High-temperature-resistant well cementation system method and well cementation process method

Abstract

The invention discloses a high-temperature-resistant well cementation system method and a well cementation process method.The method comprises the steps that according to a heat conduction model and relevant characteristic parameters of a stratum, shaft temperature field distribution is determined, and the range of a high-temperature well section and the range of a low-temperature well section are divided; determining a high-temperature-resistant system dosage and a low-temperature system dosage according to the determined range of the high-temperature well section and the determined range of the low-temperature well section respectively, and injecting the high-temperature-resistant system dosage and the low-temperature system dosage into corresponding positions; determining the tripping-in depth of a heating device according to the high-temperature well section; determining the heating time of the high-temperature well section according to the power of the heating device, the use amount of the high-temperature-resistant system and the length of the high-temperature well section; and the heating device is used for heating the high-temperature well section to the solidification temperature of the high-temperature-resistant system according to the heating time of the high-temperature well section, and the high-temperature-resistant well cementation section is obtained.

Description

Technical Field

[0001] The present invention relates to the technical field of in-situ shale oil mining, and in particular to a high temperature resistant cementing system method and a cementing process method. Background Art

[0002] In-situ extraction refers to a method of converting the solid kerogen in the oil shale into liquid hydrocarbons by heating the oil shale reservoir at high temperature, and then extracting the liquid hydrocarbons from underground through traditional oil and gas extraction processes.

[0003] The wellbore temperature of low-maturity shale oil in-situ conversion production has a great impact on the performance of completion cement. Low-maturity shale oil is generally produced by electric heating, and the maximum temperature of the heating section is as high as 650°C, which is very easy to cause cement stone damage and sealing failure and casing damage. At present, G-grade cement plus sand and high-temperature cement are used for cementing construction in heavy oil thermal production in oil fields. At present, the temperature resistance of heavy oil thermal production cement can generally only reach 350°C. Among them, after multiple rounds of high-temperature steam huff and puff, the cement stone has high-temperature decay, resulting in poor cementing quality, which is the main factor leading to casing damage and cement ring sealing failure.

[0004] In the case of shale oil in-situ conversion and production, the high wellbore temperature can easily lead to casing and cement sheath damage. Even if the use of heat-insulating tubing and packers in the upper part can reduce the temperature above the packer and make the upper casing and cement sheath safe, the heat accumulation is more concentrated below the packer, resulting in a higher temperature from the packer to the reservoir. For this section of the well, a cementing system with higher temperature resistance is required.

[0005] Therefore, how to realize a high temperature resistant cementing method and cementing process method that can meet the strength requirements of cement stone under high temperature conditions is an urgent problem to be solved. Summary of the invention

[0006] The present application provides a high-temperature resistant cementing system method, which solves the problem of failure of cement sheath due to high-temperature damage during the electric heating production process of low-maturity shale oil. The high-temperature resistant cementing system and cementing method can meet the strength requirements of cement stone under high-temperature conditions, improve the sealing ability of cement sheath, and enhance the safety of wellbore.

[0007] In a first aspect, the present application provides a high temperature resistant cementing system method, the method comprising:

[0008] Determine the wellbore temperature field distribution according to the heat conduction model and relevant characteristic parameters of the formation, and divide the range of the high-temperature well section and the range of the low-temperature well section;

[0009] Determine the amount of the high temperature resistant system and the amount of the low temperature system according to the determined range of the high temperature well section and the range of the low temperature well section, and inject the amount of the high temperature resistant system and the amount of the low temperature system into corresponding positions;

[0010] Determine the insertion depth of the heating device according to the high-temperature well section;

[0011] Determine the heating time of the high temperature well section according to the power of the heating device, the amount of the high temperature resistant system and the length of the high temperature well section;

[0012] The heating device is used to heat the high-temperature well section to the consolidation temperature of the high-temperature resistant system according to the heating time of the high-temperature well section, so as to obtain a high-temperature resistant cementing section.

[0013] Optionally, the heat conduction model is:

[0014]

[0015] Where T is temperature, t is time, x, y, z are spatial coordinates, k is the thermal diffusion coefficient, ρ is the density, and c is the specific heat capacity.

