A method for predicting formation pressure during heating of an organic-rich formation

Abstract

The present application provides a method for predicting formation pressure in the process of heating formation rich in organic matter, which comprises: preparing a core sample for testing, and simulating the water-containing environment of the formation where the core sample is located; applying pressure to the axial and radial directions of the core sample to simulate triaxial stress conditions corresponding to the burial depth of the core sample; heating the core sample at a set heating rate to reach a set simulation temperature; and measuring the pressure value during heating to reflect the change relationship between formation pressure and temperature. The present application conducts experimental research on the pressure simulation method in the process of heating formation, and obtains data of the change of formation pressure with temperature from room temperature to 500 DEG C, which is consistent with the measured pressure data in the operation site, proving that the method for predicting formation pressure in the process of heating formation rich in organic matter proposed by the present application is feasible.

Description

Technical Field

[0001] This invention relates to the field of in-situ heating mining technology for organic-rich strata, and more specifically, to a method for predicting formation pressure during the heating process of organic-rich strata. Background Technology

[0002] Organically rich formations include oil shale and low-maturity shale oil. In-situ heating extraction of oil shale and heating-refining extraction of low-maturity shale oil are considered promising technologies for the effective utilization of shale oil. Heating the formation promotes the conversion of viscous, heavy liquid hydrocarbons into light oil, thus refining the shale oil and improving its fluidity. Simultaneously, the high temperature converts solid organic matter into oil and gas, significantly increasing formation pressure. The thermal stress generated by heating creates new fracture systems, which are beneficial for shale oil production. Heating-refining technology is expected to be a breakthrough technology for the effective utilization of low-maturity shale oil. Currently, this technology is still in the laboratory and pilot testing stages. Experimental simulations of the heating-refining process of shale oil mainly rely on pyrolysis experimental devices. Currently, these devices simulate the heating of shale oil by loading it into a closed container, cooling the container after the reaction, and then collecting the gas. There are few reports on pressure simulations during the heating process.

[0003] Traditional methods for predicting formation pore pressure are based on the theory of undercompacted mudstone sediments, including empirical coefficient methods, equivalent depth methods, and the Eaton method. Non-traditional methods include the Bowers method and the Fan Honghai method. A calculation model for pore pressure in mudstone formations is presented. It is generally believed that formation pore pressure is a function of depth, and its prediction is primarily based on well depth and the pore pressure calculated using the Eaton model.

[0004] Methods for predicting formation pressure after heating, used abroad, involve confining a core sample within a container, installing an axial pressure gauge, applying pressure, and then placing it in a heating furnace. Time and temperature data are recorded. After heating, the time and pressure data from the pressure gauge are read to obtain the relationship between temperature and pressure. However, this method can only simulate pressure changes during heating under uniaxial stress conditions. For formations heated to above 300°C, formation pressure simulation and prediction require triaxial stress conditions, for which there is currently no experimental simulation method.

[0005] To address the problems of existing technologies, this invention provides a method for predicting formation pressure during the heating process of organic-rich strata. Summary of the Invention

[0006] To address the problem of predicting formation pressure during the heating and refining process of oil shale and low-maturity shale oil, and to predict production and assess formation deformation, providing a basis for scheme formulation and countermeasures, this invention provides a method for predicting formation pressure during the heating process of organic-rich formations. The method includes the following steps:

[0007] S1. Prepare core samples for the experiment and simulate the water-bearing environment of the strata where the core samples are located;

[0008] S2. Apply axial and radial pressure to the core sample to simulate the triaxial stress conditions corresponding to the burial depth of the core sample;

[0009] S3. Heat the core sample according to the set heating rate to reach the set simulated temperature;

[0010] S4. Measure the pressure value during the heating process to reflect the relationship between formation pressure and temperature.

[0011] According to an embodiment of the present invention, step S1 includes the following steps: processing the core into a regular cylinder to prepare a core sample for testing, measuring the core porosity, wherein the debris generated during the core processing is used to conduct an aluminum slurry oil content experiment, and the water content of the core sample is measured.

[0012] According to an embodiment of the present invention, step S1 includes the following steps: weighing the core sample and loading it into an autoclave, filling the space between the core sample and the autoclave with a fracturing proppant containing quartz sand or ceramsite, and calculating the packing pore volume of the proppant based on the filling volume.

[0013] According to an embodiment of the present invention, step S1 includes the following steps:

[0014] The amount of water to be added to the autoclave is determined based on the water content and weight of the core sample.

