77 results about "Bottom hole pressure" patented technology

The invention provides a method and a device for predicting a steam cavity in steam flooding by using an overlap factor, and belongs to the technical field of oil field oil extraction. The method comprises the following steps: determining an incidence relation between wellhead production characteristics of a first production well and a well bottom average temperature value, and determining a well bottom average temperature value of a second production well according to wellhead production characteristics of the second production well by utilizing the incidence relation; determining overlap factors of different displacement layer sections of the first production well; weighting the well bottom average temperature value of the second production well by using the overlay factor of each displacement layer section, and obtaining the well bottom correction temperature of each displacement layer section in the second production well in a one-to-one correspondence manner; and comparing the well bottom correction temperature of the second production well with the well bottom temperature of the steam injection well in the well group where the second production well is located, comparing the well bottom pressure of the second production well with the well bottom pressure of the steam injection well, and identifying the steam cavity of each displacement layer section of the second production well. By means of the method, rapid, accurate and low-cost recognition of the steam cavity is achieved.

The invention provides a shale gas well inter-well pressure channeling identification method, system, device and medium, the shale gas well inter-well pressure channeling identification method comprises the following steps: carrying out well test analysis in a pump stop pressure drop stage after fracturing, and collecting data; the bottom hole pressure is calculated, and pressure data oscillation caused by the water hammer effect is eliminated; drawing a pressure difference and pressure difference derivative double logarithmic curve based on the bottom hole pressure data; establishing a shale gas well non-uniform fracture multi-zone coupling well test seepage model; the model parameters are adjusted, a pressure difference and pressure difference derivative double logarithmic curve is fitted, and when the model result is close to the drawn pressure difference and pressure difference derivative double logarithmic curve, the crack parameters of the model parameters are obtained through inversion; judging whether the crack parameter is too high or not; and determining the relationship between the child well group and the mother well group, analyzing the pressure difference and pressure difference derivative curve morphological characteristics of the fracture parameter high section, and judging whether pressure channeling occurs or not. The system can realize the method. According to the method, the inter-well pressure channeling identification efficiency in the well group synchronous fracturing period can be improved.

This invention relates to the field of exploration and development, and discloses a method, system, and equipment for quantitative analysis of friction resistance in directional drilling. The method includes: acquiring logging information and drill bit speed in the drilled section; constructing a drilling speed prediction model using the drill bit speed and the composite drilling data; determining a bottom hole pressure prediction model based on the directional drilling data and the drilling speed prediction model; combining the bottom hole pressure prediction model with the surface pressure to determine a drill string axial friction resistance model; and calculating the axial friction resistance in the real-time directional drilling process using the drill string axial friction resistance model based on the logging information and drill bit speed. The quantitative friction resistance analysis method disclosed in this application solves the problem of difficulty in accurately assessing bottom hole pressure and axial friction resistance, enabling dynamic assessment of theoretical bottom hole pressure and axial friction resistance. It allows for full-process monitoring and post-drilling analysis of sliding drilling, providing a basis for improving the bottom hole drill string load condition.

The invention relates to the field of oil development engineering, in particular to a method, a system and equipment for controlling water content rise of an oil well of an ultra-low permeability reservoir. The problems that an existing method is short in validity period and causes pollution to stratums and the environment are solved. The method comprises the following steps: screening oil wells based on basic data to obtain a target oil well; pressure distribution of plane radial flow and pressure distribution of gas-phase unidirectional flow of the gas cap of the target oil well are calculated; pressure distribution of plane radial flow and pressure distribution of liquid-phase unidirectional flow of the oil layer of the target oil well are calculated; the position of the perforation is further calculated; calculating a roof-remaining reference value based on the stratigraphic dip angle, and calculating a roof-remaining thickness based on the roof-remaining reference value; setting the perforations based on the positions of the perforations and the thickness of the top, and adjusting the pressure distribution of the perforations by adjusting the bottom hole pressure based on practice so as to adjust the water content rising speed. The invention has the advantages of long period of validity and no pollution.

