WO1997046793A1 - Systeme de regulation de pompe de tete de puits - Google Patents

Systeme de regulation de pompe de tete de puits Download PDF

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Publication number
WO1997046793A1
WO1997046793A1 PCT/US1997/009632 US9709632W WO9746793A1 WO 1997046793 A1 WO1997046793 A1 WO 1997046793A1 US 9709632 W US9709632 W US 9709632W WO 9746793 A1 WO9746793 A1 WO 9746793A1
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WO
WIPO (PCT)
Prior art keywords
well
downhole
measurement
wellhead
fluid
Prior art date
Application number
PCT/US1997/009632
Other languages
English (en)
Inventor
Thomas R. Bandy
John T. Hampton, Iii
William F. Trainor
James R. Foreman
Zhenyu Wang
Original Assignee
Protechnics International, Inc.
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 Protechnics International, Inc. filed Critical Protechnics International, Inc.
Priority to AU32295/97A priority Critical patent/AU3229597A/en
Publication of WO1997046793A1 publication Critical patent/WO1997046793A1/fr

Links

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
    • 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
    • E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
    • E21B44/005—Below-ground automatic control systems

Definitions

  • the present invention is directed to artificial lift systems, and, more particularly, to wellhead pump control systems for use with artificial lift systems. 2. BACKGROUND OF THE INVENTION
  • FIG. 1 An example of a conventional artificial lift arrangement is shown in Fig. 1 , as including well casing 1 10 (having perforations 1 25 ⁇ installed inside wellbore 1 1 2, pump 1 1 5, receiver
  • 1 1 7 (such as a pipeline or storage tank), pump motor 1 20, and motor speed controller 122.
  • fluid such as oil, water, etc.
  • the invention comprises a surface wellhead pump control system which controls the motor speed of a wellhead pump that is removing fluid from within a well.
  • the system comprises a downhole well tool having means for sensing downhole measurements, as well as means for transmitting the downhole measurements to a surface data analysis apparatus.
  • the downhole measurements may comprise downhole pressure and temperature proximate the downhole well tool.
  • the downhole well tool contains temperature and pressure sensors and other sensors as well, such as torque and other measurement sensors.
  • the surface data analysis apparatus includes means for receiving the downhole measurements from the transmitting means, and means for comparing the received downhole measurements with desired predetermined measurement parameters. These desired parameters are typically associated with the well and the fluid being removed from a particular well. Additionally, the surface data analysis apparatus includes means for calculating optimum wellhead pump motor speed operation from the received downhole measurements, and, in turn, means for adjusting the operating parameters of the wellhead pump motor to the calculated optimum values -- so as to optimize the rate at which fluid is removed from the well.
  • the surface data analysis apparatus may further include means for learning the unique characteristics of a particular well.
  • the system may include means for alerting an operator when any of the downhole measurements depart from an acceptable range of measurement parameters.
  • the alert means may include means for activating a remote receiver or pager to notify the appropriate maintenance operator.
  • the invention may further include means for updating the downhole measurements at predetermined desired intervals of time. Such updating insures that optimum fluid removal rates are maintained regardless of changes in well producing behavior.
  • the adjustment means may be configured to alter the speed and the torque of the wellhead pump motor. Such alteration will be made to enable the pump to operate at or near optimal performance relative to fluid removal for the particular well, as well as safe and prudent operation of the equipment.
  • the invention further includes a method for controlling a wellhead pump comprising the steps of: (a) sensing certain downhole measurements at a downhole well tool; (b) transmitting those measurements to a surface data analysis apparatus; (c) receiving the downhole measurements at the surface data analysis apparatus; (d) comparing the received measurements with desired predetermined measurement parameters associated with the particular well and fluid being operated; (e) calculating optimum wellhead pump motor operation from the received downhole measurements; and (f) adjusting the operating parameters of the wellhead pump motor to optimize the rate at which fluid is removed from the well, to, in turn, insure the safe and prudent operation of that pump.
  • the method may further include the step of alerting an operator when the downhole measurements depart from a desired range of acceptable values.
  • the method may further include the step of updating the downhole measurements at predetermined intervals of time.
  • the method may further include the steps of: (a) learning the operating characteristics of the well; and (b) storing the learned operating characteristics of the well.
  • the step of learning may comprise the steps of: (a) setting the operating parameter of the wellhead pump motor to a predetermined set of operating parameters; (b) sensing certain measurements from the downhole well tool; (c) storing the downhole measurements; (d) repeating the foregoing steps as necessary for each of the desired range of operating parameters; and (e) computing the optimized operating characteristics of the well.
  • the invention may further include the step of remeasuring and reanalyzing the operating characteristics of the well at predetermined time intervals.
  • Fig. 1 is a schematic illustration of a conventional, prior art, artificial lift system
  • Fig. 2 is a schematic illustration of a lift system having the wellhead pump control system of the present invention.
  • Fig. 3 is a schematic illustration of the downhole tool contemplated for use with the present invention.
  • Wellhead pump control system 20 is shown in Fig. 2 as comprising downhole well tool 22, transmitting means 24, surface data analysis apparatus 26, operator alert means 28, and, updating means 30.
  • the updating means is used to update particular measurement data.
  • wellhead pump control system 20 may include a conventional bottom hole progressive cavity pump, the operating desired speed and torque of which is controlled by a. conventional variable frequency pump.
