Fracturing fluid intrusion detection method and device, electronic equipment and storage medium

Abstract

The embodiment of the invention discloses a fracturing fluid intrusion detection method and device, electronic equipment and a storage medium. The method comprises the following steps: configuring a target rock core in a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance testing system, and performing a fracturing fluid injection test on the target rock core in a uniform nuclear magnetic field corresponding to the nuclear magnetic resonance tester to obtain first nuclear magnetic resonance signal change information along with time; performing a fracturing fluid injection test on the target rock core in a gradient nuclear magnetic field corresponding to the nuclear magnetic resonance tester to obtain multiple pieces of second nuclear magnetic resonance signal change information along with time; and based on the first nuclear magnetic resonance signal change information and the multiple pieces of second nuclear magnetic resonance signal change information, the invasion depth and invasion amount of the fracturing fluid in the shale reservoir are determined. According to the technical scheme of the embodiment of the invention, the invasion depth and invasion amount of the fracturing fluid are calculated according to the uniform nuclear magnetic test and gradient nuclear magnetic test signal change information, and the efficiency and accuracy of calculating the consumption of the fracturing fluid and predicting the flowback rate during drilling operation are improved.

Description

Technical Field

[0001] The embodiments of the present application relate to the technical field of shale gas exploration and development, and in particular to a fracturing fluid intrusion detection method, device, electronic device, and storage medium. Background Art

[0002] Shale gas, with its abundant resources, has become a key area for increasing reserves and production of unconventional natural gas. Shale reservoirs have low matrix permeability, making large-scale volume fracturing a key to shale gas well development. Injecting fracturing fluid into the formation opens up a vast network of fractures, significantly increasing the matrix's drainage area.

[0003] Microseismic estimates indicate that the contact area between fractures and reservoirs can reach millions of square meters. The flowback rate of fracturing fluid in most shale reservoirs is less than 50%, and in some reservoirs, even less than 5%. The injected water that does not flow back is believed to be absorbed into the surrounding shale matrix, microfractures, and other fracture networks through various mechanisms. Therefore, after years of development, a large amount of fracturing fluid remains permanently trapped in the fractures and matrix. The injection and retention of external fracturing fluid causes the fractures and the matrix adjacent to the fractures to undergo a gas-liquid-solid three-phase interaction, triggering hydration of clay minerals in the reservoir and altering the reservoir's pore structure and permeability. Therefore, accurately determining the penetration depth of fracturing fluid into the matrix is ​​crucial for calculating fracturing fluid dosage, predicting flowback rates, and optimizing well shut-down time and flowback strategies. Summary of the Invention

[0004] The present application provides a fracturing fluid intrusion detection method, device, electronic device and storage medium. The technical solution of the embodiments of the present application calculates the fracturing fluid intrusion depth and intrusion volume through uniform nuclear magnetic resonance testing and gradient nuclear magnetic resonance testing signal change information, thereby improving the efficiency and accuracy of calculating fracturing fluid usage and predicting return flow rate during drilling operations.

[0005] According to one aspect of the present application, a fracturing fluid intrusion detection method is provided, which is applied to a fracturing fluid intrusion detection device, wherein the fracturing fluid intrusion detection device is disposed at a well site and / or a base data center. The method comprises:

[0006] The target rock core is placed in a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance test system, wherein the target rock core is a cylindrical rock sample taken from a shale reservoir;

[0007] Performing a fracturing fluid injection test on the target rock core in a uniform nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain first nuclear magnetic resonance signal change information over time, wherein the radio frequency acting on different positions of the target rock core in the uniform nuclear magnetic field is the same;

[0008] The target rock core is subjected to a fracturing fluid injection test in a gradient nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain a plurality of second nuclear magnetic resonance signal change information over time, wherein the radio frequency frequencies acting on different positions of the target rock core under the gradient nuclear magnetic field are different, and the nuclear magnetic resonance signal is a base nuclear magnetic signal;

[0009] Based on the first nuclear magnetic resonance signal change information and the plurality of second nuclear magnetic resonance signal change information, the fracturing fluid invasion depth and invasion amount in the shale reservoir are determined.

[0010] According to another aspect of the present application, a fracturing fluid intrusion detection device is provided, which is configured in a fracturing fluid intrusion detection device, wherein the fracturing fluid intrusion detection device is set at a well site and / or a base data center, and the device includes:

[0011] A target configuration module is used to configure a target rock core into a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance test system, wherein the target rock core is a cylindrical rock sample taken from a shale reservoir;

[0012] a uniform nuclear magnetic resonance testing module, configured to inject fracturing fluid into the target rock core in a uniform nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain time-dependent first nuclear magnetic resonance signal variation information, wherein the radio frequency acting on different positions of the target rock core in the uniform nuclear magnetic field is the same;

[0013] A gradient nuclear magnetic resonance testing module is used to perform a fracturing fluid injection test on the target rock core in a gradient nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain information on changes in multiple second nuclear magnetic resonance signals over time. The radio frequency frequencies acting on different positions of the target rock core under the gradient nuclear magnetic field are different, and the nuclear magnetic resonance signals are basement nuclear magnetic signals.

[0014] The invasion detection module determines the invasion depth and invasion amount of the fracturing fluid in the shale reservoir based on the first nuclear magnetic resonance signal change information and the plurality of second nuclear magnetic resonance signal change information.

