A method and system for continuous monitoring of leakage during tripping and running of heavy slurry caps in pressure-controlled drilling.

Abstract

This invention relates to the field of drilling overflow and leakage monitoring technology, and particularly to a method and system for continuous monitoring of overflow and leakage during tripping and running of a controlled-pressure drilling heavy slurry cap. The method includes: using a host computer to modulate the frequency and loudness of a detection sound wave; controlling an electromagnetic sound wave transmitter to emit the detection sound wave, provided that the frequency and loudness of the sound wave are within the measurement range; generating an echo signal as the sound wave propagates within the annulus; processing the echo signal to obtain an effective echo; obtaining the fluid surface position by combining the sound velocity of the coupling echo and the fluid surface echo time; determining the leakage status based on the fluid surface position and logging conditions; and implementing a platform output and judgment cycle based on the judgment result. This technical solution effectively solves the problem of sound wave attenuation in shallow fluid conditions in existing technologies, avoids continuous oscillation of sound waves within the channel, creates favorable conditions for effective information extraction, ensures the reliability of the fluid surface position, and further improves the monitoring effect.

Description

Technical Field

[0001] This invention relates to the field of drilling overflow and leakage monitoring technology, and in particular to a method and system for continuous monitoring of overflow and leakage during tripping in controlled-pressure drilling with heavy slurry caps. Background Technology

[0002] In recent years, the number of deep and ultra-deep wells has increased in some areas, and narrow safety density windows have become more frequent. Controlled pressure drilling faces various complex issues such as leaks and blowouts, and immense pressure. Currently, controlled pressure drilling can precisely control wellbore pressure through casing pressure during normal drilling, pump shutdown for single-joint connection, and tripping operations to ensure no leakage or overflow. However, in cases of severe well leakage or tripping operations with heavy slurry caps, the fluid level is no longer at the wellhead, and controlled pressure drilling loses its control. If leakage then turns into overflow, a serious well control event will occur.

[0003] Dynamic monitoring of the annular fluid level and overflow / leakage models are the primary technical means to prevent drilling spills and leaks. Currently, echo-based rangefinders are mainly used for annular fluid level measurement during drilling, which has the following drawbacks: Because high-pressure air guns are used as the sound source, high-pressure nitrogen needs to be replenished periodically, resulting in poor continuous monitoring performance. This can lead to a lack of specific annular fluid level data when well control problems occur, resulting in ineffective drilling risk warnings. The high gas pressure also poses certain safety risks. While the explosive sound source has high instantaneous energy, which is advantageous for deep and ultra-deep well measurements, the frequency of the explosive sound source is too low (generally less than 20Hz) and cannot be adjusted. In shallow fluid levels, it is difficult to attenuate, and the sound waves continuously oscillate within the channel, submerging the fluid surface echo within the emitted sound waves, making it difficult to extract effective information and leading to misjudgments of the fluid level position and poor monitoring performance. Furthermore, infrasound has strong penetrating power but weak reflection at the coupling, so the fluid level position can only be determined through the fluid surface echo, making it difficult to determine the annular sound velocity, resulting in significant errors. Therefore, on-site annular fluid level monitoring operations urgently need a system that can continuously monitor the annular fluid level and provide early warning of leakage when the annular fluid level is not at the wellhead. Summary of the Invention

[0004] To address the shortcomings of the existing technologies, this invention proposes a method and system for continuous monitoring of overflow during tripping and tripping of pressure-controlled drilling heavy slurry caps. It employs an electromagnetic acoustic transmitter as the sound source, capable of continuously emitting detection sound waves with adjustable frequency and loudness. The echo method is used to monitor the overflow status, solving a series of problems inherent in the traditional echo method using high-pressure air guns as the sound source, such as poor continuity, severe infrasound interference, large measurement errors, and poor monitoring performance at low liquid levels.

[0005] This invention is achieved by adopting the following technical solution:

[0006] A method for continuous monitoring of leakage during tripping and running of pressure-controlled drilling heavy slurry caps includes the following steps:

[0007] S1, During controlled pressure drilling, the host computer modulates the frequency and loudness of the detection sound wave accordingly, and sets the emission time of the detection sound wave to be... ;

[0008] S2, determine whether the loudness of the detected sound wave frequency is within the range; if not, output over-range; if yes, proceed to S3;

[0009] S3 controls the electromagnetic acoustic wave transmitter to emit detection acoustic waves;

[0010] S4, the sound wave is transmitted downward along the drill pipe in the annulus, and returns when it encounters the coupling and the liquid surface, forming an echo signal;

[0011] S5 acquires, filters, and calculates short-time energy of the echo signal to obtain the processed effective echo, including the coupling echo.

[0012] S6. Determine whether there is a liquid surface echo in the echo signal based on the valid echo. If there is, calculate the liquid surface echo time. If not, reduce the transmission frequency of the detection sound wave and increase the transmission loudness, then return to S2.

[0013] S7, obtain the sound velocity of the coupling echo, and combine the sound velocity of the coupling echo with the liquid surface echo time to obtain the liquid surface position. ;

[0014] S8 determines the overflow status based on the liquid level and logging conditions, and implements the platform output and judgment cycle based on the judgment result.

[0015] Preferably, in step S5, the echo signal is acquired using an acoustic wave sensor, including the following steps:

[0016] Based on the sampling frequency set by the host computer and sampling time ;

[0017] The host computer sends data acquisition commands to the data acquisition unit, and the moment the host computer sends the data acquisition command is defined as the starting point. ;

[0018] The data acquisition unit uses an acoustic sensor to sample at a frequency... Sampling is performed, and the sampled signal is .

[0019] Preferably, in step S5, filtering the echo signal involves converting the sampled signal into... The filtered signal is obtained by using a bandpass filter. .

[0020] Preferably, in step S5, the short-time energy calculation includes the following steps:

[0021] The filtered signal It is divided into two segments; one segment is the transmission segment signal. The time is The other segment is the received signal. The time is ;

[0022] Based on formula Receive segment signal With the signal of the transmitting segment Correlation detection was performed; among them, This indicates the correlation between any given point in time and the corresponding transmitted signal; Indicates the time period during which the signal was transmitted; Let represent a time infinitesimal element, which is a variable. This constitutes the time period for receiving the signal, i.e. This indicates the received segment signal.

