Shale oil horizontal well full life cycle sublevel mining method, terminal equipment and storage medium

Abstract

The invention relates to the technical field of shale oil and gas exploration and development, in particular to a shale oil horizontal well full-life-cycle segmented mining method, terminal equipment and a storage medium. Calculating the influence weight of each parameter on the single well liquid supply capacity of the shale oil reservoir horizontal well; the reasonable soaking time of the single well of the horizontal well is determined, the shortest soaking time and the imbibition balance soaking time are comprehensively analyzed, and meanwhile the shortest time meeting the requirement is the reasonable soaking time; determining a reasonable exploitation policy of the horizontal well flowing stage, and determining a reasonable liquid amount upper limit and a stable production minimum liquid amount lower limit; and determining a reasonable exploitation policy in the horizontal well oil pumping stage, and realizing supply and exploitation balanced production. The method has important significance for guiding lean management of an oil field production site, fully maintaining stratum energy and improving single well EUR, and is more scientific, fine, efficient, economical and higher in applicability.

Description

Technical Field

[0001] This invention relates to the field of shale oil and gas exploration and development technology, and is a method for segmented production of shale oil horizontal wells throughout their entire life cycle, as well as terminal equipment and storage media. Background Technology

[0002] Shale oil reservoirs are developed using a "horizontal well + volumetric fracturing" depletion-type development approach, which differs from conventional reservoirs that use a network of area wells + water injection for energy replenishment. Individual horizontal wells vary significantly in geological and engineering parameters, resulting in different production capacities. Production management accounts for 3-5% of the impact of horizontal well EUR (Effective Energy Tolerance).

[0003] Currently, there are technological achievements in the market for optimizing the production system of shale oil and gas horizontal wells. However, existing technologies on the market are characterized by a separation between production capacity models and production systems, and they do not adequately consider the influencing parameters of geology, engineering, and management. They mostly rely on numerical simulation methods, resulting in low correlation with on-site production. The "Technical Specification for Post-Control Production of Shale Oil Horizontal Wells," submitted for approval in September 2023, points out that the current solutions to this problem mainly employ the critical flow method, system testing method, and analogy method.

[0004] The critical flow rate method primarily calculates the critical velocity at which backflow occurs with proppant of different particle sizes. Based on the critical velocity and fracture parameters, it calculates the critical flow rate of the fracture and establishes a table or graph showing the number of fracture clusters and the critical sand production volume under different proppant particle sizes. This method only considers formation sand production and fracture closure, and can only determine the lower limit of a reasonable operating regime. The systematic well testing method primarily adjusts the operating regime and tracks changes in oil well pressure drop, fluid volume, oil volume, sand production, and gas-oil ratio under stable production conditions under different regimes. This method is relatively coarse and cannot achieve refined management. Furthermore, this method has limitations in testing conditions; it cannot be completed when the oil well pressure and fluid volume are low. The analogy method primarily compares the drainage situation of mature development blocks with similar geological conditions, well network parameters, fracturing technology, and stimulation parameters to determine the daily drainage volume of new areas and new wells. This method references the experience of previously commissioned wells, lacks practical theoretical basis, and does not consider the geological and technological differences between individual horizontal wells, making it less reasonable. Summary of the Invention

[0005] This invention provides a method for segmented production of shale oil horizontal wells throughout their entire life cycle, as well as terminal equipment and storage media. It overcomes the shortcomings of the existing technologies and effectively solves the problems of insufficient consideration of geological, engineering, and management parameters and low degree of integration with on-site production in the existing technologies.

[0006] One of the technical solutions of this invention is achieved through the following measures: a method for segmented production of shale oil horizontal wells throughout their entire life cycle, comprising the following steps: Step S1: Determine the reasonable production capacity of a single horizontal well, obtain the production parameters that affect the fluid supply capacity of a single horizontal well, and calculate the weight of each parameter on the fluid supply capacity of a single horizontal well in a shale oil reservoir. Step S2: Determine the reasonable shut-in time for a single horizontal well. Analyze the shortest shut-in time for reservoir damage recovery and the shut-in time for seepage balance. The shortest time that meets the requirements is the reasonable shut-in time. Step S3: Determine the reasonable production policy for the self-flowing stage of horizontal wells, and determine the reasonable upper limit of fluid volume and the lower limit of the minimum fluid volume for stable production; Step S4: Determine a reasonable production policy for the horizontal well pumping stage to achieve a balance between supply and production.