The invention relates to the technical field of oil and gas field drilling and logging, and particularly discloses a formation pressure monitoring method and system based on drilling and logging real-time data fusion. The formation pressure monitoring method comprises the following steps that S1, geological data of a drilling well adjacent to a target well in a geological block where the target well is located are obtained, and formation factors of the geological block are obtained; s2, comprehensive real-time well drilling data of the target well are obtained, and a dynamic factor of the target well is solved; s3, constructing a formation pressure evaluation model of the target well by using the formation factor and the dynamic factor and utilizing a formation pressure monitoring model, and taking the formation pressure evaluation model as a real-time monitoring standard of the target well; and S4, the dynamic factors and the bottom hole pressure of the target well are monitored in real time, and the formation pressure can be monitored in real time according to the formation pressure evaluation model of the target well. No underground sensor is needed, and the formation pressure can be monitored in real time only through well gas measurement data.

The present application relates to a kind of design methods of cementing annular slurry column, comprising the following steps: 1) collecting the leakage parameter of the weakest formation in the formation to be cemented, the leakage parameter of the second weakest formation, the bottom hole leakage parameter and the maximum formation pressure parameter;2) calculate the maximum pressure bearing parameter at the weakest formation when cementing operation is bumped, the maximum pressure bearing parameter at the second weakest formation when cementing operation is bumped, the maximum pressure parameter that bottom hole bears when cementing operation is bumped and the bottom hole pressure parameter when tail slurry gelatinization loses weight during cementing operation;3) according to the leakage parameter of the weakest formation, the leakage parameter of the second weakest formation, the bottom hole leakage parameter and the maximum formation pressure parameter, the maximum pressure bearing parameter at the weakest formation when cementing operation is bumped, the maximum pressure bearing parameter at the second weakest formation when cementing operation is bumped, the maximum pressure parameter that bottom hole bears when cementing operation is bumped and the bottom hole pressure parameter when tail slurry gelatinization loses weight during cementing operation, it is judged whether annular slurry column is designed reasonably.

This invention provides a method for dynamic prediction of cement slurry weight loss in long inclined vertical well sections. The method includes: calculating the effective bottom hole pressure P during the cement slurry weight loss process. b Effective pressure at the bottom of the well, P b The calculation formula is: P b = P0 + P1; where P0 is the liquid column pressure at the top of the cement slurry; P1 is the effective pressure of the cement slurry; the calculation of the effective pressure P1 of the cement slurry includes determining the remaining pressure P after the cement slurry gels and loses weight, taking into account the eccentricity of the tailpipe and the downhole temperature and pressure. sy The residual pressure P after the cementation and weight loss of the mud obtained by this invention sy The calculations are more consistent with the gelation and weight loss characteristics of cement slurry under complex downhole conditions, effectively ensuring the accuracy of dynamic prediction of cement slurry weight loss.

The invention relates to the technical field of oil and gas reservoir permeation enhancement and carbon dioxide geological sequestration, and discloses a laumontite-containing reservoir permeation enhancement and carbon dioxide sequestration strengthening method. The method comprises the following steps: firstly, screening a reservoir with the laumontite content reaching the standard and meeting thermodynamic reaction conditions; injecting carbon dioxide into the target layer by adopting a two-stage pressure control strategy; and finally, the well closing duration is dynamically controlled by monitoring the bottom hole pressure in real time and calculating the change rate of the bottom hole pressure function, and when the change rate is continuously lower than a threshold value, it is indicated that stability tends to be achieved, and well closing is stopped. By utilizing the mineralization reaction of laumonite and carbon dioxide, the carbon dioxide is converted into calcium carbonate minerals for permanent storage while effective permeation enhancement of the reservoir is realized, and the method has the advantages of small reservoir damage, high storage safety and low cost, and meets the requirements of green and low-carbon development.

The present disclosure provides a method for predicting the productivity of a direct well of a gas storage under the conditions of interwell interference and strong injection and production, comprising: obtaining basic data of a target formation of a natural gas underground gas storage; based on the basic data of the target formation of the natural gas underground gas storage and a direct well productivity prediction mathematical model, using the superposition principle to calculate the pressure superposition solution of the target direct well under the conditions of interwell interference and strong injection and production, and obtaining the bottom hole pressure solution of the target direct well of the direct well productivity prediction mathematical model; based on the bottom hole pressure solution, obtaining the production solution of the target direct well, and predicting the productivity of the target direct well in the natural gas underground gas storage. On the basis of the existing productivity prediction method, the superposition principle is used to solve the influence of interwell interference and strong injection and production on the calculation of the productivity of the direct well of the gas storage, improve the accuracy of the direct well productivity prediction mathematical model, reduce the error in the productivity calculation process, and accurately predict the productivity of the direct well of the gas storage.

