A method and apparatus for determining the timing of shaft rotation in shale oil wells

Abstract

This invention discloses a method and apparatus for determining the timing of shaft rotation in shale oil wells. The method determines the timing based on the desired instantaneous production increase ratio before and after shaft rotation, combined with calculated correlations between wellhead oil pressure and production increase ratios before and after pumping under different gas-liquid ratios. It selects candidate wellhead pressures with instantaneous production increase ratios and compares them with the gathering and transportation limit wellhead oil pressure value to obtain the optimal shaft rotation timing. If the wellhead oil pressure value does not meet the requirements, the shaft rotation timing is optimized. This invention, by determining the optimal shaft rotation timing for shale oil wells, ensures normal well production while meeting the need to adjust instantaneous production according to set targets. It overcomes the problem that traditional shaft rotation timing optimization can only obtain the latest shaft rotation timing, leading to uncontrollable instantaneous production increase ratios, thus improving the controllability of instantaneous production in shale oil wells.

Description

Technical Field

[0001] This invention belongs to the field of unconventional oil reservoir development technology, specifically relating to a method and apparatus for determining the timing of shaft rotation in shale oil wells. Background Technology

[0002] Shale oil is an important component of my country's energy system and a significant driver of crude oil production growth. Due to the low formation pressure coefficient and high fluid flow resistance of shale oil reservoirs, shale oil wells exhibit poor self-flowing capability. Shale oil extraction necessitates artificial lift methods to pump crude oil to the surface to ensure normal well production. Simultaneously, the low production per well and high crude oil start-up pressure of shale oil wells also require artificial lift to appropriately amplify the production pressure differential and increase instantaneous production according to set targets. Therefore, there is an urgent need to develop a method and device for optimizing shaft timing that can ensure normal well production and increase instantaneous production according to set targets.

[0003] Existing methods for determining shaft rotation timing primarily rely on surface flow pressure drop. This involves calculating the pressure loss as crude oil flows from the wellhead to the separation unit, directly determining the corresponding wellhead pressure limit, and using the time when this limit is reached as the shaft rotation timing. However, this method only yields the latest possible shaft rotation timing, not the optimal timing suitable for shale oil well production characteristics. While it can ensure normal well production, the increase in production is uncontrollable and cannot meet the need to adjust instantaneous production according to set targets. Therefore, improvements to the shaft rotation timing determination method and equipment are needed to ensure normal well production while further enhancing the controllability of instantaneous production after shaft rotation in shale oil wells. Summary of the Invention

[0004] The purpose of this invention is to provide a method and apparatus for determining the timing of shaft rotation in shale oil wells, so as to solve the problems mentioned in the background art.

[0005] To achieve the above objectives, the present invention provides the following technical solution: a method and apparatus for determining the timing of shaft rotation in shale oil wells.

[0006] The method for determining the timing of shaft rotation in shale oil wells includes the following steps:

[0007] S1: Set different wellhead oil pressure values;

[0008] S2: Set the gas-liquid ratio;

[0009] S3: Set a target for the percentage increase in instantaneous output;

[0010] S4: Determine the bottom hole flowing pressure before and after pumping based on different wellhead oil pressure values ​​and gas-liquid ratios;

[0011] S5: Calculate the bottom hole pressure difference before and after pumping under different wellhead oil pressure values;

[0012] S6: Determine the correspondence between bottom hole flowing pressure and instantaneous oil well production;

[0013] S7: Calculate the instantaneous production increase ratio before and after pumping, based on different wellhead oil pressure values;

[0014] S8: Compare the calculated instantaneous production increase ratio η with the set instantaneous production increase target ratio η. t Choose η greater than or equal to η t The minimum wellhead pressure corresponding to the minimum value is taken as the optimal shaft wellhead pressure, and the timing when the wellhead pressure reaches the optimal shaft wellhead pressure is determined as the optimal shaft timing.

[0015] Furthermore, the wellhead oil pressure value is used as the oil pressure value corresponding to the candidate optimal shaft rotation timing.

[0016] Furthermore, the gas-liquid ratio is the gas-liquid ratio for the current 30 days of operation.

[0017] Furthermore, the bottom-hole flowing pressure value before pumping is determined based on the depth and gas-liquid ratio characteristics of the target oil well and using wellbore multiphase flow calculation methods such as Beggs-Brill.

[0018] Furthermore, the bottom hole pressure values ​​before and after pumping are determined using a wellbore pressure drop calculation method that takes into account artificial lifting.