[0016] Optionally, the dosage of the high temperature resistant system is:

[0017]

[0018] Where H is the length of the high temperature resistant well section, r is the casing radius, T i It is the gap width of the annulus between the wellbore and the casing.

[0019] Optionally, determining the insertion depth of the heating device according to the high-temperature well section includes:

[0020]

[0021] Where H1 is the starting depth of the high-temperature well section, and H2 is the ending depth of the high-temperature well section.

[0022] Optionally, the high temperature well section and the low temperature well section respectively adopt a high temperature resistant system and a cement system;

[0023] The high temperature resistant system is composed of a main agent, an additive, an activator, high temperature resistant fiber and water;

[0024] The cement system is Portland cement.

[0025] Optionally, the heating time t is:

[0026]

[0027] Where t is the heating time, H is the length of the high temperature resistant plug, c is the specific heat capacity, r is the casing radius, T i is the annular gap width between the wellbore and the casing, and W is the heater power.

[0028] Optionally, the consolidation temperature of the high temperature resistant system is greater than or equal to 150°C.

[0029] In a second aspect, an embodiment of the present invention provides a high temperature resistant cementing process method, the method comprising:

[0030] Determine the range of the high temperature well section, the range of the first low temperature well section, the range of the second low temperature well section, the high temperature resistant system, the amount of the high temperature resistant system and the heating time of the high temperature well section according to any one of the above embodiments;

[0031] Injecting silicate cement slurry into the lower part of the high-temperature well section according to the cement system dosage of the first low-temperature well section;

[0032] After the injection is completed, the wellbore and pipe wall are flushed, and the high temperature resistant system is injected into the high temperature well section according to the dosage of the high temperature resistant system;

[0033] After flushing the wellbore and pipe wall, silicate cement slurry is injected into the upper part of the high-temperature well section according to the cement system dosage of the second low-temperature well section;

[0034] After solidification, the high-temperature well section is heated by the heating device, and the coiled tubing and the heating device are taken out after the total heating time is reached.

[0035] Optionally, before injecting silicate cement slurry into the lower part of the high-temperature well section according to the cement system dosage of the first low-temperature well section, the method further comprises:

[0036] After drilling is completed, the well is dredged and a casing string is run in the wellbore;

[0037] Connect to surface equipment for well washing;

[0038] After well washing, the prepared pre-fluid is injected into the casing string.

[0039] Compared with the related art, the present application provides a method and process implementation method of a high-temperature resistant cementing system, the method comprising: determining the wellbore temperature field distribution according to the heat conduction model and the relevant characteristic parameters of the formation, and dividing the range of the high-temperature well section and the range of the low-temperature well section; determining the amount of the high-temperature resistant system and the amount of the low-temperature system according to the determined range of the high-temperature well section and the range of the low-temperature well section, and injecting the amount of the high-temperature resistant system and the amount of the low-temperature system into the corresponding position; determining the insertion depth of the heating device according to the high-temperature well section; determining the heating time of the high-temperature well section according to the power of the heating device, the amount of the high-temperature resistant system and the length of the high-temperature well section; using the heating device to heat the high-temperature well section according to the heating time of the high-temperature well section to the consolidation temperature of the high-temperature resistant system, and obtaining a high-temperature resistant cementing section. The present application can meet the strength requirements of cement stone under high-temperature conditions through a high-temperature resistant cementing system and a cementing method, improve the sealing ability of the cement sheath, and enhance the safety of the wellbore.

[0040] Other features and advantages of the present application will be described in the following description, and partly become apparent from the description, or be understood by implementing the present application. Other advantages of the present application can be realized and obtained by the schemes described in the description and the drawings. BRIEF DESCRIPTION OF THE DRAWINGS

[0041] The accompanying drawings are used to provide an understanding of the technical solution of the present application and constitute a part of the specification. Together with the embodiments of the present application, they are used to explain the technical solution of the present application and do not constitute a limitation on the technical solution of the present application.

