WO2014164944A1 - Système et procédé pour détecter l'intégrité structurelle d'un tubage de puits - Google Patents

Système et procédé pour détecter l'intégrité structurelle d'un tubage de puits Download PDF

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Publication number
WO2014164944A1
WO2014164944A1 PCT/US2014/023863 US2014023863W WO2014164944A1 WO 2014164944 A1 WO2014164944 A1 WO 2014164944A1 US 2014023863 W US2014023863 W US 2014023863W WO 2014164944 A1 WO2014164944 A1 WO 2014164944A1
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WO
WIPO (PCT)
Prior art keywords
casing
sensors
structural integrity
well
output signals
Prior art date
Application number
PCT/US2014/023863
Other languages
English (en)
Inventor
Melvin Clark THOMPSON
David William Beck
Original Assignee
Chevron U.S.A. 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 Chevron U.S.A. Inc. filed Critical Chevron U.S.A. Inc.
Priority to US14/356,991 priority Critical patent/US20160003027A1/en
Publication of WO2014164944A1 publication Critical patent/WO2014164944A1/fr
Priority to US15/901,217 priority patent/US20180179881A1/en
Priority to US16/229,136 priority patent/US20190112912A1/en

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Classifications

    • 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
    • E21B47/007—Measuring stresses in a pipe string or casing
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/04—Casing heads; Suspending casings or tubings in well heads
    • 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
    • E21B47/04—Measuring depth or liquid level
    • 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
    • E21B47/06—Measuring temperature or pressure

Definitions

  • This disclosure relates to a system and method for detecting structural integrity of a well casing.
  • the system may detect casing structural integrity events.
  • the casing structural integrity events may include structural failures of the casing and/or potential structural failures of the casing related to the well tubing and/or other attached parts of the well structure.
  • One aspect of the disclosure relates to a system configured to detect structural integrity of a well casing in a well.
  • the system may comprise a conductive well casing, conductive tubing, one or more sensors, one or more processors, and/or other components.
  • the casing may be configured to surround the tubing.
  • the tubing may be configured to communicate liquid and/or gas from an underground reservoir to above ground extraction equipment at or near a wellhead.
  • the casing may be embedded in a geologic structure.
  • the one or more sensors may be configured to generate output signals conveying information related to a structural integrity of the casing.
  • the one or more sensors may include fluid level sensors, voltage sensors, acoustic sensors, pressure sensors, motion sensors, strain sensors, and/or other sensors.
  • the one or more sensors may include one or more sensor types.
  • the one or more sensors may include two or more sensor types.
  • At least one of the one or more sensors may be electrically coupled with the tubing and the casing separately. At least one of the one or more sensors may be located in the wellhead. The one or more sensors may be located at one or more locations along the tubing within the casing. The one or more sensors may be located within the casing at or near a tubing hanger between the wellhead and the tubing. The tubing hanger may be configured to suspend the tubing in the casing.
  • the one or more processors may be configured to detect casing structural integrity events based on the output signals.
  • the one or more processors may be configured to generate casing structural integrity event notifications.
  • the casing structural event notifications may correspond to the detected casing structural integrity events.
  • the notifications may be generated for delivery to a user responsive to the detections.
  • the casing structural integrity events may include structural failures of the casing, potential structural failures of the casing, and/or other events.
  • the one or more processors may be configured such that the casing structural integrity events are detected responsive to one or more forces acting on the casing.
  • the one or more forces may include a shear force, a tensile force, a compressive force, a torsional force, and/or other forces.
  • the one or more forces may be generated by the geologic structure surrounding the casing.
  • the one or more processors may be configured to determine extraction parameters and to detect the casing structural integrity events based on the extraction parameters.
  • the extraction parameters may include information indicating whether the well is operating in a production phase or a pre-production phase, and/or other information.
  • the one or more processors may be configured to detect the casing structural integrity events based on an algorithm.
  • the one or more processors may determine algorithm inputs based on the output signals.
  • the one or more processors may be configured to cluster the information conveyed by the output signals and detect the casing structural integrity events based on the clustering. Clustering may comprise arranging the information conveyed by the output signals in a multidimensional space.
  • the one or more processors may be configured to generate casing structural integrity scores based on the output signals.
  • the one or more processors may be configured to detect the casing structural integrity events based on the casing structural integrity scores.
  • the one or more processors may be configured to determine one or more well parameters based on the output signals.
  • the one or more well parameters may include one or more of a fluid level, a voltage, an acoustic parameter, a pressure, a motion parameter, a strain level, and/or other parameters.