[0019] Furthermore, the relationship between the bottom hole flowing pressure and the instantaneous production of the oil well is determined using methods such as the production capacity equation and numerical simulation. The production capacity equation is a trilinear flow production capacity equation, which includes three regions: formation, bedrock, microfractures, and artificial fractures.

[0020] Area 1: Stratigraphy

[0021]

[0022] Area 2: Bedrock towards microfractures

[0023]

[0024] Area 3: Artificial cracks

[0025]

[0026] Where P o The pressure value for region 1, 10 5 Pa; x F The crack half-length is in cm; x e The formation control half-length is in cm; G is the initiation pressure gradient, 10. 5 Pa / cm; P i This represents the original formation pressure value, 105 Pa;K o Permeability of region 1; P m P f Pressure values ​​in region 2, representing bedrock and natural fractures respectively; P F K represents the pressure value in artificial crack region 3. m K F The values ​​represent the permeability of the bedrock and natural fractures in region 2, respectively; y o Half the crack spacing, in cm; w f For the width of the artificial crack,

[0027] Numerical simulation methods require constructing a single-well numerical model of a volumetric fracturing well, setting different bottom hole flowing pressures, simulating the corresponding production characteristics, and thus obtaining a quantitative relationship between instantaneous production and bottom hole flowing pressure.

[0028] Furthermore, the instantaneous production increase ratio before and after pumping is calculated using the following formula:

[0029]

[0030] Where η is the instantaneous increase in output before and after pumping, dimensionless; q a The instantaneous oil production after pumping, in tons per day; q b The instantaneous oil production after pumping, in tons per day.

[0031] Furthermore, the wellhead pressure p corresponding to the optimal shaft rotation timing t-min Select an inlet pressure greater than or equal to the gathering and transportation limit wellhead pressure p. j If the wellhead pressure is less than the gathering and transportation limit wellhead pressure p j The gathering and transportation limit wellhead pressure p j The wellhead pressure p corresponding to the optimal shaft rotation timing t-min This optimizes the shaft rotation timing t under this gas-liquid ratio condition. a-max The gathering and transportation limit wellhead pressure is the minimum wellhead pressure that ensures crude oil can flow into the surface separator.

[0032] Furthermore, the shale oil well shaft rotation timing determination device includes a shale shaft rotation timing system, a processor, and a memory. The processor executes the program stored in the memory to implement the steps of the shale oil well shaft rotation timing determination method, and the memory stores the computer program.

[0033] Furthermore, the shale oil well shaft rotation timing system includes: a wellhead pressure data acquisition module, a gas-liquid ratio acquisition module, a bottom hole flowing pressure calculation module, an oil production calculation module, and a shaft rotation timing optimization module.

[0034] Furthermore, the wellhead pressure data acquisition module is used to acquire wellhead pressure in real time; the gas-liquid ratio acquisition module is used to acquire gas-liquid ratio in real time; the bottom hole flowing pressure calculation module is used to calculate the bottom hole flowing pressure and its difference before and after pumping based on the acquired wellhead pressure and gas-liquid ratio; the oil production calculation module is used to determine the correspondence between bottom hole flowing pressure and instantaneous oil well production, and to calculate the difference in instantaneous oil well production corresponding to different combinations of wellhead oil pressure and gas-liquid ratio before and after pumping; the shaft rotation timing optimization module is used to optimize the shaft rotation timing under a specific gas-liquid ratio condition based on the required target increase in instantaneous production before and after shaft rotation.

[0035] Furthermore, the shale oil well shaft rotation timing system sequentially obtains the optimal shaft rotation timing through the wellhead pressure data acquisition module, gas-liquid ratio acquisition module, bottom hole flowing pressure calculation module, oil production calculation module, and shaft rotation timing optimization module.

[0036] The technical effects and advantages of this invention are as follows: The method and apparatus for determining the optimal shaft rotation timing of shale oil wells ensure normal production of the wells while meeting the need to adjust the instantaneous production rate according to the set target. This overcomes the problem that traditional shaft rotation timing optimization can only obtain the latest shaft rotation timing, resulting in an uncontrollable increase in the instantaneous production rate, and improves the controllability of the instantaneous production rate of shale oil wells. Attached Figure Description

[0037] Figure 1 This is a flowchart illustrating the method for determining the pivot timing of shale oil wells according to the present invention.