[0023] Preferably, in step S6, it is done by... Find the maximum point and use the threshold method to determine whether there is a liquid surface echo in the echo signal; the maximum point is denoted as the liquid surface echo point. The time of this point is recorded as follows: The liquid surface echo time is .

[0024] Preferably, in step S7, it is based on the formula Obtain the liquid level position; where, This refers to the speed of sound in the annular space or the speed of sound on the ground. Current liquid level.

[0025] Preferably, in step S7, the method for obtaining the coupling echo velocity is as follows: determining whether the number of coupling waves in the received echo signal is less than 2; if not, then To measure the annular sound velocity, the fixed spacing between the two couplings on the drill pipe is utilized. Time difference with the corresponding two coupling waves Perform calculations, that is If so, then The speed of sound at ground level is calculated using surface temperature. ,in This refers to the Earth's surface temperature.

[0026] Preferably, in step S8, the logging conditions include: Condition 1, the drill bit position remains unchanged during the current time period; Condition 2, there is a tripping action during the current time period; Condition 3, the current time period includes a descent action. Based on this, determining the leakage status includes the following steps:

[0027] S81-1, Calculation Theoretical changes in annular fluid level caused by grouting over a time period: ;in, The amount of mud injected. The inner diameter of the annulus. The outer diameter of the drill pipe. This represents the theoretical distance of change in the annular liquid level; Indicates any current time period;

[0028] S81-2, based on S1~S7 The liquid level positions before and after will The difference between the liquid level positions before and after is the actual distance of change in the annular liquid level. ;

[0029] S81-3, determine whether the logging condition is condition one; if yes, proceed to S81-31 and the current leakage status determination will terminate; if not, proceed to S81-4.

[0030] S81-31, the theoretical annular liquid level change distance Distance from actual annular liquid level change As a basis for judging the leakage status; if If it is, then it is judged as an overflow; if If it is, then it is judged as a loss; if If so, it is considered a normal situation;

[0031] S81-4, Calculation The theoretical annular fluid level change distance caused by drill string movement within a time period: ;in: The length of the drill string to be pulled out. This represents the theoretical distance of change in the annular liquid level.

[0032] S81-5, determine whether the logging operation is operation condition two or operation condition three; if it is operation condition two, then after entering and implementing S81-51, the current overflow status judgment will be terminated; if it is operation condition three, then after entering and implementing S81-52, the current overflow status judgment will be terminated.

[0033] S81-51, the theoretical annular liquid level change distance Distance from theoretical annular liquid level change The absolute value of the difference, and the actual distance of change in the annular liquid level. As a basis for judging the leakage status; if If so, it is judged as an overflow or air intrusion; if If it is, then it is judged as a loss; if If so, it is considered a normal situation;

[0034] S81-52, the theoretical annular liquid level change distance Distance from theoretical annular liquid level change The sum of these, and the actual distance of the annular liquid level change. As a basis for judging the leakage status; if If so, it is judged as an overflow or air intrusion; if If it is, then it is judged as a loss; if If so, it is considered a normal situation.

[0035] Preferably, in step S8, the implementation of the platform output and judgment cycle includes: if the leakage state is judged to be normal, then output the normal state and maintain the frequency and loudness of the current detected sound wave, and return to S3; if the leakage state is judged to be overflow, gas intrusion or leakage, then output the overflow, gas intrusion or leakage state accordingly, and determine whether the frequency and loudness are still within the recommended range by measuring the liquid level position; if they are within the recommended range, then maintain the frequency and loudness of the current detected sound wave and return to S3; if they exceed the recommended range, then reduce the loudness and increase the frequency for the current detected sound wave, and return to S2.

[0036] Based on the aforementioned method for continuous monitoring of leakage during tripping and tripping of controlled-pressure drilling with heavy slurry caps, this technical solution proposes a continuous monitoring system for leakage during tripping and tripping of controlled-pressure drilling with heavy slurry caps. This system includes a host computer, a preamplifier, a postamplifier, an electromagnetic acoustic transmitter, an acoustic sensor, a temperature sensor, a data acquisition unit, and a filter. The host computer is used to modulate the detected acoustic waves, analyze the echoes, calculate the fluid level depth, and determine the leakage status by combining the fluid level depth with logging data. The preamplifier is connected to the host computer and is used to amplify the voltage of the modulated audio signal output by the host computer. The postamplifier is connected to the preamplifier. The system comprises: a current amplifier for amplifying the audio signal output from the preamplifier; an electromagnetic acoustic wave transmitter connected to a post-amplifier for transmitting the audio signal output from the post-amplifier; an acoustic wave sensor connected to a data acquisition unit for acquiring the emitted acoustic wave and echo signals within the ring; a temperature sensor connected to the data acquisition unit for acquiring the temperature within the channel where the acoustic wave sensor is located; an electrical connection to a host computer for receiving and executing data acquisition commands issued by the host computer; and a filter connected between the data acquisition unit and the host computer for filtering the signals uploaded by the data acquisition unit to the host computer.

[0037] Preferably, the continuous monitoring system further includes a solenoid valve, which is connected to a host computer via a data acquisition unit and is used to open or close the channel connecting the electromagnetic acoustic wave transmitter to the annulus.

[0038] The beneficial technical effects of this invention are as follows:

[0039] 1) This technical solution uses an electromagnetic acoustic wave transmitter as the sound source. Based on the principle that the continuous transmission frequency and loudness of the detection sound wave can be adjusted by adjusting the current frequency and magnitude, the upper computer is used for modulation to realize that the sound frequency and loudness can be adaptively changed within the allowable range. Based on this, high frequency and low volume correspond to shallow liquid surface conditions, and low frequency and high volume correspond to deep liquid surface conditions. This effectively solves the problem of sound wave attenuation in shallow liquid surface conditions in the existing technology, avoids continuous oscillation of sound waves in the channel, creates good effective information extraction conditions, ensures the reliability of liquid surface position, and further improves the monitoring effect.

[0040] 2) This technical solution does not require the replenishment of nitrogen, ensuring the continuity of the detection work.