  • the one or more processors may be configured to determine well parameter threshold levels.
  • the one or more processors may be configured to detect the casing structural integrity events responsive to the well parameters breaching the well parameter threshold levels.
  • the method may comprise surrounding conductive well tubing with a conductive well casing.
  • the tubing may be configured to communicate liquid and/or gas from an underground reservoir to above ground extraction equipment at a wellhead.
  • the casing may be embedded in a geologic structure.
  • the method may comprise generating output signals conveying information related to a structural integrity of the casing.
  • the method may include generating the output signals with one or more sensors.
  • the one or more sensors may include fluid level sensors, voltage sensors, acoustic sensors, pressure sensors, motion sensors, strain sensors, and/or other sensors.
  • the one or more sensors may include one or more sensor types.
  • the one or more sensors may include two or more sensor types.
  • the method may include electrically coupling at least one of the one or more sensors with the tubing and the casing separately. At least one of the one or more sensors may be located in the wellhead. The one or more sensors may be located at one or more locations along the tubing within the casing. The one or more sensors may be located within the casing at or near a tubing hanger between the wellhead and the tubing. The tubing hanger may be configured to suspend the tubing in the casing. [0016] The method may comprise detecting casing structural integrity events based on the output signals. The casing structural integrity events may be detected responsive to one or more forces acting on the casing. The one or more forces may include a shear force, a tensile force, a compressive force, a torsional force, and/or other forces. The one or more forces may be generated by the geologic structure surrounding the casing.
  • the method may comprise generating casing structural integrity event notifications that correspond to the detected casing structural integrity events for delivery to a user responsive to the detections.
  • the casing structural integrity events may include structural failures of the casing, potential structural failures of the casing, and/or other events.
  • the method may include determining extraction parameters and detecting the casing structural integrity events based on the extraction parameters.
  • the extraction parameters may include information indicating whether the well is operating in a production phase or a pre-production phase.
  • the method may include detecting casing structural integrity events based on an algorithm.
  • the algorithm inputs may be determined based on the output signals.
  • the method may include clustering the information conveyed by the output signals and detecting the casing structural integrity events based on the clustering.
  • Clustering may comprise arranging the information conveyed by the output signals in a multidimensional space.
  • the method may include generating casing structural integrity scores based on the output signals, and detecting casing structural integrity events based on the casing structural integrity scores.
  • the method may include determining one or more well parameters based on the output signals.
  • the one or more well parameters may include a fluid level, a voltage, an acoustic parameter, a pressure, a motion parameter, a strain level, and/or other parameters.
  • the method may include determining well parameter threshold levels, and detecting the casing structural integrity events responsive to the well parameters breaching the well parameter threshold levels.
  • FIG. 1 illustrates a system configured to detect structural integrity of a well casing.
  • FIG. 2 illustrates an example configuration of multiple sensors.
  • FIG. 3 illustrates a natural resource field that includes multiple wells.
  • FIG. 4 illustrates a method for detecting structural integrity of a well casing.
  • FIG. 1 illustrates a system 10 configured to detect structural integrity of a well casing 12 in a well 8.
  • Well 8 may be configured to extract minerals from an underground mineral reservoir. During mineral extraction, well 8 may be configured to communicate liquid and/or gas from the underground reservoir to above ground extraction equipment 16 at or near a wellhead 28.
  • Well 8 may be drilled and/or otherwise embedded into a geologic structure.
  • Well 8 may be subject to geologic forces generated by the geologic structure. Unplanned and/or unexpected forces and/or movement may pose a risk to the structural integrity of casing 12. Forces and/or movement of sufficient magnitude may result in damage to and/or destruction of casing 12. Damage to and/or destruction of casing 12 may cause a loss of the natural resources being extracted via well 8, contamination of areas surrounding well 8, undesirable surface expression, and/or other negative effects.
  • System 10 may be configured to detect casing structural integrity events and generate casing structural integrity event notifications that correspond to the detected casing structural integrity events.
  • the casing structural integrity events may include structural failures of casing 12, potential structural failures of casing 12, and/or other events.
  • system 10 may comprise casing 12, tube 14, one or more sensors 18, one or more processors 20, user interface 22, and/or other components.
  • Casing 12 may surround tube 14, sensors 18, and/or other components of system 10. Casing 12 may line a borehole and provide structural support for well 8. Casing 12 may separate well 8 from the geologic structure.
  • the geologic structure may include subsurface materials (e.g., rocks, dirt, etc.), water (e.g., in the case of a well in the ocean floor), and/or other environmental materials.
  • Casing 12 may be made from a conductive material such as steel and/or other materials.