[0042] Figure 1 This is a flow chart of a high temperature resistant cementing system method according to an embodiment of the present application;

[0043] Figure 2 This is a flow chart of a high temperature resistant cementing process method according to an embodiment of the present application;

[0044] Figure 3 A schematic diagram of simulating a high-temperature well section and a low-temperature well section in high-temperature resistant cementing in an exemplary embodiment;

[0045] Figure 4 A schematic diagram of a high temperature resistant cementing design in an exemplary embodiment. DETAILED DESCRIPTION

[0046] The present application describes multiple embodiments, but the description is exemplary rather than restrictive, and it is obvious to those skilled in the art that there may be more embodiments and implementations within the scope of the embodiments described in the present application. Although many possible feature combinations are shown in the drawings and discussed in the specific embodiments, many other combinations of the disclosed features are also possible. Unless specifically limited, any feature or element of any embodiment may be used in combination with any other feature or element in any other embodiment, or may replace any other feature or element in any other embodiment.

[0047] The present application includes and contemplates combinations of features and elements known to those of ordinary skill in the art. The embodiments, features and elements disclosed in the present application may also be combined with any conventional features or elements to form a unique invention scheme defined by the claims. Any features or elements of any embodiment may also be combined with features or elements from other invention schemes to form another unique invention scheme defined by the claims. Therefore, it should be understood that any feature shown and / or discussed in the present application may be implemented individually or in any appropriate combination. Therefore, except for the limitations made according to the attached claims and their equivalents, the embodiments are not subject to other restrictions. In addition, various modifications and changes may be made within the scope of protection of the attached claims.

[0048] In addition, when describing representative embodiments, the specification may have presented the method and / or process as a specific sequence of steps. However, to the extent that the method or process does not rely on the specific order of the steps described herein, the method or process should not be limited to the steps of the specific order described. As will be understood by those of ordinary skill in the art, other sequences of steps are also possible. Therefore, the specific sequence of the steps set forth in the specification should not be interpreted as a limitation to the claims. In addition, the claims for the method and / or process should not be limited to the steps of performing them in the order written, and those skilled in the art can easily understand that these sequences can be changed and still remain within the spirit and scope of the embodiments of the present application.

[0049] The embodiment of the present invention provides a high temperature resistant cementing system method, such as Figure 1 As shown, the method includes steps S100-S140:

[0050] S100: determining the temperature field distribution of the wellbore according to the heat conduction model and relevant characteristic parameters of the formation, and dividing the range of the high-temperature well section and the range of the low-temperature well section;

[0051] S110: determining the amount of the high temperature resistant system and the amount of the low temperature system according to the determined range of the high temperature well section and the range of the low temperature well section, and injecting the amount of the high temperature resistant system and the amount of the low temperature system into corresponding positions;

[0052] S120: Determine the insertion depth of the heating device according to the high-temperature well section;

[0053] S130: Determine the heating time of the high temperature well section according to the power of the heating device, the amount of the high temperature resistant system used and the length of the high temperature well section;

[0054] S140: using the heating device to heat the high-temperature well section to the consolidation temperature of the high-temperature resistant cementing system according to the heating time of the high-temperature well section, so as to obtain a high-temperature resistant cementing section.

[0055] In an exemplary embodiment, the range of the high-temperature well section and the range of the low-temperature well section are determined according to the heat conduction model and the relevant characteristic parameters of the formation; the range of the high-temperature well section and the range of the low-temperature well section are determined according to the location of the oil reservoir. If the oil reservoir is at the bottom, there will be only an upper low-temperature section and a lower high-temperature section; if the oil reservoir is in the middle, there will be three sections, the upper and lower sections are low-temperature sections, and the middle oil reservoir position is a high-temperature section. Figure 3 As shown, the upper part is the low-temperature well section, the middle part is the high-temperature well section, and the bottom part is the low-temperature well section. The cementing method is designed as segment plug cementing, that is, the upper low-temperature section is cemented with silicate cement, the middle high-temperature section is cemented with a high-temperature resistant cementing system, and the bottom low-temperature section is cemented with silicate cement.

