EP2469015B2 - Pronostics de données de puits - Google Patents

Pronostics de données de puits Download PDF

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Publication number
EP2469015B2
EP2469015B2 EP10196624.0A EP10196624A EP2469015B2 EP 2469015 B2 EP2469015 B2 EP 2469015B2 EP 10196624 A EP10196624 A EP 10196624A EP 2469015 B2 EP2469015 B2 EP 2469015B2
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EP
European Patent Office
Prior art keywords
data
parameter
profile
generating
underwater well
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Application number
EP10196624.0A
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German (de)
English (en)
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EP2469015B1 (fr
EP2469015A1 (fr
Inventor
Ravi Shankar Varma Addala
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Baker Hughes Energy Technology UK Ltd
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GE Oil and Gas UK Ltd
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/001—Survey of boreholes or wells for underwater installation

Definitions

  • This invention relates to a method for generating a time-dependent profile of a parameter, the parameter being associated with the operation of a device at an underwater well facility, a method of determining the health of a device at an underwater well facility and an underwater well facility comprising means for generating a time-dependent profile of a parameter.
  • Underwater hydrocarbon extraction facilities for example subsea well facilities, make use of subsea well “trees” (also known as “Xmas trees”) located on the seabed.
  • Such trees are highly complex constructions, which incorporate many different components and systems. Typically, different components and systems will deteriorate or fail at different rates, i.e. they have differing operational lifespans.
  • SCM subsea control module
  • FIG. 1 An example of a conventional subsea well system is shown in Fig. 1 .
  • the well is controlled from a surface mounted master control station (MCS) 1, which may be located on a vessel, platform or at the surface.
  • MCS surface mounted master control station
  • This feeds, via an umbilical cable 2, hydraulic power (i.e. hydraulic fluid) via a hydraulic line 3, electric power via current carrying line 4, and communications via a data carrying line 5, such as an optical fibre for example, to a subsea control module 6 which is mounted on a Xmas tree 7 located above a well head.
  • the hydraulic line 3 feeds a manifold 9 at the SCM 6.
  • a hydraulic accumulator 8 is also provided at the SCM 6, proximate the termination of hydraulic line 3, to enable supply of hydraulic fluid at peak demands to the manifold 9.
  • the manifold 9 provides a mechanical mounting for, and feeds hydraulic fluid to, the many DCVs required for operation of the well control system.
  • DCV 10 when electrically energised, operates a subsea hydraulic device, here a hydraulic valve 11 for shutting off the production fluid flow through a production pipeline 12.
  • Electric power via line 4 is fed to a subsea electronics module (SEM) 13, housed in the SCM 6.
  • SEM 13 performs electronic control functions for the tree within its internal electronic processing 14, and bi-directionally communicates with the MCS 1, via a communications system 15 linked to line 5. In this way, operating commands from a well operator at the MCS 1 may be actioned by the SEM processing 14.
  • the processing 14 is operable to output electric power via line 16, to the DCV 10, and thus to operate the valve 11.
  • Typical functions monitored may include: input hydraulic pressure via sensor 17, DCV input hydraulic pressure via sensor 18, DCV solenoid current via sensor 19 and DCV solenoid voltage via sensor 20. Other or additional sensors may also be employed. All of these sensors 17-20 are within the SCM 6, and each of the sensor outputs is connected to the SEM processing 14. Further sensors for measuring well operation parameters are also installed outside of the SCM 6, such as sensor 21 for monitoring the production fluid pressure and sensor 22 for monitoring the production fluid flow rate. The outputs from such sensors are also connected to the SEM processing 14. Note that for clarity none of the connections from the various sensors to the SEM processing 14 are shown on Fig. 1 , but simply indicated by the input arrow 23.
  • operating parameters are typically monitored with appropriate sensors or circuitry within a subsea well system mainly within the SCM, since this is the hub that houses most of the well operating devices such as directional control valves (DCVs), which control the majority of the well production flow control valves and chokes used by the facility.
  • the operating parameters that are monitored in existing well systems typically include voltages, currents and hydraulic pressures.
  • the method of monitoring employed normally provides for monitoring of the profile, with time, of these parameters.
  • the current and voltage profiles of the electrical supply applied to the coil of a DCV can often be monitored simultaneously.
  • Such data are typically transmitted to the well surface platform via a well communication system, and there selected and viewed by a well operator. The operator can therefore observe "live" parameters. In addition, the operator could try to establish trends by looking back through previously observed or recorded parameters. In practice this is difficult and is not implemented.
