A real-time monitoring system and method for tripping a heavy grout cap in a managed pressure drilling wellbore

Abstract

This specification provides a real-time monitoring system and method for the tripping and running of a pressure-controlled drilling well with a heavy slurry cap, applicable to the field of geological exploration and development. The method includes a key parameter monitoring module for tripping and running leakage, a real-time wellbore calculation and decision-making module, and a wellbore pressure intelligent control module. The key parameter monitoring module acquires the state parameters of the target wellbore during the tripping and running of the heavy slurry cap and transmits these parameters to the real-time wellbore calculation and decision-making module. The real-time wellbore calculation and decision-making module uses the state parameters to determine the wellbore pressure and slurry column changes in the target wellbore; it then determines operating condition adjustment parameters based on the wellbore pressure and slurry column changes. The intelligent wellbore pressure control module adjusts the wellbore pressure according to the operating condition adjustment parameters. This system ensures accurate early warning of leakage during the tripping and running of the heavy slurry cap, improves the control effect of wellbore pressure, and is beneficial for practical production applications.

Description

Technical Field

[0001] The embodiments in this specification relate to the field of geological exploration and development technology, and in particular to a real-time monitoring system and method for raising and lowering the drill pipe with a heavy slurry cap in controlled-pressure drilling. Background Technology

[0002] As oil and gas field development continues to expand, exploration and development are increasingly moving towards deeper and ultra-deep formations, placing higher demands on safety during production. Currently, controlled-pressure drilling technology, utilizing corresponding equipment systems, can regulate wellhead back pressure, thereby controlling wellbore pressure and ensuring it remains within a safe range, effectively preventing production accidents.

[0003] Controlled pressure drilling (CPD) technology can effectively control wellbore pressure during normal drilling and single-joint connection after pump shutdown. However, during tripping in and out of the well, especially when using heavy slurry caps, CPD technology lacks corresponding monitoring and control measures. This makes it difficult to ensure effective control of wellbore pressure during heavy slurry cap tripping. If well leakage or overflow occurs during tripping in this stage, it cannot be detected and prevented in time, posing a certain safety hazard. To ensure production safety throughout the entire process, there is an urgent need for a solution that can effectively monitor wellbore pressure during heavy slurry cap tripping. Summary of the Invention

[0004] The purpose of the embodiments in this specification is to provide a real-time monitoring system and method for tripping in and out of the wellbore with a pressure-controlled drilling cap, in order to solve the problem of how to effectively monitor the wellbore pressure during the tripping in and out of the well with a pressure-controlled drilling cap.

[0005] To address the aforementioned technical problems, this specification proposes a real-time monitoring system for the tripping and running of a controlled-pressure drilling wellbore with a heavy slurry cap. The system includes a key parameter monitoring module for tripping and running leakage, a real-time wellbore calculation and decision-making module, and an intelligent wellbore pressure control module. The key parameter monitoring module acquires state parameters of the target wellbore during the tripping and running of the heavy slurry cap and transmits these parameters to the real-time wellbore calculation and decision-making module. The real-time wellbore calculation and decision-making module uses these state parameters to determine the pressure status and slurry column changes of the target wellbore. Based on these pressure and slurry column changes, it determines operating condition adjustment parameters. These operating condition adjustment parameters include at least one of the following: heavy slurry cap drilling fluid density, heavy slurry cap drilling fluid usage, tripping and running speed, and control pressure value. The intelligent wellbore pressure control module adjusts the wellbore pressure according to the operating condition adjustment parameters.

[0006] In some embodiments, the state parameters include at least one of the following: inlet / outlet flow rate, casing pressure, stand pressure, hook height, suspended weight, drill bit position, well depth, fluid level, and temperature.

[0007] Based on the above embodiments, the tripping and running-out leakage key parameter monitoring module includes at least one of the following: stand pressure sensor, casing pressure sensor, pressure control manifold pressure sensor, pressure control manifold temperature sensor, drilling fluid inlet flow meter, drilling fluid outlet flow meter, drilling fluid inlet and outlet density monitor, electronic fluid level monitoring device, and annular fluid level continuous monitoring device.

[0008] Based on the above implementation, each sensor in the tripping and running-out leakage key parameter monitoring module is equipped with a signal transmission module; the wellbore real-time calculation and decision module is equipped with a signal receiving module; the signal transmission module is used to send the status parameters collected by the sensors to the signal receiving module.

[0009] In some embodiments, the real-time wellbore calculation and decision module pre-loads wellbore pressure profile parameters corresponding to the target wellbore; the wellbore pressure profile parameters include at least one of the following: wellbore structure, drill string assembly, drilling fluid properties, formation predicted pressure coefficient, preset control bottom hole pressure, and preset equivalent drilling fluid density.

[0010] Based on the above implementation, the real-time wellbore calculation and decision module is further configured to construct a wellbore structural model based on the wellbore pressure profile parameters; determine a wellbore dynamic model by combining the wellbore structural model and state parameters; and determine the wellbore pressure change status based on the wellbore dynamic model.

[0011] In some implementations, the real-time wellbore calculation and decision module includes a steady-state calculation unit and a transient calculation unit; the steady-state calculation unit is used to obtain the fluctuating pressure on a preset steady-state calculation path through steady-state calculation; the transient calculation unit is used to obtain the fluctuating pressure on a preset pseudo-transient path through pseudo-transient calculation.

[0012] In some implementations, the real-time wellbore calculation and decision module is used to calculate the wellbore pressure in response to drilling flow conditions, including single-phase drilling fluid flow.

[0013] Based on the above implementation method, the real-time wellbore calculation and decision module includes a drilling hydraulics calculation system; the drilling hydraulics calculation system is used to calculate the wellbore pressure; the drilling hydraulics calculation system makes corrections based on the comparison results of the calculated wellbore pressure and the measured wellbore pressure.

[0014] In some embodiments, the pressure condition includes wellbore pressure; the real-time wellbore calculation and decision module is used to calculate the wellbore pressure in real time based on the wellbore drilling fluid volume, slurry column structure, drilling fluid inlet density, drilling fluid rheological parameters, discharge rate, depth measurement, and vertical depth.

[0015] In some implementations, determining the operating condition adjustment parameters based on the wellbore pressure and slurry column changes includes: constructing an overflow model by combining electronic monitoring and annular fluid level monitoring; and determining whether abnormal operating conditions have occurred based on the electronic monitoring, annular fluid level monitoring, and the overflow model.

[0016] Based on the above implementation methods, the step of determining whether an abnormal operating condition has occurred based on the changes in the slurry column, the suspended weight, and the leakage model includes: determining a well leakage condition when the inlet flow rate remains unchanged and the outlet flow rate continues to decrease; determining an overflow condition when the inlet flow rate remains unchanged and the outlet flow rate continues to increase; determining a well leakage condition when the fluid level is not at the wellhead and the annular fluid level height continues to decrease; and determining an overflow condition when the fluid level is not at the wellhead and the annular fluid level height continues to increase.