[0041] 3) This technical solution uses an electromagnetic acoustic transmitter with adjustable frequency and loudness to achieve good identification of the drill pipe coupling echo during the detection process (the frequency of the electromagnetic acoustic transmitter is adjustable, and appropriately increasing the acoustic frequency can achieve better identification of the drill pipe coupling). Based on this, the actual annular sound velocity can be calculated by the coupling echo time difference and coupling spacing, reducing the corresponding parameter errors and improving the accuracy of the monitoring results.

[0042] 4) Based on the selection of electromagnetic acoustic wave transmitters, while realizing the modulation and demodulation of acoustic waves, the anti-interference capability of acoustic waves is improved, and the noise at the wellhead and inside the well can be avoided from interfering with the echo and causing misjudgment.

[0043] 5) Electromagnetic acoustic transmitters can emit detection acoustic waves in real time, providing good continuous monitoring. This enables continuous monitoring of the wellbore status, preventing poor drilling risk warnings due to the lack of specific annular fluid level data in the event of well control problems. In summary, it can achieve real-time monitoring of the annular fluid level when the controlled-pressure drilling fluid level is not at the wellhead, and complete real-time leakage monitoring and early warning during the tripping of the heavy-duty drilling cap. Attached Figure Description

[0044] Figure 1 This is a flowchart illustrating a preferred continuous monitoring method for this technical solution.

[0045] Figure 2 This is a block diagram of a preferred continuous monitoring system according to the present technical solution;

[0046] Figure 3 An echo map generated based on the echo signal;

[0047] Figure 4 A chart showing recommended values ​​for sound wave frequency loudness;

[0048] In the picture:

[0049] 1. Wellbore; 2. Drill pipe; 3. Annulus; 4. Coupling; 5. Fluid level; 6. Solenoid valve; 7. Acoustic sensor; 8. Temperature sensor; 9. Electromagnetic acoustic transmitter; 10. Data acquisition unit; 11. Filter; 12. Post-amplifier; 13. Pre-amplifier; 14. Host computer. Detailed Implementation

[0050] To make the purpose, technical solution and advantages of the invention clearer, the technical solution of the invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are some embodiments of the invention, but not all embodiments.

[0051] Therefore, the following detailed description of the invention provided in the accompanying drawings is not intended to limit the scope of the claimed invention, but merely to illustrate selected embodiments of the invention. All other embodiments obtained by those skilled in the art based on the embodiments of the invention without inventive effort are within the scope of protection of the invention.

[0052] Example 1

[0053] This embodiment discloses a method for continuous monitoring of leakage during tripping and running of heavy slurry caps in pressure-controlled drilling. As a preferred embodiment of the present invention, it includes the following steps:

[0054] S1, During controlled pressure drilling, if the drilling fluid fails to return and the fluid level is not at the wellhead, the host computer will adjust the frequency and loudness of the detection sound wave accordingly (when leakage first begins, the fluid level is close to the wellhead, so a high-frequency, low-loudness detection sound wave is used to obtain the best echo; as the fluid level drops, the loudness of the detection sound wave can be gradually increased and the frequency decreased to obtain the best echo; high frequency and low loudness correspond to shallow fluid level conditions, and low frequency and high loudness correspond to deep fluid level conditions), and set the sound wave emission time to T0.

[0055] S2, determine whether the frequency and loudness of the detected sound wave are within the range (frequency range of 20~1500Hz, loudness range of 70~130dB; this scheme reduces the frequency and increases the loudness when there is no obvious echo. If the range is exceeded and there is no echo, it means that the liquid depth is too deep and is not within the measurement range). If not, output over-range; if yes, proceed to S3.

[0056] S3 controls the electromagnetic sound wave transmitter to emit detection sound waves. Specifically, after the host computer modulates the detection sound waves, it sends out a corresponding audio signal. After a series of processing steps, the audio signal is input to the electromagnetic sound wave transmitter, which then emits the corresponding detection sound waves.

[0057] S4, the sound wave is transmitted downward along the drill pipe in the annulus, and returns when it encounters the coupling and the liquid surface, forming an echo signal.

[0058] S5 collects, filters, and performs short-time energy calculations on the echo signal to obtain the processed effective echo, including the coupling echo, which may contain liquid surface echo.

[0059] S6. Determine whether there is a liquid surface echo in the echo signal based on the valid echo. If there is, calculate the liquid surface echo time. If not, reduce the transmission frequency of the detection sound wave and increase the transmission loudness, then return to S2.

[0060] S7, obtain the sound velocity of the coupling echo, and combine the sound velocity of the coupling echo with the liquid surface echo time to obtain the liquid surface position. .

[0061] S8 determines the overflow status based on the liquid level and logging conditions, and implements the platform output and judgment cycle based on the judgment result.

[0062] Example 2

[0063] This embodiment discloses a method for continuous monitoring of leakage during tripping and running of heavy slurry caps in pressure-controlled drilling. As a preferred embodiment of the present invention, it includes the following steps:

[0064] S1, During controlled pressure drilling, the host computer modulates the frequency and loudness of the detection sound wave accordingly, and sets the emission time of the detection sound wave to be... ;

[0065] S2, determine whether the loudness of the detected sound wave frequency is within the range; if not, output over-range; if yes, proceed to S3;

[0066] S3 controls the electromagnetic acoustic wave transmitter to emit detection acoustic waves;

[0067] S4, the sound wave is transmitted downward along the drill pipe in the annulus, and returns when it encounters the coupling and the liquid surface, forming an echo signal;

[0068] S5 involves acquiring, filtering, and calculating the short-time energy of the echo signal to obtain the processed effective echo, including the coupling echo. Specifically, this is done using an acoustic wave sensor to acquire the echo signal, including the following steps:

[0069] Based on the sampling frequency set by the host computer and sampling time ( );

[0070] The host computer sends data acquisition commands to the data acquisition unit, and the moment the host computer sends the data acquisition command is defined as the starting point. ;

[0071] The data acquisition unit uses an acoustic sensor to sample at a frequency... Sampling is performed, and the sampled signal is .

[0072] The echo signal is filtered using a filter to obtain the sampled signal. The filtered signal is obtained by using a bandpass filter. The passband range of the filter is 20~30Hz.