[0015] According to another aspect of the present application, an electronic device is provided, comprising:

[0016] at least one processor; and

[0017] a memory communicatively connected to the at least one processor; wherein,

[0018] The memory stores a computer program executable by the at least one processor, and the computer program is executed by the at least one processor so that the at least one processor can execute the fracturing fluid intrusion detection method described in any embodiment of the present application.

[0019] According to another aspect of an embodiment of the present application, a computer-readable storage medium is provided, wherein the computer-readable storage medium stores computer instructions, and the computer instructions are used to enable a processor to implement the fracturing fluid intrusion detection method described in any embodiment of the present application when executed.

[0020] The present invention discloses a method for detecting fracturing fluid invasion, comprising: placing a target rock core in a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance test system, injecting fracturing fluid into the target rock core in a uniform nuclear magnetic field corresponding to the nuclear magnetic resonance tester to obtain first nuclear magnetic resonance signal change information over time; injecting fracturing fluid into the target rock core in a gradient nuclear magnetic field corresponding to the nuclear magnetic resonance tester to obtain multiple second nuclear magnetic resonance signal change information over time; and determining the fracturing fluid invasion depth and invasion volume in a shale reservoir based on the first nuclear magnetic resonance signal change information and the multiple second nuclear magnetic resonance signal change information. The technical solution of the present invention is to establish a nuclear magnetic resonance method to simulate the contact between the fracturing fluid and the reservoir matrix at the fracture surface under the conditions of formation temperature, pressure, stress and original water and gas content, and to monitor the imbibition distance of the fracturing fluid at different times in real time based on the nuclear magnetic resonance test, thereby obtaining the variation law of the high-pressure invasion depth of the fracturing fluid, calculating the fracturing fluid invasion depth and invasion volume, and improving the efficiency and accuracy of calculating the fracturing fluid dosage and predicting the return rate during drilling operations.

[0021] It should be understood that the content described in this section is not intended to identify the key or important features of the embodiments of the present application, nor is it intended to limit the scope of the embodiments of the present application. Other features of the embodiments of the present application will become easy to understand through the following description. BRIEF DESCRIPTION OF THE DRAWINGS

[0022] In order to more clearly illustrate the technical solutions in the embodiments of the present application, the following briefly introduces the drawings required for use in the description of the embodiments. Obviously, the drawings described below are only some embodiments of the embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without any creative work.

[0023] Figure 1 This is a flow chart of a fracturing fluid intrusion detection method provided in accordance with an embodiment of the present application;

[0024] Figure 2 1 is a schematic structural diagram of a high-temperature and high-pressure nuclear magnetic resonance system provided according to an embodiment of the present application;

[0025] Figure 3 is a graph of total signal quantity test results provided according to an embodiment of the present application;

[0026] Figure 4is a curve chart of layered signal quantity test results provided according to an embodiment of the present application;

[0027] Figure 5 is a calibration curve diagram of water content and signal quantity provided according to an embodiment of the present application;

[0028] Figure 6 is a curve diagram of signal quantity changes at different positions provided by an embodiment of the present application;

[0029] Figure 7 is a curve diagram of the change of the penetration depth of the fracturing fluid at different injection times provided in an embodiment of the present application;

[0030] Figure 8 1 is a schematic structural diagram of a fracturing fluid intrusion detection device provided according to an embodiment of the present application;

[0031] Figure 9 Schematic diagram of the structure of an electronic device for implementing the fracturing fluid intrusion detection method according to an embodiment of the present application. DETAILED DESCRIPTION

[0032] In order to enable those skilled in the art to better understand the embodiments of the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below in conjunction with the drawings in the embodiments of the present application. Obviously, the described embodiments are only part of the embodiments of the present application, not all of the embodiments. Based on the embodiments of the present application, all other embodiments obtained by ordinary technicians in this field without making creative efforts should fall within the scope of protection of the embodiments of the present application.

[0033] It should be noted that the terms "first", "second", etc. in the description and claims of the embodiments of the present application and the above-mentioned drawings are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchangeable where appropriate, so that the embodiments of the embodiments of the present application described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any variations thereof are intended to cover non-exclusive inclusions, for example, a process, method, system, product or device comprising a series of steps or units is not necessarily limited to those steps or units clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0034] Figure 1This is a flow chart of a fracturing fluid intrusion detection method provided in an embodiment of the present application. This embodiment is applicable to the detection of fracturing fluid intrusion during drilling operations. The method can be performed by a fracturing fluid intrusion detection device. The fracturing fluid intrusion detection device can be implemented in the form of hardware and / or software. The fracturing fluid intrusion detection device can be configured in any electronic device with network communication capabilities. Figure 1 As shown, the method includes:

[0035] S110. Place the target rock core in a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance test system, wherein the target rock core is a cylindrical rock sample taken from a shale reservoir.

[0036] In the embodiment of the present application, the core is a cylindrical rock sample taken from a shale reservoir, and the target core is the experimental research object. The experiment is to detect the degree of fracturing fluid invasion of the target core. Figure 2 As shown, the high-temperature, high-pressure nuclear magnetic resonance imaging analysis system is an analytical instrument used in the fields of earth science and mining engineering technology. It can statically analyze the structural characteristics of rock cores through two-dimensional nuclear magnetic resonance T2 spectrum T2-D imaging. In the embodiment of the present application, the high-temperature, high-pressure nuclear magnetic resonance tester can be used to obtain real-time measurement data related to the target rock core.

