CN116411926A - Reservoir fracturing monitoring system, method, apparatus, medium and program product - Google Patents
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Abstract
The application provides a reservoir fracturing monitoring system, method, apparatus, medium and program product. The method comprises the following steps: determining sound data of a preset frequency band generated after liquid enters a liquid inlet cluster corresponding to each perforation of a shaft according to a first scattering signal, and generating a first corresponding relation between the optical fiber depth of each liquid inlet cluster and the sound data of the preset frequency band; determining temperature data generated after liquid enters a liquid inlet cluster corresponding to each perforation of the well bore according to the second scattering signals, and generating a second corresponding relation between the optical fiber depth of each liquid inlet cluster and the temperature data; strain data generated after liquid enters into liquid inlet clusters corresponding to all perforation holes of a shaft are determined according to the third scattering signals, and a third corresponding relation between the optical fiber depth of each liquid inlet cluster and the strain data is generated; and displaying the first corresponding relation, the second corresponding relation and the third corresponding relation. The method can improve the monitoring precision and reduce the construction risk.
Description
Technical Field
The present application relates to the field of oil and gas recovery technologies, and in particular, to a reservoir fracturing monitoring system, method, apparatus, medium, and program product.
Background
Hydraulic fracturing or liquid CO 2 The fracturing technology is an effective method for reforming unconventional oil and gas reservoirs such as shale gas, and is a main means for increasing the yield and income of unconventional oil and gas wells. During fracturing, high-pressure fluid is quickly injected into a reservoir stratum, so that the pore pressure is increased sharply, and gaps are formed in the underground stratum so that oil and gas can flow out.
Monitoring the reservoir reformation process in real time is a critical means to ensure that the desired reformation effect is achieved during the fracturing construction process. In the prior art, an armored optical cable provided with an optical fiber is arranged outside a fracturing string to collect sound and temperature in a well bore, so that real-time monitoring of a reservoir fracturing process is realized. However, this method of monitoring is very limited and must be implemented by providing a fracturing string within the wellbore. However, when some reservoirs are fractured, a fracturing string is not needed, fracturing fluid is directly collected into a shaft through a high-pressure pipe, sound and temperature in the shaft cannot be collected through an optical fiber to monitor, and the existing reservoir fracturing monitoring system and method are high in limitation and low in applicability. In addition, the prior art monitors the fracturing process only by collecting the sound and the temperature in the well bore, the collected data are not comprehensive, and the quality and the risk of the fracturing process cannot be comprehensively analyzed and evaluated according to the collected data, so that the monitoring precision is low, and the construction risk is high.
However, existing reservoir fracture monitoring techniques do not address the above-described technical issues.
Disclosure of Invention
The application provides a reservoir fracturing monitoring system, a reservoir fracturing monitoring method, a reservoir fracturing monitoring device, a reservoir fracturing monitoring medium and a reservoir fracturing monitoring program product, which are used for solving the technical problems that the existing reservoir fracturing monitoring system and method are high in limitation, low in applicability, low in monitoring precision and high in construction risk.
In a first aspect, the present application provides a reservoir fracturing monitoring system comprising:
the system comprises a signal generation module, a distributed optical fiber acoustic wave sensor, a distributed optical fiber temperature sensor, a distributed optical fiber strain sensor and a monitoring module;
the distributed optical fiber acoustic wave sensor, the distributed optical fiber temperature sensor and the distributed optical fiber strain sensor are respectively connected with the monitoring module; the distributed optical fiber acoustic wave sensor, the distributed optical fiber temperature sensor and the distributed optical fiber strain sensor are respectively connected with optical fibers in an armored optical cable, and the armored optical cable is fixedly sealed in a cement ring outside a shaft;
the signal generation module is used for transmitting optical signals to the optical fibers of the armored optical cable;
the distributed optical fiber acoustic wave sensor is used for receiving a first scattering signal generated after the optical signal is contacted with the optical fiber and sending the first scattering signal to the monitoring module;
The distributed optical fiber temperature sensor is used for receiving a second scattering signal generated after the optical signal is contacted with the optical fiber and sending the second scattering signal to the monitoring module;
the distributed optical fiber strain sensor is used for receiving a third scattering signal generated after the optical signal is contacted with the optical fiber and sending the third scattering signal to the monitoring module;
the monitoring module is used for receiving a first scattering signal sent by the distributed optical fiber acoustic wave sensor, determining sound data of a preset frequency band generated after liquid enters a liquid inlet cluster corresponding to each perforation of a shaft according to the first scattering signal, and generating a first corresponding relation between the optical fiber depth of each liquid inlet cluster and the sound data of the preset frequency band; receiving a first scattering signal sent by a distributed optical fiber temperature sensor, determining temperature data generated after liquid enters liquid inlet clusters corresponding to all perforation holes of a shaft according to the second scattering signal, and generating a second corresponding relation between the optical fiber depth of each liquid inlet cluster and the temperature data; receiving a third scattering signal sent by a distributed optical fiber strain sensor, determining strain data generated after liquid enters liquid inlet clusters corresponding to all perforation holes of a shaft according to the third scattering signal, and generating a third corresponding relation between the optical fiber depth of each liquid inlet cluster and the strain data; and displaying the first corresponding relation, the second corresponding relation and the third corresponding relation.
In a second aspect, the present application provides a method for monitoring with the reservoir fracturing monitoring system described above, comprising:
receiving a first scattering signal sent by a distributed optical fiber acoustic wave sensor, determining sound data of a preset frequency band generated after liquid enters a liquid inlet cluster corresponding to each perforation of a shaft according to the first scattering signal, and generating a first corresponding relation between the optical fiber depth of each liquid inlet cluster and the sound data of the preset frequency band;
receiving a first scattering signal sent by a distributed optical fiber temperature sensor, determining temperature data generated after liquid enters liquid inlet clusters corresponding to all perforation holes of a shaft according to the second scattering signal, and generating a second corresponding relation between the optical fiber depth of each liquid inlet cluster and the temperature data;
receiving a third scattering signal sent by a distributed optical fiber strain sensor, determining strain data generated after liquid enters liquid inlet clusters corresponding to all perforation holes of a shaft according to the third scattering signal, and generating a third corresponding relation between the optical fiber depth of each liquid inlet cluster and the strain data;
and displaying the first corresponding relation, the second corresponding relation and the third corresponding relation.