[0073] Short-time energy calculation includes the following steps:

[0074] Segmented processing: The filtered signal... It is divided into two segments; one segment is the transmission segment signal. The time is The other segment is the received signal. The time is ;

[0075] Based on formula Receive segment signal With the signal of the transmitting segment Correlation detection was performed; among them, This indicates the correlation between any given point in time and the corresponding transmitted signal; Indicates the time period during which the signal was transmitted; Let represent a time infinitesimal element, which is a variable. This constitutes the time period for receiving the signal, i.e. This indicates the received segment signal.

[0076] S6. Determine whether there is a liquid surface echo in the echo signal based on the valid echo. If there is, calculate the liquid surface echo time. If not, reduce the transmission frequency of the detection sound wave and increase the transmission loudness, then return to S2.

[0077] S7, obtain the sound velocity of the coupling echo, and combine the sound velocity of the coupling echo with the liquid surface echo time to obtain the liquid surface position. ;

[0078] S8 determines the overflow status based on the liquid level and logging conditions, and implements the platform output and judgment cycle based on the judgment result.

[0079] Example 3

[0080] This embodiment discloses a method for continuous monitoring of leakage during tripping and running of heavy slurry caps in pressure-controlled drilling. As a preferred embodiment of the present invention, it includes the following steps:

[0081] S1, During controlled pressure drilling, the host computer modulates the frequency and loudness of the detection sound wave accordingly, and sets the emission time of the detection sound wave to be... ;

[0082] S2, determine whether the loudness of the detected sound wave frequency is within the range; if not, output over-range; if yes, proceed to S3;

[0083] S3 controls the electromagnetic acoustic wave transmitter to emit detection acoustic waves;

[0084] S4, the sound wave is transmitted downward along the drill pipe in the annulus, and returns when it encounters the coupling and the liquid surface, forming an echo signal;

[0085] S5 involves acquiring, filtering, and calculating the short-time energy of the echo signal to obtain the processed effective echo, including the coupling echo. Specifically, this is done using an acoustic wave sensor to acquire the echo signal, including the following steps:

[0086] Based on the sampling frequency set by the host computer and sampling time ;

[0087] The host computer sends data acquisition commands to the data acquisition unit, and the moment the host computer sends the data acquisition command is defined as the starting point. ;

[0088] The data acquisition unit uses an acoustic sensor to sample at a frequency... Sampling is performed, and the sampled signal is .

[0089] Filtering the echo signal involves converting the sampled signal into... The filtered signal is obtained by using a bandpass filter. .

[0090] Short-time energy calculation includes the following steps:

[0091] The filtered signal It is divided into two segments; one segment is the transmission segment signal. The time is The other segment is the received signal. The time is ;

[0092] Based on formula Receive segment signal With the signal of the transmitting segment Correlation detection was performed; among them, This indicates the correlation between any given point in time and the corresponding transmitted signal; Indicates the time period during which the signal was transmitted; Let represent a time infinitesimal element, which is a variable. This constitutes the time period for receiving the signal, i.e. This indicates the received segment signal.

[0093] S6, for Find the maximum point and use the threshold method to determine if there is a liquid surface echo in the echo signal. If there is, calculate the liquid surface echo time; if not, reduce the emission frequency of the detection sound wave and increase the emission loudness, then return to S2. The maximum point is denoted as the liquid surface echo point. The time of this point is recorded as follows: The liquid surface echo time is ;

[0094] S7, obtain the speed of sound of the coupling echo. The position of the liquid surface is obtained by combining the sound velocity of the coupling echo and the liquid surface echo time. The method for obtaining the velocity of the coupling echo is as follows: determine whether the number of coupling waves in the received echo signal is less than 2; if not, then... To measure the annular sound velocity, the fixed spacing between the two couplings on the drill pipe is utilized. Time difference with the corresponding two coupling waves Perform calculations, that is If so, then The speed of sound at ground level is calculated using surface temperature. ,in This refers to the Earth's surface temperature. Based on the formula... Obtain the liquid level position; where, This refers to the speed of sound in the annular space or the speed of sound on the ground. Current liquid level.

[0095] S8 determines the overflow status based on the liquid level and logging conditions, and implements the platform output and judgment cycle based on the judgment result.

[0096] Example 4

[0097] This embodiment discloses a method for continuous monitoring of leakage during tripping and running of heavy slurry caps in pressure-controlled drilling. As a preferred embodiment of the present invention, it includes the following steps:

[0098] S1, During controlled pressure drilling, the host computer modulates the frequency and loudness of the detection sound wave accordingly, and sets the emission time of the detection sound wave to be... ;

[0099] S2, determine whether the loudness of the detected sound wave frequency is within the range; if not, output over-range; if yes, proceed to S3;

[0100] S3 controls the electromagnetic acoustic wave transmitter to emit detection acoustic waves;

[0101] S4, the sound wave is transmitted downward along the drill pipe in the annulus, and returns when it encounters the coupling and the liquid surface, forming an echo signal;

[0102] S5 acquires, filters, and calculates short-time energy of the echo signal to obtain the processed effective echo, including the coupling echo.

[0103] S6. Determine whether there is a liquid surface echo in the echo signal based on the valid echo. If there is, calculate the liquid surface echo time. If not, reduce the transmission frequency of the detection sound wave and increase the transmission loudness, then return to S2.

[0104] S7, obtain the sound velocity of the coupling echo, and combine the sound velocity of the coupling echo with the liquid surface echo time to obtain the liquid surface position. ;

[0105] S8, determine and output the overflow status based on the fluid level and logging conditions. The determination of the overflow status, based on the condition that the drill bit position remains unchanged during the current time period, includes the following steps:

[0106] S81-1, Calculation Theoretical changes in annular fluid level caused by grouting over a time period: ;in, The amount of mud injected. The inner diameter of the annulus. The outer diameter of the drill pipe. This represents the theoretical distance of change in annular liquid level caused by grouting; Indicates any current time period;

[0107] S81-2, based on S1~S7 The liquid level positions before and after will The difference between the liquid level positions before and after is the actual distance of change in the annular liquid level. ;

[0108] S81-3, the theoretical annular liquid level change distance Distance from actual annular liquid level change As a basis for judging the leakage status; if If it is, then it is judged as an overflow; if If it is, then it is judged as a loss; if If the leakage condition is determined to be normal, then the normal state is output, and the current frequency and loudness of the detected sound wave are maintained, returning to S3. If the leakage condition is determined to be overflow, gas intrusion, or leakage, the corresponding overflow, gas intrusion, or leakage state is output, and the frequency and loudness are determined by measuring the liquid level to see if they are still within the recommended range; if they are within the recommended range, the current frequency and loudness of the detected sound wave are maintained, returning to S3; if they exceed the recommended range, the loudness of the current detected sound wave is reduced and the frequency is increased, returning to S2.

