CN113074861A - Stratum fracture time monitoring method, device, equipment and storage medium - Google Patents
Stratum fracture time monitoring method, device, equipment and storage medium Download PDFInfo
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Abstract
The application discloses a method, a device, equipment and a storage medium for monitoring formation fracture time, and belongs to the field of oil and gas exploitation. The method comprises the following steps: acquiring the pumping pressure of the fracturing fluid in real time; drawing a first curve of the pumping pressure of the fracturing fluid along with the change of time according to the pumping pressure acquired in real time and the acquisition time point corresponding to each pumping pressure; performing wavelet transformation on the first curve to obtain a second curve, wherein the second curve is used for reflecting the singularity of the first curve; and displaying the second curve, wherein the time point corresponding to the inflection point in the second curve is the time point of the formation fracture, so that the delay between the determined time point and the real time point of the formation fracture is reduced, and the time of the formation fracture can be more accurately determined.
Description
Technical Field
The application relates to the field of oil and gas exploitation, in particular to a method, a device, equipment and a storage medium for monitoring formation fracture time.
Background
Hydraulic fracturing is the injection of a fracturing fluid into a subterranean formation at a rate that exceeds the absorptive capacity of the formation, causing the formation to fracture and create fractures. Hydraulic fracturing is a common means for realizing the yield increase of oil and gas wells, improves the system seepage environment of the stratum, shortens the distance of oil and gas resources from flowing to high-diversion cracks, and realizes the effective utilization of the oil and gas resources.
When the stratum is broken, a small earthquake usually occurs, and at present, microseism monitoring equipment is often adopted to monitor whether the stratum has the small earthquake or not so as to determine the fracturing effect of hydraulic fracturing. However, the time point when the micro-seismic monitoring device monitors a small earthquake is affected by the distance between the earthquake source and the micro-seismic monitoring device, so that the stratum fracture time determined by the micro-seismic monitoring device is delayed and inaccurate.
Disclosure of Invention
The embodiment of the application provides a method, a device, equipment and a storage medium for monitoring stratum fracture time, which can more accurately determine the time of stratum fracture. The technical scheme provided by the embodiment of the application is as follows:
in one aspect, a method of monitoring formation fracture time is provided, the method comprising:
acquiring the pumping pressure of the fracturing fluid in real time;
drawing a first curve of the pumping pressure of the fracturing fluid along with the change of time according to the pumping pressure acquired in real time and the acquisition time point corresponding to each pumping pressure;
performing wavelet transformation on the first curve to obtain a second curve, wherein the second curve is used for reflecting the singularity of the first curve;
and displaying the second curve, wherein the time point corresponding to the inflection point in the second curve is the time point of the formation fracture.
In one possible implementation, the method further includes:
determining a time point corresponding to an inflection point in the second curve as a time point of the formation fracture;
displaying a formation fracture indicator at the inflection point in the second curve.
In one possible implementation, the method further includes:
collecting the pumping capacity of the fracturing fluid in real time;
drawing a third curve of the pumping capacity of the fracturing fluid along with the change of time according to the collected pumping capacity and the collection time point corresponding to each pumping capacity;
and displaying the third curve.
In one possible implementation, the method further includes:
acquiring a time point corresponding to an inflection point in the second curve;
determining whether the pumping capacity of the fracturing fluid changes at the time point based on the third curve;
and if the pumping capacity of the fracturing fluid is not changed at the time point, determining the time point as the time point when the stratum is fractured.
In one possible implementation, the wavelet transforming the first curve to obtain a second curve of detail coefficients varying with time includes:
and performing N-level wavelet transformation on the first curve to obtain the second curve, wherein N is any integer greater than or equal to 1.
In one possible implementation, N is any integer greater than or equal to 8 and less than or equal to 12.
In one possible implementation, the real-time collecting of the pumping pressure of the fracturing fluid includes:
and acquiring the pumping pressure of the fracturing fluid according to the reference acquisition frequency.
In one aspect, a formation fracture time monitoring apparatus is provided, the apparatus comprising:
the acquisition module is used for acquiring the pumping pressure of the fracturing fluid in real time;
the drawing module is used for drawing a first curve of the pumping pressure of the fracturing fluid along with the change of time according to the pumping pressure acquired in real time and the acquisition time point corresponding to each pumping pressure;
the processing module is used for performing wavelet transformation on the first curve to obtain a second curve, and the second curve is used for reflecting the singularity of the first curve;
and the display module is used for displaying the second curve, and the time point corresponding to the inflection point in the second curve is the time point of the formation fracture.
In one possible implementation, the apparatus further includes:
a first determining module, configured to determine a time point corresponding to an inflection point in the second curve as a time point when the formation fractures;
the display module is further configured to display a formation fracture indicator at the inflection point in the second curve.