In one possible design, the determining, according to the first scattering signal, sound data of a preset frequency band generated after the liquid enters the liquid inlet cluster corresponding to each perforation of the wellbore specifically includes:
And filtering the first scattered signal by using the following formula to obtain sound data of a preset frequency band:
x b (t)＝F -1 [X(f)·G(f)]
wherein said x b (t) represents sound data of a preset frequency band, t represents time, F -1 Representing an inverse fourier transform, said X (f) representing a frequency domain expression of said first scattered signal X (t), said
The f represents the frequency of the sound wave, the f 1 Representing the lowest frequency of the preset frequency band, the f 2 Representing the highest frequency of the preset frequency band, the f 0 ＝(f 1 +f 2 ) And 2, the sigma represents the standard deviation of a Gaussian function, and the A is a constant.
In one possible design, the determining, according to the second scattering signal, temperature data generated after the liquid enters the liquid inlet cluster corresponding to each perforation of the wellbore specifically includes:
determining an initial temperature corresponding to the second scattered signal;
and carrying out superposition and averaging on the initial temperature by using the following formula to obtain temperature data generated after liquid enters liquid inlet clusters corresponding to all perforation of the shaft:
wherein T (h) represents temperature data, h represents fiber depth, T i (h) Represents the initial temperature acquired for the i-th sampling interval, and n represents the number of sampling intervals.
In one possible design, the determining the strain data generated after the liquid enters the liquid inlet cluster corresponding to each perforation of the wellbore according to the third scattering signal specifically includes:
processing the third scattered signal to determine strain data generated after the fluid enters the fluid inlet cluster corresponding to each perforation of the wellbore using the following formula:
wherein μ represents t n Strain data of the wellbore at a time, the
Representing the brillouin shift amount caused by unit microstrain, said +.>
The U represents the value from t 1 From time to t n Brillouin shift amount generated at time, u=u n -u 1 The u is n Representing t n A third scattered signal of the moment of time, u 1 Representing t 1 A third scattered signal of time, T n Representing t n Temperature data generated at the moment, T 1 Representing t 1 Temperature data generated at the moment, said +.>
The brillouin shift amount due to the unit temperature is shown.
In one possible design, the fiber depth of the feed clusters is obtained by:
determining perforation positions corresponding to all perforations of a shaft;
and determining the optical fiber depth of the liquid inlet cluster corresponding to each perforation of the well bore according to the perforation positions.
In one possible design, the determining the optical fiber depth of the liquid inlet cluster corresponding to each perforation of the wellbore according to the perforation position specifically includes:
Determining the optical fiber depth of the liquid inlet cluster corresponding to each perforation of the shaft by using the following formula:
L＝h-l
the L represents the optical fiber depth of the liquid inlet cluster, the h represents the preset optical fiber depth of the liquid inlet cluster, and the L represents the optical fiber calibration depth; l= |h '-H' | where H 'represents a preset average perforation interval depth and H' represents an actual average perforation interval depth;
the delta H i Represents the i-th preset perforation interval depth, wherein n represents the perforation times and delta H i ＝H i+1 -H i The H is i Representing a preset depth of the ith perforation; />
The Deltah is i Represents the ith actual perforation interval depth, deltah i ＝h i+1 -h i Said h is i Indicating the actual depth of the ith perforation.
In one possible design of the device,
in one possible design of the device,
in one possible design of the device,
in a third aspect, the present application provides an apparatus for monitoring with the reservoir fracturing monitoring system described above, comprising: a processor, and a memory communicatively coupled to the processor;
the memory stores computer-executable instructions;
the processor executes the computer-executable instructions stored in the memory to implement the methods described above.
In a fourth aspect, the present application provides a computer-readable storage medium having stored therein computer-executable instructions for performing the method described above when executed by a processor.
In a fifth aspect, the present application provides a computer program product comprising a computer program which, when executed by a processor, implements the method described above.
According to the method for monitoring the reservoir fracturing monitoring system, on one hand, the armored optical cable can be fixedly sealed in the cement ring outside the shaft, devices such as a fracturing string and the like do not need to be arranged in the shaft, the space in the well is not occupied, and the applicability of the reservoir fracturing monitoring system is improved. On the other hand, the method and the device can also respectively utilize the distributed optical fiber acoustic wave sensor, the distributed optical fiber temperature sensor and the distributed optical fiber strain sensor to collect various data generated in the fracturing process, and correspondingly process and display the collected data.
Drawings
The accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments consistent with the application and together with the description, serve to explain the principles of the application.
FIG. 1 is a system architecture diagram of a prior art method of monitoring using a reservoir fracture monitoring system;
FIG. 2 is a schematic diagram of a reservoir fracturing monitoring system according to an embodiment of the present application;
FIG. 3 is a flow chart of a method of monitoring with a reservoir fracture monitoring system according to an embodiment of the present application;
fig. 4 is a schematic structural diagram of an apparatus for monitoring using a reservoir fracturing monitoring system according to an embodiment of the present application.
Reference numerals: 1. an armored optical cable; 2. fracturing a tubular column; 3. a packer; 4. DAS/DTS hydraulic fracturing monitor; 11. a signal generation module; 12. a distributed optical fiber acoustic wave sensor; 13. a distributed optical fiber temperature sensor; 14. a distributed optical fiber strain sensor; 15. and a monitoring module.
Specific embodiments thereof have been shown by way of example in the drawings and will herein be described in more detail. These drawings and the written description are not intended to limit the scope of the inventive concepts in any way, but to illustrate the concepts of the present application to those skilled in the art by reference to specific embodiments.
