate of the production fluid within the tubing string and determining a lift-gas injection rate for the gas being injected into the tubing string. The flow rate and injection rate data is communicated along the piping structure of the well to a selected location, where the data is collected and analyzed. After analysis of the data, an optimum operating point for the well can be determined.
대표청구항▼
1. A method for optimizing the production of fluid in a petroleum well having a borehole and a piping structure positioned within the borehole, comprising the steps of:determining a flow rate of the production fluid downhole in the borehole using a sensor positioned downhole in the borehole and powe
1. A method for optimizing the production of fluid in a petroleum well having a borehole and a piping structure positioned within the borehole, comprising the steps of:determining a flow rate of the production fluid downhole in the borehole using a sensor positioned downhole in the borehole and powered using an AC signal applied to the piping structure as a conductor; determining a lift-gas injection rate for an amount of lift-gas being injected into the well; communicating the flow rate data and the lift-gas injection rate data; and collecting and analyzing the flow rate data and the lift-gas injection rate data to determine an optimum operating point for the petroleum well, wherein the step of determining the flow rate further comprises the steps of: measuring a first pressure of the production fluid within a first pipe section of the tubing string; measuring a second pressure of the production fluid within a second pipe section of the tubing string, the second pipe section being greater in diameter than the first pipe section; and determining the flow rate of the production fluid based upon the first pressure and the second pressure.2. The method according to claim 1, further comprising the step of operating the well at the optimum operating point by selectively positioning a controllable gas lift valve powered using the piping structure as a conductor to control the amount of lift-gas injected into the piping structure.3. The method according to claim 1, further comprising the step of operating the well at the optimum operating point by throttling the amount of lift-gas injected into the piping structure.4. The method according to claim 1, wherein the step of collecting an analyzing further comprises the step of creating a production curve of the flow rate of the production fluid versus the lift-gas injection rate.5. The method according to claim 1, wherein the lift-gas injection rate is determined by measuring the amount of lift-gas entering a tubing string through a controllable gas-lift valve.6. The method according to claim 1, wherein the communicating step further comprises transmitting the flow rate data along the piping structure to a surface computer.7. The method according to claim 1, wherein the communicating step further comprises transmitting the flow rate data to a controller positioned downhole in the borehole.8. The method according to claim 1, wherein the piping structure is the tubing string.9. The method according to claim 1, wherein the communicating step further comprises the steps of:defining a transmission section of the piping structure using at least in part an impendance device positioned around the piping structure; and communicating the data along the transmission section of the piping structure. 10. The method according to claim 1, further comprising the step of operating the well to preventing heading.11. The method for optimizing production of liquid in a petroleum field having a plurality of petroleum wells and a piping structure disposed within the borehole of a number of wells, comprising the steps of:determining a flow rate for the production fluid within the piping structure of a number of the petroleum wells wherein the step of determining the flow rate further comprises the steps of: measuring a first pressure of the production fluid within a first pipe section of the tubing string; measuring a second pressure of production fluid within a second pipe section of the tubing string, the second pipe section being greater in diameter than the first pipe section; and determining the flow rate of the production fluid based upon the first pressure and the second pressure; communicating the flow rate data along the piping to a surface computer for a number of the petroleum wells; determining a lift-gas injection rate for an amount of lift-gas being injected into the piping structure of each of the petroleum wells; communicating the lift-gas injection rate data to a surface computer for a number of the petroleum wells; and collecting and analyzing the flow rate data and lift-gas injection rate data supplied by each of the wells to determine an optimum operating point for the petroleum field. 12. The method according to claim 11, further comprising the step of operating the petroleum field at an optimum operating point by selectively controlling the amount of lift-gas injected into one or more wells.13. The method according to claim 11, wherein the step of collecting and analyzing further comprises the step of creating a production curve of flow rate of the production fluid versus lift-gas injection rate for a number of the petroleum wells.14. The method according to claim 11, wherein the lift-gas injection rate is determined by measuring the amount of lift-gas entering a tubing string through a controllable gas lift valve.15. The method according to claim 11, wherein the piping structure is the tubing string.16. The method according to claim 11, wherein the communicating step further comprises the steps of:positioning an induction choke around the piping structure to define a transmission portion; and communicating the flow rate data along the transmission portion of the piping structure. 