In one possible implementation, the apparatus further includes:
the acquisition module is also used for acquiring the pumping capacity of the fracturing fluid in real time;
the drawing module is further used for drawing a third curve of the pumping capacity of the fracturing fluid along with the change of time according to the collected pumping capacity and the collection time point corresponding to each pumping capacity;
the display module is further configured to display the third curve.
In one possible implementation, the apparatus further includes:
the acquisition module is used for acquiring a time point corresponding to an inflection point in the second curve;
a second determination module for determining whether the pumping capacity of the fracturing fluid changes at the time point based on the third curve;
and the third determination module is used for determining the time point as the time point when the stratum is fractured if the pumping capacity of the fracturing fluid is not changed at the time point.
In a possible implementation manner, the processing module is configured to perform N-level wavelet transform on the first curve to obtain the second curve, where N is any integer greater than or equal to 1.
In one possible implementation, N is any integer greater than or equal to 8 and less than or equal to 12.
In one possible implementation manner, the acquisition module is configured to acquire the pumping pressure of the fracturing fluid according to a reference acquisition frequency.
In one aspect, a computer apparatus is provided, the computer apparatus comprising a processor and a memory, the memory having stored therein at least one program code, the at least one program code being loaded into and executed by the processor to perform operations performed in a method of formation fracture time monitoring as described in the preceding aspect.
In one aspect, a computer-readable storage medium having at least one program code stored therein is provided, the at least one program code being loaded into and executed by a processor to perform the operations performed in the formation fracture time monitoring method according to the above aspect.
In one aspect, a computer program is provided, in which at least one program code is stored, and the at least one program code is loaded and executed by a processor to implement the operations performed in the image processing method according to the above aspect.
The beneficial effects brought by the technical scheme provided by the embodiment of the application at least comprise:
the embodiment of the application provides a method, a device, equipment and a storage medium for monitoring stratum fracture time, if a stratum is fractured in the hydraulic fracturing process, instantaneous sudden change of pump injection pressure can be caused, so that a pump injection pressure curve is discontinuous, namely the pump injection pressure curve has singularity.
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In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings needed to be used in the description of the embodiments are briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present application, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.
FIG. 1 is a schematic diagram of an implementation environment shown in accordance with an exemplary embodiment;
FIG. 2 is a flow chart illustrating a method of formation fracture time monitoring in accordance with an exemplary embodiment;
FIG. 3 is a flow chart illustrating a method of formation fracture time monitoring in accordance with an exemplary embodiment;
FIG. 4 is a flow chart illustrating a method of formation fracture time monitoring in accordance with an exemplary embodiment;
FIG. 5 is a flow chart illustrating a method of formation fracture time monitoring in accordance with an exemplary embodiment;
FIG. 6 is a schematic illustration of a formation fracture time monitoring apparatus according to an exemplary embodiment;
FIG. 7 is a schematic diagram illustrating the construction of another formation fracture time monitoring apparatus in accordance with an exemplary embodiment;
FIG. 8 is a block diagram illustrating a terminal in accordance with an exemplary embodiment;
fig. 9 is a schematic diagram illustrating a configuration of a server according to an example embodiment.
Detailed Description
To make the objects, technical solutions and advantages of the present application more clear, embodiments of the present application will be described in further detail below with reference to the accompanying drawings.
It will be understood that, as used herein, the terms "first," "second," "third," "fourth," "fifth," "sixth," and the like may be used herein to describe various concepts, which are not limited by these terms unless otherwise specified. These terms are only used to distinguish one concept from another. For example, a first curve may be referred to as a second curve, and a second curve may be referred to as a first curve without departing from the scope of the present application.
As used herein, the terms "each," "plurality," "at least one," "any," and the like, at least one of which comprises one, two, or more than two, and a plurality of which comprises two or more than two, each refer to each of the corresponding plurality, and any refer to any one of the plurality. For example, the plurality of pumping pressures includes 3 pumping pressures, each of which refers to each of the 3 pumping pressures, and any one of the 3 pumping pressures may be the first, the second, or the third.
The stratum fracture time monitoring method provided by the embodiment of the application is applied to computer equipment. In one possible implementation, the computer device is a terminal, e.g., a cell phone, a tablet, a computer, etc. In another possible implementation, the computer device includes a terminal and a server.
Fig. 1 is a schematic diagram illustrating an implementation environment according to an example embodiment, as shown in fig. 1, the implementation environment includes a terminal 101 and a server 102. The terminal 101 and the server 102 are connected by a wireless or wired network.