The invention provides a prediction method and device for a steam cavity in steam flooding and computer equipment, and relates to the technical field of oil field oil extraction. The method comprises the steps that the incidence relation between wellhead production characteristics of a first production well and the bottom hole temperature is determined, and according to the incidence relation, the bottom hole temperature of a second production well is determined according to the wellhead production characteristics of the second production well; calculating the bottom hole pressure of the second production well; and comparing the well bottom temperature of the second production well with the well bottom temperature of the steam injection well, comparing the well bottom pressure of the second production well with the well bottom pressure of the steam injection well, and identifying a steam cavity at the well bottom of the second production well. According to the method, the incidence relation between the wellhead production characteristics and the bottom hole temperature is established by using the production data of the first production well with the bottom hole temperature monitoring data, and the bottom hole temperature of the second production well without the bottom hole temperature monitoring data is predicted by using the incidence relation. And rapid and accurate identification of the steam cavity of the second production well is realized.

This invention relates to the field of well test interpretation technology, and discloses a method and related equipment for calculating the length of large-scale natural fractures. By establishing a mathematical model of well test in a naturally fractured reservoir, calculating the real-time bottom hole pressure, and plotting the interpretation curve of the well test in the naturally fractured reservoir, the theoretical bottom hole pressure is obtained by combining the real-time bottom hole pressure and the interpretation curve, and the theoretical well test curve is plotted. Finally, the natural fracture length is obtained by fitting the theoretical and measured curves. This method overcomes the limitation of uniform fracture distribution in conventional models, is suitable for deep gas reservoirs with poor matrix properties and strong fracture heterogeneity, and avoids the problem of only being able to obtain equivalent parameters and interpreting parameters that do not reflect reality. It accurately characterizes the fracture development state and improves the accuracy of well test interpretation.

This invention discloses a real-time assessment method for bottom-hole pressure in annular multiphase flow driven by both physical models and data, comprising the following steps: S1: Establishing an annular multiphase flow mechanism model; S2: Initializing the annular multiphase flow mechanism model; S3: Calculating the prior estimate of the bottom-hole pressure at the current moment based on the physical parameters of the target well at the previous time step; S4: Calculating the theoretical riser pressure and obtaining the pressure residual; if the pressure residual is less than a threshold, the prior estimate is the final estimation result; otherwise, proceed to step S5; S5: Inputting the pressure residual and the operating characteristics of the target well into a neural network, mapping and outputting the physical parameter correction; S6: Correcting the physical parameters, performing a secondary solution, and obtaining the corrected value of the bottom-hole pressure at the current moment, which is the final estimation result; S7: Repeating steps S3-S6 to obtain the real-time assessment result of the bottom-hole pressure in annular multiphase flow. This invention can quickly and accurately assess the bottom-hole pressure of annular multiphase flow in real time.

The application provides a water injection well pressure analysis method considering the influence of fracture induced by pressure drive water injection, which comprises the following steps: step 1, establishing a water injection well pressure analysis model considering the influence of fracture induced by pressure drive water injection; step 2, solving the water injection well pressure analysis model considering the influence of fracture induced by pressure drive water injection; step 3, obtaining a water injection well double logarithmic pressure analysis curve through analysis, and judging different flow stages of the reservoir in the fracturing process according to the curve; and step 4, analyzing the bottom hole pressure response characteristics of the pressure drive water injection well, and applying the characteristics to an actual well to verify the accuracy of the established model. The water injection well pressure analysis method considering the influence of fracture induced by pressure drive water injection establishes a water injection well pressure analysis model considering the dynamic expansion of the fracture, has certain technical difficulty, and can determine the flow stage of fluid in the reservoir at different production moments.