[0007] The following are further optimizations and / or improvements to one of the above-mentioned technical solutions: Step S1 above may specifically include the following steps: Step S1.1: Obtain production data of wells put into production in the early stage of the study block, draw a diagram of the relationship between the production date and daily oil production of wells put into production, and extract the average data of wells put into production in the category; Step S1.2: Obtain the production parameters that affect the fluid supply capacity of a single horizontal well. These parameters include the movable porosity, oil saturation, reservoir thickness, horizontal section length, drilling rate, crude oil viscosity, spacing between fracturing sections, number of clusters per section, fracturing fluid, fracturing proppant dosage, well shut-in time, and bottom hole flowing pressure. Step S1.3: Calculate the weight of each parameter on the fluid supply capacity of a single horizontal well in a shale oil reservoir.

[0008] Step S2 above may specifically include the following steps: Step S2.1: Obtain the temperature-viscosity relationship curve of formation crude oil under different water content conditions in the study block, find the inflection point of viscosity change, monitor the formation temperature during the well shut-in period, and the shortest well shut-in time is the temperature that recovers to the viscosity change inflection point. Step S2.2: Obtain the changes in fluid conductivity and well pressure during the well simmering period in the study area. Stable conductivity and pressure indicate that the reservoir fluid is in a state of seepage-absorption balance, which is the seepage-absorption balance simmering time. Step S2.3: Based on a comprehensive analysis of steps S2.1 and S2.2, the shortest time that simultaneously meets the requirements is the reasonable well shut-in time.

[0009] Step S3 above may specifically include the following steps: Step S3.1: Obtain system test data for the study area, determine the changes in sand production, liquid volume, water cut, and gas-oil ratio under different operating conditions, and determine the upper limit of reasonable liquid production. Step S3.2: Apply the lower limit of the working system to discharge liquid. When the reasonable liquid supply calculated in step S1.3 is reached, production is carried out along the reasonable liquid supply. Step S3.3: Obtain the table of flow temperature changes of crude oil in the reservoir of the study area under different well depths, production rates, and stable conditions, as well as the parameters of wax precipitation point and solidification point of crude oil in the study area, and determine the lower limit of the minimum liquid volume for stable production at the current temperature.

[0010] Step S4 above may specifically include the following steps: Step S4.1: When the unobstructed flow rate is less than the minimum liquid volume limit for stable production in the study area, it is a reasonable switching time. Step S4.2: Obtain the fluid level drop rate under different operating conditions of the pumping wells in the study area. When the fluid level stabilizes at the same depth, the daily fluid production is the reasonable operating condition for the pumping stage of the horizontal well, so as to achieve a balance between supply and production. Step S4.3: Monitor the dynamic fluid level depth of the pumping wells in the research area, and adjust the working system appropriately according to the rate of decrease of the dynamic fluid level to maintain a balance between supply and production.

[0011] The second technical solution of the present invention is achieved through the following measures: a terminal device, including a memory and a processor, wherein the memory stores a program that can run on the processor, and the processor executes the program to realize the above-mentioned shale oil horizontal well full life cycle segmented exploitation method.

[0012] The third technical solution of the present invention is achieved through the following measures: a storage medium storing one or more programs, which can be executed by one or more processors to realize the above-mentioned shale oil horizontal well full life cycle segmented exploitation method.