17. The method according to claim 11, including optimizing the field production based on a limited supply of lift gas.18. The method according to claim 11, operating a number of wells in the field at approximately the same slope of a production curve of the flow rate of the production fluid versus the lift-gas injection rate.19. A gas lift well comprising:a tubing string positioned within the borehole for delivering a production fluid from downhole to the surface; a downhole measurement system for determining a flow rate of the production fluid within the tubing string, wherein the downhole measurement system comprises: a measurement section disposed on the tubing string having a first pipe section and a second pipe section, wherein the first pipe section is lesser in diameter than the second pipe section; a plurality of pressure sensors, wherein at least one of the pressure sensors is configured to detect a first pressure of the production fluid in the first pipe section and at least one of the pressure sensors is configured to detect a second pressure of the production fluid in the second pipe section; and whereby data obtain by the pressure sensors is used to determine the flow rate of the production fluid within the tubing string; a sensor for determining the lift gas injection rate; and a communication system operably associated with the tubing string such that flow rate data from the downhole measurement system can be communicated along the tubing string. 20. The petroleum well according to claim 19, including a controllable gas-lift valve operably connected to the tubing string and powered by a time-varying current applied to the tubing string.21. The petroleum well according to claim 19, wherein the measurement system comprises two or more pressure sensors used to determine the flow rate of the production fluid within the tubing string.22. The petroleum well according to claim 19, wherein two pressure sensors are configured to detect pressure data within the second pipe section, the pressure data being used to determine the density of the production fluid within the tubing string.23. The petroleum well according to claim 19, wherein the measurement system further comprises a paddle-wheel flowmeter.24. The petroleum well according to claim 19, wherein the measurement system further comprises differential temperature rise sensors.25. The petroleum well according to claim 19, wherein the measurement system further comprises sensors for obtaining Doppler acoustic measurements.26. The petroleum well according to claim 19, wherein the measurement system further comprises sensors for obtaining vortex shedding measurements.27. The petroleum well according to claim 19, further comprising a controllable gas-lift valve operably attached to the tubing string to regulate an amount of lift gas injected into the tubing string, wherein the amount of lift-gas injected is based upon the flow rate data obtained from the downhole measurement system.28. A petroleum well comprising:a tubing string positioned within the borehole for delivering a production fluid from downhole to the surface; a downhole measurement system for determining a flow rate of the production fluid within the tubing string; a sensor for determining the lift gas injection rate; a communication system operably associated with the tubing string such that flow rate data from the downhole measurement system can be communicated along the tubing string; a current impedance device positioned around the tubing string, wherein flow rate data from the downhole measurement system is communicated along a portion of the tubing string defined at least in part by the current impedance device; and a controllable gas-lift valve operably attached to the tubing string for controlling a lift-gas injection rate for a lift-gas injected into the tubing string, wherein the optimum lift-gas injection rate for the well is determined from a production curve of the flow rate of the production fluid versus the lift-gas injection rate wherein:the tubing string extends longitudinally within the borehole from a surface of the well to a production zone; andthe current impendance device is an electrically insulated tubing hanger positioned at the surface of the well. 29. A petroleum field having a plurality of gas-lift wells comprising:a source of compressed gas of a finite amount; one or more of the wells including a downhole measurement system for determining the flow rate of the production fluid within the production tubing of a respective well, the tubing having a transmission section for communicating the flow rate data to the surface wherein the downhole measurement system comprises: a measurement section disposed on the tubing string having a first pipe section and a second pipe section, wherein the first pipe section is lesser in diameter than the second pipe section; a plurality of pressure sensors, wherein at least one of the pressure sensor is configured to detect a first pressure of the production fluid in the first pipe section and at least one of the pressure sensors is configured to detect a second pressure of the production fluid in the second pipe section; and whereby data obtained by the pressure sensors is used to determine the flow rate of the production fluid within the tubing string; a surface communication system for collecting the flow rate data from respective wells; and a surface computer connected to the communication system for analyzing the flow rate data and determining an optimum production for each well based on the finite amount of compressed gas. 30. The petroleum field of claim 29, a number of the wells including a throttle for regulating the amount of compressed gas injected into a respective well.31. The petroleum field of claim 29, a number of the wells including gas-lift valve attached to the tubing and controllable to regulate the amount of compressed gas injected into a respective well.