The invention discloses a bottom hole pressure calculation method and device for fracturing construction, and the method comprises the steps: comparing the accumulated liquid amount of a target well at the current moment with the preset liquid amount of a corresponding well section position, and determining the well section position on which the accumulated liquid amount acts at the current moment according to the comparison result of the accumulated liquid amount; based on the corresponding relation table at the same moment, the liquid type, the sand concentration and the displacement of the well section position are searched in the corresponding relation table according to the accumulated liquid amount of the target well at the current moment and the acted well section position; according to the liquid type, the sand concentration and the displacement corresponding to the well section position, the corresponding pipe column friction resistance and the liquid column static pressure are calculated; and calculating the bottom hole pressure at the current moment according to the known casing pressure at the current moment, the calculated liquid column static pressure and the pipe column friction resistance. According to the method, measurement errors caused by dynamic change lag of shaft liquid distribution in a traditional method are effectively overcome, and the accuracy of shaft bottom pressure monitoring is remarkably improved.

The invention relates to an ultra-deep water narrow window pressure control well drilling hydraulic parameter design method, which comprises the following steps: researching the migration condition of rock debris from rock debris particle stress analysis, calculating the rock debris particle lifting critical return speed and the rock debris particle rolling critical return speed, taking the minimum value as the critical return speed of a certain well section, and taking the maximum value of the whole well section as the critical return speed of a certain well section. According to the method, the minimum rock-carrying displacement is taken as the minimum rock-carrying return speed of the whole well section, so that the obtained minimum rock-carrying displacement meets the condition of the whole well section, especially for a horizontal well, the borehole cleaning effect of the whole well section is ensured, and the change trend is more easily observed on site by drawing the change curve of the bottom hole pressure and the rock debris concentration along with the displacement; therefore, the displacement can be adjusted according to the displacement corresponding to the minimum value of the bottom hole pressure, the effect of ultra-deep water narrow window pressure control drilling is achieved, and guarantee is provided for safety and well control work.

The invention relates to the technical field of oil production engineering, in particular to a staged fracturing pump stopping test oil well packer and a control system thereof.The staged fracturing pump stopping test oil well packer comprises a central pipe, the upper end and the lower end of the central pipe are connected with an upper connector and a lower connector respectively, a rubber barrel is arranged on the periphery of the central pipe, and a thin groove is formed in the position, corresponding to the rubber barrel, of the central pipe; a traditional through hole is replaced by the thin groove, high-pressure fluid in the rubber sleeve can only be slowly decompressed through the thin groove after a pump is stopped, it is ensured that the rubber sleeve is kept in an expansion sealing state in a testing period, intersection fluid channeling is avoided, and pressure drop data of a well mouth and a well bottom truly reflects the characteristics of cracks and stratums; meanwhile, after the test is finished and the pressure of the high-pressure fluid in the central pipe is reduced to a certain value, the internal and external pressure difference of the first through hole pushes the piston to move upwards so as to open the second through hole, the fluid in the rubber sleeve can be rapidly discharged through the second through hole, the rubber sleeve rapidly shrinks and resets, the deblocking time is greatly shortened, and the single well fracturing operation efficiency is improved.

The invention provides a fractured-vuggy gas reservoir bottom hole flowing pressure calculation method considering fractured water evolution, and belongs to the field of oil and gas field development. In order to solve the problems that in a fracture-vug type gas reservoir, a fracture water body participates in seepage, and pressure response is complex, a coupling calculation process between a water body-fracture system and flowing bottomhole pressure is established. According to the method, a fracture water infiltration mechanism is introduced, the change of the fracture water content state along with the production process is dynamically described, a formation pressure iterative calculation model considering the water supply influence is constructed on the basis, and then hourly calculation of the flowing bottomhole pressure is achieved. The method only depends on conventional production data and basic geological parameters, the calculation process is clear, and the physical significance of the parameters is clear. Through comparison of example calculation and field actual measurement of flowing bottomhole pressure data, the result shows that the method can reasonably reflect the change characteristics of the bottomhole pressure in the production process of the gas well of the fracture-vug type gas reservoir, and technical support can be provided for dynamic analysis and production management of the fracture-vug type gas reservoir.