[0017] In some embodiments, the pressure condition includes wellbore pressure; the intelligent wellbore pressure control module is used to control the pressure control value and / or drilling fluid density and / or drilling fluid volume based on the relationship between wellbore pressure, formation pressure, and leakage pressure at different fluid levels.

[0018] Based on the above embodiments, the intelligent wellbore pressure control module is used to increase the control pressure value when the wellbore pressure is less than the formation pressure, and decrease the control pressure value or reduce the drilling fluid density when the wellbore pressure is greater than the leakage pressure, provided the fluid level is at the wellhead. The intelligent wellbore pressure control module is also used to increase the drilling fluid discharge rate and drilling fluid density when the wellbore pressure is less than the formation pressure, and decrease the drilling fluid discharge rate and drilling fluid density when the wellbore pressure is greater than the leakage pressure, provided the fluid level is not at the wellhead.

[0019] In some implementations, the target wellbore type includes one of vertical wells, deviated wells, and horizontal wells.

[0020] This specification also proposes a method for real-time monitoring of the drilling rig during the tripping in and out of pressure-controlled drilling with a heavy slurry cap, comprising: acquiring state parameters of the target wellbore during the tripping in and out of the heavy slurry cap; determining the pressure status and slurry column change status of the target wellbore using the state parameters; determining operating condition adjustment parameters based on the wellbore pressure and slurry column change status; the operating condition adjustment parameters including at least one of heavy slurry cap drilling fluid density, heavy slurry cap drilling fluid usage, and pressure control value; and adjusting the wellbore pressure according to the operating condition adjustment parameters.

[0021] As can be seen from the technical solutions provided in the embodiments of this specification above, the real-time monitoring system for the controlled-pressure drilling heavy slurry cap tripping and running-in of the wellbore in these embodiments acquires the state parameters of the target wellbore during the tripping and running-in process of the heavy slurry cap through a key leakage monitoring module. Then, a real-time wellbore calculation and decision module determines the pressure status and slurry column changes of the wellbore based on these state parameters, thereby determining the operating condition adjustment parameters and adjusting the wellbore pressure. By monitoring the tripping and running-in process of the heavy slurry cap in real time and dynamically adjusting the wellbore based on the real-time data processing results, the system ensures accurate early warning of leakage during the tripping and running-in process of the heavy slurry cap, improves the control effect of wellbore pressure, and is beneficial for practical production applications. Attached Figure Description

[0022] To more clearly illustrate the technical solutions in the embodiments or prior art of this specification, the drawings used in the description of the embodiments or prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments recorded in this specification. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0023] Figure 1 This is a schematic diagram of a real-time monitoring system for raising and lowering the drill pipe using a pressure-controlled drilling heavy slurry cap, as described in this specification.

[0024] Figure 2 This is a schematic diagram of a wellbore monitoring logic according to an embodiment of this specification;

[0025] Figure 3 This is a schematic diagram of a wellbore monitoring module according to an embodiment of this specification;

[0026] Figure 4 This is a schematic diagram of a real-time monitoring system for raising and lowering the drill pipe using a pressure-controlled drilling heavy slurry cap, as described in this specification.

[0027] Figure 5 This is a schematic diagram illustrating the process of a real-time monitoring method for raising and lowering a pressure-controlled drilling heavy slurry cap in an embodiment of this specification. Detailed Implementation

[0028] The technical solutions in the embodiments of this specification will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this specification, and not all embodiments. Based on the embodiments in this specification, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of this specification.

[0029] This specification provides an embodiment of a real-time monitoring system for tripping in and out of the wellbore in pressure-controlled drilling. For example... Figure 1As shown, the controlled-pressure drilling heavy slurry cap tripping and tripping real-time monitoring system 100 includes a tripping and tripping leakage key parameter monitoring module 110, a wellbore real-time calculation and decision module 120, and a wellbore pressure intelligent control module 130.

[0030] Because existing technologies lack effective monitoring and control for the tripping and running of heavy slurry caps, and lack effective prevention and control of safety accidents such as well leakage or well overflow, the pressure-controlled drilling heavy slurry cap tripping and running well real-time monitoring system is mainly a system for monitoring the tripping and running process, especially the tripping and running process of heavy slurry caps, in order to achieve the purpose of real-time monitoring and effective prevention and control.

[0031] For ease of description, the wellbore referred to in this specification embodiment is called the target wellbore. The target wellbore can be any of the following: vertical well, deviated well, and horizontal well.

[0032] The key parameter monitoring module for tripping and running out of the wellbore is mainly used to detect the condition of the target wellbore in order to obtain the state parameters of the wellbore during the tripping and running out of the heavy slurry cap.

[0033] The tripping / running-in leakage key parameter monitoring module can include various types of sensors. In some embodiments, the tripping / running-in leakage key parameter monitoring module may include a standpipe pressure sensor, a casing pressure sensor, a pressure control manifold pressure sensor, a pressure control manifold temperature sensor, a drilling fluid inlet flow meter, a drilling fluid outlet flow meter, a drilling fluid inlet / outlet density monitor, an electronic fluid level monitor, and an annular fluid level continuous monitoring device. Preferably, it may also include a gas-liquid separator exhaust pipe pressure sensor, a pressure control manifold flow meter, a gas-liquid separator outlet pipe flow meter, a gas-liquid separator exhaust pipe gas flow meter, a mud return branch drilling fluid rheology monitoring device, a gas-liquid separator outlet pipe drilling fluid rheology monitoring device, and a gas-liquid separator exhaust pipe gas component monitoring device.

[0034] Accordingly, the state parameters include at least one of the following: inlet / outlet flow rate, casing pressure, stand pressure, hook height, suspended weight, drill bit position, well depth, fluid level, and temperature. For example... Figure 2 The diagram shown is a logical schematic of wellbore monitoring based on the aforementioned monitoring module for key parameters of tripping in and out of the well.

[0035] The system includes: a standpipe pressure sensor installed on the drilling standpipe to collect standpipe pressure during oil drilling operations; a pressure control manifold pressure monitoring device installed on the pressure control manifold to collect hydraulic pressure inside the manifold; a casing pressure sensor installed on the casing to collect pressure applied from the surface to the casing; a drilling fluid flow monitoring device installed at the drilling fluid inlet and outlet to collect the inflow and outflow rates; a backpressure compensation manifold flow monitoring device installed on the backpressure compensation manifold to collect the drilling fluid flow rate after backpressure compensation; a gas-liquid separator monitoring device installed on the gas-liquid separator to collect the outflow rate, exhaust volume, and gas composition of the gas-liquid separator; a mud return branch drilling fluid rheological property monitoring device installed on the mud return branch to collect the drilling fluid rheological parameters of the mud return branch; and a parameter monitoring host connected to a communication device. Figure 3 The diagram shown is a schematic diagram of the communication structure between the different sensors mentioned above.