Detailed Description
Reference will now be made in detail to exemplary embodiments, examples of which are illustrated in the accompanying drawings. When the following description refers to the accompanying drawings, the same numbers in different drawings refer to the same or similar elements, unless otherwise indicated. The implementations described in the following exemplary examples are not representative of all implementations consistent with the present application. Rather, they are merely examples of apparatus and methods consistent with some aspects of the present application as detailed in the accompanying claims.
The terms referred to in this application are explained first:
fracturing, which is a method for forming cracks on hydrocarbon reservoirs by utilizing the hydraulic action in the oil or gas extraction process, can be roughly divided into the steps of bridge plug setting, perforation, sand feeding and the like.
Bridge plugs, which refer to a well bore plugging structure, can plug a well bore so as to segment the well bore.
Bridge plug set refers to the process of the bridge plug reaching a preset location in the wellbore and completing the plugging.
Perforation, which refers to a process of using a special energy concentrating material to enter a predetermined location of a wellbore and explosion perforating the wellbore, creates a gap in the formation adjacent the perforation so that fluid in the formation enters the wellbore through the gap and the perforation.
And adding sand feed liquid, namely injecting sand-carrying liquid with propping agent into the crack through the hole after the crack is generated in the rock stratum, so that the crack continues to extend and the propping agent is filled in the process. After sand feeding liquid is stopped, due to the supporting effect of the propping agent on the cracks, sand filling cracks which are long enough and have certain diversion capacity can be formed in the rock stratum, so that oil gas in the rock stratum flows into the shaft.
The liquid inlet cluster refers to rock cracks near holes generated by perforation, and sand and liquid can be added through the liquid inlet cluster in the fracturing process.
The armored optical cable is an optical cable coated with a layer of protective metal armor outside the optical fiber, and can prevent moisture and biting.
The distributed Optical fiber acoustic wave sensor (Optical Fiber Distributed Acoustic Sensing, DAS) is a device for detecting acoustic wave changes at any position along an Optical fiber by using the Optical fiber as a sensing element and a transmission signal medium and adopting an Optical Time-domain reflectometer (Optical Time-Domain Reflectometer, OTDR) technology and the rayleigh scattering principle of light.
A distributed Optical fiber temperature sensor (Optical Fiber Distributed Temperature Sensing, DTS) refers to a device that uses an Optical fiber as a sensing element and a transmission signal medium, and detects temperature changes at any position along the Optical fiber by using Optical Time-domain reflectometer (Optical Time-Domain Reflectometer, OTDR) technology and raman scattering and principle of light.
A distributed Optical fiber strain sensor (Optical Fiber Distributed strain Sensing, DSS) refers to a device that detects strain changes at any location along an Optical fiber using Optical Time-domain reflectometer (Optical Time-Domain Reflectometer, OTDR) technology and the brillouin scattering principle of light, using the Optical fiber as a sensing element and a transmission signal medium.
Hydraulic fracturing or liquid CO 2 The fracturing technology is an effective method for reforming unconventional oil and gas reservoirs such as shale gas, and is a main means for increasing the yield and income of unconventional oil and gas wells. During fracturing, high-pressure fluid is quickly injected into a reservoir stratum, so that the pore pressure is increased sharply, and gaps are formed in the underground stratum so that oil and gas can flow out. Monitoring reservoir fracturing processes in real time is a critical means to ensure that the desired reforming effect is achieved during the fracturing construction process.
Fig. 1 is a system architecture diagram of a prior art method of monitoring using a reservoir fracture monitoring system. As shown in fig. 1, includes an armored fiber optic cable 1, a fracturing string 2, a packer 3, and a DAS/DTS hydraulic fracturing monitor 4. The armored optical cable 1 is fixed in a clamping groove on the outer wall of the fracturing string 2 and penetrates through the fracturing tool string and all the packers 4, and is put into a fracturing well along with the fracturing string 2; the armored optical cable 1 passes through a fracturing wellhead and then is connected with a DAS/DTS hydraulic fracturing monitor 4 arranged on the ground; starting a DAS/DTS hydraulic fracturing monitor 4; carrying out a hydraulic fracturing process according to a hydraulic fracturing design scheme; observing real-time sound data and temperature data displayed on a computer control and display system in the DAS/DTS hydraulic fracturing monitor 4, and recording the sound data and the temperature data; and the staff analyzes and evaluates the data displayed on the display system and guides the operation of the whole fracturing process in real time.
However, the above monitoring methods are very limited and must be implemented by providing a fracturing string within the wellbore. However, when some reservoirs are fractured, a fracturing string is not needed, fracturing fluid is directly collected into a shaft through a high-pressure pipe, sound and temperature in the shaft cannot be collected through an optical fiber to monitor, and the existing reservoir fracturing monitoring system and method are high in limitation and low in applicability. In addition, the prior art monitors the fracturing process only by collecting the sound and the temperature in the well bore, the collected data are not comprehensive, and the quality and the risk of the fracturing process cannot be comprehensively analyzed and evaluated according to the collected data, so that the monitoring precision is low, and the construction risk is high.
The reservoir fracturing monitoring system and method provided by the application aim to solve the technical problems in the prior art. By adopting the method for monitoring the reservoir fracturing monitoring system, on one hand, the armored optical cable can be fixedly sealed in the cement ring outside the shaft, devices such as a fracturing string and the like do not need to be arranged in the shaft, the space in the well is not occupied, and the applicability of the reservoir fracturing monitoring system is improved. On the other hand, the distributed optical fiber acoustic wave sensor, the distributed optical fiber temperature sensor and the distributed optical fiber strain sensor can be used for collecting various data generated in the fracturing process, the collected data are correspondingly processed and displayed, and through the arrangement, the collected relevant data of the fracturing process are more comprehensive, so that relevant personnel can comprehensively analyze and evaluate the quality and risk of the fracturing process according to the data, monitoring accuracy is improved, and construction risk is reduced.