The terminal 101 has installed thereon a target application served by the server 102, through which the terminal 101 can implement functions such as data transmission, message interaction, and the like. Optionally, the terminal 101 is a computer, a mobile phone, a tablet computer, or other terminal. Optionally, the target application is a target application in an operating system of the terminal 101, or a target application provided by a third party. Optionally, the server 102 is a background server of the target application or a cloud server providing services such as cloud computing and cloud storage.
The method comprises the steps that a terminal 101 collects pumping pressure of fracturing fluid in real time, the collected pumping pressure is uploaded to a server 102, the server draws a first curve of the pumping pressure of the fracturing fluid along with time according to the pumping pressure collected by the terminal 101, wavelet transformation is conducted on the first curve to obtain a second curve, and the second curve is sent to the terminal 101. The terminal 101 displays the second curve.
The stratum fracture time monitoring method provided by the embodiment of the application can be applied to the scene of oil and gas exploitation.
For example, in scenarios where the effectiveness of fracturing is evaluated.
The fracturing method has the advantages that the fracturing effect is better if the fracturing time monitoring method for the stratum provided by the embodiment of the application is adopted, the fracturing time of the stratum can be determined in time, namely the fracturing time, the fracturing effect can be determined in time, the construction parameters can be adjusted in time according to the fracturing effect, and the exploitation cost is reduced.
As another example, the method is applied to a casing deformation prevention and control measure optimization scene.
In the hydraulic fracturing process, if stratum is broken, a small earthquake can be generated, so that the deformation of a sleeve can be caused, and if the sleeve is not processed in time, the problems such as sleeve damage and the like can be caused.
It should be noted that, in the embodiment of the present application, only a scenario for evaluating a fracturing effect and a scenario for optimizing casing deformation prevention and control measures are taken as examples, a scenario for exploiting oil and gas is described, and an application scenario of the present application is not limited.
FIG. 2 is a flow chart illustrating a method of formation fracture time monitoring, see FIG. 2, applied to a terminal, according to an exemplary embodiment, the method including:
201. and collecting the pumping pressure of the fracturing fluid in real time.
The fracturing fluid is a working fluid used for hydraulic fracturing reconstruction of a hydrocarbon reservoir and mainly has the function of transmitting high pressure formed by ground equipment to a stratum so as to crack the stratum to form a crack.
The pumping pressure of the fracturing fluid is a mechanical response under specific pumping capacity, specific proppant concentration, specific wellbore and formation conditions, and is comprehensively influenced by geological and construction engineering factors.
For example, when a fracturing fluid is injected into a formation, the pressure of the formation may be altered and fed back to the pressure applied by the fracturing fluid into the formation, i.e., the pressure of the formation is equal to the pressure applied by the fracturing fluid into the formation. Thus, pressure recovery from the formation may be achieved by pumping pressure of the fracturing fluid.
Optionally, the real-time acquiring of the pumping pressure of the fracturing fluid comprises: and measuring the pressure of the wellhead of the construction well by using a pressure measuring instrument, wherein the construction well is used for injecting fracturing fluid.
202. And drawing a first curve of the pumping pressure of the fracturing fluid along with the change of time according to the pumping pressure acquired in real time and the acquisition time point corresponding to each pumping pressure.
Wherein, drawing a first curve of pumping pressure of the fracturing fluid over time comprises: and taking the acquired pumping pressure as a vertical coordinate, taking an acquisition time point corresponding to the pumping pressure as a horizontal coordinate, adding a point corresponding to the horizontal coordinate and the vertical coordinate in a coordinate system, and fitting and connecting the point with the existing first curve.
Alternatively, obtaining a first profile of pumping pressure of the fracturing fluid over time comprises: and taking the acquired pumping pressure as an abscissa, taking an acquisition time point corresponding to the pumping pressure as an ordinate, adding a point corresponding to the abscissa and the ordinate in a coordinate system, and fitting and connecting the point with the existing first curve.
Wherein, fitting and connecting a point with the existing first curve means: and fitting and connecting the point with the last point in the existing first curve.
203. And performing wavelet transformation on the first curve to obtain a second curve, wherein the second curve is used for reflecting the singularity of the first curve.
The variation of the pumping pressure can be divided into two categories: one is the pumping pressure changes caused by the injection of the fracturing fluid and the other is the pumping pressure changes caused by the formation fracturing. In the hydraulic fracturing process, as fracturing fluid is continuously injected into a stratum, the pumping pressure is continuously changed, but the change is continuous and stable, and when the fracturing fluid flows into a rock mechanics non-uniform area of the stratum, the hydraulic fracture also extends to the rock mechanics non-uniform area, so that the rock mechanics non-uniform area is dislocated, a small earthquake is caused, a large hydraulic fracture is generated, the pumping pressure is suddenly changed, and the change is transient and discontinuous.