연구과제 타임라인
LOADING...
LOADING...
LOADING...
LOADING...
LOADING...
이 특허에 인용된 특허 (84)
MacLeod Norman C. (Sunnyvale CA), Apparatus and method for down-hole EM telemetry while drilling.
Van Steenwyk Donald H. ; Towle James N. ; Price Timothy, Apparatus and method for electric field telemetry employing component upper and lower housings in a well pipestring.
Veneruso Anthony F. (Richmond TX), Apparatus for electromagnetically coupling power and data signals between a first unit and a second unit and in particul.
More Henry S. (Los Altos CA) Fraser Edward C. (Cupertino CA) Bulduc Lawrence R. (Cottonwood CA), Apparatus for inductively coupling signals between a downhole sensor and the surface.
Van Gisbergen Stanislaus Johannes Cornelis Henricus Maria,NLX ; Der Kinderen Wilhelmus Johannes Godefridus Joseph,NLX, Downhole electricity transmission system.
Michael A. Carmody ; Kevin R. Jones ; Robert J. Coon ; Douglas J. Murray ; Mark E. Hopmann ; Steven L. Jennings ; Brian A. Roth, Downhole flow control devices.
Michael A. Carmody ; Kevin R. Jones ; Robert J. Coon ; Douglas J. Murray ; Mark E. Hopmann ; Steven L. Jennings ; Brian A. Roth, Downhole flow control devices.
Perkins Donald H. (Carrollton TX) Deaton Thomas M. (Farmers Branch TX) Sizer Phillip S. (Farmers Branch TX), Electric surface controlled subsurface valve system.
Jewell Andrew D. (Bracknell GBX), Electrode array construction featuring current emitting electrodes and resistive sheet guard electrode for investigating.
B.o slashed.e Einar,NOX ; Carlsen Hans Paul,NOX ; Holgersen Stig,NOX ; Haugerud Olav Sveinung,NOX, Injector for injecting a tracer into an oil or gas reservior.
Rorden Louis H. (Los Altos CA) Patel Ashok (San Jose CA) Leggett ; III James V. (Houston TX) Gibbons Frank L. (Houston TX) Owens Steven C. (Katy TX), Method and apparatus for communicating data in a wellbore and for detecting the influx of gas.
Rorden Louis H. ; Patel Ashok ; Leggett ; III James V. ; Gibbons Frank Lindsay ; Owens Steven C., Method and apparatus for communicating data in a wellbore and for detecting the influx of gas.
MacLeod ; deceased Norman C. (late of Sunnyvale CA by Martha H. MacLeod ; legal representative ) Samdahl Roger N. (San Jose CA) Bandy Thomas R. (Katy TX), Method and apparatus for communicating signals from within an encased borehole.
Thompson Larry W. (Willis TX) Wisler Macmillan M. (Kingwood TX), Method and apparatus for interrogating a borehole and surrounding formation utilizing digitally controlled oscillators.
Bilden Dean ; Browning Ron ; Cramer Dave ; Harrington Larry ; Hoel Mark E. ; Holcomb Bill ; Mack Dave, Method and apparatus for managing well production and treatment data.
Perry Carl A. (Middletown CT) Daigle Guy A. (Plainville CT) Bruck William (Glastonbury CT) Nordstrom Roy (Durham CT) Rountree Steven (Layafette LA) Dudek ; Jr. Joseph (Southington CT) Tsang James (Ma, Method and apparatus for nuclear logging using lithium detector assemblies and gamma ray stripping means.