[0056] In this embodiment, the process of determining the range of the high-temperature well section is as follows: first, determine the range of the reservoir section; second, simulate and calculate the wellbore temperature field distribution according to the heating temperature designed for in-situ reforming, and clarify the high-temperature well section. The specific calculation method can also use the heat conduction model for quantitative calculation, where the heat conduction model is:

[0057]

[0058] Wherein, T is the temperature of the heater, t is the time, x, y, z are the spatial coordinates, k is the thermal diffusion coefficient, ρ is the density, and c is the specific heat capacity. In the above formula, x, y, z are the spatial coordinates, k is the thermal diffusion coefficient, ρ is the density, and c is the specific heat capacity which can be determined experimentally.

[0059] In an exemplary embodiment, the amount of the high temperature resistant system is determined according to the determined length H of the high temperature resistant cementing section, and further according to the casing radius and the gap width of the annulus between the wellbore and the casing. The formula for the amount of the high temperature resistant system is:

[0060]

[0061] Where H is the length of the high temperature resistant well section, r is the casing radius, T i It is the gap width of the annulus between the wellbore and the casing.

[0062] In an exemplary embodiment, the high-temperature well section and the low-temperature well section respectively use a high-temperature resistant system and a cement system; the high-temperature resistant system is composed of a main agent, an additive, an activator, a high-temperature resistant fiber and water; and the cement system is silicate cement.

[0063] Since the high temperature resistant cementing system cannot be mixed with silicate cement, it is necessary to use well washing buffer and cement plug to separate the high temperature cementing system and silicate cement. The specific separation can be carried out by the following process:

[0064] After the silicate cement slurry is injected into the first plug, the well washing fluid is introduced to clean the silicate cement in the wellbore, and the rubber plug is driven in for separation;

[0065] Then drive in the high temperature resistant cementing system;

[0066] After the high temperature resistant cementing system is injected, well washing fluid and rubber plug are injected;

[0067] Finally, silicate cement slurry is injected.

[0068] In an exemplary embodiment, after the high temperature resistant cementing system is injected, a coiled tubing and a heating device are lowered from the wellhead to heat the high temperature well section, and the heating temperature is ≥150°C.

[0069] First, the insertion depth of the heating device needs to be determined according to the high-temperature well section. The specific method for calculating the insertion depth is:

[0070]

[0071] Where H1 is the starting depth of the high temperature section, and H2 is the ending depth of the high temperature section.

[0072] The heating power W of the heater is generally 2 to 6KW. The heating time is determined according to the heater power used, combined with the length of the high-temperature resistant slug, specific heat capacity, casing radius and the thickness of the annulus between the wellbore and the casing. The heating time t is:

[0073]

[0074] Where t is the heating time, H is the length of the high temperature resistant plug, c is the specific heat capacity, r is the casing radius, T i is the thickness of the annulus between the wellbore and the casing, and W is the heater power.

[0075] In a second aspect, an embodiment of the present invention provides a high temperature resistant cementing process method, such as Figure 2 As shown, the high temperature resistant cementing process includes steps S200-S240:

[0076] S200: Determine the range of the high temperature cementing section, the range of the first low temperature cementing section, the range of the second low temperature cementing section, the amount of the high temperature resistant system and the heating time of the high temperature section according to any one of the high temperature resistant cementing system methods described in the above embodiments;

[0077] S210: Injecting silicate cement slurry into the lower part of the high-temperature cementing section according to the cement system dosage of the first low-temperature section cementing;

[0078] S220: After the injection is completed, the wellbore and the pipe wall are flushed, and the high temperature resistant cementing system is injected into the high temperature cementing section according to the dosage of the high temperature resistant system;

[0079] S230: After flushing the wellbore and the pipe wall, a silicate cement slurry is injected into the upper part of the high-temperature cementing section according to the cement system dosage of the second low-temperature section cementing;

[0080] S240: After the cementing is completed, the high-temperature cementing section is heated by a heating device, and the coiled tubing and the heating device are removed after the total heating time is reached.

[0081] In an exemplary embodiment, before injecting silicate cement slurry into the lower part of the high-temperature well section according to the cement system dosage of the first low-temperature well section, the method further includes:

[0082] After drilling is completed, the well is dredged and a casing string is run in the wellbore;

[0083] Connect to surface equipment for well washing;

[0084] After well washing, use a cement truck to inject the prepared pre-fluid into the casing string.