Because the pumping pressure is influenced by the construction parameters and the stratum fracture, the construction parameters are continuous wave signals with similar frequencies, and the stratum fracture is transient wave signals with greatly different frequencies, the construction parameter signals and the stratum fracture signals can be separated by frequency analysis of the first curve. When the frequency of the stratum fracture signal jumps, the stratum fracture signal can be characterized as the stratum fracture with large energy level, namely the stratum fracture. Wherein the construction parameters are construction parameters of a hydraulic fracturing process.
In the embodiment of the application, the first curve is subjected to wavelet transformation, and a curve of the approximation coefficient changing with time and a curve of the detail coefficient changing with time are obtained, wherein the curve of the approximation coefficient changing with time is relatively smooth and represents the low-frequency part information of the first curve. And the curve variation amplitude of the detail coefficient along with the time variation is larger, and the high-frequency part information of the first curve is represented. Therefore, in the embodiment of the application, the curve of the approximation coefficient changing with time is used as a construction parameter signal, and the curve of the detail coefficient changing with time is used as a formation fracture signal.
Moreover, the curve of the detail coefficient changing along with the time can embody the singularity of the first curve. Wherein the singularity of the first curve indicates that the first curve is a discontinuous curve.
For example, when a fracturing fluid pump injects a fracturing fluid into a formation, the displacement of the fracturing fluid is generally stable, and if the formation is not fractured, the change of the pumping pressure is continuous and stable, and if the formation is fractured, the pumping pressure is suddenly changed when the formation is fractured, so that the curve of the change of the pumping pressure along with time is not continuous at the moment.
The fact that the curve of the change of the detail coefficient with time can embody the singularity of the first curve means that: when the first curve is discontinuous, an inflection point appears in the detail coefficient, that is, the time corresponding to the discontinuous part in the first curve is the same as the time corresponding to the inflection point in the second curve.
It should be noted that the second curve is drawn in real time according to the acquired data, that is, the computer device updates the first curve in real time according to the acquired pumping pressure and the acquisition time of the pumping pressure, and the second curve is updated in real time along with the real-time update of the first curve, thereby achieving the effect of updating the second curve in real time according to the acquired data.
204. And displaying a second curve, wherein the time point corresponding to the inflection point in the second curve is the time point of the formation fracture.
By displaying the second curve, the technician may observe the inflection point in the second curve, and the time corresponding to the inflection point, to determine the time at which the formation fractures.
The stratum fracture time monitoring method provided by the embodiment of the application can cause instantaneous sudden change of the pump injection pressure if the stratum is fractured in the hydraulic fracturing process, so that the pump injection pressure curve is discontinuous, namely the pump injection pressure curve has singularity.
FIG. 3 shows a flow chart of a formation fracture time monitoring method, applied to a terminal, with reference to FIG. 3, according to an exemplary embodiment, the method including:
301. and acquiring the pumping pressure and pumping displacement of the fracturing fluid in real time.
The step 301 is performed during hydraulic fracturing construction, that is, the pumping pressure and pumping displacement of the fracturing fluid are collected during the hydraulic fracturing construction.
The pump injection capacity refers to the volume of fracturing fluid injected into the stratum in unit time.
In one possible implementation, the real-time collection of the pumping pressure and the pumping displacement of the fracturing fluid comprises the following steps: and acquiring the pumping pressure and the pumping displacement of the fracturing fluid according to the reference acquisition frequency. Optionally, the reference acquisition frequency is 0.1 to 10000 pieces/second, for example, the reference acquisition frequency is 1 piece/second.
302. And drawing a first curve of the pumping pressure of the fracturing fluid along with the change of time according to the pumping pressure acquired in real time and the acquisition time point corresponding to each pumping pressure.
It should be noted that step 302 is the same as step 202, and is not described herein again.
303. And performing wavelet transformation on the first curve to obtain a second curve, wherein the second curve is used for reflecting the singularity of the first curve.
In one possible implementation, performing a wavelet transform on the first curve to obtain a second curve of detail coefficients varying with time includes: and performing N-level wavelet transformation on the first curve to obtain a second curve, wherein N is any integer greater than or equal to 1.
Optionally, N is any integer greater than or equal to 8 and less than or equal to 12.
304. And drawing a third curve of the pumping capacity of the fracturing fluid along with the change of time according to the pumping capacity acquired in real time and the acquisition time point corresponding to each pumping capacity.