[0036] The electronic drilling fluid level monitoring system is primarily used for data recording and simple analysis, detecting and triggering alarms for relatively simple anomalies. Specifically, it includes real-time recording and preliminary assessment of data such as drilling fluid properties, inlet and outlet flow rates, casing pressure, standpipe pressure, hook height, suspended weight, drill bit position, and well depth. It enables remote automatic monitoring and recording of key data, achieving intelligent and automated monitoring and reducing the likelihood of accidents due to human error.

[0037] The drilling fluid rheological parameters include apparent viscosity, plastic viscosity, structural viscosity, static shear force, and dynamic shear force. The relationship between them is relatively representative of the rheological properties of the drilling mud.

[0038] The annular liquid level continuous monitoring device includes a host computer, a preamplifier, a postamplifier, an electromagnetic acoustic transmitter, an acoustic sensor, a temperature sensor, a data acquisition unit, a filter, a solenoid valve, and a remote control connection device. The host computer uses a modulated sound wave detector to analyze the echo and calculate the liquid level depth. The preamplifier is connected to the host computer and amplifies the voltage of the modulated audio signal output by the host computer. The postamplifier is connected to the preamplifier and amplifies the current of the audio signal output by the preamplifier. The electromagnetic sound wave transmitter is connected to the postamplifier and emits the audio signal output by the postamplifier. The sound wave sensor is connected to the data acquisition unit and collects the emitted sound wave and echo signals within the annulus. The temperature sensor is connected to the data acquisition unit and collects the temperature within the channel where the sound wave sensor is located. The data acquisition unit is electrically connected to the host computer and receives and executes data acquisition commands issued by the host computer. A filter is connected between the data acquisition unit and the host computer to filter the signal sent from the data acquisition unit to the host computer. The solenoid valve is connected to the host computer through the data acquisition unit and is used to open or close the channel connecting the electromagnetic sound wave transmitter to the annulus.

[0039] In a specific application example, the number of pressure sensors is 10; the number of flow meters is 6, including 4 liquid flow meters and 2 gas flow meters; the number of gas phase component monitoring devices is at least 1; the number of drilling fluid rheology monitoring devices is at least 1; and the number of annular fluid level continuous monitoring devices is at least 1. In practical applications, the number of sensors can be adjusted according to requirements, and there is no limitation on this.

[0040] In practical applications, pressure sensors, flow meters, drilling fluid rheology monitoring devices, and annular fluid level continuous monitoring devices do not all need to be configured. They can be selected and configured according to the specific operating mode on site, or all of them can be configured to collect the necessary parameters as needed.

[0041] The key parameter monitoring module for tripping and running out of the well can include part of the integrated logging system and the data acquisition and monitoring system built into the drilling rig itself. Therefore, some of the data collected can come directly from the logging data center.

[0042] The sensors in the tripping and running-out leakage key parameter monitoring module, such as the pressure sensor, flow meter, drilling fluid rheology monitoring device, and annular fluid level continuous monitoring device, are also equipped with signal transmission modules. Correspondingly, the wellbore real-time calculation and decision-making module is equipped with a signal receiving module. The signal transmission module is used to send the status parameters collected by the sensors to the signal receiving module to realize data acquisition, transmission, and subsequent processing.

[0043] Specifically, the tripping and running-in leakage key parameter monitoring module has a port for connecting to the logging system and is connected to a remote monitoring and control system via communication network equipment. The sampling frequency of each parameter acquisition sensor in the tripping and running-in leakage key parameter monitoring module is consistent with the sampling frequency of the logging system and is adjusted according to the data sampling frequency of the on-site integrated logging system. The tripping and running-in leakage key parameter monitoring module provides core basic data for the remote intelligent and manual active control of oil and gas drilling wellbore pressure.

[0044] The drilling and tripping leakage key parameter monitoring module enables the preprocessing, storage, and unified platform display of multi-source, large-capacity data, including online monitoring data and logging data.

[0045] After the key parameter monitoring module for tripping and running out of the well transmits the data to the real-time calculation and decision module of the wellbore, the real-time calculation and decision module of the wellbore can read the status parameters and store them in the corresponding database for persistent storage.

[0046] The real-time wellbore calculation and decision module can use the state parameters to determine the pressure status and slurry column change status of the target wellbore, thereby determining the real-time changes in pressure and slurry column within the wellbore to achieve wellbore control and operating condition adjustment.

[0047] Pressure conditions can include wellbore pressure. Specifically, the real-time wellbore calculation and decision module can be used to calculate wellbore pressure in real time based on drilling fluid volume, slurry column structure, drilling fluid inlet density, drilling fluid rheological parameters, displacement, depth measurement, and vertical depth.

[0048] The real-time wellbore calculation and decision module is used to calculate the wellbore pressure based on drilling flow conditions; the drilling flow conditions include single-phase drilling fluid flow.

[0049] Specifically, the real-time wellbore calculation and decision module may include a high-precision drilling hydraulics calculation system to achieve real-time calculation of wellbore pressure. This high-precision drilling hydraulics calculation system is divided into two modules: single-phase drilling fluid and two-phase gas-liquid, to adapt to different drilling flow conditions. The drilling hydraulics calculation software can consider the changes in drilling fluid density, rheology, and other properties with temperature and pressure, and is suitable for both water-based and oil-based drilling fluids.

[0050] In some embodiments, the real-time wellbore calculation and decision module includes a steady-state calculation unit and a transient calculation unit; the steady-state calculation unit is used to obtain the calculated values ​​of fluctuating pressure and circulating pressure loss on a preset steady-state calculation path through steady-state calculation; the transient calculation unit is used to obtain the calculated values ​​of fluctuating pressure and circulating pressure loss on a preset pseudo-transient path through pseudo-transient calculation.

[0051] Specifically, the drilling hydraulics calculation software comprises two main calculation modules: a steady-state calculation model and a pseudo-transient calculation model. The steady-state calculation module performs steady-state calculations on the single-phase or gas-liquid two-phase drilling fluid within the annulus and drill string according to a preset steady-state calculation path, obtaining the fluctuating pressure along the preset steady-state path. The pseudo-transient calculation module performs pseudo-transient calculations on the gas-liquid two-phase fluid within the annulus and drill string according to a preset pseudo-transient calculation path, obtaining the fluctuating pressure along the preset pseudo-transient path.