The invention relates to the technical field of shale gas well productivity prediction, and provides a shale gas well productivity prediction method, system, device and medium, the method comprises the following steps: constructing a single well bottom pressure prediction curve of a shale gas well, the bottom pressure prediction curve being a relation curve of bottom pressure and time corresponding to different production days of a single well; constructing a single well productivity prediction curve, wherein the single well productivity prediction curve is a relation curve between the total cumulative gas production and the bottom hole pressure and a relation curve between the total cumulative liquid production and the bottom hole pressure; using the single well bottom hole pressure prediction curve and the single well productivity prediction curve to obtain a relation between the total cumulative liquid production capacity and the total cumulative gas production capacity and the number of production days; and predicting the productivity of the shale gas well by using the total cumulative liquid yield and the relational expression between the total cumulative gas yield and the number of production days. The method can predict the productivity of the shale gas well based on the production characteristics of different stages.

The invention discloses an oil and gas collecting device with bottom hole pressure compensation and backflow control functions, which is applied to the technical field of oil and gas collection, and comprises a large four-way joint, an operation shut-in valve, a first small four-way joint, an operation heightening flange and a small annular communicating pipe, the lower end of the large four-way joint is connected with an outer layer pipe, and the upper end of the large four-way joint is connected with the operation shut-in valve; the upper end of the operation well shut-in valve is connected with a first small four-way joint, the upper end of the first small four-way joint is connected with an operation heightening flange, the upper end of the operation heightening flange is connected with a third gate valve, the side face of the large four-way joint is communicated with one end of a small annular communicating pipe, and the other end of the small annular communicating pipe is communicated with the side face of the first small four-way joint. And the outer-layer pipe, the middle pipe, the small-diameter pipe and the bottom hole pressure control assembly are arranged underground from outside to inside. According to the invention, the problem of flooding of deep-sea oil and gas wells, ultra-deep wells and low-pressure wells and the problem of long-term effective drainage and production of liquid producing wells can be solved.

The invention belongs to the technical field of oil and gas exploitation, and relates to a method, a system and equipment for determining formation starting pressure carbon absorption parameters and a medium. According to the method, the carbon injection pressure difference is obtained according to the flowing bottomhole pressure, the carbon absorption curve is established according to the daily carbon injection amount and the carbon injection pressure difference, the slope of the carbon injection curve visually represents the stratum carbon absorption index, and the stratum carbon absorption capacity can be rapidly and more accurately evaluated; the starting pressure of the carbon injection stratum is obtained according to the carbon absorption curve, and a basis is provided for model selection of a carbon injection compressor or a carbon injection pump; according to the carbon injection formation starting pressure and the formation static pressure, the carbon injection minimum bottom hole pressure is obtained; the carbon absorption index is obtained according to the flowing bottomhole pressure, the daily carbon injection amount and the starting pressure of the carbon injection stratum, the stratum carbon absorption index accurately represents the stratum carbon absorption capacity, and a powerful basis can be provided for ground engineering construction, carbon dioxide injection oil displacement recovery ratio improving scheme compilation, carbon dioxide injection geological design and the like.

This invention relates to a time-varying evolution inversion method for fracture morphology, net pressure, and minimum geostress, belonging to the field of petroleum technology. The method includes: acquiring on-site bottomhole pressure data, monitoring well information, and LF-DAS data during fracturing operations; discretizing the fracture along its length into several units based on the three-dimensional displacement discontinuity method and constructing a net pressure distribution matrix; using a pre-constructed mechanical response relationship between net pressure and fracture width distribution to solve for the fracture width distribution corresponding to the current net pressure distribution; calculating the axial strain response of the fracture at the monitoring well based on the fracture width distribution to form a forward model for pressure-fracture width-strain solution; iteratively updating the fracture half-length and net pressure using the least squares method, constructing a residual between the inverted strain and the on-site strain to minimize the residual, and obtaining the time-varying inversion results for the fracture half-length and net pressure. The time-varying evolution process of minimum geostress can be characterized by the difference between the on-site bottomhole pressure and the inverted net pressure.

The invention relates to the technical field of drilling engineering, in particular to a well wall stability model construction prediction method based on an easy-to-collapse layer instability mechanism, terminal equipment and a storage medium. The height of an annular liquid level is measured in real time through an online shaft liquid level instrument, and drilling fluid parameters are collected through monitoring equipment on a drilling site such as a comprehensive logging instrument or a drilling instrument; the method comprises the following steps: quickly calculating bottom hole pressure parameters by initializing a well body structure and utilizing measured data and associated parameters; and the comprehensive logging instrument realizes real-time monitoring, remote transmission and rapid alarm according to the functions preset by the system and the bottom hole pressure change. According to the invention, the measurement frequency is improved, the continuous test of the liquid level of the shaft is realized, the safety of the liquid level of the shaft is greatly improved, and the working efficiency is effectively improved.