[0037] Optionally, placing the target core in a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance test system includes the following steps A1-A3:

[0038] Step A1: Use helium to perform a sealing test on the nuclear magnetic resonance test system.

[0039] Step A2: Use a standard sample to calibrate the test coil of the high-temperature and high-pressure nuclear magnetic resonance tester in the started nuclear magnetic resonance test system, and set the sampling parameters of the nuclear magnetic resonance test system so that the fluid nuclear magnetic signal intensity that can be sampled by the coil reaches the maximum value. The sampling parameters include center frequency, echo time and number of scans.

[0040] Step A3: Place the target rock core into a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance test system.

[0041] In the embodiment of the present application, helium is a rare gas that is colorless and odorless. It is difficult to react with other substances under normal conditions. Helium is used to test the tightness of the nuclear magnetic resonance system to ensure the accuracy of subsequent experimental data. Among them, the main function of the test coil of the nuclear magnetic resonance instrument is to receive the nuclear magnetic resonance signal and calibrate the test coil to make the subsequent test data more accurate. By setting the sampling parameters of the nuclear magnetic resonance test system, the coil receives the maximum value of the nuclear magnetic signal. The sampling parameters include the center frequency, echo time and number of scans. After the preparation is completed, the core is placed in the clamping system of the nuclear magnetic resonance tester for subsequent experimental operations.

[0042] Optionally, the target core is placed in a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance test system, including the following steps A31-A32:

[0043] Step A31: Place the target core in a thermoplastic tube that does not generate signals, fix it with the clamp at both ends, place it in the clamping system of the high-temperature and high-pressure nuclear magnetic resonance tester, heat it to the preset temperature, inject fluorine oil, add confining pressure, and control the confining pressure to the reservoir overburden pressure.

[0044] Step A32: injecting helium that does not generate a signal into the high-temperature and high-pressure nuclear magnetic resonance tester to simulate the original gas-containing state of the shale reservoir.

[0045] In the examples of the present application, it should be noted that the target core preparation process is to thoroughly dry the core at 105°C for more than 72 hours. After the core is cooled to room temperature in a drying container, the basic data of the sample such as length 6.82 cm, diameter 2.5 cm, dry weight 89.60 g, and porosity 3.39% are tested, and the original water saturation is established as 25%, so that the core is closer to the original state of the formation.

[0046] Then connect the NMR test system device, such as Figure 2 As shown, the nuclear magnetic resonance testing system includes a first chamber, a second chamber, a third chamber, a high-temperature and high-pressure nuclear magnetic resonance tester, and a back-pressure valve. The first chamber, the second chamber, and the third chamber are connected to the inlet of the high-temperature and high-pressure nuclear magnetic resonance tester through a valve, and the outlet of the high-temperature and high-pressure nuclear magnetic resonance tester is connected to the back-pressure valve. The first chamber, the second chamber, and the third chamber respectively carry formation water, fracturing fluid, and helium. The second chamber is opened, and the first and second chambers are closed, and the sealing of the system is tested with helium.

[0047] Turn on the nuclear magnetic resonance test system, calibrate the test coil using a standard sample, set the system's center frequency, echo time, scan times and other sampling parameters so that the coil can capture the maximum fluid nuclear magnetic resonance signal intensity. The test parameters and values ​​are sequence SFG-MSCPMG, frequency 1000kHz, RF delay 0.08ms, waiting time 2000ms, echo time 0.1ms, number of echoes 1889, number of layers 10, gradient climbing time 0.5ms, and gradient duration 200ms.

[0048] The core is then placed in a thermoplastic tube that does not generate a signal, fixed to both ends of the clamp, placed in the clamping system, heated to the set temperature, injected with fluorine oil and increased confining pressure, and the confining pressure is controlled to a reservoir overburden pressure of 40 MPa.

[0049] exist Figure 2 The device shown injects helium that does not generate signals to the original reservoir pressure to simulate the original gas-containing state of the shale reservoir.

[0050] S120. Perform a fracturing fluid injection test on the target rock core in a uniform nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain first nuclear magnetic resonance signal change information over time, wherein the radio frequency acting on different positions of the target rock core in the uniform nuclear magnetic field is the same.

[0051] In the embodiments of the present application, fracturing fluid refers to a heterogeneous and unstable chemical system formed by a certain ratio of multiple additives. It is a working fluid used in the fracturing of oil and gas layers. Its main function is to transmit the high pressure generated by the ground equipment to the formation, causing the formation to break and form cracks and transport proppant along the cracks, so that the well can achieve the purpose of increasing production and injection.

[0052] Optionally, a fracturing fluid injection test is performed on the target core in a uniform nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain first nuclear magnetic resonance signal change information over time, including the following steps B1-B2:

[0053] Step B1: applying a uniform nuclear magnetic field in a high-temperature and high-pressure nuclear magnetic resonance tester, and injecting fracturing fluid into the high-temperature and high-pressure nuclear magnetic resonance tester.

[0054] Step B2: During the fracturing fluid injection process, a CPMG test sequence is used to perform a fracturing fluid injection test on the target core in a uniform nuclear magnetic field to obtain first nuclear magnetic resonance signal change information over time.

[0055] In the embodiments of the present application, the uniform nuclear magnetic field means that the nuclear magnetic resonance system transmits the same radio frequency at different locations of the target core. The CPMG test sequence is a commonly used nuclear magnetic resonance imaging technology.