[0038] Figure 2 This is a schematic diagram of the bottom hole flowing pressure corresponding to different oil pressures before the pump in an embodiment of the present invention;

[0039] Figure 3 This is a schematic diagram showing the instantaneous production increase ratio corresponding to different oil pressures in an embodiment of the present invention. Detailed Implementation

[0040] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0041] This invention provides, for example Figure 1 This paper presents a method for determining the production technology of a horizontal well throughout its entire life cycle by volumetric compression fracturing.

[0042] The method for determining the timing of shaft rotation in shale oil wells includes the following steps:

[0043] S1: Set different wellhead oil pressure values;

[0044] S2: Set the gas-liquid ratio;

[0045] S3: Set a target for the percentage increase in instantaneous output;

[0046] S4: Determine the bottom hole flowing pressure before and after pumping based on different wellhead oil pressure values ​​and gas-liquid ratios;

[0047] S5: Calculate the bottom hole pressure difference before and after pumping under different wellhead oil pressure values;

[0048] S6: Determine the correspondence between bottom hole flowing pressure and instantaneous oil well production;

[0049] S7: Calculate the instantaneous production increase ratio before and after pumping, based on different wellhead oil pressure values;

[0050] S8: Compare the calculated instantaneous production increase ratio η with the set instantaneous production increase target ratio η. t Choose η greater than or equal to η t The minimum wellhead pressure corresponding to the minimum value is taken as the optimal shaft wellhead pressure, and the timing when the wellhead pressure reaches the optimal shaft wellhead pressure is determined as the optimal shaft timing.

[0051] The different wellhead pressure values ​​are set within the range that meets actual production needs. The gas-liquid ratio is set according to the actual dynamic production situation. The instantaneous production increase target is set according to the production increase requirements.

[0052] The wellhead oil pressure value is used as the oil pressure value corresponding to the candidate optimal shaft rotation time.

[0053] The gas-liquid ratio is the gas-liquid ratio for the current 30 days of operation.

[0054] The bottom-hole flowing pressure value before pumping is determined based on the depth and gas-liquid ratio characteristics of the target oil well, and using the Beggs-Brill wellbore multiphase flow calculation method.

[0055] The bottom hole pressure values ​​before and after pumping are determined using a wellbore pressure drop calculation method that takes into account artificial lifting.

[0056] The relationship between bottomhole flowing pressure and instantaneous oil well production was determined using methods such as production capacity equations and numerical simulations. The production capacity equation adopted was a trilinear flow production capacity equation, which included three regions: formation, bedrock, microfractures, and artificial fractures.

[0057] Area 1: Stratigraphy

[0058]

[0059] Area 2: Bedrock towards microfractures

[0060]

[0061] Area 3: Artificial cracks

[0062]

[0063] Where P o The pressure value for region 1, 10 5 Pa; x F The crack half-length is in cm; x e The formation control half-length is in cm; G is the initiation pressure gradient, 10. 5 Pa / cm; P i This represents the original formation pressure value, 10 5 Pa;K o Permeability of region 1; P m P f Pressure values ​​in region 2, representing bedrock and natural fractures respectively; P F K represents the pressure value in artificial crack region 3. m K F The values ​​represent the permeability of the bedrock and natural fractures in region 2, respectively; y o Half the crack spacing, in cm; w f For the width of the artificial crack,

[0064] Numerical simulation methods require constructing a single-well numerical model of a volumetric fracturing well, setting different bottom hole flowing pressures, simulating the corresponding production characteristics, and thus obtaining a quantitative relationship between instantaneous production and bottom hole flowing pressure.

[0065] The instantaneous output increase ratio before and after pumping is calculated using the following formula:

[0066]

[0067] Where η is the instantaneous increase in output before and after pumping, dimensionless; q a The instantaneous oil production after pumping, in tons per day; q b The instantaneous oil production after pumping, in tons per day.

[0068] The wellhead pressure p corresponding to the optimal shaft rotation timing t-min Select an inlet pressure greater than the gathering and transportation limit wellhead pressure p j If the wellhead pressure is less than the gathering and transportation limit wellhead pressure p j The gathering and transportation limit wellhead pressure p j The wellhead pressure p corresponding to the optimal shaft rotation timing t-minThis optimizes the shaft rotation timing t under this gas-liquid ratio condition. a-max The gathering and transportation limit wellhead pressure is the minimum wellhead pressure that ensures crude oil can flow into the surface separator.