[0109] Example 5

[0110] This embodiment discloses a method for continuous monitoring of leakage during tripping and running of heavy slurry caps in pressure-controlled drilling. As a preferred embodiment of the present invention, it includes the following steps:

[0111] S1, During controlled pressure drilling, the host computer modulates the frequency and loudness of the detection sound wave accordingly, and sets the emission time of the detection sound wave to be... ;

[0112] S2, determine whether the loudness of the detected sound wave frequency is within the range; if not, output over-range; if yes, proceed to S3;

[0113] S3 controls the electromagnetic acoustic wave transmitter to emit detection acoustic waves;

[0114] S4, the sound wave is transmitted downward along the drill pipe in the annulus, and returns when it encounters the coupling and the liquid surface, forming an echo signal;

[0115] S5 acquires, filters, and calculates short-time energy of the echo signal to obtain the processed effective echo, including the coupling echo.

[0116] S6. Determine whether there is a liquid surface echo in the echo signal based on the valid echo. If there is, calculate the liquid surface echo time. If not, reduce the transmission frequency of the detection sound wave and increase the transmission loudness, then return to S2.

[0117] S7, obtain the sound velocity of the coupling echo, and combine the sound velocity of the coupling echo with the liquid surface echo time to obtain the liquid surface position. ;

[0118] S8, based on the fluid level and logging conditions, determines and outputs the leakage status. Specifically, for situations where drilling operations occur during the current period, determining the leakage status includes the following steps:

[0119] S81-1, Calculation Theoretical changes in annular fluid level caused by grouting over a time period: ;in, The amount of mud injected. The inner diameter of the annulus. The outer diameter of the drill pipe. This represents the theoretical distance of change in the annular liquid level; Indicates any current time period;

[0120] S81-2, based on S1~S7 The liquid level positions before and after will The difference between the liquid level positions before and after is the actual distance of change in the annular liquid level. ;

[0121] S81-3, Calculation The theoretical annular fluid level change distance caused by drill string movement within a time period: ;in: The length of the drill string to be pulled out. This represents the theoretical distance of change in the annular liquid level.

[0122] S81-4, the theoretical annular liquid level change distance Distance from theoretical annular liquid level change The absolute value of the difference, and the actual distance of change in the annular liquid level. As a basis for judging the leakage status; if If so, it is judged as an overflow or air intrusion; if If it is, then it is judged as a loss; if If the leakage condition is determined to be normal, then the normal state is output, and the current frequency and loudness of the detected sound wave are maintained, returning to S3. If the leakage condition is determined to be overflow, gas intrusion, or leakage, the corresponding overflow, gas intrusion, or leakage state is output, and the frequency and loudness are determined by measuring the liquid level to see if they are still within the recommended range; if they are within the recommended range, the current frequency and loudness of the detected sound wave are maintained, returning to S3; if they exceed the recommended range, the loudness of the current detected sound wave is reduced and the frequency is increased, returning to S2.

[0123] Example 6

[0124] This embodiment discloses a method for continuous monitoring of leakage during tripping and running of heavy slurry caps in pressure-controlled drilling. As a preferred embodiment of the present invention, it includes the following steps:

[0125] S1, During controlled pressure drilling, the host computer modulates the frequency and loudness of the detection sound wave accordingly, and sets the emission time of the detection sound wave to be... ;

[0126] S2, determine whether the loudness of the detected sound wave frequency is within the range; if not, output over-range; if yes, proceed to S3;

[0127] S3 controls the electromagnetic acoustic wave transmitter to emit detection acoustic waves;

[0128] S4, the sound wave is transmitted downward along the drill pipe in the annulus, and returns when it encounters the coupling and the liquid surface, forming an echo signal;

[0129] S5 acquires, filters, and calculates short-time energy of the echo signal to obtain the processed effective echo, including the coupling echo.

[0130] S6. Determine whether there is a liquid surface echo in the echo signal based on the valid echo. If there is, calculate the liquid surface echo time. If not, reduce the transmission frequency of the detection sound wave and increase the transmission loudness, then return to S2.

[0131] S7, obtain the sound velocity of the coupling echo, and combine the sound velocity of the coupling echo with the liquid surface echo time to obtain the liquid surface position. ;

[0132] S8, based on the fluid level and logging conditions, determines and outputs the leakage status. The leakage status determination, based on the current time period including drilling operations, includes the following steps:

[0133] S81-1, Calculation Theoretical changes in annular fluid level caused by grouting over a time period: ;in, The amount of mud injected. The inner diameter of the annulus. The outer diameter of the drill pipe. This represents the theoretical distance of change in the annular liquid level; Indicates any current time period;

[0134] S81-2, based on S1~S7 The liquid level positions before and after will The difference between the liquid level positions before and after is the actual distance of change in the annular liquid level. ;

[0135] S81-3, Calculation The theoretical annular fluid level change distance caused by drill string movement within a time period: ;in: The length of the drill string to be pulled out. This represents the theoretical distance of change in the annular liquid level.

[0136] S81-4, the theoretical annular liquid level change distance Distance from theoretical annular liquid level change The sum of these, and the actual distance of the annular liquid level change. As a basis for judging the leakage status; if If so, it is judged as an overflow or air intrusion; if If it is, then it is judged as a loss; if If the leakage condition is determined to be normal, then the normal state is output, and the current frequency and loudness of the detected sound wave are maintained, returning to S3. If the leakage condition is determined to be overflow, gas intrusion, or leakage, the corresponding overflow, gas intrusion, or leakage state is output, and the frequency and loudness are determined by measuring the liquid level to see if they are still within the recommended range; if they are within the recommended range, the current frequency and loudness of the detected sound wave are maintained, returning to S3; if they exceed the recommended range, the loudness of the current detected sound wave is reduced and the frequency is increased, returning to S2.

