A method for improving and optimizing oilfield production technology

Abstract

The invention discloses a method for improving and optimizing oilfield production process, which relates to the field of petrochemical technology. The method includes: real-time collection of water content, porosity and permeability data, dynamic analysis and prediction of reservoir changes; intelligent adjustment of pumping unit operation parameters and reagent delivery based on water content changes to achieve flexible pumping control; real-time monitoring of separation device pressure and temperature, dynamic optimization of separation efficiency, and reduction of water content and emulsification; prevention of blockage through stratified priority discharge and intelligent adjustment to achieve mud and sand discharge and waste treatment; dynamic adjustment of storage tank parameters and associated gas recovery strategy to achieve multi-level recovery and safety control; real-time monitoring and feedback optimization of the entire process, combined with trend analysis and prediction models, to formulate long-term optimization strategies. The invention can effectively improve oilfield recovery, reduce water content and energy consumption, prevent equipment blockage, promote waste resource utilization, and ultimately achieve efficient, safe and green oilfield production.

Description

Technical Field

[0001] The invention relates to the technical field of petrochemical engineering, and in particular to a method for improving and optimizing oilfield production technology. Background Art

[0002] At present, oilfield production technology has become intelligent and automated, and advanced monitoring and control technologies are widely used to improve production efficiency. Through intelligent wellhead management systems and multifunctional separation devices, reservoir dynamic data is collected in real time to monitor and manage key parameters such as water content, porosity and permeability. In addition, intelligent control methods are gradually being adopted in separation, storage and associated gas recovery to promote refined management of oilfield production and efficient use of resources.

[0003] In the oilfield production process, crude oil extraction is accompanied by complex multiphase fluid behavior and water content changes, which brings challenges to the separation and processing technology. When faced with problems such as reservoir scouring, water content fluctuations, mud and sand deposition, and associated gas recovery, traditional processes have a slow response speed and relatively simple adjustment methods, making it difficult to achieve dynamic optimization and refined management of the entire process. This has affected production efficiency and resource utilization to a certain extent.

[0004] In response to the above problems, the present invention provides a method for improving and optimizing oil field production processes, which can achieve closed-loop optimization management of the entire process of oil extraction, separation, storage and associated gas recovery through real-time data collection and dynamic analysis, thereby improving oil field recovery rates, reducing energy consumption, and effectively reducing production risks and environmental impacts. Summary of the invention

[0005] In view of the above problems, the present invention provides a method for improving and optimizing oilfield production processes to solve the problems of slow response speed and relatively single adjustment means in the prior art when facing reservoir scour, water content fluctuation, mud and sand deposition and associated gas recovery.

[0006] In order to solve the above technical problems, the present invention provides the following technical solutions:

[0007] The present invention provides a method for improving and optimizing oilfield production technology, comprising the following steps:

[0008] Step S1, real-time collection of water content, porosity and permeability data, and dynamic analysis to predict reservoir changes;

[0009] Wherein step S1 also includes the following sub-steps:

[0010] S1-1, check the normal operation of the single well intelligent management system and the multifunctional separation device; collect dynamic water content, porosity and permeability parameters through sensors, and establish a real-time monitoring mechanism;

[0011] S1-2, a time series model is used to dynamically analyze the permeability, predict the impact of reservoir scouring on permeability, monitor water channeling risk through real-time water content change rate, and reflect the impact of reservoir compaction or scouring through cumulative changes in porosity, as shown in Equation (1) to Equation (3):

[0012] Formula (1)

[0013] in, is the permeability of the reservoir at a certain point in time, is the initial permeability, , are experimental fitting parameters, which depend on reservoir geological characteristics and water injection intensity;

[0014] Formula (2)

[0015] in, is the water content of the reservoir at a certain point in time, is the initial moisture content, is the water injection flushing influence coefficient;

[0016] Formula (3)

[0017] in, is the porosity of the reservoir at a certain point in time, is the initial porosity, is the porosity change over time.