[0069] The shale oil well pivot timing determination device includes a shale pivot timing system, a processor, and a memory. The processor executes the program stored in the memory to implement the steps of the shale oil well pivot timing determination method. The memory stores the computer program.

[0070] The shale oil well shaft rotation timing system includes: a wellhead pressure data acquisition module, a gas-liquid ratio acquisition module, a bottom hole flowing pressure calculation module, an oil production calculation module, and a shaft rotation timing optimization module.

[0071] The wellhead pressure data acquisition module is used to acquire wellhead pressure in real time. The gas-liquid ratio acquisition module is used to acquire gas-liquid ratio in real time. The bottom hole flowing pressure calculation module is used to calculate the bottom hole flowing pressure before and after pumping and its difference based on the acquired wellhead pressure and gas-liquid ratio. The oil production calculation module is used to determine the correspondence between bottom hole flowing pressure and instantaneous oil well production, and to calculate the difference in instantaneous oil well production corresponding to different combinations of wellhead oil pressure and gas-liquid ratio before and after pumping. The shaft rotation timing optimization module is used to optimize the shaft rotation timing under a specific gas-liquid ratio condition based on the desired instantaneous production increase ratio before and after shaft rotation. The shale oil well shaft rotation timing system obtains the optimal shaft rotation timing sequentially through the wellhead pressure data acquisition module, gas-liquid ratio acquisition module, bottom hole flowing pressure calculation module, oil production calculation module, and shaft rotation timing optimization module.

[0072] Example

[0073] S1: Set the wellhead oil pressure values ​​to 0.1, 1, 2, 3, 4, 5, 6, 7, 8, 9, and 10 MPa respectively, as the oil pressure values ​​corresponding to the candidate optimal switching pumping timing;

[0074] S2: Set the gas-liquid ratio to 200 cubic meters per cubic meter based on the production status of the oil well;

[0075] S3: Based on the depth characteristics of the target oil well and using wellbore multiphase flow calculation methods such as Beggs-Brill, determine the bottom hole flowing pressure values ​​corresponding to different wellhead oil pressures before pumping, such as... Figure 2 As shown;

[0076] S4: Using the wellbore pressure loss calculation method after pumping, determine the bottom hole flowing pressure value corresponding to different wellhead oil pressures after pumping;

[0077] S5: Calculate the bottom hole flowing pressure difference corresponding to different wellhead oil pressures before and after pumping;

[0078] S6: Use numerical simulation and other methods to determine the correspondence between bottom hole flowing pressure and instantaneous oil well production;

[0079] S7: Calculate the instantaneous production increase percentage corresponding to different combinations of wellhead oil pressure and gas-liquid ratio before and after pumping:

[0080]

[0081] Where η is the instantaneous output increase ratio before and after pumping, which is dimensionless; q a The instantaneous oil production after pumping, in tons per day; q b The instantaneous oil production after pumping is expressed in tons per day. The calculation results are as follows: Figure 3 As shown;

[0082] S8: Based on the target instantaneous production increase of 10% before and after pumping, and combining the relationship between wellhead oil pressure and production increase before and after pumping under different gas-liquid ratios calculated in step 7, for each gas-liquid ratio, select candidate wellhead pressures where the instantaneous production increase η is greater than the target η. t The minimum wellhead pressure at that time. The oil pressure corresponding to 150 cubic meters / cubic meter is 5.2 MPa.

[0083] The gathering and transportation limit wellhead pressure p of this well j The pressure is 3 MPa, and the pressure in step 8 is greater than the gathering and transportation limit wellhead pressure p. j Therefore, the wellhead pressure p corresponding to the optimal switching time for pumping when the gas-liquid ratio is 150 cubic meters / cubic meter is... t-min The pressure is set to 5.2 MPa, thus optimizing the timing of pumping transition under this gas-liquid ratio condition. a-max .

[0084] By tracking, measuring, and analyzing the gas-liquid ratio and wellhead pressure during well production, the well achieved an average gas-liquid ratio of 150 cubic meters per cubic meter after 216 days of production. The wellhead pressure decreased to 5.2 MPa, which is equal to the wellhead pressure p corresponding to the optimal switching point under the average gas-liquid ratio conditions of that day. t-min The pumping unit was switched to a pumping unit, and normal production resumed after the switch, with an instantaneous increase in oil production of approximately 10%.

[0085] The shale oil well pivot timing determination device includes a shale pivot timing system, a processor, and a memory. The processor executes the program stored in the memory to implement the steps of the shale oil well pivot timing determination method. The memory stores the computer program.