  • Tube 14 may be configured to communicate liquid and/or gas during mineral extraction.
  • Tube 14 may be configured to communicate liquid and/or gas from the underground reservoir to above ground extraction equipment 16 at or near wellhead 28.
  • Tube 14 may be a tubing string.
  • the tubing string may include a series of coupled tubes.
  • the series of tubes may be coupled via threaded ends of each tube and/or other coupling mechanisms.
  • the series of coupled tubes may be a series of coupled tubing joints.
  • the joints may include, for example, a pup joint.
  • Tube 14 may be made from electrically conductive materials such as steel and/or other electrically conductive materials.
  • tube 14 may be provided within casing 12. Providing tube 14 within casing 12 may create an inner annular space between the outer surface of tube 14 and casing 12.
  • One or more centralizers may be configured to maintain tube 14 in the annular space to maintain a physical separation between tube 14 and casing 12.
  • the centralizers may couple with the outside diameter of tube 14 via one or more coupling devices.
  • the coupling devices may include, for example, a clamp, a collar, a latch, a hook, adhesive, and/or other coupling devices.
  • the centralizers may be configured to engage casing 12 at various locations in well 8 to maintain a physical separation between tube 14 and casing 12.
  • the centralizers may include, for example, bow spring centralizers, floating collars, fixed position devices, mixed dielectric centralizers, and/or other centralizers.
  • the centralizers may be made from one or more conductive materials such as steel and/or other materials.
  • the centralizers may be made from non-conductive materials.
  • Tube 14 may cooperate with casing 12 to form a coaxial transmission line.
  • One or more electrical loads e.g., sensors 18 disposed within well 8 may be powered via the coaxial transmission line formed by casing 12 and tube 14 without the need for electrical wiring.
  • Casing 12 and tube 14 may be configured such that voltage and/or current across casing 12 and tube 14 are sufficient to power the electrical load(s).
  • tube 14 may have a positive polarity and casing 12 may have a negative polarity.
  • an electrical load may be electrically coupled with the electrically positive tube 14 and separately with the electrically negative casing 12 such that the load is powered via the connections.
  • Sensors 18 may be configured to generate output signals conveying information related to the structural integrity of casing 12.
  • the output signals may include output signals related to the casing-tubing pair.
  • the information related to the structural integrity of casing 12 may comprise information related to structural failures of casing 12, information related to potential structural failures of casing 12, and/or other information.
  • the information related to structural failures and/or the potential structural failures may include information related to movement of casing 12, tube 14, and/or other components of well 8.
  • the information related to structural failures and/or the potential structural failures may include information related to physical defects and/or a potential for physical defects in casing 12.
  • the physical defects may include, for example, breaks, cracks, holes, deformations, loss of centralization, and/or other defects.
  • Sensors 18 may comprise one or more sensors that measure such information directly (e.g., through direct contact with casing 12). Sensors 18 may comprise one or more sensors that generate output signals related to the structural integrity of casing 12 indirectly. For example, one or more of sensors 18 may generate an output based on a characteristic of tube 14 (e.g., an amount of electrical current running through tube 14) and/or based on a characteristic of the liquid and/or gas in tube 14 (e.g., a fluid level).
  • a characteristic of tube 14 e.g., an amount of electrical current running through tube 14
  • a characteristic of the liquid and/or gas in tube 14 e.g., a fluid level
  • sensors 18 may include a single sensor type. Sensors 18 may include, for example, fluid level sensors, voltage sensors, acoustic sensors, pressure sensors, motion sensors, strain sensors, force sensors, flow sensors, composition sensors, temperature sensors, strain gauges, accelerometers, and/or other sensors. For example, sensors 18 may include one or more strain gauges coupled with the tube 14 and/or casing 12.
  • sensors 18 may include two or more different sensor types.
  • fluid level sensors may generate output signals conveying information related to a fluid level in well 8.
  • the fluid level information may be indicative of casing 12 collapse, pressure in the casing, sheer forces acting on the casing, an electrical short between tubing 14 and casing 12, an open breach of the wall of casing 12, and/or other phenomena.
  • a current sensor e.g., a transformer
  • a current sensor on tube 14 may generate output signals conveying information related to voltage and/or current changes in an otherwise closed circuit (e.g., due to movement, damage, etc.). This could be multiplexed in more than one mode (sourced or passive). The passive mode may behave like a voltage and/or current receiver.
  • the voltage and/or current sensors may be located just below a tubing hanger 13.
  • Hanger 13 may be configured to suspend the tube 14 in casing 12.