[0056] like Figure 3The figure shows the first nuclear magnetic resonance signal graph obtained by the fracturing fluid injection test under the action of a uniform magnetic field. The horizontal axis represents the time change and the vertical axis represents the signal intensity value. Each curve graph represents the signal intensity change over time measured at different static times.

[0057] Optionally, a uniform nuclear magnetic field is applied in the high-temperature and high-pressure nuclear magnetic resonance tester, and fracturing fluid is injected into the high-temperature and high-pressure nuclear magnetic resonance tester, including injecting fracturing fluid into the high-temperature and high-pressure nuclear magnetic resonance tester at a high pressure constant pressure greater than the pressure of the reservoir gas, to simulate the fracturing fluid injection process.

[0058] In the embodiments of the present application, it should be noted that the fracturing fluid is injected at a high and constant pressure to simulate the fracturing fluid injection process during drilling operations.

[0059] Set a uniform nuclear magnetic field, select the CPMG test sequence to test the core's basement nuclear magnetic signal, that is, the total T2 signal, and obtain the total signal measurement curve as shown below: Figure 3 shown.

[0060] S130. Perform a fracturing fluid injection test on the target rock core in a gradient nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain information on changes in multiple second nuclear magnetic resonance signals over time. The radio frequency frequencies acting on different positions of the target rock core under the gradient nuclear magnetic field are different, and the nuclear magnetic resonance signals are basement nuclear magnetic signals.

[0061] In the embodiment of the present application, the first NMR signal change information is data obtained by a uniform nuclear magnetic field test. The second NMR signal change information is data obtained under a gradient nuclear magnetic field, where the gradient nuclear magnetic field refers to the NMR system transmitting different radio frequencies at different locations on the target core, satisfying a certain mathematical linear change.

[0062] Optionally, the target core is subjected to a fracturing fluid injection test in a gradient nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain a plurality of second nuclear magnetic resonance signal change information over time, including the following steps C1-C3:

[0063] Step C1: applying a gradient nuclear magnetic field in a high-temperature and high-pressure nuclear magnetic resonance tester, and injecting fracturing fluid into the high-temperature and high-pressure nuclear magnetic resonance tester.

[0064] Step C2: During the fracturing fluid injection process, the target core is subjected to a fracturing fluid injection test in a gradient nuclear magnetic field using a SFG-MSCPMG test sequence to obtain a plurality of second nuclear magnetic resonance signal change information over time.

[0065] Step C3: The SFG-MSCPMG test sequence can apply a gradient nuclear magnetic field in the selected shale reservoir direction, configure different frequencies at different positions, excite with a specified radio frequency, and adjust the receiving coil frequency to be consistent with the radio frequency to collect CPMG signals.

[0066] In the embodiments of the present application, the gradient nuclear magnetic field refers to the NMR system transmitting different radio frequencies at different locations in the target core, satisfying a certain mathematical linear variation. SFG-MSCPMG and CPMG test sequences are commonly used NMR imaging techniques.

[0067] like Figure 4 The figure shows the second nuclear magnetic resonance signal graph that changes with time during the fracturing fluid injection test under the action of a gradient magnetic field. It is the test result of the layered base signal and displays a three-dimensional coordinate axis. The horizontal axis represents the time change, the vertical axis represents the signal intensity value, and the axial axis represents the core layer distance.

[0068] Optionally, a gradient nuclear magnetic field is applied in the high-temperature and high-pressure nuclear magnetic resonance tester, and fracturing fluid is injected into the high-temperature and high-pressure nuclear magnetic resonance tester, including injecting fracturing fluid into the high-temperature and high-pressure nuclear magnetic resonance tester at a high pressure constant pressure greater than the pressure of the reservoir gas, so as to simulate the fracturing fluid injection process.

[0069] In the embodiments of the present application, it should be noted that the fracturing fluid is injected at a high and constant pressure to simulate the fracturing fluid injection process during drilling operations.

[0070] Set up the gradient nuclear magnetic field and select the SFG-MSCPMG sequence. After the SFG-MSCPMG sequence applies a gradient magnetic field in the direction of the selected layer, the frequencies at different positions are different. The RF frequency is used for excitation. The receiving coil frequency is adjusted to be consistent with the RF frequency. The CPMG signal is collected to obtain T2 information at different positions. The GA0 and P2 values ​​are reasonably adjusted according to the actual selected layer thickness. The 0-1cm layer signal of the core is tested. Then the receiving coil frequency is adjusted to test the 1-2cm signal. This is repeated to complete the test of the layer base signal of the entire core. The layer signal test curve is obtained as shown below. Figure 4 shown.

[0071] S140. Determine the invasion depth and invasion amount of the fracturing fluid in the shale reservoir based on the first nuclear magnetic resonance signal change information and the plurality of second nuclear magnetic resonance signal change information.

[0072] In the embodiment of the present application, the first nuclear magnetic resonance signal change information is the total signal amount test result such as Figure 3 As shown, the second NMR signal change information is the layered signal quantity test result as shown in Figure 4 As shown. The penetration depth and penetration amount of fracturing fluid are determined according to Figure 3 and Figure 4The test results are confirmed.

[0073] Optionally, determining the fracturing fluid invasion depth and invasion amount in the shale reservoir based on the first nuclear magnetic resonance signal change information and the plurality of second nuclear magnetic resonance signal change information includes the following steps D1-D2:

[0074] Step D1, determining a preset calibration curve, wherein the preset calibration curve is a calibration curve of water content and signal quantity established by using signals of different water amounts tested in a standard container, and is used to calculate water intrusion amount using nuclear magnetic resonance signals.