[0052] The high-precision drilling hydraulics calculation system for controlled pressure drilling with heavy slurry caps during tripping in and out of the well uses steady-state / quasi-transient calculation modules for real-time calculations. All calculated data is stored in a database and can be accessed at any time. Bottomhole pressure is transmitted in real-time to the tripping leakage key parameter monitoring module and displayed on the monitoring software, serving as a crucial basis for wellbore pressure control. The parameters required for the calculations come from the tripping leakage key parameter monitoring module, which automatically inputs them into the hydraulics calculation software in real-time, and calculates the bottomhole pressure accordingly. The required real-time data includes: drilling fluid inlet density, drilling fluid inlet temperature, drilling fluid rheological parameters, displacement, standpipe pressure, tool pressure drop (for kills generated by additional tools added to the drill string besides drill pipe and drill collars, such as MWD, rotary steerables, and speed-up tools; this data is obtained from pre-deployment measurements), depth sounding, and vertical depth. Other data (including wellbore structure, wellbore trajectory, drill string assembly, drill bit nozzle diameter and quantity, and nozzle pressure drop) are pre-input into the software before drilling begins in controlled pressure drilling.

[0053] The high-precision drilling hydraulics calculation system for controlled pressure drilling with heavy slurry caps during tripping in and out of the well uses steady-state / quasi-transient calculation modules for real-time calculations. All calculated data is stored in a database and can be accessed at any time. Bottomhole pressure is transmitted in real-time to the tripping leakage key parameter monitoring module and displayed on the monitoring software, serving as a crucial basis for wellbore pressure control. The parameters required for the calculations are obtained from the tripping leakage key parameter monitoring module, automatically input into the hydraulics calculation software in real-time, and the bottomhole pressure is calculated accordingly.

[0054] The high-precision drilling hydraulics calculation system also has the function of correcting and verifying the model. It utilizes data from the drilled sections of the well for calculations, compares the calculated wellbore pressure with the measured wellbore pressure, and then verifies and corrects the model. During operation, data from several drilled sections and time periods of the working well can also be manually selected for on-site model correction. Furthermore, the model can also be verified and corrected using ground simulation experiments or classic data reported in the literature.

[0055] The high-precision drilling hydraulics calculation system consists of a calculation module selection, calculation path selection, parameter input, monitoring data interface, calculation data output port, calculation data display area, data display options and settings box, and database. The calculation data output port is connected to the tripping and running-in leakage key parameter monitoring module, the intelligent wellbore pressure intelligent control module, and the manual wellbore pressure intelligent control module.

[0056] The steady-state calculation module and the quasi-transient calculation module of the high-precision drilling hydraulics calculation system are stored independently, do not interfere with each other, and can run simultaneously.

[0057] In some embodiments, the real-time wellbore calculation and decision module pre-loads wellbore pressure profile parameters corresponding to the target wellbore; the wellbore pressure profile parameters include at least one of the following: wellbore structure, drill string assembly, drilling fluid properties, formation predicted pressure coefficient, preset control bottom hole pressure, and preset equivalent drilling fluid density.

[0058] Accordingly, the real-time wellbore calculation and decision module is also used to construct a wellbore structural model based on the wellbore pressure profile parameters; determine a wellbore dynamic model by combining the wellbore structural model and state parameters; and determine the slurry column change status based on the wellbore dynamic model.

[0059] Specifically, by analyzing and calculating the friction of the drill string during tripping, an overflow / leakage model based on changes in drill string weight and fluid level is established. Based on the weight, fluid level position, and wellbore slurry column structure, wellbore overflow / leakage is determined, providing data support for wellhead backpressure control decisions.

[0060] After obtaining the wellbore pressure and slurry column changes, operating condition adjustment parameters can be determined based on these changes. These parameters include at least one of the following: heavy slurry cap drilling fluid density, heavy slurry cap drilling fluid usage, tripping speed, and pressure control value.

[0061] In some implementations, an overflow model can be constructed by combining the friction of the drill string during drilling and undrilling, and then the abnormal working conditions can be determined based on the changes in the slurry column, the suspended weight, and the overflow model.

[0062] Specifically, if the inlet flow rate remains unchanged while the outlet flow rate continues to decrease, a well leakage situation is identified; if the inlet flow rate remains unchanged while the outlet flow rate continues to increase, an overflow situation is identified; if the fluid level is not detected at the wellhead and the annular fluid level height continues to decrease, a well leakage situation is identified; and if the fluid level is not detected at the wellhead and the annular fluid level height continues to increase, an overflow situation is identified.

[0063] When automatic monitoring and control begins, the tripping and running-in leakage key parameter monitoring module acquires engineering and equipment parameters in real time from the PWD (Potential Welding Detector), the well site data acquisition system (integrated logging system or drilling rig data acquisition system), and the wellhead pressure control equipment. Based on the integrated logging data and equipment parameters, it comprehensively judges the on-site working conditions, uses real-time PWD-monitored wellbore pressure and historical data to verify the calculation model parameters, calculates the wellbore pressure profile in real time, calculates the real-time control casing pressure, and issues casing pressure value commands. Alarm prompts mainly include, but are not limited to: well leakage, overflow, stuck pipe, and drill string leakage alarms. The judgment strategy is as follows: if the inlet flow rate remains unchanged while the outlet flow rate continues to decrease, a well leakage alarm is issued; if the inlet flow rate remains unchanged while the outlet flow rate continues to increase, a kick alarm is issued; if the rotation speed, drilling pressure, and displacement parameters remain unchanged while the torque continues to increase, a stuck pipe warning is issued; if the displacement, rotation speed, and drilling pressure parameters remain unchanged while the pump pressure decreases, a drill string leakage warning is issued.

[0064] The intelligent wellbore pressure control module is used to adjust the wellbore pressure according to the aforementioned operating condition adjustment parameters. In practical applications, it can control the pressure control value and / or drilling fluid density based on the relationship between wellbore pressure and formation pressure, and bottom hole pressure and leakage pressure, at different fluid level heights.

[0065] The following describes the control measures for different situations: (1) When the fluid level is at the wellhead, ① the software simulates and calculates the wellbore pressure distribution throughout the entire process, and the drilling fluid is continuously circulated on the surface to control the pressure during tripping; ② during tripping, the annular fluid level monitor is used in conjunction with the electronic monitoring system to analyze the drilling fluid volume and slurry column structure in the wellbore and calculate the wellbore pressure distribution. When the wellbore pressure is less than the formation pressure, the throttle valve is automatically adjusted to appropriately increase the control pressure value to ensure that the bottom hole pressure is greater than or equal to the formation pressure. When the bottom hole pressure is greater than the leakage pressure, the control pressure value is automatically reduced or the drilling fluid density or the drilling fluid volume is reduced to ensure that the bottom hole pressure is less than the leakage pressure.

[0066] (2) When the fluid level is not at the wellhead, ① the software simulates and calculates the wellbore pressure distribution throughout the entire process, and drilling fluid is continuously circulated and injected into the surface for controlled tripping; ② during tripping, relying on the annular fluid level monitoring instrument and combined with the electronic monitoring system, the drilling fluid volume and slurry column structure in the wellbore are analyzed, and the wellbore pressure distribution is calculated. When the bottom hole pressure is lower than the formation pressure, the surface drilling fluid discharge rate and density are automatically increased, and real-time analysis and calculation are performed to ensure that the wellbore pressure is greater than the formation pressure; when the bottom hole pressure is greater than the leakage pressure, the drilling fluid discharge rate and density are automatically reduced to ensure that the bottom hole pressure is less than the leakage pressure.