  • a condition monitoring system has been proposed in GB 0916421.1 which assesses the data received from the wellhead and their variation over time, by comparison with a model of their expected behaviour.
  • a weakness of this system is that it is only as good as the model used. If the models are based on laboratory measurements of operational parameters for a device, there is scope for errors to emerge when used in respect of the device when deployed. Furthermore, an initial model used is static, and may not adequately model operation of the device over time.
  • This aim is achieved by directly acquiring diagnostic information of a selected set of parameters that can be used to capture how the characteristics / parameters of devices change with respect to time. This data is then used to identify patterns and failure models thus permitting prediction of failures and calculation of the useful life of devices. More particularly, the profiles generated in accordance with the present invention may be used to dynamically update the models used in a condition monitoring system.
  • a method of determining the health of a device at an underwater well facility comprising the steps of:
  • an underwater well facility comprising means for generating a time-dependent profile of a parameter, the parameter being associated with the operation of a device at the facility, the generating means comprising:
  • data may be stored over time so as to build up a library of operating parameters, thus permitting any change over time to be observed.
  • parameters are related to the eventual failure of a device it is possible to model the failure mode such that the potential for failure can be forecast, thus enabling preventive maintenance to be implemented.
  • parameters monitored may include the power factor and load voltages and currents in conjunction with the operation of DCVs over time, to identify potential power supply failure.
  • Monitoring of hydraulic pressure profiles around DCVs in conjunction with the electrical voltage and current profiles of DCV coil supplies can also reveal, from previously recorded data of a failure mode, the likelihood of a DCV failure.
  • the data recorded over time may also provide valuable information to designers to optimise designs for longer equipment life.
  • the present invention provides various advantages over existing systems, including primarily that the well operator may be provided with information regarding the life of the well operating devices and the potential to predict failure.
  • Fig. 2 shows a similar well system to Fig. 1 , and wherever possible like reference numerals have been retained.
  • the data output by the sensors received by the SEM processing 14, are also passed on to a storage / processing module 24, a new module not present in conventional systems such as that shown in Fig. 1 .
  • High speed sampling of the data is used, such the data is passed to module 24 virtually continuously and there associated with a time component.
  • the required sampling rate must be fast enough to detect a trend so that possible failure might be detected to give useful warning of a problem.
  • the module 24 produces time-dependent parameter data, i.e. a profile of the parameter data.
  • Processing module 24 stores these data profiles and compares them with previously-recorded, i.e. already stored, data to reveal operating changes and trends. If a previously recorded data profile is indicative of a correctly operating device, then a trend away from that profile may indicate faults or failures of the device. In this way, the module 24 is able to provide "failure forecasting" for devices.
  • the storage / processing module 24 communicates with the MCS 1, and thus the well operator, via communication system 15 and line 5 of umbilical cable 2.
  • the time dependent data output by module 24 can then be used to construct reference parameters or models for use in a condition monitoring system such as described in GB0916421.1 .
  • Initial operating parameters for devices for example a DCV
  • a DCV can be obtained from initial measurements made in manufacture at production testing, with failure parameters obtained from original measurements made in the laboratory at the design stage. This initial information may be used to initialise the models used in a condition monitoring system, and which would then be updated or replaced by the profiles generated in accordance with the present invention.
  • failure forecasting is programmed into the storage / processing module 24, operable to output an alarm to the operator if required, i.e. if a failure or imminent failure is detected.
  • the module 24 is operable to compare a recently generated profile against a historically obtained profile stored within module 24.
  • the data received by module 24 is measured against the temperature at the device location, i.e. it is time-correlated with the output from a temperature sensor (not shown) proximate the device.
  • the operational parameters sent to MCS 1 can be adjusted to allow for the different operating conditions subsea to that of the laboratory, e.g. a low operating environmental temperature, or obtained in the laboratory in an environmental chamber set to the subsea conditions.
  • a modification of the above-described methodology would combine a plurality of parameters associated with a particular device, such that a composite profile may be produced.
  • the output from sensors 21 and 22, i.e. which measure the pressure and flow of production fluid may be combined, with time information, to produce a composite profile of these production fluid parameters.