  • An acoustic sensor e.g., an accelerometer and/or a microphone
  • the spectral character of the monitored sound may include mechanical motion and/or resonance information related to the structural integrity of casing 12.
  • One or more pressure sensors mounted in well 8 e.g., in the annular space between tube 14 and casing 12, within tube 14, etc.
  • a motion sensor e.g., an accelerometer
  • Strain gages affixed to tube 14 may generate output signals conveying information related to internal stresses and/or strains.
  • Sensors 18 are illustrated in FIG. 1 and described above at various locations within system 10. In some implementations, at least one of sensors 18 may be electrically coupled with tube 14 and casing 12 separately. At least one of sensors 18 may be located in wellhead 28. Sensors 18 may be located at one or more locations along tube 14 within casing 12. In some implementations, one or more of the sensors may communicate via tube 14. Sensors 18 may be located within casing 12 at or near tubing hanger 13 between wellhead 28 and tube 14.
  • FIG. 2 illustrates a possible configuration of multiple sensors 18.
  • a sensor assembly 200 may be packaged as a small "launcher" on a four foot sub 204.
  • the sensors shown in FIG. 2 are examples of the sensors that may be included in such an assembly and are not intended to be limiting.
  • Assembly 200 may include other sensors not shown in FIG. 2.
  • the sensors shown in FIG. 2 include a strain sensor 210 (e.g., a strain gauge) and a current sensor 212.
  • the current sensor may include, for example, an RF/AC transformer coupled current monitor including a magnetic core on tube 14.
  • Assembly 200 may be compactly located at or near an underside 206 of tubing hanger 13. In some implementations, assembly 200 may include feed-thru capability in hanger 13 for wire leads 216.
  • an acoustic transducer (not shown in FIG. 2) may be mounted on the top of hanger 13. In some implementations, the transducer may be thermally isolated.
  • the collective electronics for assembly 200 may be packaged in a small enclosure.
  • sensor assembly 200 may be powered by a battery, solar power, and/or other power sources/supplies. In some implementations, sensor assembly 200 may require a relatively low amount of power. For example, sensor assembly 200 may require about 5 to 10 watts. In some implementations, sensor assembly 200 may include power management and RF source generation circuitry not shown in FIG. 2.
  • sensors 18 may include sensors disposed in a plurality of alternate locations in addition to and/or instead of those shown in FIG. 1.
  • sensors may be disposed within extraction equipment 16, and/or in other locations.
  • tube 14, casing 12, a conductive centralizer, and/or other components of well 8 may be configured to provide a signal path for the output signals.
  • Processor 20 may be configured to provide information processing capabilities in system 10.
  • processor 20 may include one or more of a digital processor, an analog processor, a digital circuit designed to process information, an analog circuit designed to process information, a state machine, and/or other mechanisms for electronically processing information.
  • processor 20 is shown in FIG. 1 as a single entity, this is for illustrative purposes only.
  • processor 20 may include a plurality of processing units. These processing units may be physically located within the same device, or processor 20 may represent processing functionality of a plurality of devices operating in coordination.
  • Processor 20 may be configured to execute one or more computer program modules. Individual ones the computer program modules may be configured to provide at least a portion of the functionality attributed herein to processor 20.
  • Processor 20 may be configured to execute the one or more computer program modules by software; hardware; firmware; some combination of software, hardware, and/or firmware; and/or other mechanisms for configuring processing capabilities on processor 20. It should be appreciated that the modules may be co-located within a single processing unit, and/or one or more of the modules may be located remotely from the other modules. In some implementations, processor 20 may be integrated with extraction equipment 16, user interface 22, and/or other components of system 10. [0041] Processor 20 may be configured to detect casing structural integrity events based on the output signals from sensors 18 and/or other information. In some implementations, the casing structural integrity events may include structural failures of the casing, potential structural failures of the casing, and/or other casing structure failure events.
  • the casing structural integrity events may be detected responsive to one or more forces acting on casing 12.
  • the one or more forces may include a shear force, a tensile force, a compressive force, a torsional force, and/or other forces.
  • the one or more forces may be generated by the geologic structure surrounding casing 12. For example, geologic layers and/or strata may shift on each other creating shear forces that act on casing 12.
  • Processor 20 may be configured to generate casing structural integrity event notifications that correspond to the detected casing structural integrity events.
  • the casing structural integrity event notifications may be generated for delivery to a user responsive to the detections.
  • Processor 20 may be configured to control user interface 22 to display the notifications generated by processor 20.