[0137] Example 7

[0138] This embodiment discloses a method for continuous monitoring of leakage during tripping and running of heavy slurry caps in pressure-controlled drilling. As a preferred embodiment of the present invention, it includes the following steps:

[0139] S1, During controlled pressure drilling, the host computer modulates the frequency and loudness of the detection sound wave accordingly, and sets the emission time of the detection sound wave to be... ;

[0140] S2, determine whether the loudness of the detected sound wave frequency is within the range; if not, output over-range; if yes, proceed to S3;

[0141] S3 controls the electromagnetic acoustic wave transmitter to emit detection acoustic waves;

[0142] S4, the sound wave is transmitted downward along the drill pipe in the annulus, and returns when it encounters the coupling and the liquid surface, forming an echo signal;

[0143] S5 involves acquiring, filtering, and calculating the short-time energy of the echo signal to obtain the processed effective echo, including the coupling echo. Specifically, this is done using an acoustic wave sensor to acquire the echo signal, including the following steps:

[0144] Based on the sampling frequency set by the host computer and sampling time ;

[0145] The host computer sends data acquisition commands to the data acquisition unit, and the moment the host computer sends the data acquisition command is defined as the starting point. ;

[0146] The data acquisition unit uses an acoustic sensor to sample at a frequency... Sampling is performed, and the sampled signal is .

[0147] Filtering the echo signal involves converting the sampled signal into... The filtered signal is obtained by using a bandpass filter. .

[0148] Short-time energy calculation includes the following steps:

[0149] The filtered signal It is divided into two segments; one segment is the transmission segment signal. The time is The other segment is the received signal. The time is ;

[0150] Based on formula Receive segment signal With the signal of the transmitting segment Correlation detection was performed; among them, This indicates the correlation between any given point in time and the corresponding transmitted signal; Indicates the time period during which the signal was transmitted; Let represent a time infinitesimal element, which is a variable. This constitutes the time period for receiving the signal, i.e. This indicates the received segment signal.

[0151] S6, for Find the maximum point and use the threshold method to determine if there is a liquid surface echo in the echo signal. If there is, calculate the liquid surface echo time; if not, reduce the emission frequency of the detection sound wave and increase the emission loudness, then return to S2. The maximum point is denoted as the liquid surface echo point. The time of this point is recorded as follows: The liquid surface echo time is ;

[0152] S7, obtain the speed of sound of the coupling echo. The position of the liquid surface is obtained by combining the sound velocity of the coupling echo and the liquid surface echo time. The method for obtaining the velocity of the coupling echo is as follows: determine whether the number of coupling waves in the received echo signal is less than 2; if not, then... To measure the annular sound velocity, the fixed spacing between the two couplings on the drill pipe is utilized. Time difference with the corresponding two coupling waves Perform calculations, that is If so, then The speed of sound at ground level is calculated using surface temperature. ,in This refers to the Earth's surface temperature. Based on the formula... Obtain the liquid level position; where, This refers to the speed of sound in the annular space or the speed of sound on the ground. Current liquid level.

[0153] S8, based on the fluid level and logging conditions, determines the leakage status, and implements platform output and judgment cycle based on the judgment result. The logging conditions include: Condition 1, the drill bit position remains unchanged during the current period; Condition 2, there is a tripping action during the current period; Condition 3, the current period includes a running-in action. Based on this, determining the leakage status includes the following steps:

[0154] S81-1, Calculation Theoretical changes in annular fluid level caused by grouting over a time period: ;in, The amount of mud injected. The inner diameter of the annulus. The outer diameter of the drill pipe. This represents the theoretical distance of change in the annular liquid level; Indicates any current time period;

[0155] S81-2, based on S1~S7 The liquid level positions before and after will The difference between the liquid level positions before and after is the actual distance of change in the annular liquid level. ;

[0156] S81-3, determine whether the logging condition is condition one; if yes, proceed to S81-31 and the current leakage status determination will terminate; if not, proceed to S81-4.

[0157] S81-31, the theoretical annular liquid level change distance Distance from actual annular liquid level change As a basis for judging the leakage status; if If it is, then it is judged as an overflow; if If it is, then it is judged as a loss; if If so, it is considered a normal situation;

[0158] S81-4, Calculation The theoretical annular fluid level change distance caused by drill string movement within a time period: ;in: The length of the drill string to be pulled out. This represents the theoretical distance of change in the annular liquid level.

[0159] S81-5, determine whether the logging operation is operation condition two or operation condition three; if it is operation condition two, then after entering and implementing S81-51, the current overflow status judgment will be terminated; if it is operation condition three, then after entering and implementing S81-52, the current overflow status judgment will be terminated.

[0160] S81-51, the theoretical annular liquid level change distance Distance from theoretical annular liquid level change The absolute value of the difference, and the actual distance of change in the annular liquid level. As a basis for judging the leakage status; if If so, it is judged as an overflow or air intrusion; if If it is, then it is judged as a loss; if If so, it is considered a normal situation;

[0161] S81-52, the theoretical annular liquid level change distance Distance from theoretical annular liquid level change The sum of these, and the actual distance of the annular liquid level change. As a basis for judging the leakage status; if If so, it is judged as an overflow or air intrusion; if If it is, then it is judged as a loss; if If so, it is considered a normal situation.

[0162] Furthermore, during the aforementioned leakage status judgment process, if the leakage status is judged to be normal, the normal status is output, and the current frequency and loudness of the detected sound wave are maintained, returning to S3; if the leakage status is judged to be overflow, gas intrusion, or leakage, the corresponding overflow, gas intrusion, or leakage status is output, and the frequency and loudness are judged by measuring the liquid level position to determine whether they are still within the recommended range; if they are within the recommended range (this recommended range is obtained experimentally, and different recommended values ​​exist for different well structures, see details...), Figure 4 If the frequency and loudness of the current sound wave are within the recommended range, then return to S3; if the frequency and loudness are exceeded, then reduce the loudness and increase the frequency of the current sound wave, and return to S2.