[0075] Step D2: determining the invasion depth and invasion amount of the fracturing fluid in the shale reservoir based on the first nuclear magnetic resonance signal change information, the plurality of second nuclear magnetic resonance signal change information, and a preset calibration curve.

[0076] In the embodiment of the present application, a calibration curve diagram of water content and signal quantity is established by testing signals of different water amounts in a standard container. The main purpose is to provide a basis for the subsequent calculation of the fracturing fluid invasion amount using the first nuclear magnetic signal quantity and the second nuclear magnetic signal quantity.

[0077] like Figure 5 The figure shows the calibration curve of water content and nuclear magnetic signal. The horizontal axis is the standard water content, the vertical axis is the sample signal, and the calibration relationship is y=17011x+2956.4.

[0078] like Figure 6 The figure shows the curve of signal quantity change at different positions. The horizontal axis represents the change over time, and the vertical axis represents the water content. Different curves represent the trend of water content change at different positions of the core over time.

[0079] like Figure 7 The graph shows the change curve of the core fracturing fluid invasion depth at different injection times, where the abscissa represents the change over time and the ordinate represents the fracturing fluid invasion depth.

[0080] In the embodiments of the present application, it should be noted that the fracturing fluid invasion depth and invasion amount are determined based on the change in the first nuclear magnetic resonance signal, the change in the second nuclear magnetic resonance signal, and the calibration curve of water content and signal amount. The specific implementation steps are to test signals with different water amounts through a standard container, establish a calibration curve of water content and signal amount, calculate the fracturing fluid invasion amount using the nuclear magnetic resonance signal, and obtain the fracturing fluid invasion detection results.

[0081] The present invention discloses a method for detecting fracturing fluid invasion, comprising: placing a target rock core in a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance test system, injecting fracturing fluid into the target rock core in a uniform nuclear magnetic field corresponding to the nuclear magnetic resonance tester to obtain first nuclear magnetic resonance signal change information over time; injecting fracturing fluid into the target rock core in a gradient nuclear magnetic field corresponding to the nuclear magnetic resonance tester to obtain multiple second nuclear magnetic resonance signal change information over time; and determining the fracturing fluid invasion depth and invasion volume in a shale reservoir based on the first nuclear magnetic resonance signal change information and the multiple second nuclear magnetic resonance signal change information. The technical solution of the present invention is to establish a nuclear magnetic resonance method to simulate the contact between the fracturing fluid and the reservoir matrix at the fracture surface under the conditions of formation temperature, pressure, stress and original water and gas content, and to monitor the imbibition distance of the fracturing fluid at different times in real time based on the nuclear magnetic resonance test, thereby obtaining the variation law of the high-pressure invasion depth of the fracturing fluid, calculating the fracturing fluid invasion depth and invasion volume, and improving the efficiency and accuracy of calculating the fracturing fluid dosage and predicting the return rate during drilling operations.

[0082] Figure 8 This is a structural schematic diagram of a fracturing fluid intrusion detection device provided in an embodiment of the present application.

[0083] like Figure 8 As shown, the device includes:

[0084] A target configuration module 810 is used to configure a target rock core into a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance test system, wherein the target rock core is a cylindrical rock sample taken from a shale reservoir;

[0085] The uniform nuclear magnetic resonance testing module 820 is configured to perform a fracturing fluid injection test on the target rock core in a uniform nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain time-dependent first nuclear magnetic resonance signal variation information, wherein the radio frequency acting on different positions of the target rock core in the uniform nuclear magnetic field is the same;

[0086] The gradient nuclear magnetic resonance testing module 830 is configured to perform a fracturing fluid injection test on the target core in a gradient nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain information on changes in multiple second nuclear magnetic resonance signals over time. The radio frequency frequencies acting on different positions of the target core under the gradient nuclear magnetic field are different, and the nuclear magnetic resonance signals are basement nuclear magnetic signals.

[0087] The invasion detection module 840 is configured to determine the invasion depth and invasion amount of the fracturing fluid in the shale reservoir based on the first nuclear magnetic resonance signal change information and the plurality of second nuclear magnetic resonance signal change information.

[0088] Optionally, the target configuration module 810 includes:

[0089] Use helium to test the tightness of the nuclear magnetic resonance test system;

[0090] Calibrate the test coil of the high-temperature and high-pressure nuclear magnetic resonance tester in the activated nuclear magnetic resonance test system using a standard sample, and maximize the fluid nuclear magnetic signal intensity that can be sampled by the coil by setting the sampling parameters of the nuclear magnetic resonance test system, including the center frequency, echo time, and number of scans;

[0091] The target core is placed in the high-temperature and high-pressure nuclear magnetic resonance tester in the nuclear magnetic resonance test system.

[0092] Optionally, the nuclear magnetic resonance testing system includes a first chamber, a second chamber, a third chamber, a high-temperature and high-pressure nuclear magnetic resonance tester, and a back pressure valve. The first chamber, the second chamber, and the third chamber are connected to the inlet of the high-temperature and high-pressure nuclear magnetic resonance tester through a valve, and the outlet of the high-temperature and high-pressure nuclear magnetic resonance tester is connected to the back pressure valve. The first chamber, the second chamber, and the third chamber carry formation water, fracturing fluid, and helium, respectively.