  • a pump may be obtained from Energy Ventures Incorporated or National Oilwell, both of Houston, Texas.
  • Downhole well tool 22 is shown in Fig. 2 (and in Fig. 3 as operatively positioned within a conventional bottom hole assembly) as including sensing means 32 which serves to measure the particular downhole data and power source 47.
  • the sensing means includes temperature sensor 44 and pressure sensor 46.
  • Temperature sensor 44 may comprise a conventional transducer capable of obtaining accurate temperature measurement in excess of 300°F (148.8 C C)
  • pressure sensor 46 may comprise a conventional strain gauge or quartz crystal pressure transducer which is capable of obtaining accurate pressure readings in excess of 15,000 psi (pounds per square inch).
  • Pressure sensor 46 indirectly determines the depth at which the fluid level is located above the downhole well tool 22 within the well in which downhole well tool 22 is positioned.
  • downhole well tool 22 may be attached directly to downhole well tool 22, and, may comprise batteries such as conventional "AA", "B", or “C” cell alkaline or lithium batteries, as well as customized, long-lasting batteries suited for extended use.
  • batteries such as conventional "AA”, "B”, or “C” cell alkaline or lithium batteries, as well as customized, long-lasting batteries suited for extended use.
  • other applicable conventional power sources as would be readily understood to those with ordinary skill in the art, are likewise contemplated.
  • downhole well tool 22 may be powered from a surface generator coupled through electric cabling from the surface.
  • Transmitting means 24 is shown in Fig. 2 as comprising transmitter 60.
  • the transmitting means serves to transmit the measured downhole data measurements, from the sensing means, to surface data analysis apparatus 26.
  • the transmitter may be positioned on the downhole tool, or, proximate thereto, as a stand-alone unit. Additionally, transmitter 60 may share power source 47 of sensing means 32, or, alternatively, transmitter 60 may be powered by a separate power source.
  • transmitter 60 may comprise a conventional transmitter capable of transmitting the measured downhole measurements from downhole to surface data analysis apparatus 26.
  • a conventional transmitter includes, but is not limited to, a subsurface modulated electromagnetic frequency (EMF) antenna.
  • EMF electromagnetic frequency
  • Such an antenna may likewise comprise toroids, gap-subs and/or hardwired data transmission technology.
  • the transmitter transmits the measurement, representative of, for example, the bottom hole fluid pressure and temperature data to receiver 34 (associated with surface data analysis apparatus 26).
  • Surface data analysis apparatus 26 (which may comprise a computing device) is shown in Fig. 2 as including receiving means 34, comparing means 36, calculating means 38, and adjustment means 40.
  • Receiving means 34 may comprise a conventional receiving device which is suitable for receiving and processing the downhole measurements received from transmitting means 24.
  • receiving means 34 may be connected to wellhead 1 1 (Fig. 2) and the ground for sensing the voltage potential at the wellhead (which represents the signal from transmitter 60 in downhole well tool 22).
  • the transmitting apparatus comprises an EMF transmitter
  • the receiver may comprise an EMF antenna coupled with a conventional surface receiver.
  • receiving means 34 may be provided with appropriate circuitry and programming to filter and/or amplify the received measurement/signal, to, in turn, clarify the signal by reducing/eliminating other interfering electrical noise from the signal. Inasmuch as the signal often travels extended distances through the ground and is susceptible to other electrical interference, the received measurements often require clarifying, filtering and/or amplifying.
  • Data comparing means 36, calculating means 38 and motor operating adjustment means 40 are all part of surface data analysis apparatus 26, and are each programmed using conventionally known programming techniques to perform various functions. Specifically, after receiving means 34 receives the transmitted measurements/signals, data comparing means 36 compares the received downhole measurements with desired (and programmed) measurement parameters associated with the particular well and fluid being removed from the well.
  • Calculating means 38 then calculates the optimum wellhead pump motor operation parameters (for the particular well), based on the compared received data. If the calculations reveal that the pump motor is not operating optimally (i.e. speed and torque) for the particular well, then adjustment means 40, as will be explained, alters the speed and/or torque to such optimal settings.
  • Adjustment means 40 comprises signal generator 50 and pump motor speed controller 52.
  • the signal generator is capable of transmitting desired output parameters to the motor controller which, in turn, implements these altered output parameters to the wellhead pump motor.
  • the motor controller may comprise a commercially available device such as Toshia.
  • surface data analysis apparatus 26 may also be capable of comparing, calculating and adjusting other data inputs, such as "maximum and/or minimum flow line pressure", “maximum and/or minimum sucker rod torque”, “maximum and/or minimum drive speeds", “pump rpm", “pump current”, etc.
  • Surface data analysis apparatus 26, in combination with transmitting means 24, may further include measurement updating means 30.
  • Such updating means 30 transmits downhole measurements, at predetermined time periods, (from sensing means 32) to surface data analysis apparatus 26. At each time period, the downhole measurements will be subjected to comparing means 36 and calculating means 38. Accordingly, in one embodiment, if the motor pump parameters at that specific time period differ from optimum motor pump parameters, such differences will then result in adjustment means 40 causing, for example, real time adjustments to the pump motor. Alternatively, if adjustments are required, the adjustment means may alert a maintenance operator (as will be more fully explained) who will then make the appropriate adjustments to the pump motor in accordance with the calculated optimum pump parameters. Updating means, and in particular, triggering the . receiving and transmitting of downhole measurements (at predetermined time intervals) can be accomplished through conventional programming techniques as would be readily understood to those with ordinary skill in the art.