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  • Physics & Mathematics (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Geophysics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Testing Or Calibration Of Command Recording Devices (AREA)
  • Testing And Monitoring For Control Systems (AREA)

Claims (9)

  1. Procédé de détermination du bon état de fonctionnement d'un dispositif au niveau d'une installation de forage sous-marine, comprenant les étapes de :
    a) génération d'un profil dépendant du temps d'un paramètre, le paramètre étant associé au fonctionnement d'un dispositif au niveau d'une installation de forage sous-marine, en
    i) obtenant des données relatives aux valeurs mesurées dudit paramètre,
    ii) en passant lesdites données à un moyen de mémorisation,
    iii) en mémorisant lesdites données pour produire un ensemble de données liés au paramètre à une pluralité de temps, et
    iv) en générant un profil du paramètre à partir de l'ensemble de données, caractérisé en ce que ledit procédé comprend en outre l'étape de
    b) comparaison du profile avec des données de paramètre obtenues à une période de temps différente durant le fonctionnement du dispositif au niveau de l'installation de forage sous-marine,
    lesdites étapes a) et b) étant effectuées dans un module électronique sous-marin (13).
  2. Procédé selon la revendication 1, ladite étape ii) comprenant l'échantillonnage desdites données à une cadence requise.
  3. Procédé selon l'une quelconque des revendications 1 et 2, comprenant l'étape de corrélation dans le temps des données obtenues avec des mesures de températures prises par rapport au dispositif.
  4. Procédé selon l'une quelconque des revendications précédentes, comprenant l'étape initiale de mesure des valeurs de paramètre.
  5. Procédé selon l'une quelconque des revendications précédentes, ledit profil étant utilisé pour construire un modèle de comportement de paramètre, et ledit modèle étant comparé aux données de paramètre présentement générées.
  6. Procédé selon la revendication 5, ledit profil étant utilisé pour mettre à jour dynamiquement le modèle.
  7. Procédé selon l'une quelconque des revendications 1 à 4, ledit profil étant comparé à un profil de paramètre obtenu précédemment.
  8. Procédé selon l'une quelconque des revendications précédentes, comprenant les étapes de : obtention de secondes données relatives aux valeurs mesurées d'un second paramètre associé au fonctionnement du dispositif,
    passage desdites secondes données au moyen de mémorisation, mémorisation desdites secondes données afin de produire un second ensemble de données et génération d'un profil composite dépendant du temps des premier et second paramètres à partir des premier et second ensembles de données.
  9. Installation de forage sous-marine comprenant un moyen de génération d'un profil dépendant du temps d'un paramètre, le paramètre étant associé au fonctionnement d'un dispositif au niveau de l'installation, ledit moyen de génération comprenant :
    un moyen d'obtention des données relatives aux valeurs mesurées dudit paramètre ; un moyen de mémorisation de données (24) ;
    un moyen (24) de production d'un ensemble de données lié au paramètre à une pluralité de temps ; et
    un moyen (24) de génération d'un profil du paramètre à partir de l'ensemble de données ;
    caractérisé en ce que le moyen de génération comprend en outre un moyen de comparaison du profil avec des données de paramètre obtenues à une période de temps différente durant le fonctionnement du dispositif au niveau de l'installation de forage sous-marine, ledit moyen (24) de mémorisation de données et ledit moyen (24) de production de données étant situés dans un module électronique sous-marin (13), et ledit moyen (24) de génération de profil et ledit moyen de comparaison de profil avec des données de paramètre obtenues à une période de temps différente durant le fonctionnement du dispositif au niveau de l'installation de forage sous-marine étant situés dans un module électronique sous-marin (13).
EP10196624.0A 2010-12-22 2010-12-22 Pronostics de données de puits Active EP2469015B2 (fr)