[0018] Step S2, based on the change of water content, intelligently adjust the pumping unit operating parameters and the dosage of chemicals to achieve flexible pumping control;

[0019] Wherein step S2 also includes the following sub-steps:

[0020] S2-1, real-time monitoring of the rate of change of water content as the key basis for pumping adjustment; according to the changing trend of wellhead water content, the operating parameters of the pumping unit, namely frequency, stroke and pressure, are adjusted to achieve flexible pumping control, prevent water cone from rising and reduce water content, as shown in formula (4) to formula (7):

[0021] Formula (4)

[0022] in, is the rate of change of moisture content, reflecting the speed at which moisture content increases or decreases;

[0023] Formula (5)

[0024] in, is the initial pumping frequency, , is the adjustment factor, , emphasizing the influence of moisture content;

[0025] Formula (6)

[0026] in, Initial pumping unit stroke, is the stroke adjustment coefficient, which is dynamically adjusted according to the change of moisture content;

[0027] Formula (7)

[0028] in, is the initial displacement pressure, is the pressure adjustment factor;

[0029] S2-2, by real-time monitoring of moisture content changes as the basis for adjusting the dosage of agents, dynamically select different types of agents according to the moisture content level, intelligently adjust the agent concentration according to the moisture content change rate, adjust the agent injection rate, and quickly respond to moisture content fluctuations, as shown in formulas (8)-(9):

[0030] Formula (8)

[0031] in, It is the real-time drug delivery concentration. is the basic drug concentration, is the adjustment coefficient, which indicates the effect of moisture content change on the dosage of the agent;

[0032] Formula (9)

[0033] in, is the real-time drug injection rate, is the basic injection rate, is the adjustment factor.

[0034] Step S3, real-time monitoring of the pressure and temperature of the separation device, dynamic optimization of the separation efficiency, and reduction of the water content and emulsification phenomenon;

[0035] Wherein step S3 also includes the following sub-steps:

[0036] S3-1, by monitoring the water content, the internal pressure of the separation device, and the changes in the flow rate of the three phases of oil, gas and water, the negative pressure gradient and temperature in the separation device are dynamically adjusted, as shown in formula (10) to formula (12):

[0037] Formula (10)

[0038] in, For the Real-time pressure in the area, is the initial reference pressure, , is the pressure adjustment factor;

[0039] Formula (11)

[0040] in, No. Real-time temperature of the area, is the temperature adjustment factor;

[0041] Formula (12)

[0042] in, Real-time separation efficiency, Oil phase yield, is the total fluid volume;

[0043] S3-2, through real-time monitoring and calculation of separation efficiency, dynamically adjust the pressure and interface height, reduce the water content and prevent emulsification, as shown in formula (13)-formula (14):

[0044] Formula (13)

[0045] Adjust the pressure difference between the inlet area, separation area and discharge area respectively to enhance the phase separation;

[0046] Formula (14)

[0047] in, is the oil-water interface height, is the initial interface height, is the adjustment factor.

[0048] Step S4, through stratified priority discharge and intelligent regulation to prevent blockage, realize mud and sand discharge and waste treatment;

[0049] Wherein step S4 also includes the following sub-steps:

[0050] S4-1, through moisture content monitoring and mud accumulation data, through layered priority discharge strategy and intelligent path adjustment, prevent equipment blockage and operation failure caused by mud deposition, as shown in formula (15) to formula (17):

[0051] Formula (15)

[0052] in, For the Layer discharge pressure, For the The accumulation rate of mud and sand in the layer, For the adjustment coefficient, priority is given to discharge from areas where mud and sand accumulate the fastest;

[0053] Formula (16)

[0054] in, No. Laminar discharge flow rate, is the basic discharge flow rate, is the flow rate adjustment factor;

[0055] Formula (17)

[0056] in, is the blocking risk indicator, is the discharge pressure fluctuation, Fluctuation of discharge flow rate;

[0057] S4-2, by separating and recycling the oily mud and sand and waste liquid generated during the mud and sand discharge process, the residual oil and valuable components can be recovered to the maximum extent, the solid waste discharge can be reduced, and the treatment cost can be reduced, as shown in formula (18) to formula (20):

[0058] Formula (18)

[0059] in, is the oil-sand separation efficiency, is the mass of recovered oil, is the total mass of oil in the oily sediment;

[0060] Formula (19)

[0061] in, is the extraction ratio, is the mass of oil recovered by extraction (kg), is the total mass of sediment (kg);

[0062] Formula (20)

[0063] in, The utilization rate of waste residue resources is The quality of the waste residue used for recycled materials, is the total waste mass.