[0013] This invention addresses the challenge of varying geological and engineering parameters among horizontal wells in continental shale reservoirs, resulting in different production capacities and a lack of established development policies. It establishes a phased, rational operating system for the entire lifecycle of horizontal wells by relying on static parameters such as geology and engineering, and dynamic parameters such as production data and routine monitoring data. This provides guidance for on-site production management and fills the gap in the current lack of reasonable policies for horizontal wells after volumetric fracturing in unconventional shale reservoirs. This invention normalizes the differences in geological, engineering, and management factors, tailoring production targets for each horizontal well and fully leveraging its potential. It clarifies the patterns during the well-closing period, determining reasonable closing times and well-opening principles, effectively preventing reservoir cold damage and improving percolation displacement efficiency. It establishes a rational operating system for each of the three major and six minor stages, achieving lean management throughout the entire lifecycle. This invention is of great significance for guiding lean management in oilfield production, preserving formation energy, and improving the EUR (Effective Return) of individual wells. It is more scientific, precise, efficient, economical, and applicable. Attached Figure Description

[0014] Figure 1 This is a diagram showing the relationship between daily oil production and production time of block-classified wells in this embodiment of the invention.

[0015] Figure 2 This is a graph showing the temperature change over time during the well-sealing process in an embodiment of the present invention.

[0016] Figure 3 This is a graph showing the temperature-viscosity variation of shale oil under different water content conditions in the embodiments of the present invention.

[0017] Figure 4 This is a graph showing the change in the conductivity of the reservoir fluid during the well-sealing process in an embodiment of the present invention.

[0018] Figure 5 This is a graph showing the change in simmering time of a horizontal well as pressure in an embodiment of the present invention.

[0019] Figure 6 This is a diagram showing the relationship between oil pressure and water cut in a horizontal well, as described in an embodiment of the present invention.

[0020] Figure 7 This is a well test curve diagram of the self-flowing well system in an embodiment of the present invention.

[0021] Figure 8 This is a graph showing the pressure drop of produced fluid per 100 cubic meters in a horizontal well, as described in this embodiment of the invention.

[0022] Figure 9 This is a diagram showing the relationship between different nozzles, oil pressure, and daily fluid production during the self-flowing period of a horizontal well in an embodiment of the present invention.

[0023] Figure 10 This is a graph showing the relationship between deep flow temperature and production rate in shale oil wells according to an embodiment of the present invention.

[0024] Figure 11 This is a graph showing the relationship between the daily fluid production and the rate of fluid level drop in well J41 in this embodiment of the invention.

[0025] Figure 12 This is a comparison chart of production curves before and after optimization of the shale oil horizontal well system in an embodiment of the present invention.

[0026] Figure 13 This is a comparison chart of the cumulative oil production over the entire life cycle of shale oil horizontal wells in embodiments of the present invention. Detailed Implementation

[0027] The present invention is not limited to the following embodiments, and specific implementation methods can be determined according to the technical solutions and actual conditions of the present invention.

[0028] The present invention will be further described below with reference to embodiments: Example 1: As Figures 1 to 13 As shown, the shale oil horizontal well full life cycle segmented production method includes the following steps: Step S1: Determine the reasonable production capacity of a single horizontal well, obtain the production parameters affecting the fluid supply capacity of a single horizontal well, and calculate the weight of each parameter on the fluid supply capacity of a single horizontal well in a shale oil reservoir; in this embodiment, step S1 specifically includes the following steps: Step S1.1: Obtain production data of wells put into production in the early stage of the study block, plot the relationship between the production date (x) and daily oil production (t) of each well, and extract the average data of each well. Figure 1 As shown; Step S1.2: Obtain the production parameters that affect the fluid supply capacity of a single horizontal well. These parameters include the movable porosity, oil saturation, reservoir thickness, horizontal section length, drilling rate, crude oil viscosity, spacing between fracturing sections, number of clusters per section, fracturing fluid, fracturing proppant dosage, well shut-in time, and bottom hole flowing pressure. Step S1.3: Calculate the weights of each parameter's influence on the single-well fluid supply capacity of a horizontal well in a shale oil reservoir using the random forest algorithm; where, in this embodiment, the normalization formula is: a = ln(movable porosity^ 0.101 +Oil saturation ^0.056 +Reservoir thickness ^0.068 +Horizontal well section ^0.089 +Drilling rate ^0.101 Viscosity ^0.064 ln (segment spacing) ^0.071 +Number of cracks ^0.071 + Fracturing fluid volume ^0.099 +Supportive dose ^0.087 )∙ln (well simmering time) ^0.090 Bottom hole flowing pressure ^0.103 In the formula, a = the daily oil production coefficient between wells in the same block profile. 研究 =a·X 剖面 In the formula, x 研究 =Reasonable daily oil production of the research well, t / d; X 剖面 =The reasonable daily oil production of the profile well, t / d, is shown in Table 1.