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EP10196624.0A EP2469015B2 (fr) 2010-12-22 2010-12-22 Pronostics de données de puits

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Application Number Priority Date Filing Date Title
EP10196624.0A EP2469015B2 (fr) 2010-12-22 2010-12-22 Pronostics de données de puits

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EP2469015A1 EP2469015A1 (fr) 2012-06-27
EP2469015B1 EP2469015B1 (fr) 2014-04-02
EP2469015B2 true EP2469015B2 (fr) 2018-11-21

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Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20030103551A1 (en) † 2001-11-30 2003-06-05 Sammy Haddad Method of predicting formation temperature
US20040262008A1 (en) † 2003-06-25 2004-12-30 Deans Gregor E. Subsea communications system
US20050194184A1 (en) † 2004-03-04 2005-09-08 Gleitman Daniel D. Multiple distributed pressure measurements
US20050200498A1 (en) † 2004-03-04 2005-09-15 Gleitman Daniel D. Multiple distributed sensors along a drillstring
US20050210961A1 (en) † 2002-09-18 2005-09-29 Technip France Method and device for monitoring a flexible pipe
US20090044938A1 (en) † 2007-08-16 2009-02-19 Baker Hughes Incorporated Smart motor controller for an electrical submersible pump
GB2453947A (en) † 2007-10-23 2009-04-29 Vetco Gray Controls Ltd Solenoid coil current used in armature movement monitoring
US20090277644A1 (en) † 2008-05-09 2009-11-12 Mcstay Daniel Method and apparatus for christmas tree condition monitoring
WO2010034986A1 (fr) † 2008-09-24 2010-04-01 Schlumberger Holdings Limited Diagnostic d'intégrité de colonne montante à l’aide de fibre optique distribuée

Family Cites Families (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6985831B2 (en) * 2000-01-13 2006-01-10 Zed.I Solutions (Canada), Inc. System for acquiring data from facilities and method CIP
US20080270328A1 (en) * 2006-10-18 2008-10-30 Chad Lafferty Building and Using Intelligent Software Agents For Optimizing Oil And Gas Wells
GB2473640A (en) * 2009-09-21 2011-03-23 Vetco Gray Controls Ltd Condition monitoring of an underwater facility

Patent Citations (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20030103551A1 (en) † 2001-11-30 2003-06-05 Sammy Haddad Method of predicting formation temperature
US20050210961A1 (en) † 2002-09-18 2005-09-29 Technip France Method and device for monitoring a flexible pipe
US20040262008A1 (en) † 2003-06-25 2004-12-30 Deans Gregor E. Subsea communications system
US20050194184A1 (en) † 2004-03-04 2005-09-08 Gleitman Daniel D. Multiple distributed pressure measurements
US20050200498A1 (en) † 2004-03-04 2005-09-15 Gleitman Daniel D. Multiple distributed sensors along a drillstring
US20090044938A1 (en) † 2007-08-16 2009-02-19 Baker Hughes Incorporated Smart motor controller for an electrical submersible pump
GB2453947A (en) † 2007-10-23 2009-04-29 Vetco Gray Controls Ltd Solenoid coil current used in armature movement monitoring
US20090107682A1 (en) † 2007-10-23 2009-04-30 Vetco Gray Controls Limited Monitoring A Solenoid of A Directional Control Valve
US20090277644A1 (en) † 2008-05-09 2009-11-12 Mcstay Daniel Method and apparatus for christmas tree condition monitoring
WO2010034986A1 (fr) † 2008-09-24 2010-04-01 Schlumberger Holdings Limited Diagnostic d'intégrité de colonne montante à l’aide de fibre optique distribuée

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
ERIKSSON K.G. ET AL: "Predictive Condition Monitoring for Subsea Pumping Systems", vol. 19872, May 2009, OFFSHORE TECHNOLOGY CONFERENCE, HOUSTON, pages: 1 - 23 †

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Publication number Publication date
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