[0064] Step S5, dynamically adjusting storage tank parameters and associated gas recovery strategy to achieve multi-level recovery and safety control;

[0065] Wherein, in step S5, the following sub-steps are also included:

[0066] S5-1, real-time dynamic adjustment of tank farm operating parameters, based on the real-time dynamic data of reservoir water content, permeability and associated gas volume, to adjust the pressure, temperature and liquid level of the storage tank;

[0067] S5-2, dynamically adjust the gas recovery system, by real-time monitoring of associated gas production fluctuations, using dynamic adjustment algorithms to adjust the operating parameters of the gas recovery system and set a multi-level recovery strategy, as follows:

[0068] Primary recovery: Prioritize recovery of gas in high pressure area;

[0069] Secondary recovery: Continue to recover the remaining gas after reducing the pressure;

[0070] Excess gas treatment: recompress or burn the low-pressure excess gas;

[0071] Pressure safety threshold control is performed by setting upper and lower safety limits.

[0072] Step S6: Real-time monitoring and feedback optimization of the entire process, combined with trend analysis and prediction models, to formulate long-term optimization strategies.

[0073] Wherein, in step S6, the following sub-steps are also included:

[0074] S6-1, full-process real-time monitoring and intelligent feedback optimization, using the full-process real-time monitoring and intelligent feedback optimization mechanism to dynamically optimize and adjust the oil extraction, separation, storage, and associated gas recovery links;

[0075] S6-2, trend analysis and prediction model optimization, evaluates the oilfield development effect through trend analysis and prediction model of full-process production data, and formulates long-term optimization strategies accordingly.

[0076] Compared with the prior art, the present invention has the following beneficial effects:

[0077] The present invention collects and analyzes real-time dynamic data and intelligently adjusts the pumping, separation, storage and associated gas recovery links, thereby significantly improving oilfield production efficiency and resource utilization.

[0078] The present invention optimizes the operating parameters (frequency, stroke, pressure) of the oil pump and the agent delivery strategy in real time based on the change of water content, effectively preventing the water cone from rising and reducing the water content and energy consumption.

[0079] The present invention monitors the three-phase flow rates of oil, gas and water and the internal pressure and temperature of the separation device in real time, dynamically adjusts the separation conditions, improves the separation efficiency, avoids emulsification, ensures the quality of the oil product, and maximizes the recovery of residual oil and valuable components through efficient separation and recovery technology, reduces solid waste emissions, and reduces processing costs and environmental pressures.

[0080] The present invention improves the gas recovery rate and reduces energy waste and environmental pollution through real-time monitoring and multi-stage recovery strategies, high-pressure recovery, low-pressure recovery, and residual gas treatment. It also implements real-time monitoring and intelligent feedback optimization throughout the entire process, effectively reducing production risks, energy consumption, and environmental pollution, and achieving safe, green, and sustainable oilfield development. BRIEF DESCRIPTION OF THE DRAWINGS

[0081] In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings required for use in the embodiments will be briefly introduced below. It is understood that the following drawings only show certain embodiments of the present invention and therefore should not be regarded as limiting the scope. For ordinary technicians in this field, other related drawings can be obtained based on these drawings without creative work.

[0082] Figure 1 It is a flow chart of the method of the present invention. DETAILED DESCRIPTION

[0083] In order to make the purpose, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making creative work belong to the scope of protection of the present invention. Therefore, the following detailed description of the embodiments of the present invention provided in the drawings is not intended to limit the scope of the invention claimed for protection, but is only for selected embodiments of the present invention. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making creative work belong to the scope of protection of the present invention.