This invention discloses a method for determining the production capacity of a coalbed methane (CBM) well without shutting it in. The method includes: acquiring basic data of the CBM well; determining a relationship table between pressure and CBM deviation factor, and a relationship table between pressure and apparent pressure, based on CBM PVT experimental data; recording the daily gas production, bottom hole pressure, and cumulative gas production of the CBM well at each stable flowing pressure test moment during three or more different production stages; determining the formation pressure corresponding to each stable flowing pressure test moment using a mass balance equation; determining the coefficients of the CBM well's production capacity equation based on the formation pressure, bottom hole pressure, and production at each stable flowing pressure test moment, thereby obtaining the CBM well's production capacity equation; and substituting the formation pressure and bottom hole pressure values ​​into the production capacity equation and solving for the corresponding CBM well production capacity. This invention effectively overcomes the shortcomings of traditional well testing methods that require shutting in the well to test formation pressure, and avoids the problem that the applicable conditions of existing non-shutdown methods for determining gas well production capacity equations are difficult to meet.

Methods for determining hydrocarbon recovery injection well bottom hole pressures where a downhole liner has liner-deployed outflow control devices, for attempting to ensure operation below a maximum operating pressure. Steam flowrate is varied using a range of valve positions, including shut-in periods (0-5% flowrate) sufficient to approach equilibrium between a surface pressure and bottom hole pressure, generating a determined bottom hole pressure which can be used to calculate an average bottom hole pressure. An average steam flowrate and average surface pressure are determined for a range of valve positions. A pressure drop is calculated for each of the valve positions by subtracting the average bottom hole pressure from the measured surface pressure. Plotting the pressure drop against the average surface pressure for each of the valve positions allows generation of a best fit model defining a polynomial relationship between the pressure drop and the surface pressure. Parameters can then be derived from the best fit model, enabling prediction of the bottom hole pressure for any steam flowrate for the well. The maximum operating pressure can then be more confidently determined for various steam flowrate values. The methods may be automated using a programmable logic controller (PLC) or similar platform located at the well pad.

The application provides a method and device for calculating the working gas amount of an underground gas storage which is increased due to an increase in the upper limit pressure, the method comprising: splitting the underground gas storage into a plurality of gas storage units with each gas injection well as the center of each gas storage unit; simulating the operation of each gas injection well in each gas storage unit to obtain the bottom hole pressure resistance value of each gas injection well; determining the stratum radius influenced by each gas injection well in each gas storage unit according to the bottom hole pressure resistance value of each gas injection well, the operation parameters of the underground gas storage and the target upper limit pressure of the underground gas storage; determining the increased working gas amount of each gas storage unit and the increased working gas amount of the underground gas storage according to the stratum radius and the target upper limit pressure. By splitting into the gas storage units with the gas injection well as the center, the stratum radius influenced by each gas injection well is determined independently, the problem of pressure imbalance does not need to be solved, and the working gas amount of the underground gas storage which is increased due to an increase in the upper limit pressure can be accurately determined.

The invention discloses a gas storage injection-production capacity analysis method, which comprises the following steps of: establishing a binomial productivity equation for an injection-production well of which productivity well testing data is obtained; for a well which only obtains a one-point method productivity test, a binomial productivity equation is established through approximate regression by using a stable test point (qg, pwf) and a calculated open-flow capacity point (qAOF, 0.1). And combining with the well body structure of the injection-production well, making an injection-production capacity analysis chart of the injection-production well at different injection-production stages and under different formation pressures through node analysis, and evaluating the matching relationship between the reservoir seepage capacity and the well shaft through the chart to obtain the injection-production gas quantity of the injection-production well under different formation pressures, well bottom pressures and well mouth pressures. Meanwhile, the influence of gas flow erosion on the oil pipe in the injection-production process of the injection-production well is considered, an oil pipe injection-production anti-erosion capacity analysis chart of the injection-production well under different formation pressures is formed, and technical support is provided for evaluating the injection-production capacity of a gas storage and optimizing deployment of the injection-production well.