[0029] Step S2: Determine the reasonable shut-in time for a single horizontal well. Analyze the shortest shut-in time for reservoir damage recovery and the shut-in time for permeability balance, and determine the shortest time that simultaneously meets the requirements as the reasonable shut-in time. In this embodiment, step S2 specifically includes the following steps: Step S2.1: Obtain the temperature-viscosity relationship curves of formation crude oil under different water cut conditions in the study block, find the viscosity change inflection point, monitor the formation temperature during well shut-in, and the minimum shut-in time is the temperature at the viscosity change inflection point. Figure 2 , Figure 3 As shown; Step S2.2: Obtain the changes in fluid conductivity and well pressure during the well-shutting period in the study area. Stable conductivity and pressure indicate that the reservoir fluid is in a state of seepage-absorption balance, which is the seepage-absorption balance well-shutting time. Figure 4 , Figure 5 As shown; Step S2.3: Based on a comprehensive analysis of steps S2.1 and S2.2, the shortest time that simultaneously meets the requirements is the reasonable well shut-in time.

[0030] Step S3: Determine a reasonable production policy for the self-flowing stage of the horizontal well, and determine the reasonable upper limit of fluid volume and the lower limit of stable production fluid volume; in this embodiment, step S3 specifically includes the following steps: Step S3.1: Obtain system test data for the study area, determine the changes in sand production, fluid volume, water cut, and gas-oil ratio under different operating conditions, and determine the upper limit of a reasonable fluid volume, such as... Figure 6 , Figure 7 As shown; Step S3.2: Apply the lower limit of the working system for liquid discharge. When the reasonable liquid supply calculated in step S1.3 is reached, production continues along the reasonable liquid supply line, such as... Figure 8 , Figure 9 As shown; Step S3.3: Obtain the table of flow temperature changes of crude oil in the study area reservoir under different well depths, production rates, and stable conditions, as well as the wax precipitation point and pour point parameters of the crude oil in the study area, and determine the lower limit of the minimum liquid production rate for stable production at the current temperature, such as... Figure 10 As shown.

[0031] Step S4: Determine a reasonable production policy for the horizontal well pumping stage to achieve a supply-production balance. In this embodiment, step S4 specifically includes the following steps: Step S4.1: When the unobstructed flow rate is less than the minimum liquid volume limit for stable production in the study area, it is a reasonable switching time. Step S4.2: Obtain the fluid level drop rate under different operating conditions of the pumping wells in the study area. When the fluid level stabilizes at the same depth, the daily fluid production is the reasonable operating condition for the pumping stage of the horizontal well, so as to achieve a balance between supply and production. Step S4.3: Monitor the dynamic fluid level depth of the pumping wells in the study area, and adjust the operating system appropriately according to the rate of decrease of the dynamic fluid level to maintain a balance between supply and production. Figure 11 As shown.

[0032] This shale oil horizontal well full life-cycle segmented development method addresses the significant differences in geological and engineering parameters among horizontal wells in continental shale reservoirs, resulting in varying production capacities and the lack of established development technology policies. It establishes a rational operating system for each horizontal well throughout its entire life-cycle by relying on static parameters such as geology and engineering, and dynamic parameters such as production data and routine monitoring data. This provides guidance for on-site production management and fills the gap in the current lack of reasonable policies for horizontal wells after volumetric fracturing in unconventional shale oil reservoirs. This shale oil horizontal well full life-cycle segmented development method normalizes the differences in geological, engineering, and management factors, tailoring production targets for each horizontal well and fully leveraging its potential. It clarifies the patterns during the well-closing period, determining reasonable closing times and well-opening principles, effectively preventing reservoir cold damage and improving percolation displacement efficiency. It establishes a rational operating system for each of the three major and six minor stages, achieving lean management throughout the entire life-cycle. After applying the full life-cycle segmented production method for horizontal shale oil wells in Xinjiang, the consistency rate between the horizontal well production data and the production capacity profile reached over 95%. Figure 12 As shown, the EUR of a single well increased by more than 5%, such as Figure 13 As shown, this shale oil horizontal well full life-cycle segmented production method is of great significance for guiding lean management in oilfield production sites, fully preserving formation energy, and improving the EUR (Effective Return) of a single well. Compared with existing technologies, the production capacity model of this shale oil horizontal well full life-cycle segmented production method is closely integrated with institutional adjustments, making it more scientific, precise, efficient, economical, and applicable.