[0067] The intelligent wellbore pressure control module can also include a human intelligent wellbore pressure control module. In the event of complex operating conditions, it can switch to human control based on the corresponding analysis results to ensure effective control of complex operating conditions such as well leakage and blowout.

[0068] The following example uses a specific scenario to illustrate this, such as... Figure 4 The diagram shows the structure of the real-time monitoring system for tripping in and out of the wellbore under pressure control drilling with heavy slurry cap. The real-time data monitoring module is connected to both the intelligent wellbore pressure control module and the manual wellbore pressure control module. The real-time data monitoring module collects relevant data during tripping in and out of the well under pressure control drilling with heavy slurry cap. The intelligent wellbore pressure control module processes and analyzes the collected parameters to form a database and automatically controls and adjusts the wellbore pressure based on actual operating conditions. The manual wellbore pressure control module allows on-site operators to manually control the wellbore pressure based on actual operating conditions and relevant parameters.

[0069] After receiving engineering and equipment parameters, the real-time data monitoring module calculates, analyzes, and processes the data, visualizing the wellbore slurry column structure. It then corrects and adjusts the calculated data based on real-time data to ensure real-time leakage monitoring and early warning during the tripping of the heavy slurry cap. In the event of a complex leakage, when the fluid level is at the wellhead, the intelligent wellbore pressure control module issues a casing pressure control command to control the throttle valve opening and further control the wellhead back pressure. When the fluid level is not at the wellhead, the module, in conjunction with the electronic monitoring system, uses the heavy slurry cap drilling fluid density, usage, location, displacement mud volume, and tripping speed as decision output samples, and issues multi-parameter control commands.

[0070] As can be seen from the above embodiments and scenario examples, the aforementioned real-time monitoring system for the tripping and running of the heavy slurry cap in pressure-controlled drilling acquires the state parameters of the target wellbore during the tripping and running process through a key leakage monitoring module. Then, a real-time wellbore calculation and decision module determines the pressure status and slurry column changes of the wellbore based on these state parameters, thereby determining the operating condition adjustment parameters and regulating the wellbore pressure. By monitoring the tripping and running process of the heavy slurry cap in real time and dynamically adjusting the wellbore based on the real-time data processing results, the system ensures accurate early warning of leakage during the tripping and running process, improves the control effect of wellbore pressure, and is beneficial for practical production applications.

[0071] Based on the aforementioned real-time monitoring system for tripping in and out of the wellbore using a controlled-pressure drilling heavy slurry cap, this specification also proposes a method for real-time monitoring of tripping in and out of the wellbore using a controlled-pressure drilling heavy slurry cap. The executing entity of this method can be the aforementioned real-time monitoring system for tripping in and out of the wellbore using a controlled-pressure drilling heavy slurry cap. For example... Figure 5 As shown, the real-time monitoring method for raising and lowering the drill pipe using the controlled pressure drilling heavy slurry cap may include the following specific implementation steps.

[0072] S510: Obtain the state parameters of the target wellbore during the tripping of the heavy slurry cap.

[0073] The key parameter monitoring module for tripping and running out of drilling is mainly used to detect the condition of the target wellbore in order to obtain the state parameters of the wellbore during the tripping and running out of the heavy slurry cap.

[0074] The tripping / running-in leakage key parameter monitoring module can include various types of sensors. In some embodiments, the tripping / running-in leakage key parameter monitoring module may include a standpipe pressure sensor, a casing pressure sensor, a pressure control manifold pressure sensor, a pressure control manifold temperature sensor, a drilling fluid inlet flow meter, a drilling fluid outlet flow meter, a drilling fluid inlet / outlet density monitor, an electronic fluid level monitor, and an annular fluid level continuous monitoring device. Preferably, it may also include a gas-liquid separator exhaust pipe pressure sensor, a pressure control manifold flow meter, a gas-liquid separator outlet pipe flow meter, a gas-liquid separator exhaust pipe gas flow meter, a mud return branch drilling fluid rheology monitoring device, a gas-liquid separator outlet pipe drilling fluid rheology monitoring device, and a gas-liquid separator exhaust pipe gas component monitoring device.

[0075] Accordingly, the state parameters include at least one of the following: inlet / outlet flow rate, casing pressure, stand pressure, hook height, suspended weight, drill bit position, well depth, fluid level, and temperature. For example... Figure 2 The diagram shown is a logical schematic of wellbore monitoring based on the aforementioned monitoring module for key parameters of tripping and running-out leakage.

[0076] The system includes: a standpipe pressure sensor installed on the drilling standpipe to collect standpipe pressure during oil drilling operations; a pressure control manifold pressure monitoring device installed on the pressure control manifold to collect hydraulic pressure inside the manifold; a casing pressure sensor installed on the casing to collect pressure applied from the surface to the casing; a drilling fluid flow monitoring device installed at the drilling fluid inlet and outlet to collect the inflow and outflow rates; a backpressure compensation manifold flow monitoring device installed on the backpressure compensation manifold to collect the drilling fluid flow rate after backpressure compensation; a gas-liquid separator monitoring device installed on the gas-liquid separator to collect the outflow rate, exhaust volume, and gas composition of the gas-liquid separator; a mud return branch drilling fluid rheological property monitoring device installed on the mud return branch to collect the drilling fluid rheological parameters of the mud return branch; and a parameter monitoring host connected to a communication device. Figure 3 The diagram shown is a schematic diagram of the communication structure between the different sensors mentioned above.

[0077] The electronic drilling fluid level monitoring system is primarily used for data recording and simple analysis, detecting and triggering alarms for relatively simple anomalies. Specifically, it includes real-time recording and preliminary assessment of data such as drilling fluid properties, inlet and outlet flow rates, casing pressure, standpipe pressure, hook height, suspended weight, drill bit position, and well depth. It enables remote automatic monitoring and recording of key data, achieving intelligent and automated monitoring and reducing the likelihood of accidents due to human error.

[0078] The drilling fluid rheological parameters include apparent viscosity, plastic viscosity, structural viscosity, static shear force, and dynamic shear force. The relationship between them is relatively representative of the rheological properties of the drilling mud.

[0079] The annular liquid level continuous monitoring device includes a host computer, a preamplifier, a postamplifier, an electromagnetic acoustic transmitter, an acoustic sensor, a temperature sensor, a data acquisition unit, a filter, a solenoid valve, and a remote control connection device. The host computer uses a modulated sound wave detector to analyze the echo and calculate the liquid level depth. The preamplifier is connected to the host computer and amplifies the voltage of the modulated audio signal output by the host computer. The postamplifier is connected to the preamplifier and amplifies the current of the audio signal output by the preamplifier. The electromagnetic sound wave transmitter is connected to the postamplifier and emits the audio signal output by the postamplifier. The sound wave sensor is connected to the data acquisition unit and collects the emitted sound wave and echo signals within the annulus. The temperature sensor is connected to the data acquisition unit and collects the temperature within the channel where the sound wave sensor is located. The data acquisition unit is electrically connected to the host computer and receives and executes data acquisition commands issued by the host computer. A filter is connected between the data acquisition unit and the host computer to filter the signal sent from the data acquisition unit to the host computer. The solenoid valve is connected to the host computer through the data acquisition unit and is used to open or close the channel connecting the electromagnetic sound wave transmitter to the annulus.