  • the invention additionally contemplates operator alert means 28 for alerting a maintenance operator (at, for example, a remote location) of any adverse condition associated with the well pump motor (including non-optimal performance).
  • the alert means may be programmed into surface data analysis apparatus 26 and may include receiver actuator 42 and receiver 43.
  • Remote receiver actuator 42 may comprise a conventional transmitter for triggering receiver 43.
  • receiver actuator 42 Upon detection of an adverse pumping condition, which could be relative to fluid removal from the well (as determined by comparing means 36) receiver actuator 42 transmits an alerting indication to receiver 43, which alerts the maintenance operator of the potential problem.
  • the receiver actuator may comprise a telephone/modem
  • receiver 43 may comprise a remote terminal or other device such as a cellular telephone or pager which the maintenance operator may have on his person.
  • the alerting indication may comprise an audio signal, video signal or any combination of audio and visual signals which are receivable, through receiver 43, by a maintenance operator.
  • downhole well tool 22 of automated wellhead pump control system 20 is positioned and is lowered down a well through conventional techniques.
  • the well itself is bored out proximate to an underground reservoir, for removal of fluid therefrom.
  • Sensing means 32 of tool 22 when activated, receives downhole measurements (data) as to the pressure and temperature at the downhole tool location in the well.
  • specialized sensors may likewise be positioned to take readings other than temperature and pressure.
  • 1 - 3 pressure and temperature measurements are made over a span of 24 hours. Between measurements, the sensing means is temporarily turned off. However, it is also contemplated that sensing means 32 may remain activated constantly. However, the selective activation/deactivation, as needed, conserves power and extends sensor life. This increases the length of time the downhole tool can stay in the well, which is highly desirable, inasmuch as the replacement of the downhole tool and its power supply typically requires downtime and, in turn, adversely affects operating costs and production output.
  • the wellhead measurements obtained are transmitted by transmitting means 24 via receiving means 34 to surface data analysis device 26. While other locations are contemplated, the surface data analysis device 26 may be situated in the field office thereby reducing the need for well operators to visit individual well sites. Thus, instead of having to personally inspect each well on a daily basis, visits to a well can be limited to only those necessary to address potential trouble situations or to perform preventive maintenance.
  • comparing means 36 compares the received downhole measurement to known or desired parameters preprogrammed and stored within the surface data analysis apparatus 26.
  • the tabulation of these known or desired parameters may be based on mathematical analysis, or based on prior gathered information regarding the particular well or other wells with similar properties.
  • the calculating means 38 calculates the optimum parameters for the wellhead pump motor.
  • the adjustment apparatus 40 adjusts the output parameters of the wellhead pump, if needed, to operate based on the calculated optimal values. These optimal values translate into the maximum safe fluid removal rates. While other parameters are contemplated for specific purposes, the adjustment apparatus is capable of altering, or causing to be altered, the speed and the torque outputs of the wellhead pump motor.
  • the automated wellhead pump control system 20 is provided with a learning mode wherein the surface data analysis apparatus can
  • surface data analysis apparatus 26 further includes means 31 for learning the characteristics of the particular well.
  • the learning means uses adjustment means 40 to set several wellhead pump motor output parameters. At each of the set output parameters, learning means 31 stores the downhole measurements received by the receiving means 34. Subsequently, through various algorithms, such as interpolation, trial and error, or other conventional computations, learning means 31 is capable of generating a mathematical model embodying the characteristics of the well, toward determining the resulting optimal pump operating parameters. More specifically, the mathematical model used toward determining the maximum removal rate of the fluid from the particular well can be obtained without risk of damage to any of the equipment (such as the pump). In operation of this embodiment, automated wellhead pump control system
  • the learning mode essentially begins with a desired set of well pump motor output parameters. Sensing means 32 senses the downhole measurements and transmitting means 24 transmits these to learning means 31 of surface data analysis apparatus 26. Learning means 31 may be configured to use several sets of determined pump motor output parameters for which the foregoing procedure is repeated. Once the values for the downhole measurements have been received and stored, the learning means 31 computes a mathematical model of the particular operating characteristics of the well. Learning means 31 maintains this computed mathematical model as the operating characteristics of the well. The mathematical model, maintained by the learning means, is used by comparing means 36 and calculating means 38 to determine optimum wellhead pump motor parameters toward maximizing safe fluid removal rates.
  • update means 30 is configured to trigger the operation of the learning means 31 to recompute the operating characteristics of the well at predetermined intervals of time. For each interval, the learning means obtains new downhole measurements to compute an updated mathematical model of the operating characteristics of the well.
  • the present invention is believed to provide several advantages.
  • the invention permits the maximum fluid to be removed from the well, without damaging the equipment. This results not only in greater fluid removal rates, but also in reduced down-time and lower maintenance costs. Further, inasmuch as downhole measurements may be gathered on a real-time basis, potentially dangerous well conditions may be uncovered and responded to quickly. Moreover, no moving parts or downline wires are required, reducing outside interference with the well during operation.