Wherein, drawing a third curve of the pumping capacity of the fracturing fluid along with the change of time comprises: and taking the collected pump displacement as a vertical coordinate, taking a collection time point corresponding to the pump displacement as a horizontal coordinate, adding a point corresponding to the horizontal coordinate and the vertical coordinate in a coordinate system, and fitting and connecting the point with an existing third curve.
Alternatively, obtaining a third curve of pumping volume of the fracturing fluid over time comprises: and taking the acquired pump displacement as an abscissa, taking an acquisition time point corresponding to the pump displacement as an ordinate, adding a point corresponding to the abscissa and the ordinate in a coordinate system, and fitting and connecting the point with an existing third curve.
Wherein, fitting and connecting a point with an existing third curve means: and fitting and connecting the point with the last point in the existing third curve.
305. The second curve and the third curve are displayed.
By displaying the first curve and the third curve, technicians can observe inflection points in the second curve, time corresponding to the inflection points and points at which the pump injection displacement changes, the time at which the pump injection displacement changes, and if the time corresponding to a certain inflection point is very close to the time corresponding to the pump injection displacement, the pump injection pressure curve is possibly discontinuous due to the change of the pump injection displacement, and the inflection points appear on the second curve, so that the technicians can eliminate the abnormal points (inflection points) of the detail curve caused by the manual change of the pump injection displacement, and can more accurately determine the time of formation fracture.
Illustratively, hydraulic fracturing is started by a pump from 15:27 minutes, a second curve (d12) and a third curve (pump displacement) are plotted by acquiring pump injection pressure and pump injection displacement in real time, and are monitored by a microseismic monitoring device which acquires microseismic event points with energy levels of 1.31, 1.18, 0.84 at 16:31, 17:01, 18:00 minutes, respectively, and the three microseismic event points are: a microseism event point A, a microseism event point B and a microseism event point C; the distances from the shaft are 255m, 83m and 241m respectively. As shown in FIG. 4, the three microseismic event points are all located near the inflection point of the second curve, with corresponding second curve inflection times of 16:01, 16:34, and 17:42, respectively.
Illustratively, starting hydraulic fracturing from a pump at 7:49, stopping the pump midway due to equipment reasons, restarting the pump at 10:10, recovering hydraulic fracturing construction, drawing a second curve (d12) and a third curve (pump injection displacement) by acquiring pump injection pressure and pump injection displacement in real time, and monitoring by a microseism monitoring device, wherein the corresponding relation between the inflection point in the second curve and the microseism time point monitored by the microseism monitoring device is shown in the table 1, and the second curve is shown in the figure 5.
TABLE 1
It follows that the time at which a microseismic event point occurs is concentrated primarily near the inflection point of the second curve and generally lags behind the inflection point of the second curve. The reason is that the microseism event point has a certain distance from the shaft, so that the monitoring result has certain hysteresis, and the hysteresis time is positively correlated with the distance from the microseism event point to the shaft.
In addition, the embodiment of the application is only exemplified by displaying the second curve and the third curve, and in another embodiment, the terminal may further detect an inflection point and mark the inflection point, so that a technician can conveniently check the time corresponding to the inflection point. In one possible implementation, the method further comprises: determining a time point corresponding to an inflection point in the second curve as a time point when the formation fractures; a formation fracture indicator is displayed at an inflection point in the second curve. Alternatively, the formation fracture identification may be the time corresponding to the inflection point.
In other embodiments, the terminal can automatically determine from the third curve whether an inflection point in the second curve is caused by a fracture in the formation or as a result of a manual modification of the construction parameters. In another possible implementation, the method further includes: acquiring a time point corresponding to an inflection point in the second curve; determining whether the pumping capacity of the fracturing fluid changes at the time point or not based on the third curve; and if the pumping capacity of the fracturing fluid is not changed at the time point, determining the time point as the time point of the formation fracture.
Alternatively, the terminal may add the determined point in time at which the formation was fractured to a list of formation fracture times for viewing by a technician.
The stratum fracture time monitoring method provided by the embodiment of the application can cause instantaneous sudden change of the pump injection pressure if the stratum is fractured in the hydraulic fracturing process, so that the pump injection pressure curve is discontinuous, namely the pump injection pressure curve has singularity.
FIG. 6 is a schematic diagram illustrating the structure of a formation fracture time monitoring apparatus according to an exemplary embodiment, as shown in FIG. 6, the apparatus comprising:
the acquisition module 601 is used for acquiring the pumping pressure of the fracturing fluid in real time;
the drawing module 602 is configured to draw a first curve of changes of the pumping pressure of the fracturing fluid along with time according to the pumping pressure acquired in real time and the acquisition time point corresponding to each pumping pressure;
a processing module 603, configured to perform wavelet transformation on the first curve to obtain a second curve, where the second curve is used to represent singularity of the first curve;
and a display module 604, configured to display the second curve, where a time point corresponding to an inflection point in the second curve is a time point when the formation fractures.