[0080] In a specific application example, the number of pressure sensors is 10; the number of flow meters is 6, including 4 liquid flow meters and 2 gas flow meters; the number of gas phase component monitoring devices is at least 1; the number of drilling fluid rheology monitoring devices is at least 1; and the number of annular fluid level continuous monitoring devices is at least 1. In practical applications, the number of sensors can be adjusted according to requirements, and there is no limitation on this.

[0081] In practical applications, pressure sensors, flow meters, drilling fluid rheology monitoring devices, and annular fluid level continuous monitoring devices do not all need to be configured. They can be selected and configured according to the specific operating mode on site, or all of them can be configured to collect the necessary parameters as needed.

[0082] The key parameter monitoring module for tripping and running out of the well can include part of the integrated logging system and the data acquisition and monitoring system built into the drilling rig itself. Therefore, some of the data collected can come directly from the logging data center.

[0083] The sensors in the tripping and running-out leakage key parameter monitoring module, such as the pressure sensor, flow meter, drilling fluid rheology monitoring device, and annular fluid level continuous monitoring device, are also equipped with signal transmission modules. Correspondingly, the wellbore real-time calculation and decision-making module is equipped with a signal receiving module. The signal transmission module is used to send the status parameters collected by the sensors to the signal receiving module to realize data acquisition, transmission, and subsequent processing.

[0084] Specifically, the tripping and running-in leakage key parameter monitoring module has a port for connecting to the logging system and is connected to a remote monitoring and control system via communication network equipment. The sampling frequency of each parameter acquisition sensor in the tripping and running-in leakage key parameter monitoring module is consistent with the sampling frequency of the logging system and is adjusted according to the data sampling frequency of the on-site integrated logging system. The tripping and running-in leakage key parameter monitoring module provides core basic data for the remote intelligent and manual active control of oil and gas drilling wellbore pressure.

[0085] The drilling and tripping leakage key parameter monitoring module enables the preprocessing, storage, and unified platform display of multi-source, large-capacity data, including online monitoring data and logging data.

[0086] S520: Use the aforementioned state parameters to determine the pressure status and slurry column variation of the target wellbore.

[0087] Pressure conditions can include wellbore pressure. Specifically, the real-time wellbore calculation and decision module can be used to calculate wellbore pressure in real time based on drilling fluid volume, slurry column structure, drilling fluid inlet density, drilling fluid rheological parameters, displacement, depth measurement, and vertical depth.

[0088] The real-time wellbore calculation and decision module is used to calculate the wellbore pressure based on drilling flow conditions; the drilling flow conditions include single-phase drilling fluid flow.

[0089] Specifically, the real-time wellbore calculation and decision module may include a high-precision drilling hydraulics calculation system to achieve real-time calculation of wellbore pressure. This high-precision drilling hydraulics calculation system is divided into two modules: single-phase drilling fluid and two-phase gas-liquid, to adapt to different drilling flow conditions. The drilling hydraulics calculation software can consider the changes in drilling fluid density, rheology, and other properties with temperature and pressure, and is suitable for both water-based and oil-based drilling fluids.

[0090] In some embodiments, the real-time wellbore calculation and decision module includes a steady-state calculation unit and a transient calculation unit; the steady-state calculation unit is used to obtain the calculated values ​​of fluctuating pressure and circulating pressure loss on a preset steady-state calculation path through steady-state calculation; the transient calculation unit is used to obtain the calculated values ​​of fluctuating pressure and circulating pressure loss on a preset pseudo-transient path through pseudo-transient calculation.

[0091] Specifically, the drilling hydraulics calculation software comprises two main calculation modules: a steady-state calculation model and a pseudo-transient calculation model. The steady-state calculation module performs steady-state calculations on the single-phase or gas-liquid two-phase drilling fluid within the annulus and drill string according to a preset steady-state calculation path, obtaining the fluctuating pressure along the preset steady-state path. The pseudo-transient calculation module performs pseudo-transient calculations on the gas-liquid two-phase fluid within the annulus and drill string according to a preset pseudo-transient calculation path, obtaining the fluctuating pressure along the preset pseudo-transient path.

[0092] The high-precision drilling hydraulics calculation system for controlled pressure drilling with heavy slurry caps during tripping in and out of the well uses steady-state / quasi-transient calculation modules for real-time calculations. All calculated data is stored in a database and can be accessed at any time. Bottomhole pressure is transmitted in real-time to the tripping leakage key parameter monitoring module and displayed on the monitoring software, serving as a crucial basis for wellbore pressure control. The parameters required for the calculations come from the tripping leakage key parameter monitoring module, which automatically inputs them into the hydraulics calculation software in real-time, and calculates the bottomhole pressure accordingly. The required real-time data includes: drilling fluid inlet density, drilling fluid inlet temperature, drilling fluid rheological parameters, displacement, standpipe pressure, tool pressure drop (for kills generated by additional tools added to the drill string besides drill pipe and drill collars, such as MWD, rotary steerables, and speed-up tools; this data is obtained from pre-deployment measurements), depth sounding, and vertical depth. Other data (including wellbore structure, wellbore trajectory, drill string assembly, drill bit nozzle diameter and quantity, and nozzle pressure drop) are pre-input into the software before drilling begins in controlled pressure drilling.

[0093] The high-precision drilling hydraulics calculation system for controlled pressure drilling with heavy slurry caps during tripping in and out of the well uses steady-state / quasi-transient calculation modules for real-time calculations. All calculated data is stored in a database and can be accessed at any time. Bottomhole pressure is transmitted in real-time to the tripping leakage key parameter monitoring module and displayed on the monitoring software, serving as a crucial basis for wellbore pressure control. The parameters required for the calculations are obtained from the tripping leakage key parameter monitoring module, automatically input into the hydraulics calculation software in real-time, and the bottomhole pressure is calculated accordingly.

[0094] The high-precision drilling hydraulics calculation system also has the function of correcting and verifying the model. It utilizes data from the drilled sections of the well for calculations, compares the calculated wellbore pressure with the measured wellbore pressure, and then verifies and corrects the model. During operation, data from several drilled sections and time periods of the working well can also be manually selected for on-site model correction. Furthermore, the model can also be verified and corrected using ground simulation experiments or classic data reported in the literature.