[0086] The shale oil well shaft rotation timing system includes: a wellhead pressure data acquisition module, a gas-liquid ratio acquisition module, a bottom hole flowing pressure calculation module, an oil production calculation module, and a shaft rotation timing optimization module.

[0087] The wellhead pressure data acquisition module is used to acquire wellhead pressure in real time; the gas-liquid ratio acquisition module is used to acquire gas-liquid ratio in real time; the bottom hole flowing pressure calculation module is used to calculate the bottom hole flowing pressure and its difference before and after pumping based on the acquired wellhead pressure and gas-liquid ratio; the oil production calculation module is used to determine the correspondence between bottom hole flowing pressure and instantaneous oil well production, and to calculate the difference in instantaneous oil well production corresponding to different combinations of wellhead oil pressure and gas-liquid ratio before and after pumping; the shaft rotation timing optimization module is used to optimize the shaft rotation timing under a specific gas-liquid ratio condition based on the required target increase in instantaneous production before and after shaft rotation.

[0088] Working Principle: This shale oil well shaft rotation timing determination method, based on the desired instantaneous production increase ratio before and after shaft rotation, combines the calculated correspondence between wellhead oil pressure and production increase ratio before and after pumping under different gas-liquid ratios. It selects candidate wellhead pressures with the instantaneous production increase ratio and compares it with the gathering and transportation limit wellhead oil pressure value to obtain the optimal shaft rotation timing. If the wellhead oil pressure value does not meet the conditions, the shaft rotation timing is optimized. The shale oil well shaft rotation timing determination device includes a shale shaft rotation timing system, a processor, and a memory. The shale oil well shaft rotation timing system includes: a wellhead pressure data acquisition module, a gas-liquid ratio acquisition module, a bottomhole flowing pressure calculation module, an oil production calculation module, and a shaft rotation timing optimization module. The shaft rotation timing optimization module optimizes the shaft rotation timing under specific gas-liquid ratio conditions based on the desired instantaneous production increase ratio before and after shaft rotation.

[0089] Finally, it should be noted that the above description is only a preferred embodiment of the present invention and is not intended to limit the present invention. Although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art can still modify the technical solutions described in the foregoing embodiments or make equivalent substitutions for some of the technical features. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the protection scope of the present invention.

Claims

1. A method for determining the timing of shaft rotation in shale oil wells, characterized in that: The method for determining the timing of shaft rotation in shale oil wells includes the following steps: S1: Set different wellhead oil pressure values; S2: Set the gas-liquid ratio; S3: Set a target for the percentage increase in instantaneous output; S4: Determine the bottom hole flowing pressure before and after pumping based on different wellhead oil pressure values ​​and gas-liquid ratios; the bottom hole flowing pressure before pumping is determined based on the depth and gas-liquid ratio characteristics of the target oil well and using the Beggs-Brill wellbore multiphase flow calculation method; the bottom hole flowing pressure after pumping is determined using the wellbore pressure drop calculation method considering artificial lift. S5: Calculate the bottom hole pressure difference before and after pumping under different wellhead oil pressure values; S6: Determine the correspondence between bottom hole flowing pressure and instantaneous oil well production; the correspondence between bottom hole flowing pressure and instantaneous oil well production is determined using the production capacity equation and numerical simulation method, wherein the production capacity equation adopts the trilinear flow production capacity equation; Numerical simulation methods require constructing a single-well numerical model of a volumetric fracturing well, setting different bottom hole flowing pressures, simulating the corresponding production characteristics, and thus obtaining a quantitative relationship between instantaneous production and bottom hole flowing pressure. S7: Calculate the instantaneous production increase ratio before and after pumping, based on different wellhead oil pressure values; S8: Comparison calculation yields the instantaneous output increase ratio Compared with the set instantaneous production increase target Select Greater than or equal to The minimum wellhead oil pressure corresponding to the optimal shaft wellhead oil pressure is taken as the optimal shaft wellhead oil pressure, and the timing when the wellhead oil pressure reaches the optimal shaft wellhead oil pressure is determined as the optimal shaft timing; the wellhead oil pressure corresponding to the optimal shaft timing... Select a wellhead oil pressure greater than or equal to the gathering and transportation limit wellhead pressure. ; If the wellhead oil pressure is less than the gathering and transportation limit wellhead pressure The gathering and transportation limit wellhead pressure The wellhead oil pressure corresponding to the optimal shaft rotation time This optimizes the timing of shaft rotation under this gas-liquid ratio condition. The gathering and transportation limit wellhead pressure is the minimum wellhead oil pressure that ensures crude oil can flow into the surface separator.