[0093] Optionally, the target core is placed in a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance test system, including:

[0094] The target core is placed in a thermoplastic tube that does not generate signals, fixed with the two ends of the clamp, and placed in the holding system of the high-temperature and high-pressure nuclear magnetic resonance tester. The temperature is raised to the preset temperature, and fluorine oil is injected to increase the confining pressure and control the confining pressure to the overburden pressure of the reservoir.

[0095] Helium that does not generate signals is injected into the high-temperature and high-pressure nuclear magnetic resonance tester to simulate the original gas-containing state of the shale reservoir.

[0096] Optionally, the uniform nuclear magnetic resonance testing module 820 includes:

[0097] applying a uniform nuclear magnetic field in a high-temperature and high-pressure nuclear magnetic resonance tester, and injecting fracturing fluid into the high-temperature and high-pressure nuclear magnetic resonance tester;

[0098] During the fracturing fluid injection process, the target core is subjected to a fracturing fluid injection test in a uniform nuclear magnetic field using a CPMG test sequence to obtain first nuclear magnetic resonance signal change information over time.

[0099] Optionally, a uniform nuclear magnetic field is applied in the high-temperature and high-pressure nuclear magnetic resonance tester, and fracturing fluid is injected into the high-temperature and high-pressure nuclear magnetic resonance tester, including injecting fracturing fluid into the high-temperature and high-pressure nuclear magnetic resonance tester at a high pressure constant pressure greater than the pressure of the reservoir gas, to simulate the fracturing fluid injection process.

[0100] Optionally, the gradient nuclear magnetic resonance testing module 830 includes:

[0101] applying a gradient nuclear magnetic field in a high-temperature and high-pressure nuclear magnetic resonance tester, and injecting fracturing fluid into the high-temperature and high-pressure nuclear magnetic resonance tester;

[0102] During the fracturing fluid injection process, the target core is subjected to a fracturing fluid injection test in a gradient nuclear magnetic field using an SFG-MSCPMG test sequence to obtain a plurality of second nuclear magnetic resonance signal change information over time;

[0103] Among them, the SFG-MSCPMG test sequence can apply a gradient nuclear magnetic field in the selected shale reservoir direction, configure different frequencies at different positions, excite with a specified radio frequency, and adjust the receiving coil frequency to be consistent with the radio frequency to collect CPMG signals.

[0104] Optionally, a gradient nuclear magnetic field is applied in the high-temperature and high-pressure nuclear magnetic resonance tester, and fracturing fluid is injected into the high-temperature and high-pressure nuclear magnetic resonance tester, including injecting fracturing fluid into the high-temperature and high-pressure nuclear magnetic resonance tester at a high pressure constant pressure greater than the pressure of the reservoir gas, so as to simulate the fracturing fluid injection process.

[0105] Optionally, the intrusion detection module 840 includes:

[0106] Determining a preset calibration curve, wherein the preset calibration curve is a calibration curve of water content and signal quantity established by using signals of different water amounts tested in a standard container, and is used to calculate the water intrusion amount using the nuclear magnetic resonance signal;

[0107] Based on the first nuclear magnetic resonance signal change information, the plurality of second nuclear magnetic resonance signal change information and a preset calibration curve, the fracturing fluid invasion depth and invasion amount in the shale reservoir are determined.

[0108] The fracturing fluid intrusion detection device provided in the embodiments of the present application can execute the fracturing fluid intrusion detection method provided in any of the embodiments of the present application, and has the corresponding functions and beneficial effects of executing the fracturing fluid intrusion detection method. For detailed processes, please refer to the relevant operations of the fracturing fluid intrusion detection method in the aforementioned embodiments.

[0109] Figure 9 A schematic diagram of the structure of an electronic device 10 that can be used to implement an embodiment of the present application is shown. The electronic device is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processing, cellular phones, smart phones, wearable devices (such as helmets, glasses, watches, etc.) and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely examples and are not intended to limit the implementation of the embodiments of the present application described and / or required herein.

[0110] like Figure 9 As shown, the electronic device 10 includes at least one processor 11 and a memory, such as a read-only memory (ROM) 12, a random access memory (RAM) 13, etc., which is communicatively connected to the at least one processor 11. The memory stores a computer program that can be executed by the at least one processor. The processor 11 can perform various appropriate actions and processes according to the computer program stored in the read-only memory (ROM) 12 or the computer program loaded from the storage unit 18 into the random access memory (RAM) 13. Various programs and data required for the operation of the electronic device 10 can also be stored in the RAM 13. The processor 11, ROM 12, and RAM 13 are connected to each other via a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0111] Multiple components in the electronic device 10 are connected to the I / O interface 15, including an input unit 16, such as a keyboard, a mouse, etc.; an output unit 17, such as various types of displays, speakers, etc.; a storage unit 18, such as a magnetic disk, an optical disk, etc.; and a communication unit 19, such as a network card, a modem, a wireless communication transceiver, etc. The communication unit 19 allows the electronic device 10 to exchange information / data with other devices via a computer network such as the Internet and / or various telecommunication networks.

[0112] The processor 11 can be any general-purpose and / or specialized processing component with processing and computing capabilities. Some examples of the processor 11 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various specialized artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any other suitable processor, controller, microcontroller, etc. The processor 11 executes the various methods and processes described above, such as the fracturing fluid intrusion detection method.