[0084] Please refer to Figure 1 The present invention provides a flow chart of a method for improving and optimizing oilfield production technology, which includes the following steps:

[0085] Step S1, real-time collection of water content, porosity and permeability data, and dynamic analysis to predict reservoir changes;

[0086] Wherein step S1 also includes the following sub-steps:

[0087] S1-1, check the normal operation of the single well intelligent management system and the multifunctional separation device; collect dynamic water content, porosity and permeability parameters through sensors, and establish a real-time monitoring mechanism;

[0088] S1-2, a time series model is used to dynamically analyze the permeability, predict the impact of reservoir scouring on permeability, monitor water channeling risk through real-time water content change rate, and reflect the impact of reservoir compaction or scouring through cumulative changes in porosity, as shown in Equation (1) to Equation (3):

[0089] Formula (1)

[0090] in, is the permeability of the reservoir at a certain point in time, is the initial permeability, , are experimental fitting parameters, which depend on reservoir geological characteristics and water injection intensity;

[0091] Formula (2)

[0092] in, is the water content of the reservoir at a certain point in time, is the initial moisture content, is the water injection flushing influence coefficient;

[0093] Formula (3)

[0094] in, is the porosity of the reservoir at a certain point in time, is the initial porosity, is the porosity change over time.

[0095] It should be noted that permeability, that is, water injection and flushing, causes the permeability of the high permeability area to increase rapidly, while the change in the low permeability area is small, and the permeability change shows a power growth relationship; the water content increases exponentially with the injection time, but the growth rate gradually slows down. The better the reservoir permeability, the faster the water content increases; the overall porosity changes little, but the pores in the high permeability area increase, and the pores in the low permeability area decrease.

[0096] Step S2, based on the change of water content, intelligently adjust the pumping unit operating parameters and the dosage of chemicals to achieve flexible pumping control;

[0097] Wherein step S2 also includes the following sub-steps:

[0098] S2-1, real-time monitoring of the rate of change of water content as the key basis for pumping adjustment; according to the changing trend of wellhead water content, the operating parameters of the pumping unit, namely frequency, stroke and pressure, are adjusted to achieve flexible pumping control, prevent water cone from rising and reduce water content, as shown in formula (4) to formula (7):

[0099] Formula (4)

[0100] in, is the rate of change of moisture content, reflecting the speed at which moisture content increases or decreases;

[0101] Formula (5)

[0102] in, is the initial pumping frequency, , is the adjustment factor, , emphasizing the influence of moisture content;

[0103] Formula (6)

[0104] in, Initial pumping unit stroke, is the stroke adjustment coefficient, which is dynamically adjusted according to the change of moisture content;

[0105] Formula (7)

[0106] in, is the initial displacement pressure, is the pressure adjustment factor;

[0107] S2-2, by real-time monitoring of moisture content changes as the basis for adjusting the dosage of agents, dynamically select different types of agents according to the moisture content level, intelligently adjust the agent concentration according to the moisture content change rate, adjust the agent injection rate, and quickly respond to moisture content fluctuations, as shown in formulas (8)-(9):

[0108] Formula (8)

[0109] in, It is the real-time drug delivery concentration. is the basic drug concentration, is the adjustment coefficient, which indicates the effect of moisture content change on the dosage of the agent;

[0110] Formula (9)

[0111] in, is the real-time drug injection rate, is the basic injection rate, is the adjustment factor.

[0112] It should be noted that the relationship between the change in water content and the pumping parameters is: the pumping speed is too fast (high frequency, large stroke) → water cone rises → the water content rises sharply; the pumping speed is too slow → insufficient oil displacement pressure → oil well production decreases.

[0113] When the reservoir permeability changes dynamically, the pumping parameters are flexibly adjusted to prevent water cone phenomenon while ensuring a high oil recovery rate. Through dynamic adjustment, the water cone rise is effectively controlled to reduce the rapid increase rate of water content. Flexible pumping control matches the dynamic changes of the reservoir to maximize the liquid production of the oil well. Dynamic adjustment based on real-time data can avoid ineffective high-load operation of the pumping unit and reduce energy consumption.

[0114] For high water content (>90%), profile control agents are injected first to block water channeling channels; for medium water content (70%-90%), oil displacement agents and demulsifiers are injected to improve oil-water separation and oil recovery effect; for low water content (<70%), an appropriate amount of oil displacement agent is injected to maintain oil recovery efficiency.