[0015] Based on the stated water volume, water is added to the autoclave, and after compaction, the autoclave is placed in a heating furnace to simulate the water-bearing environment of the strata where the core sample is located.

[0016] By setting and adjusting the pressure of the constant pressure valve on the outlet pipeline, the changes in formation pressure during in-situ mining under conditions of simultaneous heating and mining are simulated.

[0017] According to an embodiment of the present invention, step S2 includes the following steps:

[0018] The upper and lower ports of the autoclave are sealed using a sealing pressure applicator;

[0019] The core sample is compacted by applying the overlying static rock pressure value at the burial depth of the core sample using a static rock pressure applicator.

[0020] According to one embodiment of the present invention, step S3 includes the following steps: starting the temperature controller of the heating furnace, heating the core sample in the autoclave at a set heating rate to reach the set simulated temperature.

[0021] According to one embodiment of the present invention, step S4 includes the following steps: measuring the outlet pressure value of the autoclave using a pressure sensor to determine the relationship between the pressure value and the temperature change.

[0022] According to one embodiment of the present invention, the relationship between formation pressure and temperature is reflected by the following formula:

[0023]

[0024] Where P1 and P2 represent the pressure values ​​under T1 and T2, respectively; V s φ represents the surface area of ​​the core sample; φ represents the porosity of the core sample; V1 represents the packing pore volume of the proppant; V t Indicates the volume of the pipeline.

[0025] According to another aspect of the invention, a storage medium is also provided, which includes a series of instructions for performing the steps of the method described in any of the preceding claims.

[0026] According to another aspect of the invention, a system for predicting formation pressure during heating of organic-rich formations is also provided, performing the method as described in any of the preceding claims, the system comprising:

[0027] An autoclave is used to hold core samples and simulate the water-bearing environment of the strata where the core samples are located.

[0028] The triaxial stress condition simulation device is used to apply pressure to the axial and radial directions of the core sample to simulate the triaxial stress conditions corresponding to the burial depth of the core sample.

[0029] A heating furnace is used to heat core samples at a set heating rate to reach a set simulated temperature.

[0030] A pressure measuring device is used to measure the pressure value during the heating process to reflect the relationship between formation pressure and temperature.

[0031] This invention conducted an experimental study on the pressure simulation method during the formation heating process, and obtained data on the change of formation pressure with temperature from room temperature to 500℃. The data were consistent with the pressure data measured at the operation site, proving that the formation pressure prediction method proposed in this invention during the heating process of organic-rich formations is feasible. Moreover, the experimental device and method are simple and the obtained data have high accuracy.

[0032] Other features and advantages of the invention will be set forth in the description which follows, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures particularly pointed out in the description, claims, and drawings. Attached Figure Description

[0033] The accompanying drawings are provided to further illustrate the invention and form part of the specification. They are used in conjunction with the embodiments of the invention to explain the invention and do not constitute a limitation thereof. In the drawings:

[0034] Figure 1 A flowchart of a method for predicting formation pressure during the heating process of an organic-rich stratum according to an embodiment of the present invention is shown.

[0035] Figure 2 A schematic diagram of a formation pressure prediction system during the heating process of an organic-rich stratum is shown according to an embodiment of the present invention.

[0036] Figure 3 A graph showing the relationship between pressure and temperature according to an embodiment of the present invention is displayed.

[0037] In the accompanying drawings, the same parts use the same reference numerals. Also, the drawings are not drawn to scale.

[0038] The meanings of the reference numerals in the attached figures are as follows: 1. Heating furnace; 2. Quartz sand; 3. Core sample; 4. Sealing pressure applicator; 5. Static rock pressure applicator; 6. Pressure regulating valve; 7. Product container; 8. Piston; 9. Volume measuring instrument. Detailed Implementation

[0039] To make the objectives, technical solutions, and advantages of the present invention clearer, the embodiments of the present invention will be further described in detail below with reference to the accompanying drawings.