[0113] In some embodiments, the fracturing fluid intrusion detection method can be implemented as a computer program tangibly embodied in a computer-readable storage medium, such as the storage unit 18. In some embodiments, part or all of the computer program can be loaded and / or installed on the electronic device 10 via the ROM 12 and / or the communication unit 19. When the computer program is loaded into the RAM 13 and executed by the processor 11, one or more steps of the fracturing fluid intrusion detection described above can be performed. Alternatively, in other embodiments, the processor 11 can be configured to perform the fracturing fluid intrusion detection method in any other suitable manner (e.g., via firmware).

[0114] Various embodiments of the systems and techniques described herein can be implemented in digital electronic circuit systems, integrated circuit systems, field programmable gate arrays (FPGAs), application specific integrated circuits (ASICs), application specific standard products (ASSPs), system-on-chip systems (SOCs), programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments can include being implemented in one or more computer programs that are executable and / or interpreted on a programmable system comprising at least one programmable processor, which can be a special purpose or general purpose programmable processor that can receive data and instructions from a storage system, at least one input device, and at least one output device, and transmit data and instructions to the storage system, the at least one input device, and the at least one output device.

[0115] The computer programs for implementing the methods of the embodiments of the present application can be written in any combination of one or more programming languages. These computer programs can be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, so that when the computer program is executed by the processor, the functions / operations specified in the flowchart and / or block diagram are implemented. The computer program can be executed entirely on the machine, partially on the machine, as a stand-alone software package, partially on the machine and partially on a remote machine, or entirely on a remote machine or server.

[0116] In the context of an embodiment of the present application, a computer-readable storage medium can be a tangible medium that can contain or store a computer program for use by an instruction execution system, device or equipment or used in combination with an instruction execution system, device or equipment. A computer-readable storage medium can include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared or semiconductor systems, devices or equipment, or any suitable combination of the foregoing. Alternatively, a computer-readable storage medium can be a machine-readable signal medium. A more specific example of a machine-readable storage medium can include an electrical connection based on one or more lines, a portable computer disk, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), an optical fiber, a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the foregoing.

[0117] To provide interaction with a user, the systems and techniques described herein can be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and pointing device (e.g., a mouse or trackball) through which the user can provide input to the electronic device. Other types of devices can also be used to provide interaction with the user; for example, the feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including acoustic input, voice input, or tactile input).

[0118] The systems and techniques described herein can be implemented in a computing system that includes back-end components (e.g., as a data server), or a computing system that includes middleware components (e.g., an application server), or a computing system that includes front-end components (e.g., a user computer with a graphical user interface or web browser through which a user can interact with implementations of the systems and techniques described herein), or a computing system that includes any combination of such back-end components, middleware components, or front-end components. The components of the system can be interconnected by any form or medium of digital data communication (e.g., a communication network). Examples of communication networks include: a local area network (LAN), a wide area network (WAN), a blockchain network, and the Internet.

[0119] A computing system may include clients and servers. The clients and servers are typically remote from each other and typically interact via a communication network. This client-server relationship arises through computer programs running on the respective computers, creating a client-server relationship. The server may be a cloud server, also known as a cloud computing server or cloud host. This server is a hosting product within the cloud computing service ecosystem that addresses the management difficulties and limited scalability of traditional physical hosting and VPS services.

[0120] It should be understood that the various forms of processes shown above can be used to reorder, add, or delete steps. For example, the steps described in the embodiments of the present application can be performed in parallel, sequentially, or in a different order, as long as the desired results of the technical solutions of the embodiments of the present application can be achieved, and this document is not limited here.

[0121] The above specific implementation manner does not constitute a limitation on the protection scope of the embodiments of the present application. It should be understood by those skilled in the art that various modifications, combinations, sub-combinations, and substitutions can be made based on design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of the embodiments of the present application should be included in the protection scope of the embodiments of the present application.

Claims

1. A method for detecting fracturing fluid intrusion, characterized in that: The method comprises: The target rock core is placed in a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance test system, wherein the target rock core is a cylindrical rock sample taken from a shale reservoir; Performing a fracturing fluid injection test on the target rock core in a uniform nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain first nuclear magnetic resonance signal change information over time, wherein the radio frequency acting on different positions of the target rock core in the uniform nuclear magnetic field is the same; The target rock core is subjected to a fracturing fluid injection test in a gradient nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain a plurality of second nuclear magnetic resonance signal change information over time, wherein the radio frequency frequencies acting on different positions of the target rock core under the gradient nuclear magnetic field are different, and the nuclear magnetic resonance signal is a base nuclear magnetic signal; Based on the first nuclear magnetic resonance signal change information and the plurality of second nuclear magnetic resonance signal change information, the fracturing fluid invasion depth and invasion amount in the shale reservoir are determined.

2. The method according to claim 1, characterized in that The target core is placed in a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance test system, including: Use helium to test the tightness of the nuclear magnetic resonance test system; Calibrate the test coil of the high-temperature and high-pressure nuclear magnetic resonance tester in the activated nuclear magnetic resonance test system using a standard sample, and maximize the fluid nuclear magnetic signal intensity that can be sampled by the coil by setting the sampling parameters of the nuclear magnetic resonance test system, including the center frequency, echo time, and number of scans; The target core is placed in the high-temperature and high-pressure nuclear magnetic resonance tester in the nuclear magnetic resonance test system.

