EP4121633B1 - System und verfahren zur verhinderung von bohrlochinteraktionen - Google Patents

System und verfahren zur verhinderung von bohrlochinteraktionen Download PDF

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Publication number
EP4121633B1
EP4121633B1 EP21712579.8A EP21712579A EP4121633B1 EP 4121633 B1 EP4121633 B1 EP 4121633B1 EP 21712579 A EP21712579 A EP 21712579A EP 4121633 B1 EP4121633 B1 EP 4121633B1
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EP
European Patent Office
Prior art keywords
fracture
data
processors
detection
hydraulic fracturing
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EP21712579.8A
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English (en)
French (fr)
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EP4121633A1 (de
Inventor
Ivan LIM CHEN NING
Tamas Nemeth
David C. BARTEL
Zhishuai ZHANG
Yunhui Tan
Joseph P. Stefani
James P. Disiena
Dimitri Bevc
Kelly Hughes
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Chevron USA Inc
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Chevron USA Inc
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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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • 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
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/13—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency
    • E21B47/135—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. radio frequency using light waves, e.g. infrared or ultraviolet waves
    • 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
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/20—Computer models or simulations, e.g. for reservoirs under production, drill bits
    • 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
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/22—Fuzzy logic, artificial intelligence, neural networks or the like

Definitions

  • the disclosed embodiments relate generally to techniques for preventing wellbore interactions and, in particular, to a method of preventing wellbore interactions by using strain/strain-rate measurements.
  • Completion of wells in the subsurface may include injection of fluids that may cause fracturing in the rock formations surrounding the injection well. Such fracturing may be beneficial for the purpose of extracting (producing) hydrocarbons from the subsurface since the hydrocarbons can flow through the fractures.
  • fracturing may be beneficial for the purpose of extracting (producing) hydrocarbons from the subsurface since the hydrocarbons can flow through the fractures.
  • the situation may not be desirable if the fractures from the injection well extend to another well (commonly known as a fracture driven wellbore interaction or a "frack hit").
  • Conventional methods for preventing wellbore interactions leverage technology such as distributed acoustic sensing (DAS) for strain/strain-rate measurements for a nearby monitoring well during completions. In the conventional methods, the low frequency band of the strain/strain-rate measurement are used for this detection. However, this detection takes too long for real-time intervention to prevent wellbore interactions.
  • DAS distributed acoustic sensing
  • Described below are methods, systems, and computer readable storage media that provide a manner of wellbore interaction prevention by detection of precursor signals and patterns of strain or strain-rate measurements. These embodiments are designed to be of assistance in avoiding causing induced fracturing that reaches wells that are geographically close to the injection well.
  • the present invention uses the idea that the future stress level in a monitor well (and potential fracture propagation to the monitor well) can be predicted by identifying patterns of stress propagation in time for operational decisions.
  • the system will include pumps that are used to inject the fluids into an injection well that can be stopped when the predicted future stress level indicates that the monitor well may be impacted by an induced fracture.
  • the method detects precursor events in data that is recorded by distributed acoustic sensing (DAS) or distributed strain sensing (DSS) in one or more monitor wells near the injection well.
  • DAS distributed acoustic sensing
  • DSS distributed strain sensing
  • the low-frequency DAS or DSS signal contains information that describes the strain field surrounding hydraulic fractures.
  • simulations show that the DAS or DSS field recordings during hydraulic fracturing capture the strain field around propagating fractures, highlighting heart-shaped like phenomena as precursor events to fracture tips.
  • the present invention provides a method for detection of such events as an indicator for an imminent fracture hit.
  • Early detection of the precursor event stress build-up
  • This object detection may be done by template matching, machine-learning, and/or inversion.
  • the top panel of Figure 2 shows an example of the fiber optics data recorded during and after a wellbore interaction.
  • the lower panel shows an example of a template for precursor detection.
  • This template example is not meant to be limiting; any shape template that emulates the wellbore interaction precursor event can be used. Additionally, rather than having a user-defined template, a machine-learning method may be used to identify a characteristic pattern like a template.