[0115] Step S3, real-time monitoring of the pressure and temperature of the separation device, dynamic optimization of the separation efficiency, and reduction of the water content and emulsification phenomenon;

[0116] Wherein step S3 also includes the following sub-steps:

[0117] S3-1, by monitoring the water content, the internal pressure of the separation device, and the changes in the flow rate of the three phases of oil, gas and water, the negative pressure gradient and temperature in the separation device are dynamically adjusted, as shown in formula (10) to formula (12):

[0118] Formula (10)

[0119] in, For the Real-time pressure in the area, is the initial reference pressure, , is the pressure adjustment factor;

[0120] Formula (11)

[0121] in, No. Real-time temperature of the area, is the temperature adjustment factor;

[0122] Formula (12)

[0123] in, Real-time separation efficiency, Oil phase yield, is the total fluid volume;

[0124] S3-2, through real-time monitoring and calculation of separation efficiency, dynamically adjust the pressure and interface height, reduce the water content and prevent emulsification, as shown in formula (13)-formula (14):

[0125] Formula (13)

[0126] Adjust the pressure difference between the inlet area, separation area and discharge area respectively to enhance the phase separation;

[0127] Formula (14)

[0128] in, is the oil-water interface height, is the initial interface height, is the adjustment factor.

[0129] It should be noted that the relationship between water content and negative pressure gradient is: as water content increases → emulsification is more likely to occur during the separation process → negative pressure gradient and temperature adjustment need to be increased.

[0130] The influence of pressure gradient on three-phase separation: too high negative pressure → serious oil-water emulsification; too low negative pressure → incomplete separation, resulting in decreased separation efficiency.

[0131] Step S4, through stratified priority discharge and intelligent regulation to prevent blockage, realize mud and sand discharge and waste treatment;

[0132] Wherein step S4 also includes the following sub-steps:

[0133] S4-1, through moisture content monitoring and mud accumulation data, through layered priority discharge strategy and intelligent path adjustment, prevent equipment blockage and operation failure caused by mud deposition, as shown in formula (15) to formula (17):

[0134] Formula (15)

[0135] in, For the Layer discharge pressure, For the The accumulation rate of mud and sand in the layer, For the adjustment coefficient, priority is given to discharge from areas where mud and sand accumulate the fastest;

[0136] Formula (16)

[0137] in, No. Laminar discharge flow rate, is the basic discharge flow rate, is the flow rate adjustment factor;

[0138] Formula (17)

[0139] in, is the blocking risk indicator, is the discharge pressure fluctuation, Fluctuation of discharge flow rate;

[0140] S4-2, by separating and recycling the oily mud and sand and waste liquid generated during the mud and sand discharge process, the residual oil and valuable components can be recovered to the maximum extent, the solid waste discharge can be reduced, and the treatment cost can be reduced, as shown in formula (18) to formula (20):

[0141] Formula (18)

[0142] in, is the oil-sand separation efficiency, is the mass of recovered oil, is the total mass of oil in the oily sediment;

[0143] Formula (19)

[0144] in, is the extraction ratio, is the mass of oil recovered by extraction (kg), is the total mass of sediment (kg);

[0145] Formula (20)

[0146] in, The utilization rate of waste residue resources is The quality of the waste residue used for recycled materials, is the total waste mass.

[0147] It should be noted that the increase in water content and sediment production and the intensification of reservoir scouring lead to an increase in the proportion of crude oil entrained in sediment, which needs to be recovered in time; the relationship between sediment particle size and oil viscosity is that the finer the particle size, the more serious the residual oil adhesion → the synergistic recovery effect of hot washing and solvent extraction is better.

[0148] Step S5, dynamically adjusting storage tank parameters and associated gas recovery strategy to achieve multi-level recovery and safety control;

[0149] Wherein, in step S5, the following sub-steps are also included:

[0150] S5-1, real-time dynamic adjustment of tank farm operating parameters, based on the real-time dynamic data of reservoir water content, permeability and associated gas volume, to adjust the pressure, temperature and liquid level of the storage tank;

[0151] S5-2, dynamically adjust the gas recovery system, by real-time monitoring of associated gas production fluctuations, using dynamic adjustment algorithms to adjust the operating parameters of the gas recovery system and set a multi-level recovery strategy, as follows:

[0152] Primary recovery: Prioritize recovery of gas in high pressure area;

[0153] Secondary recovery: Continue to recover the remaining gas after reducing the pressure;

[0154] Excess gas treatment: recompress or burn the low-pressure excess gas;

[0155] Pressure safety threshold control is performed by setting upper and lower safety limits.