3. The method according to claim 2, characterized in that The nuclear magnetic resonance testing system includes a first chamber, a second chamber, a third chamber, a high-temperature and high-pressure nuclear magnetic resonance tester, and a back-pressure valve. The first chamber, the second chamber, and the third chamber are connected to the inlet of the high-temperature and high-pressure nuclear magnetic resonance tester through valves, and the outlet of the high-temperature and high-pressure nuclear magnetic resonance tester is connected to the back-pressure valve. The first chamber, the second chamber, and the third chamber respectively carry formation water, fracturing fluid, and helium.

4. The method according to claim 2, characterized in that The target core is placed in the high-temperature and high-pressure nuclear magnetic resonance tester in the nuclear magnetic resonance test system, including: The target core is placed in a thermoplastic tube that does not generate signals, fixed with the two ends of the clamp, and placed in the holding system of the high-temperature and high-pressure nuclear magnetic resonance tester. The temperature is raised to the preset temperature, and fluorine oil is injected to increase the confining pressure and control the confining pressure to the overburden pressure of the reservoir. Helium that does not generate signals is injected into the high-temperature and high-pressure nuclear magnetic resonance tester to simulate the original gas-containing state of the shale reservoir.

5. The method according to claim 1, wherein The target rock core is subjected to a fracturing fluid injection test in a uniform nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain first nuclear magnetic resonance signal change information over time, including: applying a uniform nuclear magnetic field in a high-temperature and high-pressure nuclear magnetic resonance tester, and injecting fracturing fluid into the high-temperature and high-pressure nuclear magnetic resonance tester; During the fracturing fluid injection process, the target core is subjected to a fracturing fluid injection test in a uniform nuclear magnetic field using a CPMG test sequence to obtain first nuclear magnetic resonance signal change information over time.

6. The method according to claim 1, characterized in that The target core is subjected to a fracturing fluid injection test in a gradient nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain a plurality of second nuclear magnetic resonance signal change information over time, including: applying a gradient nuclear magnetic field in a high-temperature and high-pressure nuclear magnetic resonance tester, and injecting fracturing fluid into the high-temperature and high-pressure nuclear magnetic resonance tester; During the fracturing fluid injection process, the target core is subjected to a fracturing fluid injection test in a gradient nuclear magnetic field using an SFG-MSCPMG test sequence to obtain a plurality of second nuclear magnetic resonance signal change information over time; Among them, the SFG-MSCPMG test sequence can apply a gradient nuclear magnetic field in the selected shale reservoir direction, configure different frequencies at different positions, excite with a specified radio frequency, and adjust the receiving coil frequency to be consistent with the radio frequency to collect CPMG signals.

7. The method according to claim 5 or 6, characterized in that Injecting fracturing fluid into a high-temperature, high-pressure nuclear magnetic resonance tester includes: Fracturing fluid is injected into the high-temperature and high-pressure nuclear magnetic resonance tester at a constant pressure greater than the pressure of the reservoir gas to simulate the fracturing fluid injection process.

8. The method according to claim 1, characterized in that Determining the invasion depth and invasion amount of the fracturing fluid in the shale reservoir based on the first nuclear magnetic resonance signal change information and the plurality of second nuclear magnetic resonance signal change information includes: Determining a preset calibration curve, wherein the preset calibration curve is a calibration curve of water content and signal quantity established by using signals of different water amounts tested in a standard container, and is used to calculate the water intrusion amount using the nuclear magnetic resonance signal; Based on the first nuclear magnetic resonance signal change information, the plurality of second nuclear magnetic resonance signal change information and a preset calibration curve, the fracturing fluid invasion depth and invasion amount in the shale reservoir are determined.

9. A fracturing fluid intrusion detection device, characterized in that: The device comprises: A target configuration module is used to configure a target rock core into a high-temperature and high-pressure nuclear magnetic resonance tester in a nuclear magnetic resonance test system, wherein the target rock core is a cylindrical rock sample taken from a shale reservoir; a uniform nuclear magnetic resonance testing module, configured to inject fracturing fluid into the target rock core in a uniform nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain time-dependent first nuclear magnetic resonance signal variation information, wherein the radio frequency acting on different positions of the target rock core in the uniform nuclear magnetic field is the same; A gradient nuclear magnetic resonance testing module is used to perform a fracturing fluid injection test on the target rock core in a gradient nuclear magnetic field corresponding to a high-temperature and high-pressure nuclear magnetic resonance tester to obtain information on changes in multiple second nuclear magnetic resonance signals over time. The radio frequency frequencies acting on different positions of the target rock core under the gradient nuclear magnetic field are different, and the nuclear magnetic resonance signals are basement nuclear magnetic signals. The invasion detection module is used to determine the invasion depth and invasion amount of the fracturing fluid in the shale reservoir based on the first nuclear magnetic resonance signal change information and the plurality of second nuclear magnetic resonance signal change information.

10. An electronic device, characterized in that: The electronic device comprises: at least one processor; and a memory communicatively connected to the at least one processor; wherein, The memory stores a computer program executable by the at least one processor. The computer program is executed by the at least one processor to enable the at least one processor to perform the fracturing fluid invasion detection method according to any one of claims 1 to 8.

11. A computer-readable storage medium, characterized in that The computer-readable storage medium stores computer instructions, and the computer instructions are used to enable a processor to implement the fracturing fluid intrusion detection method according to any one of claims 1 to 8 when executed.

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