The following describes the technical solutions of the present application and how the technical solutions of the present application solve the above technical problems in detail with specific embodiments. The following embodiments may be combined with each other, and the same or similar concepts or processes may not be described in detail in some embodiments. Embodiments of the present application will be described below with reference to the accompanying drawings.
Example 1
Fig. 2 is a schematic structural diagram of a reservoir fracturing monitoring system provided in an embodiment of the present application. As shown in fig. 2, the reservoir fracturing monitoring system may include: the system comprises a signal generation module 11, a distributed optical fiber acoustic wave sensor 12, a distributed optical fiber temperature sensor 13, a distributed optical fiber strain sensor 14 and a monitoring module 15.
The distributed optical fiber acoustic wave sensor 12, the distributed optical fiber temperature sensor 13 and the distributed optical fiber strain sensor 14 can be respectively connected with the monitoring module 15; the distributed optical fiber acoustic wave sensor 12, the distributed optical fiber temperature sensor 13 and the distributed optical fiber strain sensor 14 can be respectively connected with optical fibers in the armored optical cable 1, and the armored optical cable 1 is fixedly sealed in a cement ring outside a shaft.
The signal generating module 11 may be used to emit an optical signal to an optical fiber of the armored cable 1.
The distributed optical fiber acoustic wave sensor 12 may be configured to receive a first scattered signal generated after the optical signal contacts the optical fiber and send the first scattered signal to the monitoring module 15.
The distributed optical fiber temperature sensor 13 may be configured to receive a second scattered signal generated after the optical signal contacts the optical fiber and send the second scattered signal to the monitoring module 15.
The distributed optical fiber strain sensor 14 may be configured to receive a third scattered signal generated after the optical signal contacts the optical fiber and send the third scattered signal to the monitoring module 15.
The monitoring module 15 may be configured to receive a first scattering signal sent by the distributed optical fiber acoustic wave sensor 12, determine, according to the first scattering signal, sound data of a preset frequency band generated after a liquid enters a liquid inlet cluster corresponding to each perforation of the wellbore, and generate a first correspondence between a depth of an optical fiber of each liquid inlet cluster and the sound data of the preset frequency band; receiving a first scattering signal sent by a distributed optical fiber temperature sensor 13, determining temperature data generated after liquid enters a liquid inlet cluster corresponding to each perforation of a shaft according to a second scattering signal, and generating a second corresponding relation between the optical fiber depth of each liquid inlet cluster and the temperature data; receiving a third scattering signal sent by the distributed optical fiber strain sensor 14, determining strain data generated after liquid enters the liquid inlet cluster corresponding to each perforation of the shaft according to the third scattering signal, and generating a third corresponding relation between the optical fiber depth of each liquid inlet cluster and the strain data; and displaying the first corresponding relation, the second corresponding relation and the third corresponding relation.
In the present embodiment, the signal generation module 11 may be any device capable of emitting pulsed laser light. The armored optical cable 1 is at least provided with three optical fibers which are respectively connected with a distributed optical fiber acoustic wave sensor 12, a distributed optical fiber temperature sensor 13 and a distributed optical fiber strain sensor 14 which are arranged on the ground. When monitoring, the signal generating module 11 transmits optical signals to three optical fibers of the armored optical cable 1, and the sensors connected with the three optical fibers respectively receive scattered signals generated after the optical signals are contacted with the optical fibers. The optical fiber may be a single-mode optical fiber or a multimode optical fiber, and is not limited thereto. In a specific example, two single-mode fibers are configured in the armored optical cable, one multimode optical fiber is connected with the distributed optical fiber acoustic wave sensor and the distributed optical fiber strain sensor respectively, and the multimode optical fiber is connected with the distributed optical fiber temperature sensor.
In the present embodiment, the armored fiber optic cable 1 is composed of a plurality of optical fibers, outer armor, and optical fiber paste. The outer armor of the armored optical cable 1 can protect the optical fibers in the armored optical cable from mechanical injury. The optical fiber paste plays roles in preventing water invasion and mechanical shock absorption. While the well bore is being run in, the armored fiber optic cable 1 is bundled outside the well bore, is run in along with the well bore, is fixed in a cement sheath, is permanently arranged in the well bore, and is protected and fixed by a special protector at the coupling which is most easily damaged in the well bore.
In a specific embodiment, the laser pulse width of the signal generating module 11 is not greater than 20ns, and the laser emission frequency is not lower than 2000Hz. The data recording frequency bandwidth of the distributed optical fiber acoustic wave sensor DAS is not lower than 1000Hz, the spatial resolution is not lower than 2m, and the strain sensitivity is not higher than 5 picometers. The spatial resolution of the distributed optical fiber temperature sensor DTS is not lower than 1m, the spatial sampling rate is lower than 0.5m, the temperature measurement precision is 0.1 ℃, and the temperature resolution is 0.01 ℃. The spatial resolution of the distributed optical fiber strain sensor DSS is not lower than 5m, and the strain sensitivity is lower than 5 nano strain. The data demodulation time of the sensing system is not more than 10s.
In this embodiment, through sealing the armoured optical cable in the cement sheath outside the shaft, need not set up devices such as fracturing string in the shaft, no longer occupy the well space, no matter set up fracturing string when fracturing, through this kind of method, can both set up the sound and the temperature monitoring in the optical fiber collection shaft, improved reservoir fracturing monitoring system's suitability.
In the present embodiment, the first scattering signal is rayleigh scattering generated after the optical signal contacts the optical fiber, and the first scattering signal can represent the sound variation of different optical fiber depths. The second scattering signal is raman scattering generated after the optical signal contacts the optical fiber, and the second scattering signal can represent temperature change conditions of different optical fiber depths. The third scattering signal is brillouin scattering generated after the optical signal contacts the optical fiber, and can represent strain change conditions of different optical fiber depths.
In the embodiment, the sensors are used for respectively acquiring the sound data, the temperature data and the strain data of different optical fiber depths, so that the related data of the fracturing process can be comprehensively acquired, and related personnel can comprehensively analyze and evaluate the quality and the risk of the fracturing process according to the related data, thereby improving the monitoring precision and reducing the construction risk.