[0163] In this technical solution, the amount of mud injected... , annulus inner diameter Drill pipe outer diameter Length of drill string pulled out Parameters such as these can be obtained from well logging data. Therefore, well logging data can be imported into a host computer to obtain the corresponding data parameters.

[0164] Example 8

[0165] This embodiment, implemented according to any of the schemes in Embodiments 1-7, provides a continuous monitoring system for leakage during tripping and running of pressure-controlled drilling heavy slurry caps. Compared to traditional explosive sound sources, this continuous monitoring system uses an electromagnetic acoustic wave transmitter as the sound source. It can continuously emit detection sound waves with adjustable frequency and loudness by adjusting the current frequency and magnitude. Based on the principle that low-frequency sound waves attenuate slowly and high-frequency sound waves attenuate quickly in the annulus, a high-frequency, low-noise method is used for shallow liquid surfaces to reduce multiple echo interference, while a low-frequency, high-noise method is used for deep liquid surfaces to increase the detection distance. In summary, this technical solution utilizes the echo method to monitor leakage status, solving a series of problems inherent in the traditional echo method using high-pressure air guns as sound sources, such as poor continuity, severe infrasound interference, large measurement errors, and poor monitoring performance at low liquid levels. Specifically, as a preferred embodiment of this invention, it includes a host computer, a preamplifier, a postamplifier, an electromagnetic acoustic wave transmitter, an acoustic wave sensor, a temperature sensor, and a data acquisition unit.

[0166] The host computer is used to modulate the sound waves, analyze the echoes, calculate the liquid level depth, and determine the leakage status by combining the liquid level depth and logging data.

[0167] The preamplifier is connected to the host computer to amplify the voltage of the modulated audio signal output by the host computer, further improving the signal-to-noise ratio of the continuous monitoring system, reducing external interference, and achieving impedance conversion and matching.

[0168] The post-amplifier connects to the pre-amplifier and amplifies the current that outputs the audio signal from the pre-amplifier to ensure the electromagnetic sound wave transmitter functions properly.

[0169] The electromagnetic sound wave transmitter is connected to a power amplifier to output the audio signal from the power amplifier. The loudness of the sound wave emitted by the electromagnetic sound wave transmitter is adjustable, specifically by modulation using a host computer. Its frequency range is 20~1500Hz, and its loudness range is 70~130dB.

[0170] The acoustic wave sensor is connected to the data acquisition unit to collect the emitted and echo signals within the annulus. Specifically, the acoustic wave sensor and the electromagnetic acoustic wave transmitter are located in the same channel (this channel can be formed by the grouting pipeline and the annulus, or by the kill manifold and the annulus). There can be one or more acoustic wave sensors with different sensitivities. A single acoustic wave transmitter is sensitive to acoustic wave signals within a specific frequency range (the detection frequency range of this technical solution is 20~1500Hz, and the monitoring frequency range of a single acoustic wave transmitter may be 20~300Hz; the sensitivity decreases beyond this range. Multiple acoustic wave sensors with different sensitivities are used to obtain the best monitoring effect).

[0171] The temperature sensor is connected to a data acquisition unit and is used to collect the temperature (i.e., surface temperature) within the channel where the acoustic sensor is located. This temperature is used for sound speed calculation. Furthermore, the temperature sensor is located in the same channel as the sound wave sensor and the electromagnetic sound wave transmitter.

[0172] The data acquisition unit is electrically connected to the host computer and is used to receive and execute data acquisition commands issued by the host computer, and to collect corresponding data signals in conjunction with temperature sensors and sound wave sensors and transmit them back to the host computer.

[0173] Furthermore, it also includes a filter, which is connected between the data acquisition unit and the host computer to filter the signal uploaded by the data acquisition unit to the host computer. This filter can filter out signals outside the frequency range emitted by the electromagnetic sound wave transmitter, thereby reducing noise signals and improving the signal-to-noise ratio.

[0174] Furthermore, it also includes a solenoid valve, which is connected to a host computer via a data acquisition unit. This solenoid valve is used to open or close the channel connecting the electromagnetic acoustic transmitter to the annulus. During grouting, slurry may enter the channel containing the electromagnetic acoustic transmitter, causing damage to the equipment. Therefore, closing the solenoid valve can prevent slurry from entering. After grouting is complete, the solenoid valve is opened to perform corresponding monitoring. Specifically, the solenoid valve is controlled by the host computer and can automatically open or close according to the monitoring needs. It has a certain pressure resistance capacity.

[0175] Example 9

[0176] This embodiment provides a specific case: A modulated sound wave is emitted using an electromagnetic acoustic transmitter. A suitable frequency is selected based on the well structure, and the frequency and loudness are adaptively adjusted. The echo signal is then acquired and processed (e.g., ...). Figure 3 (As shown), calculate the time difference between the transmitted signal and the liquid surface echo. Utilizing the time difference between coupling echoes Calculate the annular sound velocity at the fixed distance between the coupling and the coupling. The distance between the liquid surfaces is... .