[0033] Example 2: Figures 1 to 13 As shown, the shale oil horizontal well full life cycle segmented production method includes the following steps: Determine the reasonable production capacity of a single horizontal well: Obtain production data of wells put into production in the early stages of the study block, plot the relationship between the production date (x) and daily oil production (t) of each well, and extract the average data of each well. Figure 1 As shown; production parameters affecting the fluid supply capacity of a single horizontal well in a shale oil reservoir are obtained, including movable porosity, oil saturation, reservoir thickness, horizontal section length, drilling rate, crude oil viscosity, fracturing interval, number of clusters per section, fracturing fluid, fracturing proppant dosage, well shut-in time, and bottom hole flowing pressure. The influence weights of each parameter on the fluid supply capacity of a single horizontal well in a shale oil reservoir are calculated using a random forest algorithm, with the normalization formula: a = ln(movable porosity^ 0.101 +Oil saturation ^0.056 +Reservoir thickness ^0.068 +Horizontal well section ^0.089 +Drilling rate ^0.101 Viscosity ^0.064 ln (segment spacing) ^0.071 +Number of cracks ^0.071+ Fracturing fluid volume ^0.099 +Supportive dose ^0.087 )∙ln (well simmering time) ^0.090 Bottom hole flowing pressure ^0.103 ), where a = the daily oil production coefficient among wells in the same block profile. x 研究 =a·X 剖面 In the formula: x 研究 =Reasonable daily oil production of the research well, t / d; X 剖面 =Reasonable daily oil production of profiled wells, t / d.

[0034] Determining the appropriate well-locking time: After fracturing fluid is injected into the well, the reservoir temperature drops to 30℃, and the crude oil viscosity rises to over 8000 mPa·s, significantly reducing fluidity. After 20 days of well-locking, the reservoir temperature can recover to over 80℃, reaching 80% of the original formation temperature, and the crude oil viscosity returns to normal, reducing cold damage to the reservoir. This represents the shortest well-locking time. Figure 2 , Figure 3 As shown. After 27 days of well simmering, the reservoir fluid conductivity and wellhead pressure drop basically stabilized, as... Figure 4 , Figure 5 As shown, this proves that the reservoir has basically reached the permeation-absorption balance, and the fracturing fluid and crude oil have been fully replaced, which is a reasonable well shut-in time.

[0035] Determine a reasonable operating system for flowing wells: In shale reservoirs, the oil pressure is strongly correlated with water cut after fracturing of horizontal wells, such as... Figure 6 As shown, the water cut can only drop to 90% after the pressure is below 28 MPa, according to the well test curve of the flowing well system (e.g.) Figure 7 By obtaining the pressure drop inflection point (as shown), the maximum operating regime can be determined. This can be obtained from the pressure drop relationship diagram per 100 cubic meters of produced fluid in a horizontal well (as shown). Figure 8 As shown in the figure, the smaller the working regime, the lower the pressure drop and the larger the EUR. This is further supported by the relationship between different nozzles, oil pressure, and daily fluid production during the self-flowing period of a horizontal well (as shown in the figure). Figure 9 (As shown) the optimal working system that meets the capacity design can be determined.

[0036] Determining the appropriate switching time for pumping: Taking a horizontal shale oil well in Xinjiang as an example, the wax content of the shale oil is 7.6%~22.3%, with an average of 16.7%; the pour point is 20.4~37.0℃, with an average of 27.5℃; and the wax precipitation point is 32~39℃, with an average of 35.2℃. When the daily fluid production falls below 30t, the wellhead flow temperature drops below the pour point, and wax begins to form at the wellhead. When the daily fluid production falls below 30t, the nozzles need to be gradually adjusted upwards. When even unrestricted flow production cannot meet the needs of stable on-site production, pumping production must be switched. Figure 10 As shown.