[0040] The prior art (CN101231279A) discloses a high-pressure reactor and a high-pressure thermal simulation experimental method for high-pressure thermal simulation experiments, belonging to the field of petroleum geochemical experimental technology. The key technical feature of the high-pressure reactor is that multiple annular grooves are set on the outer surface of the reactor body, and at least one ceramic rod is placed in the tubular cavity of the reactor body. The outer diameter of the ceramic rod is slightly smaller than the inner diameter of the tubular cavity. The experimental method includes (1) determining the correction temperature at different heating rates using standard samples; (2) placing three gold tubes containing samples into the reactor body in sequence, then placing the ceramic rod, and positioning the reactor body in the heating furnace cavity, with the threaded sealing part outside the heating furnace body, and starting the heating experiment according to the conventional method at the set heating rate; (3) obtaining the gas yield curve and performing temperature correction; (4) processing the temperature-corrected data to obtain hydrocarbon generation kinetic parameters. This invention is used for high-pressure thermal simulation experiments. However, the existing technology (CN101231279A) mainly considers the problem that, in order to achieve good sealing, the top of the high-temperature and high-pressure reactor is placed outside the electric furnace, which causes a large and unstable temperature difference between the top and bottom of the reactor and cannot be corrected. Placing a gold tube at the bottom also greatly prolongs the time. The existing technology cannot solve the problem of simulating and predicting the formation pressure during the high-temperature real-time heating process.

[0041] Existing technology (CN107831297A) discloses a high-temperature, high-pressure crude oil cracking to gasification simulation experimental apparatus and method, including a high-temperature, high-pressure reactor. The reactor's bottom inlet is connected to an inlet pipeline, and its top outlet is connected to an outlet pipeline. The reactor includes a reactor body and an oil-absorbing material layer disposed inside the reactor body. At least one oil-absorbing material layer is provided. The oil-absorbing material layer is made of an oleophilic porous metal material, which is disposed on the inner wall of the reactor body cavity by sintering or welding. However, existing technology (CN107831297A) mainly considers the generation method of geochemical plates for oil-cracking natural gas and the understanding of its formation mechanism, but it cannot solve the problem of simulating and predicting formation pressure during the high-temperature real-time heating process.

[0042] Figure 1 A flowchart illustrating a method for predicting formation pressure during the heating process of organic-rich strata according to an embodiment of the present invention is shown. This invention can simulate formation pressure changes during the formation heating process in a laboratory setting, reflecting the trend of formation pressure changes with temperature during in-situ heating and extraction of oil shale, thereby guiding in-situ heating and extraction of oil shale and the heating and upgrading of low-maturity shale oil.

[0043] like Figure 1 As shown, in step S1, a core sample for the experiment is prepared, and the water-bearing environment of the stratum where the core sample is located is simulated.

[0044] In one embodiment, step S1 includes the following steps: processing the core into a regular cylinder to prepare a core sample for testing, measuring the core porosity, wherein the debris generated during core processing is used to perform an aluminum slurry oil content experiment, and the water content of the core sample is measured. Specifically, the core from the strata at the experimental depth is processed into a regular cylinder with a surface volume of V. s The porosity φ of the core sample was measured, the oil content of the aluminum pot was tested using the debris generated during the processing, and the water content of the core sample was determined.

[0045] In one embodiment, step S1 includes the following steps: weighing the core sample and loading it into an autoclave, filling the space between the core sample and the autoclave with a fracturing proppant such as quartz sand or ceramsite, and calculating the packing pore volume of the proppant based on the filling volume. Specifically, the space between the core sample and the reactor cavity is filled with proppant (quartz sand or small-diameter ceramsite) to simulate the effect of the surrounding rock of the formation, and the packing pore volume V1 of the proppant is calculated based on the filling volume.

[0046] In one embodiment, step S1 includes the following steps: determining the amount of water to be added to the autoclave based on the water content and weight of the core sample; adding water to the autoclave according to the calculated amount, compacting the autoclave, and then placing the autoclave in a heating furnace to simulate the water-bearing environment of the stratum where the core sample is located; and simulating the formation pressure changes during in-situ mining under conditions of simultaneous heating and mining by setting and adjusting the pressure of the constant pressure valve on the outlet pipeline. Specifically, the amount of water to be added to the autoclave can be determined using the water content and weight of the core sample. Then, water is added to the autoclave according to the calculated amount, and after compaction, the autoclave is placed in a heating furnace to simulate the water-bearing environment of the actual stratum where the core sample is located.

[0047] like Figure 1 As shown, in step S2, pressure is applied to the axial and radial directions of the core sample to simulate the triaxial stress conditions corresponding to the burial depth of the core sample.