  • the template matching embodiment uses a cross-correlation between the template and the recorded fiber optics data which is continuously applied as the fiber optics data is acquired.
  • the method may utilize the fast normalized cross-correlation implementation in Scikit-Image, which is known to those of skill in the art.
  • This embodiment uses a user-specified geometrical template for the cross-correlation process. The method aims to continuously match the proposed template against the low-frequency fiber optics data. Since the tensile stress feature is mainly positive, the highest positive value from the cross-correlation process is selected for the cross-correlation.
  • the different panels act as different time intervals of a field recording in real-time.
  • the star denotes the maximum positive correlation using the proposed template for the precursor event.
  • the star location may appear random as the entire image shares the likelihood of the precursor event.
  • the detection system would flag a potential wellbore interaction as early as time 20 in Figure 3 .
  • the method performs object detection with machine-learning. Since this invention performs real-time detection of the precursor events, the machine-learning algorithm must be able to process a large number of frames quickly.
  • the you-only-look-once (YOLO) architecture a convolutional neural network (CNN)-based object detection algorithm may be used.
  • the CNN may be trained on synthetic data, such as shown in Figures 1 - 4 , or field data.
  • Figure 4 shows the validation results on synthetic data hidden from the CNN training process.
  • the bounding box together with the confidence score indicates the likely presence of a precursor event.
  • the example of multiple fracture tips is unlikely in practice as first detection would have triggered the warning system. However, this example includes such scenarios to demonstrate the ability to perform multiple detection.
  • a method of non-max suppression can overcome multiple overlapping boxes on the same detected event.
  • the object detection may be done by inversion of the fiber optics data.
  • the fracture hit identification inversion process minimizes the misfit between recorded and modelled DAS or DSS responses.
  • the modelled response from an inverted fracture hit location best simulates the field recording response.
  • the individual frames in Figure 3 simulate field recordings at different snapshots where we invert for a fracture location that best represents the snapshot of interest. In situations where the precursor event is slowly unveiling, the inversion results are given as position along and distance away from the observation well. Once the fracture hit pattern establishes, the inverted spatial distance converges to a static position.
  • FIG. 5 is a diagram illustrating a hydraulic fracturing system, in accordance with some embodiments. While certain specific features are illustrated, those skilled in the art will appreciate from the present disclosure that various other features have not been illustrated for the sake of brevity and so as not to obscure more pertinent aspects of the embodiments disclosed herein.
  • the hydraulic fracturing system includes an injection well 20 with one or more injection pumps 26, at least one monitoring well 21 with seismic sensors deployed in it, and a computer system 23 that receives data from the monitoring well 21 through input line 25 and sends signals to the injection pumps 26 through output line 24.
  • injection well 20 and monitoring well(s) 21 appear as vertical wellbores, this is not meant to be limiting. As is know to those of skill in the art, the wellbores may be vertical, deviated, and/or horizontal.
  • the computer system 23 includes one or more processing units (CPUs), one or more network interfaces and/or other communications interfaces, memory, and one or more communication buses for interconnecting these and various other components.
  • the computer system 23 also includes a user interface (e.g., a display and an input device).
  • the communication buses may include circuitry (sometimes called a chipset) that interconnects and controls communications between system components.
  • Memory includes high-speed random access memory, such as DRAM, SRAM, DDR RAM or other random access solid state memory devices; and may include non-volatile memory, such as one or more magnetic disk storage devices, optical disk storage devices, flash memory devices, or other non-volatile solid state storage devices. Memory may optionally include one or more storage devices remotely located from the CPUs. Memory, including the non-volatile and volatile memory devices within memory, comprises a non-transitory computer readable storage medium and may store data or data products.

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  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Geology (AREA)
  • Remote Sensing (AREA)
  • Geochemistry & Mineralogy (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Electromagnetism (AREA)
  • Geophysics (AREA)
  • Complex Calculations (AREA)
  • Geophysics And Detection Of Objects (AREA)
  • Laminated Bodies (AREA)
  • Lubricants (AREA)

Claims (9)