[0037] Establish a reasonable operating system for wells undergoing pumping: Taking well J41 as an example, such as... Figure 11As shown, when the daily liquid production is 40t, the liquid level drops at a rate of 7m / d, making stable production impossible and indicating an excessively high production regime. When the daily liquid production is 23t, the liquid level recovers at a rate of 2m / d, failing to fully utilize the formation's capacity and indicating an excessively low production regime. When the daily liquid production is 27t, the liquid level stabilizes at 670m, achieving a balanced production supply.

[0038] This embodiment is of great significance for guiding lean management in oilfield production sites, fully preserving formation energy, and improving the EUR (Effective Return) of single wells. The production capacity model in this embodiment is closely integrated with institutional adjustments, making it more scientific, precise, efficient, economical, and applicable.

[0039] Example 3: This example provides a terminal device, which includes a memory, a processor, a communication interface, and a communication bus. The memory stores a program that can run on the processor. When the processor executes the program, it implements the shale oil horizontal well full life cycle segmented exploitation method in the above example.

[0040] The processor can be a central processing unit, or it can be other general-purpose processors, digital signal processors, application-specific integrated circuits, field-programmable gate arrays or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, or combinations of the above types of chips.

[0041] The memory, as a non-transitory computer-readable storage medium, can be used to store non-transitory software programs, non-transitory computer-executable programs, and units, such as the program units corresponding to those in the above-described method embodiments of the present invention. The processor executes various functional applications and data processing by running the non-transitory software programs, instructions, and modules stored in the memory, thereby realizing the shale oil horizontal well full-lifecycle segmented exploitation method in the above embodiments.

[0042] The memory may include a program storage area and a data storage area. The program storage area may store the operating system and applications required for at least one function; the data storage area may store data created by the processor, etc. Furthermore, the memory may include high-speed random access memory and non-transitory memory, such as at least one disk storage device, flash memory device, or other non-transitory solid-state storage device. The memory may optionally include memory remotely located relative to the processor, which can be connected to the processor via a network. One or more programs are stored in the memory and, when executed by the processor, perform the shale oil horizontal well full lifecycle segmented production method described in the above embodiments.

[0043] Example 4: This example provides a storage medium for computer-readable storage. The storage medium stores one or more programs, which can be executed by one or more processors to realize the shale oil horizontal well full life cycle segmented exploitation method as described in the above examples.

[0044] The storage medium can be an internal storage unit of the terminal device, such as the hard drive or memory of the terminal device. Alternatively, the storage medium can be an external storage device of the terminal device, such as a plug-in hard drive, smart memory card, secure digital card, or flash memory card installed on the terminal device.

[0045] The above technical features constitute the embodiments of the present invention, which have strong adaptability and implementation effect. Unnecessary technical features can be added or removed according to actual needs to meet the needs of different situations.

Claims

1. A method for segmented production of shale oil horizontal wells throughout their entire life cycle, characterized in that... Includes the following steps: Step S1: Determine the reasonable production capacity of a single horizontal well, obtain the production parameters that affect the fluid supply capacity of a single horizontal well, and calculate the weight of each parameter on the fluid supply capacity of a single horizontal well in a shale oil reservoir. Step S2: Determine the reasonable shut-in time for a single horizontal well. Analyze the shortest shut-in time for reservoir damage recovery and the shut-in time for seepage balance. The shortest time that meets the requirements is the reasonable shut-in time. Step S3: Determine the reasonable production policy for the self-flowing stage of horizontal wells, and determine the reasonable upper limit of fluid volume and the lower limit of the minimum fluid volume for stable production; Step S4: Determine a reasonable production policy for the horizontal well pumping stage to achieve a balance between supply and production.