[0095] The high-precision drilling hydraulics calculation system consists of a calculation module selection, calculation path selection, parameter input, monitoring data interface, calculation data output port, calculation data display area, data display options and settings box, and database. The calculation data output port is connected to the tripping and running-in leakage key parameter monitoring module, the intelligent wellbore pressure intelligent control module, and the manual wellbore pressure intelligent control module.

[0096] The steady-state calculation module and the quasi-transient calculation module of the high-precision drilling hydraulics calculation system are stored independently, do not interfere with each other, and can run simultaneously.

[0097] In some embodiments, the real-time wellbore calculation and decision module pre-loads wellbore pressure profile parameters corresponding to the target wellbore; the wellbore pressure profile parameters include at least one of the following: wellbore structure, drill string assembly, drilling fluid properties, formation predicted pressure coefficient, preset control bottom hole pressure, and preset equivalent drilling fluid density.

[0098] Accordingly, the real-time wellbore calculation and decision module is also used to construct a wellbore structural model based on the wellbore pressure profile parameters; determine a wellbore dynamic model by combining the wellbore structural model and state parameters; and determine the slurry column change status based on the wellbore dynamic model.

[0099] Specifically, by analyzing and calculating the friction of the drill string during tripping, an overflow / leakage model based on changes in drill string weight and fluid level is established. Based on the weight, fluid level position, and wellbore slurry column structure, wellbore overflow / leakage is determined, providing data support for wellhead backpressure control decisions.

[0100] S530: Determine the operating condition adjustment parameters based on the wellbore pressure and slurry column changes; the operating condition adjustment parameters include at least one of the following: heavy slurry cap drilling fluid density, heavy slurry cap drilling fluid usage, tripping speed, and pressure control value.

[0101] After obtaining the wellbore pressure and slurry column changes, operating condition adjustment parameters can be determined based on these changes. These parameters include at least one of the following: heavy slurry cap drilling fluid density, heavy slurry cap drilling fluid usage, tripping speed, and pressure control value.

[0102] In some implementations, an overflow model can be constructed by combining the friction of the drill string during drilling and undrilling, and then the abnormal working conditions can be determined based on the changes in the slurry column, the suspended weight, and the overflow model.

[0103] Specifically, if the inlet flow rate remains unchanged while the outlet flow rate continues to decrease, a well leakage situation is identified; if the inlet flow rate remains unchanged while the outlet flow rate continues to increase, an overflow situation is identified; if the fluid level is not detected at the wellhead and the annular fluid level height continues to decrease, a well leakage situation is identified; and if the fluid level is not detected at the wellhead and the annular fluid level height continues to increase, an overflow situation is identified.

[0104] When automatic monitoring and control begins, the tripping and running-in leakage key parameter monitoring module acquires engineering and equipment parameters in real time from the PWD (Potential Welding Detector), the well site data acquisition system (integrated logging system or drilling rig data acquisition system), and the wellhead pressure control equipment. Based on the integrated logging data and equipment parameters, it comprehensively judges the on-site working conditions, uses real-time PWD-monitored wellbore pressure and historical data to verify the calculation model parameters, calculates the wellbore pressure profile in real time, calculates the real-time control casing pressure, and issues casing pressure value commands. Alarm prompts mainly include, but are not limited to: well leakage, overflow, stuck pipe, and drill string leakage alarms. The judgment strategy is as follows: if the inlet flow rate remains unchanged while the outlet flow rate continues to decrease, a well leakage alarm is issued; if the inlet flow rate remains unchanged while the outlet flow rate continues to increase, a kick alarm is issued; if the rotation speed, drilling pressure, and displacement parameters remain unchanged while the torque continues to increase, a stuck pipe warning is issued; if the displacement, rotation speed, and drilling pressure parameters remain unchanged while the pump pressure decreases, a drill string leakage warning is issued.

[0105] S540: Adjust the wellbore pressure according to the operating condition adjustment parameters.

[0106] The intelligent wellbore pressure control module is used to adjust the wellbore pressure according to the aforementioned operating condition adjustment parameters. In practical applications, it can control the pressure control value and / or drilling fluid density based on the relationship between wellbore pressure and formation pressure, and bottom hole pressure and leakage pressure, at different fluid level heights.

[0107] The following describes the control measures for different situations: (1) When the fluid level is at the wellhead, ① the software simulates and calculates the wellbore pressure distribution throughout the entire process, and the drilling fluid is continuously circulated on the surface to control the pressure during tripping; ② during tripping, the annular fluid level monitor is used in conjunction with the electronic monitoring system to analyze the drilling fluid volume and slurry column structure in the wellbore and calculate the wellbore pressure distribution. When the wellbore pressure is less than the formation pressure, the throttle valve is automatically adjusted to appropriately increase the control pressure value to ensure that the bottom hole pressure is greater than or equal to the formation pressure. When the bottom hole pressure is greater than the leakage pressure, the control pressure value is automatically reduced or the drilling fluid density or the drilling fluid volume is reduced to ensure that the bottom hole pressure is less than the leakage pressure.

[0108] (2) When the fluid level is not at the wellhead, ① the software simulates and calculates the wellbore pressure distribution throughout the entire process, and drilling fluid is continuously circulated and injected into the surface for controlled tripping; ② during tripping, relying on the annular fluid level monitoring instrument and combined with the electronic monitoring system, the drilling fluid volume and slurry column structure in the wellbore are analyzed, and the wellbore pressure distribution is calculated. When the bottom hole pressure is lower than the formation pressure, the surface drilling fluid discharge rate and density are automatically increased, and real-time analysis and calculation are performed to ensure that the wellbore pressure is greater than the formation pressure; when the bottom hole pressure is greater than the leakage pressure, the drilling fluid discharge rate and density are automatically reduced to ensure that the bottom hole pressure is less than the leakage pressure.

[0109] The intelligent wellbore pressure control module can also include a human intelligent wellbore pressure control module. In the event of complex operating conditions, it can switch to human control based on the corresponding analysis results to ensure effective control of complex operating conditions such as well leakage and blowout.

[0110] It should be noted that the real-time monitoring system for the lifting and lowering of the drilling rig with the pressure-controlled drilling heavy slurry cap can be applied to the field of geological exploration and development technology, or to other technical fields other than geological exploration and development technology, without any limitation.

[0111] Although the process described above includes multiple operations that occur in a specific order, it should be clearly understood that these processes may include more or fewer operations, which may be executed sequentially or in parallel (e.g., using parallel processors or a multithreaded environment).

[0112] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this specification. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart... Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0113] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0114] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 A step that specifies a function in one or more boxes.

[0115] Those skilled in the art will understand that the embodiments of this specification can be provided as methods, systems, or computer program products. Therefore, the embodiments of this specification can take the form of entirely hardware embodiments, entirely software embodiments, or embodiments combining software and hardware aspects. Furthermore, the embodiments of this specification can take the form of computer program products implemented on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0116] The embodiments described in this specification can be described in the general context of computer-executable instructions, such as program modules, that are executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, etc., that perform a specific task or implement a specific abstract data type. The embodiments of this specification can also be practiced in distributed computing environments where tasks are performed by remote processing devices connected via a communication network. In distributed computing environments, program modules can reside in local and remote computer storage media, including storage devices.