[0085] In an exemplary embodiment, after each injection of the slurry or the high temperature system is completed, the following process is performed:

[0086] Release the rubber plug, inject the plugging liquid through the plugging liquid inlet, and the plugging liquid pushes the rubber plug downward;

[0087] Start the mud pump and inject drilling fluid to replace the mud. The drilling fluid pushes the plugging fluid downward, and the plugging fluid pushes the cement slurry downward through the rubber plug. After the cement slurry enters the wellbore annulus from the float shoe, it pushes the pre-fluid upward, and the pre-fluid pushes the drilling fluid upward;

[0088] When the rubber plug moves down to the baffle of the floating collar, the mud pump is turned off, and the cement slurry returns to the predetermined well section and enters the waiting stage.

[0089] In the case of in-situ conversion and production of shale oil, high wellbore temperature can easily lead to casing damage and cement ring damage. Even if the use of insulation methods such as insulated oil pipes and packers in the upper part can reduce the temperature above the packer, the upper casing and cement ring can be safe. However, in the part below the packer, the heat accumulation is more concentrated, resulting in a higher temperature from the packer to the reservoir. For this section of the well, a cementing system with higher temperature resistance is required. In response to this problem, the high-temperature resistant cementing system method and process method implemented in the embodiment of the present application have the following technical effects:

[0090] 1. According to the working condition simulation calculation, determine the temperature field distribution of the wellbore and divide the high-temperature well section;

[0091] 2. For high-temperature well sections, a high-temperature resistant cementing system is used to meet the strength requirements of cement stone under high-temperature conditions, improve the sealing ability of the cement sheath, and enhance the safety of the wellbore;

[0092] 3. The cementing process method realized by the high temperature resistant cementing section can obtain a cementing system with higher temperature resistance, for example: when the temperature reaches 500℃, the compressive strength can still reach more than 40MPa;

[0093] When the temperature reaches 600℃, the compressive strength can still reach above 35MPa.

[0094] Example 1

[0095] This example shows the process implementation method of high temperature resistant cementing. The cementing design diagram used in this cementing process is as follows: Figure 4 As shown, 1 is the wellhead; 2 is the coiled tubing; 3 is the heater; 4 is the rubber plug; 5 is the hole; 6 is the cement rubber plug plus the isolation fluid / well washing fluid; 7 is the cementing section of the high temperature resistant cementing system; 8 is the reservoir; 9 is the silicate cement cementing section;

[0096] Based on the above cementing design schematic diagram, the specific steps for implementing the high temperature resistant cementing process are as follows:

[0097] S301, after drilling is completed, the well is dredged, and after the well is dredged, a casing string is run into the wellbore;

[0098] S302, connecting to ground equipment for well washing;

[0099] S303, injecting the prepared pre-fluid into the casing string using a cement truck;

[0100] S304, injecting the prepared cement slurry into the casing string by a cement truck until the cement slurry reaches the designed cementing volume of the first low-temperature well section (upper low-temperature well section);

[0101] S305, release the rubber plug, and the cement truck injects the plugging liquid through the plugging liquid inlet, and the plugging liquid pushes the rubber plug downward; start the mud pump, inject drilling fluid to replace the slurry, the drilling fluid pushes the plugging liquid downward, the plugging liquid pushes the cement slurry downward through the rubber plug, and the cement slurry enters the wellbore annulus from the float shoe, pushing the pre-fluid upward, and the pre-fluid pushes the drilling fluid upward. When the rubber plug moves down to the baffle of the float collar, it stops, generating collision pressure, and immediately shuts off the mud pump. At this time, the cement slurry returns to the predetermined well section and enters the waiting setting stage;

[0102] S306, injecting well washing fluid to wash the silicate cement residue on the wellbore and pipe wall;

[0103] S307, injecting the high temperature resistant cementing system into the high temperature well section according to the pre-calculated amount of the high temperature resistant cementing system;

[0104] In this step, the amount of the high temperature resistant system is determined according to the determined length H of the high temperature resistant cementing section, and further according to the casing radius and the gap width of the annulus between the wellbore and the casing; the formula for the amount of the high temperature resistant system is:

[0105]

[0106] Where H is the length of the high temperature resistant slug, r is the casing radius, T i It is the gap width of the annulus between the wellbore and the casing.