2. The method for determining the timing of shaft rotation in a shale oil well according to claim 1, characterized in that: The wellhead oil pressure value is used as the oil pressure value corresponding to the candidate optimal shaft rotation time.

3. The method for determining the timing of shaft rotation in a shale oil well according to claim 1, characterized in that: The gas-liquid ratio is the gas-liquid ratio for the current 30 days of operation.

4. The method for determining the timing of shaft rotation in a shale oil well according to claim 1, characterized in that: The productivity equation includes three regions: formation, bedrock, microfractures, and artificial fractures. Area 1: Stratigraphy Area 2: Bedrock towards microfractures Area 3: Artificial cracks Where P o The pressure value for region 1; x F For half the length of the crack; x e G is the formation control half-length; G is the initiation pressure gradient; P i K represents the original formation pressure value. o Permeability of region 1; P m P f Pressure values ​​in region 2, representing bedrock and natural fractures respectively; P F K represents the pressure value in artificial crack region 3. m K F The values ​​represent the permeability of the bedrock and natural fractures in region 2, respectively; y o Half the crack spacing; w f The width of the artificial crack.

5. The method for determining the timing of shaft rotation in a shale oil well according to claim 1, characterized in that: The instantaneous output increase ratio before and after pumping is calculated using the following formula: in The instantaneous increase in output before and after pumping is dimensionless. The instantaneous oil production after pumping, in tons per day; The instantaneous oil production rate before pumping, in tons per day.

6. A shale oil well shaft rotation timing determination system for implementing any one of claims 1-5, characterized in that: The shale oil well rotation timing determination system includes: The wellhead oil pressure data acquisition module is used to acquire wellhead oil pressure in real time. The gas-liquid ratio acquisition module is used to acquire the gas-liquid ratio in real time. The bottom hole flowing pressure calculation module is used to calculate the bottom hole flowing pressure and its difference before and after pumping based on the obtained wellhead oil pressure and gas-liquid ratio. The bottom hole flowing pressure value before pumping is determined based on the depth and gas-liquid ratio characteristics of the target oil well and using the Beggs-Brill wellbore multiphase flow calculation method. The bottom hole flowing pressure value after pumping is determined using a wellbore pressure drop calculation method that takes into account artificial lift. The oil production calculation module is used to determine the correspondence between bottom hole flowing pressure and instantaneous oil well production, and to calculate the difference in instantaneous oil well production corresponding to different combinations of wellhead oil pressure and gas-liquid ratio before and after pumping. The correspondence between bottom hole flowing pressure and instantaneous oil well production is determined using a production capacity equation and numerical simulation methods. The production capacity equation adopts a trilinear flow production capacity equation. The numerical simulation method requires constructing a single-well numerical model of the volumetric fracturing well, setting different bottom hole flowing pressures, simulating and obtaining the corresponding production characteristics, thereby obtaining a quantitative relationship between instantaneous production and bottom hole flowing pressure. The shaft rotation timing optimization module is used to optimize the shaft rotation timing under a target gas-liquid ratio based on the desired instantaneous production increase ratio before and after the shaft rotation. The shale oil well rotation timing determination system sequentially obtains the optimal rotation timing through the wellhead oil pressure data acquisition module, gas-liquid ratio acquisition module, bottom hole flowing pressure calculation module, oil production calculation module, and rotation timing optimization module; the wellhead oil pressure corresponding to the optimal rotation timing... Select a wellhead oil pressure greater than or equal to the gathering and transportation limit wellhead pressure. If the wellhead oil pressure is less than the gathering and transportation limit wellhead pressure The gathering and transportation limit wellhead pressure The wellhead oil pressure corresponding to the optimal shaft rotation time This optimizes the timing of shaft rotation under this gas-liquid ratio condition. The gathering and transportation limit wellhead pressure is the minimum wellhead oil pressure that ensures crude oil can flow into the surface separator.

7. A device for determining the timing of shaft rotation in a shale oil well as described in claim 6, characterized in that: The system includes a shale well rotation timing determination system, a processor, and a memory. The processor executes a program stored in the memory to implement the steps of the shale oil well rotation timing determination method, and the memory stores the computer program.

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