The flow of the method of monitoring using the reservoir fracturing monitoring system described above is described in detail below in example two.
Example two
Fig. 3 is a flowchart of a method for monitoring by using the reservoir fracturing monitoring system according to an embodiment of the present application, where an execution body of the method for monitoring by using the reservoir fracturing monitoring system according to the embodiment of the present application may be a monitoring module or a server, and the method for monitoring by using the reservoir fracturing monitoring system is described by using the execution body as the monitoring module. After the fracturing fluid with the propping agent enters the well bore through the high pressure pipe, as shown in fig. 3, the method for monitoring by adopting the reservoir fracturing monitoring system can comprise the following steps:
s101: and receiving a first scattering signal sent by the distributed optical fiber acoustic wave sensor, determining sound data of a preset frequency band generated after liquid enters a liquid inlet cluster corresponding to each perforation of the shaft according to the first scattering signal, and generating a first corresponding relation between the optical fiber depth of each liquid inlet cluster and the sound data of the preset frequency band.
In this embodiment, after the fracturing fluid enters the wellbore through the high-pressure pipe, the situation of sand feeding needs to be monitored in real time, so that relevant personnel can guide the construction of the on-site fracturing operation. The first corresponding relation between the optical fiber depth of each liquid inlet cluster and the sound data of the preset frequency band can be determined through the first scattering signals received by the distributed optical fiber sound wave sensor, so that relevant personnel can monitor the sand feeding condition according to the sound data.
In this embodiment, as liquid enters the liquid inlet clusters, sound in the well bore becomes loud, so that the liquid inlet effect of each liquid inlet cluster can be determined by sound data. If the sound data of a certain liquid inlet cluster is large, the liquid inlet effect of the liquid inlet cluster is good, and if the sound data of the certain liquid inlet cluster is basically not available, the liquid inlet effect of the liquid inlet cluster is poor.
In this embodiment, the fiber depth of the feed clusters may be obtained by: determining perforation positions corresponding to all perforations of a shaft; and determining the optical fiber depth of the liquid inlet cluster corresponding to each perforation of the well bore according to the perforation position.
In this embodiment, each perforation corresponds to a fluid inlet cluster, and when sand is added to the fluid, fluid in the wellbore enters the fluid inlet cluster through the perforation in the wellbore. The location of the fluid inlet clusters can be considered the location of the perforations. Because of the redundancy of the optical fiber during the optical fiber running down-hole, the depth of the optical fiber corresponding to the perforation designed before the optical fiber running down-hole may not be accurate, and thus the depth of the optical fiber corresponding to the perforation needs to be corrected. The perforating positions of the perforating gun are set, and no error is usually caused, namely, the perforating positions corresponding to the perforating holes are known, so that the optical fiber depth of the liquid inlet cluster corresponding to each perforating hole can be corrected by utilizing the perforating positions, the accuracy of the optical fiber depth is improved, and the monitoring accuracy is improved.
In this embodiment, the optical fiber depth and the perforation position of the liquid inlet cluster corresponding to each perforation are not greatly different, so that the optical fiber depth of a liquid inlet cluster and the perforation position are in one-to-one correspondence, for example, the detection optical fiber depth of a certain liquid inlet cluster is 2501m, and the adjacent perforation positions of the liquid inlet cluster are 2500m and 2000m, and the actual optical fiber depth corresponding to the liquid inlet cluster should be 2500m.
In the embodiment, before sand feeding, whether the processes of bridge plug setting, perforation and the like are finished can be determined through the first scattering signals received by the distributed optical fiber acoustic wave sensor. In perforating, a composite structure of a perforating gun and a bridge plug connected together can be launched into a wellbore, the composite structure can emit a sound during operation, and when the composite structure reaches a designated position for fixation and the perforating gun and bridge plug are separated to complete setting, a louder sound can be emitted. Thereafter, the perforating gun is operated upwards and the perforation is completed, and the sound generated during perforation is the largest. Therefore, whether the bridge plug setting and perforation are completed can be judged through sound data received by the distributed optical fiber sound wave sensor.
In this embodiment, whether the liquid inlet has a problem or not and the cause of the problem can also be determined by the first scattering signal received by the distributed optical fiber acoustic wave sensor. For example, if there is also liquid ingress below the corresponding depth of the bridge plug, this is caused by the bridge plug moving down.
In this embodiment, determining, according to the perforation positions, the optical fiber depth of the liquid inlet cluster corresponding to each perforation of the wellbore may include:
determining the optical fiber depth of the liquid inlet cluster corresponding to each perforation of the shaft by using the following formula (1):
L＝h-l (1)
l represents the optical fiber depth of the liquid inlet cluster, h represents the preset optical fiber depth of the liquid inlet cluster, and L represents the optical fiber calibration depth; l= |h '-H' |, H 'represents a preset average perforation interval depth, and H' represents an actual average perforation interval depth;
ΔH i represents the i-th preset perforation interval depth, n represents the perforation times, delta H i ＝H i+1 -H i ，H i Representing a preset depth of the ith perforation; />
Δh i Represents the ith actual perforation interval depth, deltah i ＝h i+1 -h i ，h i Indicating the actual depth of the ith perforation.
In the embodiment, the optical fiber calibration depth is determined by adding and averaging the perforation interval depths, so that the accuracy of the optical fiber calibration depth can be improved, error interference caused by accidental factors is avoided, and the accuracy of the optical fiber depth of the liquid inlet cluster is ensured.
In this embodiment, determining, according to the first scattering signal, sound data of a preset frequency band generated after the liquid enters a liquid inlet cluster corresponding to each perforation of the wellbore may include:
the first scattered signal is filtered by the following formula (2) to obtain sound data of a preset frequency band:
x b (t)＝F -1 [X(f)·G(f)] (2)
Wherein x is b (t) represents sound data of a preset frequency band, t represents time, F -1 Representing an inverse fourier transform, X (f) representing a frequency domain representation of the first scattered signal X (t),
f represents the frequency of the sound wave, f 1 Represents the lowest frequency f of the preset frequency band 2 Representing the highest frequency of the preset frequency band, f 0 ＝(f 1 +f 2 ) And 2, sigma represents the standard deviation of the Gaussian function, and A is a constant.