2. The shale oil horizontal well full life cycle segmented production method according to claim 1, characterized in that... Step S1 specifically includes the following steps: Step S1.1: Obtain production data of wells put into production in the early stage of the study block, draw a diagram of the relationship between the production date and daily oil production of wells put into production, and extract the average data of wells put into production in the category; Step S1.2: Obtain the production parameters that affect the fluid supply capacity of a single horizontal well. These parameters include the movable porosity, oil saturation, reservoir thickness, horizontal section length, drilling rate, crude oil viscosity, spacing between fracturing sections, number of clusters per section, fracturing fluid, fracturing proppant dosage, well shut-in time, and bottom hole flowing pressure. Step S1.3: Calculate the weight of each parameter on the fluid supply capacity of a single horizontal well in a shale oil reservoir.

3. The shale oil horizontal well full life cycle segmented production method according to claim 1 or 2, characterized in that... Step S2 specifically includes the following steps: Step S2.1: Obtain the temperature-viscosity relationship curve of formation crude oil under different water content conditions in the study block, find the inflection point of viscosity change, monitor the formation temperature during the well shut-in period, and the shortest well shut-in time is the temperature that recovers to the viscosity change inflection point. Step S2.2: Obtain the changes in fluid conductivity and well pressure during the well simmering period in the study area. Stable conductivity and pressure indicate that the reservoir fluid is in a state of seepage-absorption balance, which is the seepage-absorption balance simmering time. Step S2.3: Based on a comprehensive analysis of steps S2.1 and S2.2, the shortest time that simultaneously meets the requirements is the reasonable well shut-in time.

4. The shale oil horizontal well full life cycle segmented production method according to claim 2, characterized in that... Step S3 specifically includes the following steps: Step S3.1: Obtain system test data for the study area, determine the changes in sand production, liquid volume, water cut, and gas-oil ratio under different operating conditions, and determine the upper limit of reasonable liquid production. Step S3.2: Apply the lower limit of the working system to discharge liquid. When the reasonable liquid supply calculated in step S1.3 is reached, production is carried out along the reasonable liquid supply. Step S3.3: Obtain the table of flow temperature changes of crude oil in the reservoir of the study area under different well depths, production rates, and stable conditions, as well as the parameters of wax precipitation point and solidification point of crude oil in the study area, and determine the lower limit of the minimum liquid volume for stable production at the current temperature.

5. The shale oil horizontal well full life cycle segmented production method according to claim 1, 2, or 4, characterized in that... Step S4 specifically includes the following steps: Step S4.1: When the unobstructed flow rate is less than the minimum liquid volume limit for stable production in the study area, it is a reasonable switching time. Step S4.2: Obtain the fluid level drop rate under different operating conditions of the pumping wells in the study area. When the fluid level stabilizes at the same depth, the daily fluid production is the reasonable operating condition for the pumping stage of the horizontal well, so as to achieve a balance between supply and production. Step S4.3: Monitor the dynamic fluid level depth of the pumping wells in the research area, adjust the working system appropriately according to the rate of decrease of the dynamic fluid level, and always maintain a balance between supply and production.

6. The shale oil horizontal well full life cycle segmented production method according to claim 3, characterized in that... Step S4 specifically includes the following steps: Step S4.1: When the unobstructed flow rate is less than the minimum liquid volume limit for stable production in the study area, it is a reasonable switching time. Step S4.2: Obtain the fluid level drop rate under different operating conditions of the pumping wells in the study area. When the fluid level stabilizes at the same depth, the daily fluid production is the reasonable operating condition for the pumping stage of the horizontal well, so as to achieve a balance between supply and production. Step S4.3: Monitor the dynamic fluid level depth of the pumping wells in the research area, adjust the working system appropriately according to the rate of decrease of the dynamic fluid level, and always maintain a balance between supply and production.

7. A terminal device, comprising a memory and a processor, wherein the memory stores a program executable on the processor, characterized in that, When the processor executes the program, it implements the shale oil horizontal well full life cycle segmented production method as described in any one of claims 1 to 6.

8. A storage medium, characterized in that, The storage medium stores one or more programs, which can be executed by one or more processors to implement the shale oil horizontal well full life cycle segmented production method as described in any one of claims 1 to 6.

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