  • processor 20 may be configured to detect casing structural integrity events based on the output signals from a single type of sensors 18 (e.g., strain sensors). In some implementations, processor 20 may be configured to detect casing structural integrity events based on the output signals from at two or more different types of sensors 18. Processor 20 may be configured to process the information conveyed by the output signals of the two or more different types of sensors to detect casing structural integrity events.
  • a single type of sensors 18 e.g., strain sensors
  • processor 20 may be configured to detect casing structural integrity events based on the output signals from at two or more different types of sensors 18.
  • Processor 20 may be configured to process the information conveyed by the output signals of the two or more different types of sensors to detect casing structural integrity events.
  • processor 20 may be configured such that processing the information includes determining baseline well information, detecting casing structural integrity events based on an algorithm, detecting casing structural integrity events by clustering the information conveyed by the output signals in a multidimensional space, determining a casing structural integrity score and/or other metrics related to casing structural integrity, determining well parameters, monitoring change in the determined parameters (e.g., rate of change, standard deviation, and/or other measurements of change), determining well parameter thresholds, and/or other information processing.
  • processing the information may include determining other information based on an integration and/or conglomeration of the information conveyed by the output signals.
  • determining baseline well information may include determining information that indicates normal operation of well 8.
  • the information that indicates normal operation of well 8 may be determined by, for example, monitoring and evaluating multiple wells during various seasons of the year, at various production levels, and/or in various geographic locations.
  • processor 20 may be configured such that determining baseline well information may include determining extraction parameters.
  • the extraction parameters may include information indicating whether the well is operating in a production phase, a pre-production phase, and/or other phases.
  • the extraction parameters may include parameters related to whether or not liquid and/or gas is actively flowing through tube 14.
  • the baseline well information for normal operation of well 8 during the pre-production may be different than during the production phase.
  • Processor 20 may be configured to detect the casing structural integrity events based on the extraction parameters. For example, processor 20 may be configured to determine that well 8 is in a pre- production phase based on the extraction parameters. Processor 20 may detect a casing structural integrity event responsive to the information conveyed by the output signals of sensors 18 being outside the normal well information range for the pre-production phase.
  • processor 20 may be configured to detect the casing structural integrity events based on an algorithm. Processor 20 may determine algorithm inputs based on the output signals. In some implementations, processor 20 may be configured such that the algorithm may be configured to indicate whether a casing structural integrity event has occurred and/or will occur. The algorithm may be configured to indicate one or more structural integrity events occurring at one or more locations in casing 12. Algorithm inputs may include information conveyed by the output signals of sensors 18, baseline well information determined by processor 20, one or more extraction parameters determined by processor 20, one or more well parameters determined by processor 20, and/or other inputs.
  • the one or more well parameters may include, for example, a fluid level, a voltage, an acoustic parameter, a pressure, a motion parameter, a strain level, and/or other parameters.
  • Algorithm inputs may include currently determined information (e.g., the spectral character of current well noise) and/or previously determined information (e.g., the normal spectral character of well noise).
  • the algorithm may include and/or represent an electronic model of well 8.
  • the electronic model may be a mathematical model.
  • the mathematical model may include multi-dimensional model-based algorithms and/or other algorithms configured to interpret the output signals generated by sensors 18.
  • processor 20 may be configured to determine a fluid level in well 8, a strain level in tube 14, and the spectral character of current noise in well 8 based on the output signals generated by three different types of sensors 18.
  • the fluid level, the strain level, and the spectral character of the noise may be algorithm inputs.
  • Processor 20 may be configured such that the algorithm indicates that a structural integrity event is about to occur based on the fluid level, the strain level, and the spectral character inputs. In this example, processor 20 may not have detected the structural integrity event based on the fluid level, the strain level, and or the spectral character of the noise alone.
  • the fluid level, the strain level, and the spectral character of the noise together indicated the structural integrity event.
  • the three types of information used in this example are not intended to be limiting.
  • the algorithm may be configured to indicate structural integrity events based on any amount and/or type of input.
  • the algorithm may include one or more algorithms.
  • the one or more algorithms may be determined at manufacture, programmed, adjusted, uploaded, and/or updated by a user via user interface 22, and/or determined by other methods.
  • processor 20 may be configured to cluster the information conveyed by the output signals.
  • Processor 20 may be configured to detect the casing structural integrity events based on the clustering.
  • Clustering may comprise arranging the information conveyed by the output signals in a multidimensional space.
  • Arranging the information in the multidimensional space may comprise grouping the information conveyed by the output signals of sensors 18 into separate data clusters based on similarities in the information conveyed by the output signals. Similarities in the data may indicate, for example, that well 8 is operating normally.