As shown in fig. 7, in one possible implementation, the apparatus further includes:
a first determining module 605, configured to determine a time point corresponding to an inflection point in the second curve as a time point when the formation fractures;
the display module 604 is further configured to display a formation fracture indicator at the inflection point in the second curve.
In one possible implementation, the apparatus further includes:
the acquisition module 601 is further configured to acquire the pumping capacity of the fracturing fluid in real time;
the drawing module 602 is further configured to draw a third curve of the pumping capacity of the fracturing fluid along with time change according to the collected pumping capacity and the collection time point corresponding to each pumping capacity;
the display module 604 is further configured to display the third curve.
In one possible implementation, the apparatus further includes:
an obtaining module 606, configured to obtain a time point corresponding to an inflection point in the second curve;
a second determination module 607 for determining whether the pumping capacity of the fracturing fluid changes at the time point based on the third curve;
a third determining module 608, configured to determine the time point as a time point when the formation is fractured if the pumping capacity of the fracturing fluid is not changed at the time point.
In a possible implementation manner, the processing module 603 is configured to perform N-level wavelet transform on the first curve to obtain the second curve, where N is any integer greater than or equal to 1.
In one possible implementation, N is any integer greater than or equal to 8 and less than or equal to 12.
In a possible implementation manner, the acquisition module 601 is configured to acquire the pumping pressure of the fracturing fluid according to a reference acquisition frequency.
In an exemplary embodiment, there is also provided a computer apparatus comprising a processor and a memory having stored therein at least one program code, the at least one program code being loaded into and executed by the processor to carry out the operations performed in the method of formation fracture time monitoring according to the above aspect.
Optionally, the computer device is provided as a terminal. Fig. 8 is a block diagram illustrating a structure of a terminal according to an exemplary embodiment. The terminal 800 is used for executing the steps executed by the terminal in the above embodiments, and may be a portable mobile terminal, such as: a smart phone, a tablet computer, an MP3 player (Moving Picture Experts Group Audio Layer III, motion video Experts compression standard Audio Layer 3), an MP4 player (Moving Picture Experts Group Audio Layer IV, motion video Experts compression standard Audio Layer 4), a notebook computer, or a desktop computer. The terminal 800 may also be referred to by other names such as user equipment, portable terminal, laptop terminal, desktop terminal, etc.
Among them, the terminal 800 includes: a processor 801 and a memory 802.
The processor 801 may include one or more processing cores, such as a 4-core processor, an 8-core processor, and so forth. The processor 801 may be implemented in at least one hardware form of a DSP (Digital Signal Processing), an FPGA (Field-Programmable Gate Array), and a PLA (Programmable Logic Array). The processor 801 may also include a main processor and a coprocessor, where the main processor is a processor for Processing data in an awake state, and is also called a Central Processing Unit (CPU); a coprocessor is a low power processor for processing data in a standby state. In some embodiments, the processor 801 may be integrated with a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content required to be displayed on the display screen. In some embodiments, the processor 801 may further include an AI (Artificial Intelligence) processor for processing computing operations related to machine learning.
In some embodiments, the terminal 800 may further include: a peripheral interface 803 and at least one peripheral. The processor 801, memory 802 and peripheral interface 803 may be connected by bus or signal lines. Various peripheral devices may be connected to peripheral interface 803 by a bus, signal line, or circuit board. Specifically, the peripheral device includes: at least one of a radio frequency circuit 804, a touch screen display 805, a camera assembly 806, an audio circuit 807, a positioning assembly 808, and a power supply 809.
The peripheral interface 803 may be used to connect at least one peripheral related to I/O (Input/Output) to the processor 801 and the memory 802. In some embodiments, the processor 801, memory 802, and peripheral interface 803 are integrated on the same chip or circuit board; in some other embodiments, any one or two of the processor 801, the memory 802, and the peripheral interface 803 may be implemented on separate chips or circuit boards, which are not limited by this embodiment.
The Radio Frequency circuit 804 is used for receiving and transmitting RF (Radio Frequency) signals, also called electromagnetic signals. The radio frequency circuitry 804 communicates with communication networks and other communication devices via electromagnetic signals. The rf circuit 804 converts an electrical signal into an electromagnetic signal to be transmitted, or converts a received electromagnetic signal into an electrical signal. Optionally, the radio frequency circuit 804 includes: an antenna system, an RF transceiver, one or more amplifiers, a tuner, an oscillator, a digital signal processor, a codec chipset, a subscriber identity module card, and so forth. The radio frequency circuit 804 may communicate with other terminals via at least one wireless communication protocol. The wireless communication protocols include, but are not limited to: the world wide web, metropolitan area networks, intranets, generations of mobile communication networks (2G, 3G, 4G, and 5G), Wireless local area networks, and/or WiFi (Wireless Fidelity) networks. In some embodiments, the radio frequency circuit 804 may further include NFC (Near Field Communication) related circuits, which are not limited in this application.