The invention discloses an annulus liquid level monitoring system and method. The system comprises a nitrogen generation pressure control module, a sound wave control module, a liquid level monitoring module and an actuator control module, the nitrogen generation pressure control module is connected with a drilling gas source, the sound wave control module is arranged on an annular liquid level wellhead rotary blowout preventer four-way joint, and the liquid level monitoring module and the actuator control module are arranged on a pressure control drilling operation table. According to the technical scheme of the embodiment, the annulus liquid level monitoring system is constructed by integrating the nitrogen generation pressure control module, the sound wave control module, the liquid level monitoring module and the actuator control module, and the system is integrated on the pressure control drilling equipment, so that continuous monitoring of the drilling annulus liquid level under the working condition of well leakage and return in the pressure control drilling process is achieved, and the drilling efficiency is improved. Meanwhile, according to the annulus liquid level height and the real-time annulus liquid level bottom hole pressure, actuator control parameters and grouting parameters are guided in real time, so that the problem that the annulus liquid level drops due to return loss in the drilling process is quickly responded, and the well control safety is improved.

The application provides a differentiated hole arrangement design method for increasing the number of fracture cracks in a heterogeneous reservoir, and belongs to the technical field of oil and gas exploitation. Reservoir quality parameters, rock mechanics parameters and ground stress parameters of a target well and fracture crack distribution of a neighboring well of the target well are obtained to design the number of fracture cracks / cluster number, position and shape of each cluster of cracks. A mathematical model of the fracture cracks is selected according to the ground stress parameters and the shape of each cluster of cracks to calculate the net pressure required by the shape of each cluster of cracks. A random algorithm is used to determine the displacement of each cluster of cracks and the number of perforation holes, and the friction of each cluster of crack holes is calculated. The bottom hole pressure of each cluster of cracks is calculated according to the net pressure of each cluster of cracks and the friction of each cluster of crack holes, and if the bottom hole pressure of each cluster of cracks is equal, the next step is performed. The ground pumping pressure is calculated by using a fluid mechanics method, and if the ground pumping pressure meets the set conditions, the design is completed. The method can reduce the downhole complex risks such as channeling, improve the fracturing construction efficiency and reservoir reconstruction effect, and reduce the construction cost.

This invention discloses a high-pressure deep well multi-stage blowout preventer (BOP), mainly composed of a first-stage BOP assembly, a second-stage BOP assembly, a pressure balancing system, an outer annular BOP assembly, and a sealing joint. The pressure balancing system of this invention requires no other auxiliary structures and effectively utilizes the fluid pressure of the inner and outer annular spaces to automatically compress or reset the sealing rubber, thus automatically adjusting the balance between wellhead and bottomhole pressures. The second-stage BOP system combines the advantages of a conical valve core and the automatic closing and opening of a butterfly valve to achieve automatic dual isolation of the lower formation fluid pressure, preventing the high-pressure formation fluid from continuing to rise. Compared to previous BOP tools, this invention does not use electro-hydraulic valves; it only utilizes the pressure difference between the drilling fluid and the formation to open the butterfly valve and the main valve core. It has a simple structure, is easy to manufacture, has low cost, and is easy to maintain.

This invention discloses a method, system, storage medium, and equipment for diagnosing communication issues during acid fracturing in fractured-vuggy carbonate reservoirs, belonging to the field of reservoir stimulation technology. The method includes: establishing a bottomhole pressure calculation model; collecting geomechanical parameters, reservoir parameters, communication characteristic parameters during acid fracturing, and fracture-vuggy body parameters from previously stimulated wells in the work area, establishing and training a first neural network model to obtain a prediction model for the communication parameters of fracture-vuggy bodies during acid fracturing; collecting geomechanical parameters and reservoir parameters from the target well, and real-time acquiring the communication characteristic parameters during acid fracturing of the target well to construct a real-time dataset; and substituting the real-time dataset into the prediction model to calculate the communication parameters of fracture-vuggy bodies during acid fracturing. This invention employs integrated monitoring technology and data analysis algorithms, enabling real-time monitoring and diagnosis of communication issues during reservoir acid fracturing, providing a basis for decision-making during construction, and improving construction efficiency and reservoir stimulation effectiveness.