  • processor 20 may be configured to cluster information conveyed by the output signals of sensors 18 that indicates well 8 is operating normally into a first data cluster and information that indicates a casing structural integrity event into one or more additional data clusters.
  • the information conveyed by the output signals of sensors 18 may be clustered by processor 20 based on statistical similarities in the information, magnitudes and/or directions of vectors that represent the information in the multidimensional space, and/or other information. Clustering may be known as networking in some implementations.
  • processor 20 may be configured to generate casing structural integrity scores based on the output signals. Processor 20 may be configured to detect the casing structural integrity events based on the casing structural integrity scores. In some implementations, the casing structural integrity scores may be individual values related to individual structural integrity events. In some implementations, the casing structural integrity scores may be individual values that indicate a likelihood that a structural integrity event has occurred and/or will occur. In some implementations, processor 20 may be configured such that the casing structural integrity scores comprise weighted structural integrity scores.
  • a weighted structural integrity score may comprise a collection of individually weighted scores based on information conveyed by the output signals from individual ones of the different types of sensors 18 (e.g., fluid level, strain, etc.)
  • the individually weighted scores may be weighted based on individual relationships between the information conveyed by the output signals from specific sensors 18 and whether that information has more or less importance relative to a specific casing structural integrity event.
  • Processor 20 may be configured to determine the importance of the information conveyed by the output signals from specific sensors 18 based on input from user interface 22, information determined at manufacture, and/or other information.
  • processor 20 may be configured to determine one or more well parameters based on the output signals.
  • the one or more well parameters may include a fluid level, a voltage, an acoustic parameter, a pressure, a motion parameter, a strain level, and/or other parameters.
  • processor 20 may be configured to monitor change in the determined parameters. Monitoring change may include, analyzing the determined parameters, comparing currently determined parameters to previously determined parameters, generating one or more graphics showing change in a given parameter over time, and/or other monitoring. For example, processor 20 may be configured to analyze the determined parameters by determining a rate of change, a standard deviation, a moving average, and/or other determinations representative of change for a given parameter. Processor 20 may be configured to generate a two dimensional graph showing a level of a given parameter over time. Change may be monitored based on various increments of time.
  • Change may be monitored on a yearly basis, a monthly basis, a weekly basis, a daily basis, an hourly basis, a minute by minute basis, a second by second basis, and/or based on other increments of time.
  • a current pressure may be compared to a previous pressure that was determined one second prior to the current pressure.
  • a current amount of strain may be represented on a two dimensional graph with prior strain levels determined one day, one week, one month, and one year prior to the current strain level.
  • processor 20 may be configured to determine well parameter threshold levels, and to detect the casing structural integrity events responsive to the well parameters breaching the well parameter threshold levels. For example, a first casing structural integrity event may be detected responsive to a first well parameter breaching a first well parameter threshold level. As a second example, a second casing structural integrity event may be detected responsive to the first well parameter breaching the first well parameter threshold level and a second well parameter breaching a second well parameter threshold level. Processor 20 may be configured to detect casing structural integrity events based on any number well parameters breaching any number of well parameter threshold levels. For example, processor 20 may detect a casing structural integrity event responsive to six different well parameters breaching six corresponding well parameter threshold levels. In some implementations, the well parameter threshold levels may be determined at manufacture, programmed, adjusted, uploaded, and/or updated by a user via user interface 22, and/or determined by other methods.
  • User interface 22 may be configured to facilitate delivery of casing structural integrity event notifications generated by processor 20 and/or other information to users.
  • User interface 22 may be configured to receive entry and/or selection of information from users.
  • User interface 22 may be configured to receive entry and/or selection of control inputs from users that facilitate operation of well 8 such that the users may adjust and/or cease the operation of well 8 if necessary, responsive to receiving casing structural integrity event notifications.
  • Users may include well site managers, remote operators, petroleum engineers, and/or other users. This enables data, cues, results, notifications, instructions, and/or any other communicable items, collectively referred to as "information,” to be communicated between users and processor 20, extraction equipment 16, and/or other components of system 10.
  • Examples of interface devices suitable for inclusion in user interface 22 comprise a keypad, buttons, switches, a keyboard, knobs, levers, a display screen, a touch screen, speakers, a microphone, an indicator light, an audible alarm, a printer, a tactile feedback device, and/or other interface devices.
  • user interface 22 comprises a plurality of separate interfaces.
  • user interface 22 comprises at least one interface that is provided integrally with processor 20 and/or extraction equipment 16.
  • user interface 22 may be integrated with a removable electronic storage interface disposed in extraction equipment 16.
  • information may be loaded into system 10 from removable storage (e.g., a smart card, a flash drive, a removable disk, etc.) that enables the user(s) to customize the implementation of system 10.