[0048] In one embodiment, step S2 includes the following steps: sealing the upper and lower ports of the autoclave using a sealing pressure applicator; and compacting the core sample by applying the overlying static rock pressure value at the burial depth of the core sample using a static rock pressure applicator to simulate axial pressure. Specifically, to simulate the triaxial stress conditions of the core sample in the actual formation environment, pressure needs to be applied to the axial and radial directions of the core sample, with the axial pressure and confining pressure respectively applied to the formation stress corresponding to the burial depth of the core sample. Further, after sealing the upper and lower ports of the autoclave using the sealing pressure applicator, the airtightness needs to be tested by filling the device with nitrogen gas. After verifying good sealing performance, the nitrogen gas is discharged through the vent valve.

[0049] like Figure 1As shown, in step S3, the core sample is heated according to the set heating rate to reach the set simulated temperature.

[0050] In one embodiment, step S3 includes the following steps: activating the temperature controller of the heating furnace and heating the core sample in the autoclave at a set heating rate to reach the set simulated temperature. Specifically, to simulate the in-situ heating and extraction of oil shale and the heating and upgrading extraction environment of low-maturity shale oil, it is necessary to measure pressure and temperature data from room temperature to 500 degrees Celsius. Furthermore, the heating rate is determined based on the actual range of shale heating, or it can be determined based on experience. This experience is not laboratory experience, but rather experience from field applications.

[0051] like Figure 1 As shown, in step S4, the pressure value during the heating process is measured to reflect the relationship between formation pressure and temperature.

[0052] In one embodiment, step S4 includes the following steps: measuring the outlet pressure value of the autoclave using a pressure sensor to determine the relationship between the pressure value and temperature changes.

[0053] In one embodiment, the relationship between formation pressure and temperature is reflected by the following formula:

[0054]

[0055] Where P1 and P2 represent the outlet pressure values ​​of the autoclave under T1 and T2, respectively; V s φ represents the surface area of ​​the core sample; φ represents the porosity of the core sample; V1 represents the packing pore volume of the proppant; V t Indicates the volume of the pipeline.

[0056] Figure 2 A schematic diagram of a formation pressure prediction system during the heating process of an organic-rich stratum is shown, according to an embodiment of the present invention.

[0057] A formation pressure prediction system for heating organic-rich strata includes an autoclave, a triaxial stress condition simulation device, a heating furnace, and a pressure measuring device. Specifically, the autoclave is used to hold core samples and simulate the water-bearing environment of the strata containing the core samples. The triaxial stress condition simulation device applies axial and radial pressure to the core samples to simulate the triaxial stress conditions corresponding to the burial depth of the core samples. The heating furnace heats the core samples at a set heating rate to reach the set simulated temperature. The pressure measuring device measures the pressure values ​​during the heating process to reflect the relationship between formation pressure and temperature.

[0058] based on Figure 2The formation pressure prediction system shown in the figure includes the following steps when predicting formation pressure during the heating process of organic-rich strata:

[0059] Step 1: Process the core into a regular cylinder, which will be core sample 3. Measure the surface area V. s The debris generated during processing was used to conduct an oil content test in the aluminum still, and the water content and porosity φ of the core sample were determined. After weighing, the core sample was placed in an autoclave, and the space between the core sample and the autoclave was filled with 60 / 100 mesh ceramsite or quartz sand 2.

[0060] Step 2: Add water according to the formation water content, compact it, and then place the autoclave in the heating furnace 1. Specifically, the amount of water to be added to the autoclave can be determined by using the water content and weight of the core sample 3. Then, based on the calculated amount of water, water is added to the autoclave, compacted, and then the autoclave is placed in the heating furnace 1 to simulate the actual water-bearing environment of the formation where the core sample 3 is located.

[0061] Step 3: Open the sealing pressure applicator 4 to seal the upper and lower ports of the autoclave. To conduct an airtightness test, fill the device with nitrogen gas. After verifying that the seal is good, release the nitrogen gas through the vent valve.

[0062] Step 4: Apply the set overlying static rock pressure value using the static rock pressure applicator 5 to compact the sample. Specifically, apply the overlying static rock pressure value at the burial depth of the core sample using the static rock pressure applicator 5 to compact the core sample 3 to simulate axial pressure. Furthermore, the overlying static rock pressure value at the burial depth of the core sample can be obtained by consulting measured data or estimated based on the formation burial depth.

[0063] Step 5: Start the temperature controller of heating furnace 1 and heat the sample in the autoclave according to the set heating rate to reach the set simulated temperature. Specifically, in order to simulate the in-situ heating and extraction of oil shale and the heating and upgrading extraction environment of low-maturity shale oil, it is necessary to measure pressure and temperature data from room temperature to 500 degrees Celsius.