[0156] Step S6: Real-time monitoring and feedback optimization of the entire process, combined with trend analysis and prediction models, to formulate long-term optimization strategies.

[0157] Wherein, in step S6, the following sub-steps are also included:

[0158] S6-1, full-process real-time monitoring and intelligent feedback optimization, using the full-process real-time monitoring and intelligent feedback optimization mechanism to dynamically optimize and adjust the oil extraction, separation, storage, and associated gas recovery links;

[0159] S6-2, trend analysis and prediction model optimization, evaluates the oilfield development effect through trend analysis and prediction model of full-process production data, and formulates long-term optimization strategies accordingly.

[0160] The above description is only a preferred embodiment of the present invention and is not intended to limit the present invention. For those skilled in the art, the present invention has various modifications and variations. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present invention shall be included in the protection scope of the present invention.

Claims

1. A method for improving and optimizing oilfield production technology, characterized in that: The following steps are involved: Step S1, real-time collection of water content, porosity and permeability data, and dynamic analysis to predict reservoir changes; Step S2, based on the change of water content, intelligently adjust the pumping unit operating parameters and the dosage of chemicals to achieve flexible pumping control; Step S3, real-time monitoring of the pressure and temperature of the separation device, dynamic optimization of the separation efficiency, and reduction of the water content and emulsification phenomenon; Step S4, through stratified priority discharge and intelligent regulation to prevent blockage, realize mud and sand discharge and waste treatment; Step S5, dynamically adjusting storage tank parameters and associated gas recovery strategy to achieve multi-level recovery and safety control; Step S6: real-time monitoring and feedback optimization of the entire process, combined with trend analysis and prediction models, to formulate long-term optimization strategies; Wherein step S2 also includes the following sub-steps: S2-1, real-time monitoring of the rate of change of water content as the key basis for pumping adjustment; according to the changing trend of wellhead water content, the operating parameters of the pumping unit, namely frequency, stroke and pressure, are adjusted to achieve flexible pumping control, prevent water cone from rising and reduce water content, as shown in formula (4) to formula (7): Formula (4) in, is the rate of change of moisture content, reflecting the speed at which moisture content increases or decreases; Formula (5) in, is the initial pumping frequency, , is the adjustment factor, , emphasizing the influence of moisture content; Formula (6) in, is the stroke of the pumping unit, Initial pumping unit stroke, is the stroke adjustment coefficient, which is dynamically adjusted according to the change of moisture content; Formula (7) in, is the oil displacement pressure of the pumping unit, is the initial displacement pressure, is the pressure adjustment factor; S2-2, by real-time monitoring of moisture content changes as the basis for adjusting the dosage of agents, dynamically select different types of agents according to the moisture content level, intelligently adjust the agent concentration according to the moisture content change rate, adjust the agent injection rate, and quickly respond to moisture content fluctuations, as shown in formulas (8)-(9): Formula (8) in, It is the real-time drug delivery concentration. is the basic drug concentration, is the adjustment coefficient, which indicates the effect of moisture content change on the dosage of the agent; Formula (9) in, is the real-time drug injection rate, is the basic injection rate, is the adjustment factor.

2. The method for improving and optimizing oilfield production process according to claim 1, characterized in that: Wherein step S1 also includes the following sub-steps: S1-1, check the normal operation of the single well intelligent management system and the multifunctional separation device; collect dynamic water content, porosity and permeability parameters through sensors, and establish a real-time monitoring mechanism; S1-2, a time series model is used to dynamically analyze the permeability, predict the impact of reservoir scouring on permeability, monitor water channeling risk through real-time water content change rate, and reflect the impact of reservoir compaction or scouring through cumulative changes in porosity, as shown in Equation (1) to Equation (3): Formula (1) in, is the permeability of the reservoir at a certain point in time, is the initial permeability, , are experimental fitting parameters, which depend on reservoir geological characteristics and water injection intensity; Formula (2) in, is the water content of the reservoir at a certain point in time, is the initial moisture content, is the water injection flushing influence coefficient; Formula (3) in, is the porosity of the reservoir at a certain point in time, is the initial porosity, is the porosity change over time.