[0107] S308, release the rubber plug, and the cement truck injects the plugging liquid through the plugging liquid inlet, and the plugging liquid pushes the rubber plug downward; start the mud pump, inject drilling fluid to replace the slurry, the drilling fluid pushes the plugging liquid downward, the plugging liquid pushes the cement slurry downward through the rubber plug, and the cement slurry enters the wellbore annulus from the float shoe, pushing the pre-fluid upward, and the pre-fluid pushes the drilling fluid upward. When the rubber plug moves down to the baffle of the float collar, it stops, generating collision pressure, and immediately shuts off the mud pump. At this time, the cement slurry returns to the predetermined well section and enters the waiting setting stage;

[0108] S309, injecting well flushing fluid to flush the high temperature resistant cementing system residues on the wellbore and pipe wall;

[0109] S310, injecting silicate cement slurry according to the second low-temperature well section (the designed cementing amount of the lower low-temperature section);

[0110] Calculate the amount of silicate cement slurry for the second low-temperature well section based on depth and annulus.

[0111] S311, release the rubber plug, and the cement truck injects the plugging liquid through the plugging liquid inlet, and the plugging liquid pushes the rubber plug downward; start the mud pump, inject drilling fluid to replace the slurry, the drilling fluid pushes the plugging liquid downward, the plugging liquid pushes the cement slurry downward through the rubber plug, and the cement slurry enters the wellbore annulus from the float shoe, pushing the pre-fluid upward, and the pre-fluid pushes the drilling fluid upward. When the rubber plug moves down to the baffle of the float collar, it stops, generating collision pressure, and immediately shuts off the mud pump. At this time, the cement slurry returns to the predetermined well section and enters the waiting setting stage;

[0112] S312, run the coiled tubing to the high temperature section, and heat the high temperature resistant cementing system section to 150°C by a heating device. The heating time can be calculated based on the heating well section and the power of the heater. The specific calculation is as follows:

[0113] The heating power W of the heater is generally 2 to 6KW. The heating time is determined according to the heater power used, combined with the length of the high-temperature resistant slug, specific heat capacity, casing radius and the thickness of the annulus between the wellbore and the casing. The heating time t is:

[0114]

[0115] Where t is the heating time, H is the length of the high temperature resistant plug, c is the specific heat capacity, r is the casing radius, T i is the thickness of the annulus between the wellbore and the casing, and W is the heater power.

[0116] S313, after the heating is completed, the coiled tubing and the heating device are removed, and all cementing steps are completed.

[0117] This example shows a process flow of a segment-type cementing system construction process. In view of the high temperature of the wellbore during in-situ conversion and production of shale oil, which can easily lead to casing damage and cement sheath damage, a cementing system with higher temperature resistance is implemented for high-temperature resistant well sections. Ultimately, the temperature can reach 500°C and the compressive strength can still reach more than 40MPa; the temperature can reach 600°C and the compressive strength can still reach more than 35MPa.

[0118] It will be appreciated by those skilled in the art that all or some of the steps, systems, and functional modules / units in the methods disclosed above may be implemented as software, firmware, hardware, and appropriate combinations thereof. In hardware implementations, the division between the functional modules / units mentioned in the above description does not necessarily correspond to the division of physical components; for example, a physical component may have multiple functions, or a function or step may be performed by several physical components in cooperation. Some or all components may be implemented as software executed by a processor, such as a digital signal processor or a microprocessor, or implemented as hardware, or implemented as an integrated circuit, such as an application-specific integrated circuit. Such software may be distributed on a computer-readable medium, which may include a computer storage medium (or non-transitory medium) and a communication medium (or temporary medium). As known to those skilled in the art, the term computer storage medium includes volatile and non-volatile, removable and non-removable media implemented in any method or technology for storing information (such as computer-readable instructions, data structures, program modules, or other data). Computer storage media include, but are not limited to, RAM, ROM, EEPROM, flash memory or other memory technology, CD-ROM, digital versatile disks (DVD) or other optical disk storage, magnetic cassettes, magnetic tapes, magnetic disk storage or other magnetic storage devices, or any other medium that can be used to store the desired information and can be accessed by a computer. In addition, it is well known to those of ordinary skill in the art that communication media typically contain computer-readable instructions, data structures, program modules, or other data in a modulated data signal such as a carrier wave or other transport mechanism, and may include any information delivery media.