[0117] The various embodiments in this specification are described in a progressive manner. Similar or identical parts between embodiments can be referred to mutually. Each embodiment focuses on describing the differences from other embodiments. In particular, system embodiments are basically similar to method embodiments, so the description is relatively simple; relevant parts can be referred to the descriptions in the method embodiments. In the description of this specification, the terms "one embodiment," "some embodiments," "example," "specific example," or "some examples," etc., refer to specific features, structures, materials, or characteristics described in connection with that embodiment or example, which are included in at least one embodiment or example of the embodiments in this specification. In this specification, the illustrative expressions of the above terms do not necessarily refer to the same embodiment or example. Furthermore, the specific features, structures, materials, or characteristics described can be combined in any suitable manner in one or more embodiments or examples. Moreover, without contradiction, those skilled in the art can combine and integrate the different embodiments or examples described in this specification and the features of different embodiments or examples.

[0118] The foregoing is merely an embodiment of the present application and is not intended to limit the present application. For those skilled in the art, the present application may have various changes and variations. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principles of the present application should all be included within the scope of the claims of the present application.

Claims

1. A real-time monitoring system for tripping in and out of the wellbore using a pressure-controlled drilling heavy slurry cap, characterized in that, It includes a key parameter monitoring module for tripping and running out of the well, a real-time wellbore calculation and decision-making module, and a wellbore pressure intelligent control module; The key parameter monitoring module for tripping and running leakage is used to acquire the status parameters of the target wellbore during the tripping and running process of the heavy slurry cap, and transmit the status parameters to the wellbore real-time calculation and decision module. The real-time wellbore calculation and decision module is used to determine the pressure status and slurry column change status of the target wellbore using the state parameters; and to determine the operating condition adjustment parameters based on the wellbore pressure and slurry column change status; the operating condition adjustment parameters include at least one of the following: heavy slurry cap drilling fluid density, heavy slurry cap drilling fluid usage, tripping speed, and pressure control value. The intelligent wellbore pressure control module is used to adjust the wellbore pressure according to the operating condition adjustment parameters. The state parameters include at least one of the following: inlet / outlet flow rate, casing pressure, stand pressure, hook height, suspended weight, drill bit position, well depth, fluid level depth, and temperature. The real-time calculation and decision-making module for the wellbore includes a steady-state calculation unit and a transient calculation unit; the steady-state calculation unit is used to obtain the fluctuating pressure on a preset steady-state calculation path through steady-state calculation; the transient calculation unit is used to obtain the fluctuating pressure on a preset pseudo-transient path through pseudo-transient calculation; The pressure conditions include wellbore pressure; the intelligent wellbore pressure control module is used to increase the control pressure value when the wellbore pressure is less than the formation pressure, and to decrease the control pressure value, reduce the drilling fluid density, or reduce the drilling fluid volume when the fluid level is at the wellhead; The intelligent wellbore pressure control module is used to increase the drilling fluid discharge rate and density when the wellbore pressure is less than the formation pressure, and to decrease the drilling fluid discharge rate and density when the wellbore pressure is greater than the leakage pressure, provided that the fluid level is not at the wellhead.

2. The system as described in claim 1, characterized in that, The tripping and running-out leakage key parameter monitoring module includes at least one of the following: stand pressure sensor, casing pressure sensor, pressure control manifold pressure sensor, pressure control manifold temperature sensor, drilling fluid inlet flow meter, drilling fluid outlet flow meter, drilling fluid inlet and outlet density monitor, electronic fluid level monitoring device, and annular fluid level continuous monitoring device.

3. The system as described in claim 1, characterized in that, The real-time wellbore calculation and decision module pre-inputs wellbore pressure profile parameters corresponding to the target wellbore; the wellbore pressure profile parameters include at least one of the following: wellbore structure, drill string assembly, drilling fluid properties, formation predicted pressure coefficient, preset control bottom hole pressure, and preset equivalent drilling fluid density.

4. The system as described in claim 3, characterized in that, The real-time wellbore calculation and decision module is also used to construct a wellbore structural model based on the wellbore pressure profile parameters; determine a wellbore dynamic model by combining the wellbore structural model and state parameters; and determine the wellbore pressure change status based on the wellbore dynamic model.

5. The system as described in claim 1, characterized in that, The real-time wellbore calculation and decision module is used to calculate the wellbore pressure based on drilling flow conditions; the drilling flow conditions include single-phase drilling fluid flow.

6. The system as described in claim 5, characterized in that, The real-time wellbore calculation and decision module includes a drilling hydraulics calculation system; the drilling hydraulics calculation system is used to calculate wellbore pressure.

7. The system as described in claim 1, characterized in that, The real-time wellbore calculation and decision module is used to calculate wellbore pressure in real time based on wellbore drilling fluid volume, slurry column structure, drilling fluid inlet density, drilling fluid rheological parameters, discharge rate, depth measurement, and vertical depth.

8. The system as described in claim 1, characterized in that, The determination of operating condition adjustment parameters based on the wellbore pressure and slurry column changes includes: An overflow model was constructed by combining electronic monitoring and annular liquid level monitoring. The system uses electronic monitoring, annular liquid level monitoring, and the aforementioned leakage model to determine whether any abnormal operating conditions have occurred.

9. The system as described in claim 8, characterized in that, Based on the changes in the slurry column, the suspended weight, and the aforementioned leakage model, it is determined whether any abnormal operating conditions have occurred, including: If the fluid level is detected at the wellhead and the inlet flow rate remains unchanged while the outlet flow rate continues to decrease, it is determined that a well leakage has occurred. If the fluid level is detected at the wellhead and the inlet flow rate remains unchanged while the outlet flow rate continues to rise, it is determined that an overflow has occurred. If the fluid level is detected to be outside the wellhead and the annular fluid level continues to decrease, it is determined that a well leakage has occurred. If the fluid level is detected to be outside the wellhead and the annular fluid level continues to rise, an overflow is determined to have occurred.

10. A method for real-time monitoring of the tripping in and out of the wellbore in pressure-controlled drilling with a heavy slurry cap, characterized in that, The method, applied to the real-time monitoring system for tripping in and out of the wellbore using the pressure-controlled drilling heavy slurry cap as described in any one of claims 1 to 9, comprises: Acquire the state parameters of the target wellbore during the tripping of the heavy slurry cap; The pressure status and slurry column variation of the target wellbore are determined using the aforementioned state parameters; The operating condition adjustment parameters are determined based on the wellbore pressure and slurry column changes; the operating condition adjustment parameters include at least one of the following: heavy slurry cap drilling fluid density, heavy slurry cap drilling fluid usage, and pressure control value. The wellbore pressure is adjusted according to the aforementioned operating condition adjustment parameters.

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