In this embodiment, the sound of the liquid entering the liquid inlet cluster is relatively large, and the frequency range of the sound can be approximately determined, so that the first scattering signal can be filtered, only the sound data of the preset frequency band is displayed, the interference of irrelevant data is avoided, and the accuracy of monitoring by using the sound data is improved.
In this embodiment, the preset frequency band can be flexibly set by those skilled in the art according to the actual situation, and no limitation is made herein. Furthermore, the sampling interval of sound data can be flexibly set by those skilled in the art according to the actual circumstances, and no limitation is made herein. As a specific example, the sampling interval of the sound data may be 0.25ms.
S102: and receiving the first scattering signals sent by the distributed optical fiber temperature sensors, determining temperature data generated after liquid enters the liquid inlet clusters corresponding to the perforations of the well bore according to the second scattering signals, and generating a second corresponding relation between the optical fiber depth of each liquid inlet cluster and the temperature data.
In this embodiment, the second correspondence between the optical fiber depth of each liquid inlet cluster and the temperature data may be determined through the second scattering signal received by the distributed optical fiber temperature sensor, so that a related person monitors the situation of adding sand and liquid according to the temperature data.
In this embodiment, the temperature of the underground rock layer is high, and the fracturing fluid is a high-pressure low-temperature fluid, so after the fluid enters the fluid inlet cluster, the temperature corresponding to the depth of the optical fiber of the fluid inlet cluster is reduced, and the better the fluid inlet effect is, the lower the temperature is.
In this embodiment, determining, according to the second scattering signal, temperature data generated after the liquid enters the liquid inlet cluster corresponding to each perforation of the wellbore specifically includes:
determining an initial temperature corresponding to the second scattered signal;
and (3) carrying out superposition and average on the initial temperature by using the following formula (3) to obtain temperature data generated after liquid enters into liquid inlet clusters corresponding to all perforation of the shaft:
wherein T (h) represents temperature data, h represents optical fiber depth, T i (h) Indicating the initial temperature acquired for the i-th sampling interval and n indicating the number of sampling intervals.
In this embodiment, by adding and averaging the initial temperatures acquired at a plurality of sampling intervals, the temperature data corresponding to the depths of the optical fibers can be more accurate, and the accuracy of monitoring by using the temperature data can be improved.
In this embodiment, the sampling interval of the temperature data can be flexibly set by those skilled in the art according to the actual circumstances, and no limitation is made herein. As a specific example, the sampling interval of the temperature data may be 30s.
S103: and receiving a third scattering signal sent by the distributed optical fiber strain sensor, determining strain data generated after liquid enters the liquid inlet cluster corresponding to each perforation of the shaft according to the third scattering signal, and generating a third corresponding relation between the optical fiber depth of each liquid inlet cluster and the strain data.
In this embodiment, a third correspondence between the fiber depth of each liquid inlet cluster and strain data may be determined by a third scattering signal received by the distributed optical fiber strain sensor, so as to facilitate monitoring of the sand feeding condition by related personnel according to the strain data.
In this embodiment, the liquid will exert pressure on the wall of the wellbore after entering the wellbore, thereby causing strain to the wellbore, the strain to the wall of the wellbore near the perforations is greater, and when all of the liquid in the wellbore enters the liquid intake clusters, the wellbore will resume no strain. Therefore, the strain data of the liquid inlet cluster can be used for indicating the liquid inlet effect of the liquid inlet cluster, and meanwhile, the strain condition of the shaft can be monitored according to the strain data, so that the shaft is prevented from being damaged due to too high pressure or weak shaft at a certain place during liquid inlet.
In this embodiment, strain data generated after the liquid enters the liquid inlet cluster corresponding to each perforation of the wellbore is determined according to the third scattering signal, specifically including:
processing the third scattered signal to determine strain data generated after the fluid enters the fluid inlet cluster corresponding to each perforation of the wellbore using the following equation (4):
wherein μ represents t n Strain data for the wellbore at the time instant,
represents the brillouin shift amount caused by unit microstrain,
u represents the value from t 1 From time to t n Brillouin shift amount generated at time, u=u n -u 1 ，u n Representing t n Third scattered signal of time instant u 1 Representing t 1 Third scattered signal of time, T n Representing t n Temperature data generated at the moment, T 1 Representing t 1 Temperature data generated at the moment->
The brillouin shift amount due to the unit temperature is shown.
In this embodiment, the sampling interval of the strain data can be flexibly set by those skilled in the art according to the actual circumstances, and no limitation is made herein. Since strain occurs slowly, the sampling interval of strain data may be smaller than the sampling interval of temperature data and the sampling interval of sound data to reduce the computational effort. As a specific example, the sampling interval of the strain data may be 360s.
S104: and displaying the first corresponding relation, the second corresponding relation and the third corresponding relation.
In this embodiment, the first correspondence, the second correspondence, and the third correspondence may be displayed by the first correspondence map, the second correspondence map, and the third correspondence map, respectively. As a specific example, the first correspondence map, the second correspondence map, and the third correspondence map may be waterfall maps.
In this embodiment, the first correspondence of the sound data has a fast response but a low accuracy, the second correspondence of the temperature data has a slow response but a high accuracy, the two are complementary, the second correspondence of the strain data supplements and judges the liquid inlet effect from the strain dimension, and the three data are synthesized, so that the related personnel can comprehensively analyze and evaluate the quality and risk of the fracturing process according to the three data, thereby improving the monitoring accuracy and reducing the construction risk.
The flow of a method of monitoring using the reservoir fracture monitoring system described above is described in detail below with one specific embodiment.