  1. Computerimplementiertes Verfahren zur Verhinderung von Bohrlochwechselwirkungen zwischen Bohrungen (20, 21) im Erduntergrund, umfassend:
    a. Empfangen (25) von Glasfaserdaten aus einer Überwachungsbohrung (21) während einer hydraulischen Frakturierung unter Verwendung eines hydraulischen Frakturierungssystems (26) an einem oder mehreren Computerprozessoren (23), wobei die Glasfaserdaten Distributed Acoustic Sensing-Daten, DAS-Daten, oder Distributed Strain Sensing-Daten, DSS-Daten, umfassen, die Informationen enthalten, die das Dehnungsfeld beschreiben, das hydraulische Frakturen umgibt, und wobei das hydraulische Frakturierungssystem (26) Pumpen zum Injizieren von Flüssigkeiten in eine Injektionsbohrung umfasst, die gestoppt werden können, wenn ein vorhergesagtes zukünftiges Spannungsniveau eine Impaktierung der Überwachungsbohrung durch eine induzierte Fraktur anzeigt;
    b. während der hydraulischen Frakturierung Vorhersagen einer möglichen Frakturausbreitung zur Überwachungsbohrung (21), indem über den einen oder die mehreren Computerprozessoren (23) herzförmige Phänomene als Vorläuferereignisse von Frakturspitzen in den DAS-oder DSS-Daten als Indikatoren für einen bevorstehenden Frakturstoß erkannt werden; und
    c. bei frühzeitiger Erkennung eines Vorläuferereignisses Senden (24) von Anweisungen an das hydraulische Frakturierungssystem (26), um zumindest eines von einem Injektionsvolumen oder einer Injektionsrate zu verringern oder die Injektion zu stoppen, bevor eine Fraktur die Überwachungsbohrung (21) erreicht.
  2. Verfahren nach Anspruch 1, wobei die Erkennung durch Template-Matching erfolgt.
  3. Verfahren nach Anspruch 1, wobei die Erkennung durch ein Verfahren maschinellen Lernens erfolgt.
  4. Verfahren nach Anspruch 3, wobei das Verfahren maschinellen Lernens ein neuronales Faltungsnetzwerk, CNN, verwendet.
  5. Verfahren nach Anspruch 4, wobei das CNN ein You-Only-Look-Once-CNN ist.
  6. Verfahren nach Anspruch 1, wobei die Erkennung durch Umkehrung der Glasfaserdaten erfolgt.
  7. Computersystem (23) zum Verhindern von Bohrlochwechselwirkungen zwischen Bohrungen (20, 21) im Erduntergrund, umfassend:
    einen oder mehrere Prozessoren (23); und
    einen Speicher (23),
    wobei ein oder mehrere Programme in dem Speicher gespeichert und dazu ausgelegt sind, durch den einen oder die mehreren Prozessoren ausgeführt zu werden, wobei das eine oder die mehreren Programme Anweisungen beinhalten, die bei Ausführung durch den einen oder die mehreren Prozessoren das System zum Durchführen des Verfahrens nach einem der vorhergehenden Ansprüche veranlassen.
  8. Ein oder mehrere Programme, die bei Ausführung durch einen oder mehrere Prozessoren (23) ein Computersystem (23) zum Durchführen des Verfahrens nach einem der Ansprüche 1 bis 6 veranlassen.
  9. Nichtflüchtiges computerlesbares Medium, das das eine oder die mehreren Programme nach Anspruch 8 darauf gespeichert aufweist.
EP21712579.8A 2020-03-18 2021-03-12 System und verfahren zur verhinderung von bohrlochinteraktionen Active EP4121633B1 (de)

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US202062991538P 2020-03-18 2020-03-18
PCT/IB2021/052068 WO2021186309A1 (en) 2020-03-18 2021-03-12 System and method for preventing wellbore interactions

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EP4121633A1 EP4121633A1 (de) 2023-01-25
EP4121633B1 true EP4121633B1 (de) 2024-11-06

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WO2018204920A1 (en) * 2017-05-05 2018-11-08 Conocophillips Company Stimulated rock volume analysis
AU2018352983B2 (en) * 2017-10-17 2024-02-22 Conocophillips Company Low frequency distributed acoustic sensing hydraulic fracture geometry
US11643913B2 (en) * 2018-08-20 2023-05-09 Landmark Graphics Corporation Hybrid physics-based and machine learning models for reservoir simulations

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WO2021186309A1 (en) 2021-09-23
EP4121633A1 (de) 2023-01-25
AU2021238989A1 (en) 2022-09-08
AU2021238989B2 (en) 2025-04-10

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