Claims

1. A high temperature resistant cementing system method, It is characterized in that The method comprises: Determine the wellbore temperature field distribution according to the heat conduction model and relevant characteristic parameters of the formation, and divide the range of the high-temperature well section and the range of the low-temperature well section; Determine the amount of the high temperature resistant system and the amount of the low temperature system according to the determined range of the high temperature well section and the range of the low temperature well section, and inject the amount of the high temperature resistant system and the amount of the low temperature system into corresponding positions; Determine the insertion depth of the heating device according to the high-temperature well section; Determine the heating time of the high temperature well section according to the power of the heating device, the amount of the high temperature resistant system and the length of the high temperature well section; The heating device is used to heat the high-temperature well section to the consolidation temperature of the high-temperature resistant system according to the heating time of the high-temperature well section, so as to obtain a high-temperature resistant cementing section.

2. The high temperature resistant cementing system method according to claim 1, It is characterized in that The heat conduction model is: Where T is temperature, t is time, x, y, z are spatial coordinates, k is the thermal diffusion coefficient, ρ is the density, and c is the specific heat capacity.

3. The high temperature resistant cementing system method according to claim 1, It is characterized in that The dosage of the high temperature resistant system is: Where V is the amount of high temperature resistant system, H is the length of the high temperature well section, r is the casing radius, T i It is the gap width of the annulus between the wellbore and the casing.

4. The high temperature resistant cementing system method according to claim 3, It is characterized in that The step of determining the insertion depth of the heating device according to the high-temperature well section comprises: In the formula, H 1 is the starting depth of the high temperature section, H 2 It is the end depth of the high-temperature well section.

5. The high temperature resistant cementing system method according to claim 1, It is characterized in that The high temperature resistant system is composed of a main agent, an additive, an activator, high temperature resistant fiber and water; The low temperature system is silicate cement.

6. The high temperature resistant cementing system method according to claim 4, It is characterized in that The heating time of the high temperature well section is: Where t is the heating time of the high-temperature well section, H is the length of the high-temperature well section, c is the specific heat capacity, r is the casing radius, T i is the width of the annular gap between the wellbore and the casing, and W is the heater power.

7. The high temperature resistant cementing system method according to claim 1, It is characterized in that The solidification temperature of the high temperature resistant system is greater than or equal to 150°C.

8. A high temperature resistant cementing process, It is characterized in that The method comprises: Determine the range of the high temperature well section, the range of the first low temperature well section, the range of the second low temperature well section, the amount of the high temperature resistant system and the heating time of the high temperature well section according to the high temperature resistant cementing system method described in any one of claims 1 to 7; Injecting silicate cement slurry into the lower part of the high-temperature well section according to the cement system dosage of the first low-temperature well section; After the injection is completed, the wellbore and pipe wall are flushed, and the high temperature resistant system is injected into the high temperature well section according to the dosage of the high temperature resistant system; After flushing the wellbore and pipe wall, silicate cement slurry is injected into the upper part of the high-temperature well section according to the cement system dosage of the second low-temperature well section; After solidification, the high-temperature well section is heated by the heating device, and the coiled tubing and the heating device are taken out after the total heating time is reached.

9. The high temperature resistant cementing process according to claim 8, It is characterized in that Before injecting silicate cement slurry into the lower part of the high-temperature well section according to the cement system dosage of the first low-temperature well section, the method further comprises: After drilling is completed, the well is dredged and a casing string is run in the wellbore; Connect to surface equipment for well washing; After well washing, the prepared pre-fluid is injected into the casing string.

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