Example III
The reservoir fracturing monitoring system is used for monitoring the reservoir fracturing, and comprises the following steps of:
firstly, when the well bore is in the well, the armored optical cable is bundled outside the well bore, is in the well along with the well bore and is fixed in the cement ring to be permanently arranged in the well, and three optical fibers of the armored optical cable are respectively connected with a distributed optical fiber acoustic wave sensor, a distributed optical fiber temperature sensor and a distributed optical fiber strain sensor which are arranged on the ground. The signal generation module emits pulsed laser light to the optical fiber.
Then, a composite structure of the perforating gun and the bridge plug which are connected together is transmitted into a shaft, a first scattering signal sent by a cloth-type optical fiber acoustic wave sensor is received, sound data are determined according to the first scattering signal, and a waterfall diagram of the optical fiber depth of each liquid inlet cluster and the sound data is generated, so that a relevant person can judge whether the bridge plug is set and perforated according to the situation.
And correcting the optical fiber depth of the liquid inlet cluster according to the perforation positions corresponding to the perforations.
And finally, collecting the fracturing fluid with high pressure and low temperature into a shaft from a high pressure pipe, receiving a first scattering signal sent by a cloth-type optical fiber acoustic wave sensor, receiving a second scattering signal sent by a cloth-type optical fiber temperature sensor and receiving a third scattering signal sent by a cloth-type optical fiber strain sensor, and respectively generating a first waterfall diagram of optical fiber depth and sound data of a preset frequency band of each fluid inlet cluster, a second waterfall diagram of optical fiber depth and temperature data of each fluid inlet cluster and a third waterfall diagram of optical fiber depth and strain data of each fluid inlet cluster so as to monitor the fracturing process in real time.
Fig. 4 is a schematic structural diagram of an apparatus for monitoring with a reservoir fracturing monitoring system according to an embodiment of the present application, as shown in fig. 4, the apparatus for monitoring with a reservoir fracturing monitoring system includes: a processor 101, and a memory 102 communicatively coupled to the processor 101; memory 102 stores computer-executable instructions; the processor 101 executes computer-executable instructions stored in the memory 102 to implement the steps of the method for monitoring using a reservoir fracture monitoring system in the method embodiments described above.
The device for monitoring with the reservoir fracturing monitoring system may be stand alone or may be part of the monitoring system, and the processor 101 and memory 102 may be implemented with existing hardware of the monitoring system.
In the above-described devices that employ reservoir fracture monitoring systems for monitoring, the memory 102 and the processor 101 are electrically connected, either directly or indirectly, to enable transmission or interaction of data. For example, the elements may be electrically connected to each other via one or more communication buses or signal lines, such as through a bus connection. The memory 102 stores therein computer-executable instructions for implementing a data access control method, including at least one software functional module that may be stored in the memory 102 in the form of software or firmware, and the processor 101 executes the software programs and modules stored in the memory 102 to thereby perform various functional applications and data processing.
The Memory 102 may be, but is not limited to, random access Memory (Random Access Memory, RAM), read Only Memory (ROM), programmable Read Only Memory (PROM), erasable Read Only Memory (Erasable Programmable Read-Only Memory, EPROM), electrically erasable Read Only Memory (Electric Erasable Programmable Read-Only Memory, EEPROM), etc. The memory 102 is used for storing a program, and the processor 101 executes the program after receiving an execution instruction. Further, the software programs and modules within the memory 102 may also include an operating system, which may include various software components and/or drivers for managing system tasks (e.g., memory management, storage device control, power management, etc.), and may communicate with various hardware or software components to provide an operating environment for other software components.
The processor 101 may be an integrated circuit chip with signal processing capabilities. The processor 101 may be a general-purpose processor, including a central processing unit (Central Processing Unit, abbreviated as CPU), a network processor (Network Processor, abbreviated as NP), and the like. The disclosed methods, steps, and logic blocks in the embodiments of the present application may be implemented or performed. A general purpose processor may be a microprocessor or the processor may be any conventional processor or the like.
An embodiment of the present application further provides a computer-readable storage medium, where computer-executable instructions are stored, where the computer-executable instructions, when executed by a processor, are configured to implement the steps of the method embodiments of the present application.
An embodiment of the present application also provides a computer program product comprising a computer program which, when executed by a processor, implements the steps of the method embodiments of the present application.
Other embodiments of the present application will be apparent to those skilled in the art from consideration of the specification and practice of the invention disclosed herein. This application is intended to cover any variations, uses, or adaptations of the application following, in general, the principles of the application and including such departures from the present disclosure as come within known or customary practice within the art to which the application pertains. It is intended that the specification and examples be considered as exemplary only, with a true scope and spirit of the application being indicated by the following claims.
It is to be understood that the present application is not limited to the precise arrangements and instrumentalities shown in the drawings, which have been described above, and that various modifications and changes may be effected without departing from the scope thereof. The scope of the application is limited only by the appended claims.
Claims (10)
1. A reservoir fracturing monitoring system, comprising: the system comprises a signal generation module, a distributed optical fiber acoustic wave sensor, a distributed optical fiber temperature sensor, a distributed optical fiber strain sensor and a monitoring module;
the distributed optical fiber acoustic wave sensor, the distributed optical fiber temperature sensor and the distributed optical fiber strain sensor are respectively connected with the monitoring module; the distributed optical fiber acoustic wave sensor, the distributed optical fiber temperature sensor and the distributed optical fiber strain sensor are respectively connected with optical fibers in an armored optical cable, and the armored optical cable is fixedly sealed in a cement ring outside a shaft;
the signal generation module is used for transmitting optical signals to the optical fibers of the armored optical cable;
the distributed optical fiber acoustic wave sensor is used for receiving a first scattering signal generated after the optical signal is contacted with the optical fiber and sending the first scattering signal to the monitoring module;
the distributed optical fiber temperature sensor is used for receiving a second scattering signal generated after the optical signal is contacted with the optical fiber and sending the second scattering signal to the monitoring module;
The distributed optical fiber strain sensor is used for receiving a third scattering signal generated after the optical signal is contacted with the optical fiber and sending the third scattering signal to the monitoring module;
the monitoring module is used for receiving a first scattering signal sent by the distributed optical fiber acoustic wave sensor, determining sound data of a preset frequency band generated after liquid enters a liquid inlet cluster corresponding to each perforation of a shaft according to the first scattering signal, and generating a first corresponding relation between the optical fiber depth of each liquid inlet cluster and the sound data of the preset frequency band; receiving a first scattering signal sent by a distributed optical fiber temperature sensor, determining temperature data generated after liquid enters liquid inlet clusters corresponding to all perforation holes of a shaft according to the second scattering signal, and generating a second corresponding relation between the optical fiber depth of each liquid inlet cluster and the temperature data; receiving a third scattering signal sent by a distributed optical fiber strain sensor, determining strain data generated after liquid enters liquid inlet clusters corresponding to all perforation holes of a shaft according to the third scattering signal, and generating a third corresponding relation between the optical fiber depth of each liquid inlet cluster and the strain data; and displaying the first corresponding relation, the second corresponding relation and the third corresponding relation.