Abstract

La présente invention concerne un système de régulation de pompe de tête de puits (20) destiné à des systèmes d'ascension artificielles, ce système commandant une pompe de tête de puits soutirant du fluide dans un puits. Le système comporte un outil de fond de puits (22) pourvu de capteurs (32) permettant de mesurer des états particuliers du puits et du fluide à soutirer. Un émetteur (60) émet, vers un analyseur de données (26) situé en surface, les conditions captées. Cet analyseur de données (26) situé en surface compare ensuite les mesures de fond de puits à des valeurs de consigne spécifiques de certains paramètres, puis il calcule le régime moteur optimal de la pompe de tête de puits à partir des comparaisons de mesures pour déterminer si le régime de la pompe est réglé au plus juste pour un rendement optimal concernant le soutirage du fluide. Si ce n'est pas le cas, l'information calculée permet de régler manuellement ou automatiquement le moteur de pompe (les paramètres vitesse et couple notamment) pour obtenir un rendement optimal.
PCT/US1997/009632 1996-06-03 1997-06-02 Systeme de regulation de pompe de tete de puits WO1997046793A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU32295/97A AU3229597A (en) 1996-06-03 1997-06-02 Wellhead pump control system

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US1908896P 1996-06-03 1996-06-03
US60/019,088 1996-06-03

Publications (1)

Publication Number Publication Date
WO1997046793A1 true WO1997046793A1 (fr) 1997-12-11

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Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1999060247A1 (fr) * 1998-05-15 1999-11-25 Baker Hughes Incorporated Systeme de gestion de production automatique d'hydrocarbures
WO2000029707A2 (fr) * 1998-11-18 2000-05-25 Schlumberger Technology Corporation Controle des performances d'un equipement de fond de trou
WO2001063091A1 (fr) * 2000-02-22 2001-08-30 Weatherford/Lamb, Inc. Appareil d'ascension artificielle permettant de surveiller automatiquement des caracteristiques
US6595287B2 (en) 2000-10-06 2003-07-22 Weatherford/Lamb, Inc. Auto adjusting well control system and method
US7490675B2 (en) 2005-07-13 2009-02-17 Weatherford/Lamb, Inc. Methods and apparatus for optimizing well production
US8453764B2 (en) 2010-02-01 2013-06-04 Aps Technology, Inc. System and method for monitoring and controlling underground drilling
USD843381S1 (en) 2013-07-15 2019-03-19 Aps Technology, Inc. Display screen or portion thereof with a graphical user interface for analyzing and presenting drilling data
US10472944B2 (en) 2013-09-25 2019-11-12 Aps Technology, Inc. Drilling system and associated system and method for monitoring, controlling, and predicting vibration in an underground drilling operation
WO2023164526A1 (fr) * 2022-02-25 2023-08-31 Schlumberger Technology Corporation Structure de commande de pompe

Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4461172A (en) * 1982-05-24 1984-07-24 Inc. In-Situ Well monitoring, controlling and data reducing system
US5314016A (en) * 1993-05-19 1994-05-24 Shell Oil Company Method for controlling rod-pumped wells

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4461172A (en) * 1982-05-24 1984-07-24 Inc. In-Situ Well monitoring, controlling and data reducing system
US5314016A (en) * 1993-05-19 1994-05-24 Shell Oil Company Method for controlling rod-pumped wells

Cited By (23)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1999060247A1 (fr) * 1998-05-15 1999-11-25 Baker Hughes Incorporated Systeme de gestion de production automatique d'hydrocarbures
GB2354785A (en) * 1998-05-15 2001-04-04 Baker Hughes Inc Automatic hydrocarbon production management system
GB2354785B (en) * 1998-05-15 2003-01-22 Baker Hughes Inc Automatic hydrocarbon production management system
WO2000029707A2 (fr) * 1998-11-18 2000-05-25 Schlumberger Technology Corporation Controle des performances d'un equipement de fond de trou
WO2000029707A3 (fr) * 1998-11-18 2000-07-20 Schlumberger Technology Corp Controle des performances d'un equipement de fond de trou
GB2360594A (en) * 1998-11-18 2001-09-26 Schlumberger Technology Corp Monitoring performance of downhole equipment
US6310559B1 (en) 1998-11-18 2001-10-30 Schlumberger Technology Corp. Monitoring performance of downhole equipment
GB2360594B (en) * 1998-11-18 2003-03-05 Schlumberger Technology Corp Monitoring performance of downhole equipment
WO2001063091A1 (fr) * 2000-02-22 2001-08-30 Weatherford/Lamb, Inc. Appareil d'ascension artificielle permettant de surveiller automatiquement des caracteristiques
US6536522B2 (en) 2000-02-22 2003-03-25 Weatherford/Lamb, Inc. Artificial lift apparatus with automated monitoring characteristics
US6595287B2 (en) 2000-10-06 2003-07-22 Weatherford/Lamb, Inc. Auto adjusting well control system and method
US7490675B2 (en) 2005-07-13 2009-02-17 Weatherford/Lamb, Inc. Methods and apparatus for optimizing well production
US7806188B2 (en) 2005-07-13 2010-10-05 Weatherford/Lamb, Inc. Methods and apparatus for optimizing well production
US8453764B2 (en) 2010-02-01 2013-06-04 Aps Technology, Inc. System and method for monitoring and controlling underground drilling
US8640791B2 (en) 2010-02-01 2014-02-04 Aps Technology, Inc. System and method for monitoring and controlling underground drilling
US8684108B2 (en) 2010-02-01 2014-04-01 Aps Technology, Inc. System and method for monitoring and controlling underground drilling
US9696198B2 (en) 2010-02-01 2017-07-04 Aps Technology, Inc. System and method for monitoring and controlling underground drilling
US10416024B2 (en) 2010-02-01 2019-09-17 Aps Technology, Inc. System and method for monitoring and controlling underground drilling
USD843381S1 (en) 2013-07-15 2019-03-19 Aps Technology, Inc. Display screen or portion thereof with a graphical user interface for analyzing and presenting drilling data
US11078772B2 (en) 2013-07-15 2021-08-03 Aps Technology, Inc. Drilling system for monitoring and displaying drilling parameters for a drilling operation of a drilling system
USD928195S1 (en) 2013-07-15 2021-08-17 Aps Technology, Inc. Display screen or portion thereof with a graphical user interface for analyzing and presenting drilling data
US10472944B2 (en) 2013-09-25 2019-11-12 Aps Technology, Inc. Drilling system and associated system and method for monitoring, controlling, and predicting vibration in an underground drilling operation
WO2023164526A1 (fr) * 2022-02-25 2023-08-31 Schlumberger Technology Corporation Structure de commande de pompe

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