3. The method for improving and optimizing oilfield production process according to claim 1, characterized in that: Wherein step S3 also includes the following sub-steps: S3-1, by monitoring the water content, the internal pressure of the separation device, and the changes in the flow rate of the three phases of oil, gas and water, the negative pressure gradient and temperature in the separation device are dynamically adjusted, as shown in formula (10) to formula (12): Formula (10) in, For the Real-time pressure in the area, is the initial reference pressure, , is the pressure adjustment factor; Formula (11) in, No. Real-time temperature of the area, is the temperature adjustment factor; Formula (12) in, Real-time separation efficiency, Oil phase yield, is the total fluid volume; S3-2, through real-time monitoring and calculation of separation efficiency, dynamically adjust the pressure and interface height, reduce the water content and prevent emulsification, as shown in formula (13)-formula (14): Formula (13) Adjust the pressure difference between the inlet area, separation area and discharge area respectively to enhance the phase separation; Formula (14) in, is the oil-water interface height, is the initial interface height, is the adjustment factor.

4. The method for improving and optimizing oilfield production process according to claim 1, characterized in that: Wherein step S4 also includes the following sub-steps: S4-1, through moisture content monitoring and mud accumulation data, through layered priority discharge strategy and intelligent path adjustment, prevent equipment blockage and operation failure caused by mud deposition, as shown in formula (15) to formula (17): Formula (15) in, For the Layer discharge pressure, For the The accumulation rate of mud and sand in the layer, For the adjustment coefficient, priority is given to discharge from areas where mud and sand accumulate the fastest; Formula (16) in, No. Laminar discharge flow rate, is the basic discharge flow rate, is the flow rate adjustment factor; Formula (17) in, is the blocking risk indicator, is the discharge pressure fluctuation, Fluctuation of discharge flow rate; S4-2, by separating and recycling the oily mud and sand and waste liquid generated during the mud and sand discharge process, the residual oil and valuable components can be recovered to the maximum extent, the solid waste discharge can be reduced, and the treatment cost can be reduced, as shown in formula (18) to formula (20): Formula (18) in, is the oil-sand separation efficiency, is the mass of recovered oil, is the total mass of oil in the oily sediment; Formula (19) in, is the extraction ratio, is the mass of oil recovered by extraction (kg), is the total mass of sediment (kg); Formula (20) in, The utilization rate of waste residue resources is The quality of the waste residue used for recycled materials, is the total waste mass.

5. The method for improving and optimizing oilfield production process according to claim 1, characterized in that: Wherein, in step S5, the following sub-steps are also included: S5-1, real-time dynamic adjustment of tank farm operating parameters, based on the real-time dynamic data of reservoir water content, permeability and associated gas volume, to adjust the pressure, temperature and liquid level of the storage tank; S5-2, dynamically adjust the gas recovery system, by real-time monitoring of associated gas production fluctuations, using dynamic adjustment algorithms to adjust the operating parameters of the gas recovery system and set a multi-level recovery strategy, as follows: Primary recovery: Prioritize recovery of gas in high pressure area; Secondary recovery: Continue to recover the remaining gas after reducing the pressure; Excess gas treatment: recompress or burn the low-pressure excess gas; Pressure safety threshold control is performed by setting upper and lower safety limits.

6. The method for improving and optimizing oilfield production process according to claim 1, characterized in that: Wherein, in step S6, the following sub-steps are also included: S6-1, full-process real-time monitoring and intelligent feedback optimization, using the full-process real-time monitoring and intelligent feedback optimization mechanism to dynamically optimize and adjust the oil extraction, separation, storage, and associated gas recovery links; S6-2, trend analysis and prediction model optimization, evaluates the oilfield development effect through trend analysis and prediction model of full-process production data, and formulates long-term optimization strategies accordingly.

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