  • removable storage e.g., a smart card, a flash drive, a removable disk, etc.
  • Other exemplary input devices and techniques adapted for use with system 10 as user interface 22 comprise, but are not limited to, an RS-232 port, RF link, an IR link, modem (telephone, cable or other).
  • any technique for communicating information with system 10 is contemplated by the present disclosure as user interface 22.
  • extraction equipment 16 may include equipment configured to manage operation of well 8. Managing the operation of well 8 may include drawing liquid and/or gas through well 8, storing the liquid and/or gas, monitoring well 8, powering well 8, preparing well 8 for production, analyzing data related to the operation of well 8, and/or other activities.
  • Such equipment may include pumps, piping, wiring, liquid and/or gas storage devices, power supplies, data processing equipment (e.g., one or more computers and/or processors), communication equipment, cameras, safety systems, well control devices, and/or other extraction equipment.
  • a well power supply may be configured to supply a positive polarity to tube 14 and a negative polarity to casing 12.
  • user interface 22 may be provided by extraction equipment 16.
  • Wellhead 28 may be located at the surface of well 8.
  • Wellhead 28 may be configured to suspend tube 14 and/or casing 12 in well 8.
  • Wellhead 28 may be a structural interface between tube 14 and extraction equipment 16 configured to couple tube 14 with extraction equipment 16.
  • Wellhead 28 may be configured to contain pressure present in well 8.
  • Wellhead 28 may be configured to provide physical access to well 8 including access to annular space(s) between casing 12 and/or tube 14.
  • Wellhead 28 may be configured to provide electrical ports that are electrically coupled with tube 14, casing 12, sensors 18, and/or other components of system 10.
  • Extraction equipment 16, sensors 18, processor 20, user interface 22, and/or other components of system 10 may be operatively linked via one or more electronic communication links. Such electronic communication links may be wired and/or wireless.
  • such electronic communication links may be established, at least in part, via a network and/or other links.
  • extraction equipment 16, sensors 18, processor 20, and/or user interface 22 may be configured to communicate directly. It will be appreciated that this is not intended to be limiting, and that the scope of this disclosure includes implementations in which extraction equipment 16, sensors 18, processor 20, user interface 22, and/or other components of system 10 may be operatively linked via some other communication media, or with linkages not shown in FIG. 1.
  • FIG. 3 illustrates a natural resource field 300 that includes multiple wells 8.
  • Sensors 18 and/or the other components of system 10 may be located at the individual wells 8 and generate output signals conveying information related to the structural integrity of the casings of the individual wells 8 to processor 20.
  • Such an arrangement of sensors 18 and/or wells 8 in natural resource field 300 may facilitate mapping geologic behavior of field 300.
  • Geologic behavior may include, for example, geologic movement, temperature changes, pressure changes, satellite provided geologic data, GPS data, and/or other geologic behavior.
  • the information generated for each well 8 may be time synchronized by processor 20 such that geologic events may be detected and/or predicted in the areas of natural resource field 300 that are not directly instrumented. Notifications related to the geologic behavior of natural resource field 300 may be generated by processor 20 for delivery to a user via user interface 22, for example.
  • FIG. 4 illustrates a method 400 for detecting structural integrity of a well casing in a well.
  • the operations of method 400 presented below are intended to be illustrative. In some implementations, method 400 may be accomplished with one or more additional operations not described, and/or without one or more of the operations discussed. Additionally, the order in which the operations of method 400 are illustrated in FIG. 4 and described herein is not intended to be limiting.
  • method 400 may be implemented in one or more processing devices (e.g., a digital processor, an analog processor, a digital circuit designed to process information, an analog circuit designed to process information, a state machine, and/or other mechanisms for electronically processing information).
  • the one or more processing devices may include one or more devices executing some or all of the operations of method 400 in response to instructions stored electronically on one or more electronic storage mediums.
  • the one or more processing devices may include one or more devices configured through hardware, firmware, and/or software to be specifically designed for execution of one or more of the operations of method 400.
  • conductive well tubing may be surrounded with a conductive well casing.
  • the tubing may be configured to communicate liquid and/or gas from an underground reservoir to above ground extraction equipment at a wellhead.
  • the tubing may be a tubing string.
  • the casing may be embedded in a geologic structure.
  • operation 402 may be performed by a well casing the same as or similar to casing 12 (shown in FIG. 1 and described herein).
  • output signals conveying information related to a structural integrity of the casing may be generated.
  • the output signals may be generated with one or more sensors.
  • the one or more sensors may include one or more sensor types.