2. A method of monitoring with the reservoir fracturing monitoring system of claim 1, comprising:
receiving a first scattering signal sent by a distributed optical fiber acoustic wave sensor, determining sound data of a preset frequency band generated after liquid enters a liquid inlet cluster corresponding to each perforation of a shaft according to the first scattering signal, and generating a first corresponding relation between the optical fiber depth of each liquid inlet cluster and the sound data of the preset frequency band;
receiving a first scattering signal sent by a distributed optical fiber temperature sensor, determining temperature data generated after liquid enters liquid inlet clusters corresponding to all perforation holes of a shaft according to the second scattering signal, and generating a second corresponding relation between the optical fiber depth of each liquid inlet cluster and the temperature data;
receiving a third scattering signal sent by a distributed optical fiber strain sensor, determining strain data generated after liquid enters liquid inlet clusters corresponding to all perforation holes of a shaft according to the third scattering signal, and generating a third corresponding relation between the optical fiber depth of each liquid inlet cluster and the strain data;
and displaying the first corresponding relation, the second corresponding relation and the third corresponding relation.
3. The method according to claim 2, wherein the determining, according to the first scattering signal, sound data of a preset frequency band generated after the liquid enters the liquid inlet cluster corresponding to each perforation of the wellbore, specifically includes:
And filtering the first scattered signal by using the following formula to obtain sound data of a preset frequency band:
x b (t)＝F -1 [X(f)·G(f)]
wherein said x b (t) represents sound data of a preset frequency band, t represents time, F -1 Representing an inverse fourier transform, said X (f) representing a frequency domain expression of said first scattered signal X (t), said
The f represents the frequency of the sound wave, the f 1 Representing the lowest frequency of the preset frequency band, the f 2 Representing the highest frequency of the preset frequency band, the f 0 ＝(f 1 +f 2 ) And 2, the sigma represents the standard deviation of a Gaussian function, and the A is a constant.
4. The method of claim 3, wherein determining temperature data generated after the liquid enters the liquid inlet cluster corresponding to each perforation of the wellbore according to the second scattering signal specifically comprises:
determining an initial temperature corresponding to the second scattered signal;
and carrying out superposition and averaging on the initial temperature by using the following formula to obtain temperature data generated after liquid enters liquid inlet clusters corresponding to all perforation of the shaft:
wherein T (h) represents temperature data, h represents fiber depth, T i (h) Represents the initial temperature acquired for the i-th sampling interval, and n represents the number of sampling intervals.
5. The method of claim 4, wherein determining strain data generated after the fluid enters the fluid intake cluster corresponding to each perforation of the wellbore based on the third scattering signal, specifically comprises:
processing the third scattered signal to determine strain data generated after the fluid enters the fluid inlet cluster corresponding to each perforation of the wellbore using the following formula:
wherein μ represents t n Strain data of the wellbore at a time, the
Representing the brillouin shift amount caused by unit microstrain, said +.>
The U represents the value from t 1 From time to t n Brillouin shift amount generated at time, u=u n -u 1 The u is n Representing t n A third scattered signal of the moment of time, u 1 Representing t 1 A third scattered signal of time, T n Representing t n Temperature data generated at the moment, T 1 Representing t 1 Temperature data generated at the moment, said +.>
The brillouin shift amount due to the unit temperature is shown.
6. The method according to any one of claims 2-5, wherein the fiber depth of the feed clusters is obtained by:
determining perforation positions corresponding to all perforations of a shaft;
and determining the optical fiber depth of the liquid inlet cluster corresponding to each perforation of the well bore according to the perforation positions.
7. The method of claim 6, wherein determining the fiber depth of the fluid feed clusters corresponding to each perforation of the wellbore according to the perforation location, specifically comprises:
determining the optical fiber depth of the liquid inlet cluster corresponding to each perforation of the shaft by using the following formula:
L＝h-l
the L represents the optical fiber depth of the liquid inlet cluster, the h represents the preset optical fiber depth of the liquid inlet cluster, and the h represents the optical fiber calibration depth; l= |h '-H' | where H 'represents a preset average perforation interval depth and H' represents an actual average perforation interval depth;
the delta H i Represents the i-th preset perforation interval depth, wherein n represents the perforation times and delta H i ＝H i+1 -H i The H is i Representing a preset depth of the ith perforation; />
The Deltah is i Represents the ith actual perforation interval depth, deltah i ＝h i+1 -h i Said h is i Indicating the actual depth of the ith perforation.
8. An apparatus for monitoring with a reservoir fracturing monitoring system comprising a processor and a memory communicatively coupled to the processor;
the memory stores computer-executable instructions;
the processor executes computer-executable instructions stored in the memory to implement the method of any one of claims 2 to 7.
9. A computer readable storage medium having stored therein computer executable instructions which when executed by a processor are adapted to carry out the method of any one of claims 2 to 7.
10. A computer program product comprising a computer program which, when executed by a processor, implements the method of any of claims 2-7.
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