[0064] Step 6: Measure the outlet pressure of the autoclave using a pressure sensor. Specifically, the pressure regulating valve 6 automatically releases pressure inside the container when the pressure exceeds a certain value. The pressure regulating valve 6 simulates formation pressure during both well production and non-production conditions during the heating process. This is achieved by automatically opening and closing the pressure regulating valve 6 and setting the pressure, and by measuring the outlet pressure of the autoclave. The product container 7 is used to hold the oil, gas, and carbon dioxide produced during the heating process. The volumetric meter 9 is used to measure the volume of the product in the product container 7.

[0065] Step 7: Calculate the formation pressure based on the measured outlet pressure value to reflect the relationship between formation pressure and temperature.

[0066] In summary, this invention simulates the change in formation pressure with temperature during formation heating. Core samples are processed into regular cylinders, and the fragments are used to conduct an oil content experiment in an aluminum still, along with measurements of the sample's water content and porosity. The space between the core sample and the reactor cavity is filled with quartz sand or small-diameter ceramsite to simulate the effect of the surrounding rock, and the proppant's packing pore volume is calculated based on the filling volume. Axial and radial pressures are applied to the core sample to simulate triaxial stress conditions. The axial and confining pressures are applied to the formation stress corresponding to the core sample's burial depth, respectively, which can simulate the pressure changes in organic-rich formations during heating, obtaining a pressure-temperature curve.

[0067] Figure 3 A graph showing the relationship between pressure and temperature according to an embodiment of the present invention is displayed.

[0068] In one embodiment, an organic-rich shale sample taken from a depth of 500 meters was prepared into an oil shale sample with a diameter of 1 inch and a length of 5 cm, and the porosity was measured to be 6%. A small amount of 600 / 100 mesh ceramsite proppant was used to load the core sample into a reactor, filling the annular space with ceramsite. Based on the moisture content test of the received sample, water was added at a weight percentage of 5%. The reactor was sealed, and after verifying the seal, axial pressure was applied. The temperature was increased to 500°C at a heating rate of 0.2°C per minute. The pressure of the constant pressure valve was set to 25 MPa, and its pressure value was measured to obtain the pressure and temperature data as follows. Figure 3 As shown.

[0069] The method for predicting formation pressure during the heating process of organic-rich strata provided by this invention can also be used in conjunction with a computer-readable storage medium. The storage medium stores a computer program, which is executed to run the method for predicting formation pressure during the heating process of organic-rich strata. The computer program can execute computer instructions, which include computer program code. The computer program code can be in the form of source code, object code, executable file, or some intermediate form.

[0070] Computer-readable storage media can include: any entity or device capable of carrying computer program code, recording media, USB flash drives, portable hard drives, magnetic disks, optical disks, computer memory, read-only memory (ROM), random access memory (RAM), electrical carrier signals, telecommunication signals, and software distribution media, etc.

[0071] It should be noted that the contents of computer-readable storage media may be appropriately added to or subtracted from the contents according to the requirements of legislation and patent practice in a jurisdiction. For example, in some jurisdictions, according to legislation and patent practice, computer-readable storage media may not include electrical carrier signals and telecommunication signals.

[0072] In summary, this invention conducted an experimental study on the pressure simulation method during the formation heating process, obtaining data on the formation pressure variation with temperature from room temperature to 500℃. This data is consistent with the pressure data measured at the operation site, proving that the formation pressure prediction method proposed in this invention during the heating process of organic-rich formations is feasible. Furthermore, the experimental apparatus and method are simple, and the obtained data has high accuracy.

[0073] It should be understood that the embodiments disclosed herein are not limited to the specific structures, processing steps, or materials disclosed herein, but should be extended to equivalent substitutions of these features as understood by those skilled in the art. It should also be understood that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting.

[0074] In the description of this invention, unless otherwise stated, "a plurality of" means two or more; the terms "upper," "lower," "left," "right," "inner," "outer," "front end," "rear end," "head," "tail," etc., indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings, and are only for the convenience of describing the invention and simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, or be constructed and operated in a specific orientation, and therefore should not be construed as a limitation of the invention. Furthermore, the terms "first," "second," "third," etc., are used for descriptive purposes only and should not be construed as indicating or implying relative importance.