  • the one or more sensors may include two or more sensor types.
  • the sensor types may include fluid level sensors, voltage sensors, acoustic sensors, pressure sensors, motion sensors, strain sensors, and/or other sensors.
  • the sensors may be located at various locations in and/or near the well. At least one of the sensors may be electrically coupled with the well tubing and the well casing separately. At least one of the sensors may be located in the wellhead.
  • the one or more sensors may be located at one or more locations along the tubing within the casing.
  • the one or more sensors may be located within the well casing at or near a tubing hanger between the wellhead and the well tubing.
  • the tubing hanger may be configured to suspend the tubing in the casing.
  • operation 404 may be performed by sensors the same as or similar to sensors 18 (shown in FIG. 1 and described herein).
  • casing structural integrity events may be detected.
  • the casing structural integrity events may be detected based on the output signals.
  • the casing structural integrity events may be detected responsive to one or more forces acting on the well casing.
  • the one or more forces may include a shear force, a tensile force, and a compressive force, a torsional force, and/or other forces.
  • the one or more forces may be generated by the geologic structure surrounding the casing.
  • extraction parameters may be determined at operation 406.
  • the extraction parameters may include information indicating whether the well is operating in a production phase or a pre-production phase.
  • the casing structural integrity events may be detected based on an algorithm.
  • the algorithm inputs may be determined based on the output signals.
  • the information conveyed by the output signals may be clustered and/or networked. Detecting the casing structural integrity events may be based on the clustering. Clustering may comprise arranging the information conveyed by the output signals in a multidimensional space.
  • casing structural integrity scores may be generated based on the output signals. Detecting the casing structural integrity events may be based on the casing structural integrity scores.
  • one or more well parameters may be determined based on the output signals.
  • the one or more well parameters may include one or more of a fluid level, a voltage, an acoustic parameter, a pressure, a motion parameter, a strain level, and/or other parameters.
  • Well parameter threshold levels may be determined and the casing structural integrity events may be detected responsive to the well parameters breaching the well parameter threshold levels. For example, a first casing structural integrity event may be detected responsive to a first well parameter breaching a first well parameter threshold level.
  • operation 406 may be performed by a processor the same as or similar to processor 20 (shown in FIG. 1 and described herein).
  • casing structural integrity event notifications that correspond to the detected casing structural integrity events may be generated.
  • the notifications may be generated for delivery to a user responsive to the detections.
  • the well casing structural integrity events may include one or both of structural failures of the casing and/or potential structural failures of the casing.
  • operation 408 may be performed by a processor the same as or similar to processor 20 (shown in FIG. 1 and described herein).

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Geophysics (AREA)
  • Pipeline Systems (AREA)

Abstract

L'invention porte sur un système et sur un procédé pour détecter une intégrité structurelle d'un tubage de puits. Le système peut détecter des évènements d'intégrité structurelle de tubage. Les évènements d'intégrité structurelle de tubage peuvent comprendre des défaillances structurelles du tubage et/ou des défaillances structurelles potentielles du tubage. Le tubage de puits peut être forée et/ou incorporée d'une autre façon dans une structure géologique. Le tubage de puits peut être soumis à des forces géologiques générées par la structure géologique. Des forces et/ou un mouvement non planifiés et/ou imprévus peuvent présenter un risque pour l'intégrité structurelle du tubage. Des forces et/ou un mouvement de grandeur suffisante peuvent produire en résultat une détérioration et/ou une destruction du tubage. Une détérioration et/ou une destruction du tubage peuvent provoquer une perte des ressources naturelles qui sont extraites par l'intermédiaire du puits associé au tubage de puits, une contamination de zones entourant le puits, une expression de surface indésirable, et/ou d'autres effets négatifs.
PCT/US2014/023863 2013-03-12 2014-03-12 Système et procédé pour détecter l'intégrité structurelle d'un tubage de puits WO2014164944A1 (fr)

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US14/356,991 US20160003027A1 (en) 2013-03-12 2014-03-12 System and method for detecting structural integrity of a well casing
US15/901,217 US20180179881A1 (en) 2013-03-12 2018-02-21 System and method for detecting structural integrity of a well casing
US16/229,136 US20190112912A1 (en) 2013-03-12 2018-12-21 System and method for detecting structural integrity of a well casing

Applications Claiming Priority (2)

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US201361777553P 2013-03-12 2013-03-12
US61/777,553 2013-03-12

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US15/901,217 Continuation-In-Part US20180179881A1 (en) 2013-03-12 2018-02-21 System and method for detecting structural integrity of a well casing

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