Bankston Douglas P. (Hammond LA) Fry Keith (Des Allemands LA) Guidry Chester (Slidell LA), Method and apparatus for removing gas lift valves from side pocket mandrels.
Espinoza Jose A. (Edo Lara VEX), Method and apparatus for testing the physical integrity of production tubing and production casing in gas-lift wells sys.
Goodman Kenneth R. (LaPorte TX) Puckett Robert D. (LaPorte TX), Method and apparatus to train telemetry system for optimal communications with downhole equipment.
Georgi Daniel T. (Houston TX) Song Shanhong (Houston TX) Zhang Jian C. (Houston TX), Method for determining flow regime in multiphase fluid flow in a wellbore.
Gass John C. (Wichita KS) Kerr Noell C. (Liberty TX) Pittmann Robert W. (Sugarland TX), Method for forming remotely actuated gas lift systems and balanced valve systems made thereby.
Diatschenko Victor (Houston TX) Brown Winthrop K. (Bellaire TX) Stoy James R. (Missouri City TX), Passive acoustic detection of flow regime in a multi-phase fluid flow.
Woodward George H. (New Britain CT), Phase and amplitude calibration system for electromagnetic propagation based earth formation evaluation instruments.
Forehand Gilbert H. (Duncan OK) Lynch Michael J. (Duncan OK) Duncan Richard L. (Duncan OK) Tilghman Stephen E. (Duncan OK) Penn Jack C. (Duncan OK), Power-conserving self-contained downhole gauge system.
Tubel Paulo (The Woodlands TX) Mullins ; II Albert A. (Humble TX) Jones Kevin (Humble TX) Richardson Frank D. (Huntsville TX), Production wells having permanent downhole formation evaluation sensors.
Lagerlef David L. (Eagle River AK) Brady Jerry L. (Anchorage AK) Gerlek Stephen (Anchorage AK) Hightower Charles M. (Plano TX) Wydrinksi Raymond (Lewisville TX), System for monitoring gas lift wells.
Mathieu Yves M. G. (Les Ulis FRX) DeCorps Jean-Luc R. A. L. (Antony FRX) Fouillou Didier (Fontainebleau FRX) Revel Jean-Marie (Bombon FRX), Transmitter device with two insulating couplings for use in a borehole.
McDonald William J. (Houston TX) Pittard Gerard T. (Houston TX) Steele Charles G. (Houston TX) Kiefer Karl F. (The Woodlands TX) Clifton Terry P. (Houston TX) Leitko Curtis E. (Houston TX), Wireless downhole electromagnetic data transmission system and method.
Wallace, Jon M.; Huang, Hao; Wan, Jing, Discretized physics-based models and simulations of subterranean regions, and methods for creating and using the same.
Nooruddin, Hasan A.; Rahman, Noor M. Anisur, Estimating measures of formation flow capacity and phase mobility from pressure transient data under segregated oil and water flow conditions.
Rahman, Noor M. Anisur; Nooruddin, Hasan A., Measuring inter-reservoir cross flow rate through unintended leaks in zonal isolation cement sheaths in offset wells.
Rashid, Kashif; Lucas-Clements, Daniel Colin-Nesbitt; Hallquist, Aron Edward; Huber, Michael; Tonkin, Trevor Graham; Shand, Andrew Michael, Methods and systems for performing oilfield production operations.
Dale, Bruce A.; Pakal, Rahul; Burdette, Jason A.; Haeberle, David C.; Clingman, Scott R., Well modeling associated with extraction of hydrocarbons from subsurface formations.
Dale, Bruce A.; Pakal, Rahul; Haeberle, David C.; Burdette, Jason A.; Mohr, John W.; Rosenbaum, Darren F.; Asmann, Marcus; Clingman, Scott R.; Duffy, Brian W.; Benish, Timothy G., Well modeling associated with extraction of hydrocarbons from subsurface formations.
Fastovets, Andrey; Abbott, William John Jack; Fonneland, Jostein Engeseth; Ollre, Albert G.; Cardenas, Alejandro Camacho, Wireless sensor system for electric submersible pump.
※ AI-Helper는 부적절한 답변을 할 수 있습니다.