[0075] In the description of this invention, it should be noted that, unless otherwise explicitly specified and limited, the terms "connected" and "linked" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection; they can refer to a mechanical connection or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium. Those skilled in the art can understand the specific meaning of the above terms in this invention based on the specific circumstances.

[0076] The phrase "an embodiment" or "an embodiment" used in this specification means that a particular feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment of the invention. Therefore, the phrase "an embodiment" or "an embodiment" appearing in various places throughout the specification does not necessarily refer to the same embodiment.

[0077] The embodiments of the present invention are given for illustrative and descriptive purposes only, and are not intended to be exhaustive or to limit the invention to the forms disclosed. Many modifications and variations will be apparent to those skilled in the art. The embodiments were chosen and described in order to better illustrate the principles and practical application of the invention, and to enable those skilled in the art to understand the invention and to design various embodiments with various modifications suitable for a particular purpose.

[0078] While the embodiments disclosed in this invention are as described above, the content is merely for the purpose of facilitating understanding of the invention and is not intended to limit the invention. Any person skilled in the art to which this invention pertains may make any modifications and variations in form and detail of the implementation without departing from the spirit and scope disclosed herein; however, the scope of patent protection for this invention shall still be determined by the scope defined in the appended claims.

Claims

1. A method for predicting formation pressure during the heating process of organic-rich strata, characterized in that, The method includes the following steps: S1. Prepare core samples for the experiment and simulate the water-bearing environment of the strata where the core samples are located; S2. Apply axial and radial pressure to the core sample to simulate the triaxial stress conditions corresponding to the burial depth of the core sample; S3. Heat the core sample according to the set heating rate to reach the set simulated temperature; S4. Measure the pressure value during the heating process to reflect the relationship between formation pressure and temperature. Step S1 includes the following steps: weighing the core sample and loading it into the autoclave, filling the space between the core sample and the autoclave with fracturing proppant containing quartz sand or ceramsite, and calculating the packing pore volume of the proppant based on the filling volume. Step S1 also includes the following steps: determining the amount of water to be added to the autoclave based on the water content and weight of the core sample; adding water to the autoclave according to the stated amount, compacting it, and then placing the autoclave in a heating furnace to simulate the water-bearing environment of the stratum where the core sample is located; and simulating the formation pressure changes during in-situ mining under conditions of simultaneous heating and mining by setting and adjusting the pressure of the constant pressure valve on the outlet pipeline. Step S4 includes the following steps: measuring the outlet pressure of the autoclave using a pressure sensor to determine the relationship between the pressure value and the temperature change; The relationship between formation pressure and temperature is reflected by the following formula: in, , They represent , The pressure value below; Indicates the apparent volume of the core sample; Indicates the porosity of the core sample; This indicates the volume of the proppant's packing pores. Indicates the volume of the pipeline.

2. The method for predicting formation pressure during the heating process of organic-rich strata as described in claim 1, characterized in that, Step S1 includes the following steps: processing the core into a regular cylinder to prepare a core sample for testing, measuring the core porosity, and using the debris generated during core processing to conduct an oil content test of the aluminum pot and to measure the water content of the core sample.

3. The method for predicting formation pressure during the heating process of organic-rich strata as described in claim 1, characterized in that, Step S2 includes the following steps: The upper and lower ports of the autoclave are sealed using a sealing pressure applicator; The core sample is compacted by applying the overlying static rock pressure value at the burial depth of the core sample using a static rock pressure applicator.

4. The method for predicting formation pressure during the heating process of organic-rich strata as described in claim 1, characterized in that, Step S3 includes the following steps: starting the temperature controller of the heating furnace, heating the core sample in the autoclave according to the set heating rate, and reaching the set simulated temperature.

5. A storage medium, characterized in that, It includes instructions for performing the method steps as described in any one of claims 1-4.

6. A system for predicting formation pressure during the heating process of organic-rich strata, characterized in that, The system, which performs the method as described in any one of claims 1-4, comprises: An autoclave is used to hold core samples and simulate the water-bearing environment of the strata where the core samples are located. The triaxial stress condition simulation device is used to apply pressure to the axial and radial directions of the core sample to simulate the triaxial stress conditions corresponding to the burial depth of the core sample. A heating furnace is used to heat core samples at a set heating rate to reach a set simulated temperature. A pressure measuring device used to measure pressure values ​​during the heating process to reflect the relationship between formation pressure and temperature. A pressure regulating valve is installed on the outlet pipeline.

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