The display screen 805 is used to display a UI (User Interface). The UI may include graphics, text, icons, video, and any combination thereof. When the display 805 is a touch display, the display 805 also has the ability to capture touch signals on or above the surface of the display 805. The touch signal may be input to the processor 801 as a control signal for processing. At this point, the display 805 may also be used to provide virtual buttons and/or a virtual keyboard, also referred to as soft buttons and/or a soft keyboard. In some embodiments, the display 805 may be one, providing the front panel of the terminal 800; in other embodiments, the display 805 may be at least two, respectively disposed on different surfaces of the terminal 800 or in a folded design; in still other embodiments, the display 805 may be a flexible display disposed on a curved surface or a folded surface of the terminal 800. Even further, the display 805 may be arranged in a non-rectangular irregular pattern, i.e., a shaped screen. The Display 805 can be made of LCD (Liquid Crystal Display), OLED (Organic Light-Emitting Diode), and other materials.
The camera assembly 806 is used to capture images or video. Optionally, camera assembly 806 includes a front camera and a rear camera. In some embodiments, the front camera is disposed on a front panel of the terminal and the rear camera is disposed on a rear side of the terminal. In some embodiments, the number of the rear cameras is at least two, and each rear camera is any one of a main camera, a depth-of-field camera, a wide-angle camera and a telephoto camera, so that the main camera and the depth-of-field camera are fused to realize a background blurring function, and the main camera and the wide-angle camera are fused to realize panoramic shooting and VR (Virtual Reality) shooting functions or other fusion shooting functions. In some embodiments, camera assembly 806 may also include a flash. The flash lamp can be a monochrome temperature flash lamp or a bicolor temperature flash lamp. The double-color-temperature flash lamp is a combination of a warm-light flash lamp and a cold-light flash lamp, and can be used for light compensation at different color temperatures.
The audio circuit 807 may include a microphone and a speaker. The microphone is used for collecting sound waves of a user and the environment, converting the sound waves into electric signals, and inputting the electric signals to the processor 801 for processing or inputting the electric signals to the radio frequency circuit 804 to realize voice communication. For the purpose of stereo sound collection or noise reduction, a plurality of microphones may be provided at different portions of the terminal 800. The microphone may also be an array microphone or an omni-directional pick-up microphone. The speaker is used to convert electrical signals from the processor 801 or the radio frequency circuit 804 into sound waves. The loudspeaker can be a traditional film loudspeaker or a piezoelectric ceramic loudspeaker. When the speaker is a piezoelectric ceramic speaker, the speaker can be used for purposes such as converting an electric signal into a sound wave audible to a human being, or converting an electric signal into a sound wave inaudible to a human being to measure a distance. In some embodiments, the audio circuitry 807 may also include a headphone jack.
The positioning component 808 is used to locate the current geographic position of the terminal 800 for navigation or LBS (Location Based Service). The Positioning component 808 may be a Positioning component based on the GPS (Global Positioning System) in the united states, the beidou System in china, or the graves System in russia, or the galileo System in the european union.
In some embodiments, terminal 800 also includes one or more sensors 810. The one or more sensors 810 include, but are not limited to: acceleration sensor 811, gyro sensor 812, pressure sensor 813, fingerprint sensor 814, optical sensor 815 and proximity sensor 816.
The acceleration sensor 811 may detect the magnitude of acceleration in three coordinate axes of the coordinate system established with the terminal 800. For example, the acceleration sensor 811 may be used to detect the components of the gravitational acceleration in three coordinate axes. The processor 801 may control the touch screen 805 to display the user interface in a landscape view or a portrait view according to the gravitational acceleration signal collected by the acceleration sensor 811. The acceleration sensor 811 may also be used for acquisition of motion data of a game or a user.
The gyro sensor 812 may detect a body direction and a rotation angle of the terminal 800, and the gyro sensor 812 may cooperate with the acceleration sensor 811 to acquire a 3D motion of the user with respect to the terminal 800. From the data collected by the gyro sensor 812, the processor 801 may implement the following functions: motion sensing (such as changing the UI according to a user's tilting operation), image stabilization at the time of photographing, game control, and inertial navigation.
The optical sensor 815 is used to collect the ambient light intensity. In one embodiment, the processor 801 may control the display brightness of the touch screen 805 based on the ambient light intensity collected by the optical sensor 815. Specifically, when the ambient light intensity is high, the display brightness of the touch display screen 805 is increased; when the ambient light intensity is low, the display brightness of the touch display 805 is turned down. In another embodiment, the processor 801 may also dynamically adjust the shooting parameters of the camera assembly 806 based on the ambient light intensity collected by the optical sensor 815.
Those skilled in the art will appreciate that the configuration shown in fig. 8 is not intended to be limiting of terminal 800 and may include more or fewer components than those shown, or some components may be combined, or a different arrangement of components may be used.
Optionally, the server is provided as a server. Fig. 9 is a block diagram illustrating a structure of a server 900 according to an example embodiment. The server 900 may have a relatively large difference due to different configurations or performances, and may include one or more processors (CPUs) 901 and one or more memories 902, where at least one program code is stored in the memory 902, and the at least one program code is loaded and executed by the processors 901 to implement the methods provided by the above method embodiments. Of course, the server may also have components such as a wired or wireless network interface, a keyboard, and an input/output interface, so as to perform input/output, and the server may also include other components for implementing the functions of the device, which are not described herein again.
The server 900 may be used to perform the steps performed by the server in the formation fracture time monitoring methods described above.
In an embodiment of the present application, there is also provided a computer readable storage medium having at least one program code stored therein, the at least one program code being loaded and executed by a processor to implement the operations performed in the method for monitoring formation fracture time as described in the above aspect.
In an embodiment of the present application, there is also provided a computer program, in which at least one program code is stored, and the at least one program code is loaded and executed by a processor to implement the operations executed in the image processing method according to the above aspects.
The above description is only for facilitating the understanding of the technical solutions of the present application by those skilled in the art, and is not intended to limit the present application. Any modification, equivalent replacement, improvement and the like made within the spirit and principle of the present application shall be included in the protection scope of the present application.
Claims (10)
1. A method of monitoring formation fracture time, the method comprising:
acquiring the pumping pressure of the fracturing fluid in real time;
drawing a first curve of the pumping pressure of the fracturing fluid along with the change of time according to the pumping pressure acquired in real time and the acquisition time point corresponding to each pumping pressure;
performing wavelet transformation on the first curve to obtain a second curve, wherein the second curve is used for reflecting the singularity of the first curve;
and displaying the second curve, wherein the time point corresponding to the inflection point in the second curve is the time point of the formation fracture.
2. The method of claim 1, further comprising:
determining a time point corresponding to an inflection point in the second curve as a time point of the formation fracture;
displaying a formation fracture indicator at the inflection point in the second curve.
3. The method of claim 1, further comprising:
collecting the pumping capacity of the fracturing fluid in real time;
drawing a third curve of the pumping capacity of the fracturing fluid along with the change of time according to the pumping capacity acquired in real time and the acquisition time point corresponding to each pumping capacity;
and displaying the third curve.
4. The method of claim 3, further comprising:
acquiring a time point corresponding to an inflection point in the second curve;
determining whether the pumping capacity of the fracturing fluid changes at the time point based on the third curve;
and if the pumping capacity of the fracturing fluid is not changed at the time point, determining the time point as the time point when the stratum is fractured.
5. The method of claim 1, wherein the wavelet transforming the first curve to obtain a second curve comprises:
and performing N-level wavelet transformation on the first curve to obtain the second curve, wherein N is any integer greater than or equal to 1.
6. The method according to claim 5, wherein N is any integer of 8 or more and 12 or less.
7. The method of claim 1, wherein the collecting in real time the pumping pressure of the fracturing fluid comprises:
and acquiring the pumping pressure of the fracturing fluid according to the reference acquisition frequency.
8. A formation fracture time monitoring apparatus, the apparatus comprising:
the acquisition module is used for acquiring the pumping pressure of the fracturing fluid in real time;
the drawing module is used for drawing a first curve of the pumping pressure of the fracturing fluid along with the change of time according to the pumping pressure acquired in real time and the acquisition time point corresponding to each pumping pressure;
the processing module is used for performing wavelet transformation on the first curve to obtain a second curve, and the second curve is used for reflecting the singularity of the first curve;
and the display module is used for displaying the second curve, and the time point corresponding to the inflection point in the second curve is the time point of the formation fracture.
9. A computer device comprising a processor and a memory, the memory having stored therein at least one program code, the at least one program code being loaded into and executed by the processor to perform the operations of the method of monitoring formation fracture time according to any of claims 1 to 7.
10. A computer readable storage medium having at least one program code stored therein, the at least one program code being loaded into and executed by a processor to perform the operations of the method for monitoring formation fracture time according to any of claims 1 to 7.
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