Claims

1. A method for continuous monitoring of leakage during tripping and running of heavy slurry caps in pressure-controlled drilling, characterized in that, Includes the following steps: S1, During controlled pressure drilling, the host computer modulates the frequency and loudness of the detection sound wave accordingly, and sets the emission time of the detection sound wave to be... ; S2, determine whether the loudness of the detected sound wave frequency is within the range; if not, output over-range; if yes, proceed to S3; S3 controls the electromagnetic acoustic wave transmitter to emit detection acoustic waves; S4, the sound wave is transmitted downward along the drill pipe in the annulus, and returns when it encounters the coupling and the liquid surface, forming an echo signal; S5 acquires, filters, and calculates short-time energy of the echo signal to obtain the processed effective echo, including the coupling echo. S6. Determine whether there is a liquid surface echo in the echo signal based on the valid echo. If there is, calculate the liquid surface echo time. If not, reduce the transmission frequency of the detection sound wave and increase the transmission loudness, then return to S2. S7, obtain the sound velocity of the coupling echo, and combine the sound velocity of the coupling echo with the liquid surface echo time to obtain the liquid surface position. ; S8, determine the leakage status based on the fluid level and logging conditions, and implement the platform output and judgment cycle based on the judgment result; the logging conditions include: Condition 1, the drill bit position remains unchanged in the current period; Condition 2, there is a tripping action in the current period; Condition 3, the current period includes a running-in action; based on this, the leakage status determination includes the following steps: S81-1, Calculation Theoretical changes in annular fluid level caused by grouting over a time period: ;in, The amount of mud injected. The inner diameter of the annulus. The outer diameter of the drill pipe. This represents the theoretical distance of change in annular liquid level caused by grouting; Indicates any current time period; S81-2, based on S1~S7 The liquid level positions before and after will The difference between the liquid level positions before and after is the actual distance of change in the annular liquid level. ; S81-3, determine whether the logging condition is condition one; if yes, proceed to S81-31 and the current leakage status determination will terminate; if not, proceed to S81-4. S81-31, the theoretical annular liquid level change distance Distance from actual annular liquid level change As a basis for judging the leakage status; if If it is, then it is judged as an overflow; if If it is, then it is judged as a loss; if If so, it is considered a normal situation; S81-4, Calculation The theoretical annular fluid level change distance caused by drill string movement within a time period: ;in: The length of the drill string to be pulled out. This represents the theoretical annular fluid level change distance caused by the drill string motion. S81-5, determine whether the logging operation is operation condition two or operation condition three; if it is operation condition two, then after entering and implementing S81-51, the current overflow status judgment will be terminated; if it is operation condition three, then after entering and implementing S81-52, the current overflow status judgment will be terminated. S81-51, the theoretical annular liquid level change distance caused by grouting. Distance from the theoretical annular fluid level change caused by drill string movement The absolute value of the difference, and the actual distance of change in the annular liquid level. As a basis for judging the leakage status; if If so, it is judged as an overflow or air intrusion; if If it is, then it is judged as a loss; if If so, it is considered a normal situation; S81-52, the theoretical annular liquid level change distance Distance from theoretical annular liquid level change The sum of these, and the actual distance of the annular liquid level change. As a basis for judging the leakage status; if If so, it is judged as an overflow or air intrusion; if If it is, then it is judged as a loss; if If so, it is considered a normal situation.

2. The method for continuous monitoring of leakage during tripping and running of pressure-controlled drilling heavy slurry caps as described in claim 1, characterized in that: In step S5, the echo signal is acquired using an acoustic wave sensor, including the following steps: Based on the sampling frequency set by the host computer and sampling time ; The host computer sends data acquisition commands to the data acquisition unit, and the moment when the host computer sends the data acquisition commands is defined as the starting point. ; The data acquisition unit uses an acoustic sensor to sample at a frequency... Sampling is performed, and the sampled signal is .

3. The method for continuous monitoring of leakage during tripping and running of pressure-controlled drilling heavy slurry caps as described in claim 2, characterized in that: In step S5, filtering the echo signal involves converting the sampled signal into... The filtered signal is obtained by using a bandpass filter. .

4. The method for continuous monitoring of leakage during tripping and running of pressure-controlled drilling heavy slurry caps as described in claim 3, characterized in that: In step S5, the short-time energy calculation includes the following steps: The filtered signal It is divided into two segments; one segment is the transmission segment signal. The time is The other segment is the received signal. The time is ; Based on formula Receive segment signal With the signal of the transmitting segment Correlation detection was performed; among them, This indicates the correlation between any given point in time and the corresponding transmitted signal; Indicates the time period during which the signal was transmitted; Let represent a time infinitesimal element, which is a variable. This constitutes the time period for receiving the signal, i.e. This indicates the received segment signal.

5. The method for continuous monitoring of leakage during tripping and running of pressure-controlled drilling heavy slurry caps as described in claim 4, characterized in that: In S6, it is through... Find the maximum point and use the threshold method to determine whether there is a liquid surface echo in the echo signal; the maximum point is denoted as the liquid surface echo point. The time of this point is recorded as follows: The liquid surface echo time is .

6. The method for continuous monitoring of leakage during tripping and running of pressure-controlled drilling heavy slurry caps as described in claim 5, characterized in that: In S7, it is based on the formula Obtain the liquid level position; where, This refers to the speed of sound in the annular space or the speed of sound on the ground. This indicates the current liquid level.

7. The method for continuous monitoring of leakage during tripping and running of pressure-controlled drilling heavy slurry caps as described in claim 6, characterized in that: In step S7, the method for obtaining the coupling echo velocity is as follows: determine whether the number of coupling waves in the received echo signal is less than 2; if not, then To measure the annular sound velocity, the fixed spacing between the two couplings on the drill pipe is utilized. Time difference with the corresponding two coupling waves Perform calculations, that is If so, then The speed of sound at ground level is calculated using surface temperature. ,in This refers to the Earth's surface temperature.

8. The method for continuous monitoring of leakage during tripping and running of pressure-controlled drilling heavy slurry caps as described in claim 1, characterized in that: In step S8, the implementation of the assembly output and judgment loop includes: If the overflow status is judged to be normal, output the normal status, maintain the frequency and loudness of the current detected sound wave, and return to S3; If the leakage status is determined to be overflow, gas intrusion, or leakage, the corresponding overflow, gas intrusion, or leakage status will be output, and the frequency and loudness will be determined by measuring the liquid level position to see if they are still within the recommended range. If they are within the recommended range, the frequency and loudness of the current sound wave will be maintained, and the system will return to S3. If they exceed the recommended range, the loudness of the current sound wave will be reduced and the frequency will be increased, and the system will return to S2.

9. A continuous monitoring system for leakage during tripping and running of pressure-controlled drilling heavy slurry caps, characterized in that, The system is used to implement the continuous monitoring method for leakage during tripping and tripping of the pressure-controlled drilling heavy slurry cap as described in any one of claims 1-8; the system includes a host computer, a preamplifier, a postamplifier, an electromagnetic acoustic transmitter, an acoustic sensor, a temperature sensor, a data acquisition unit, and a filter. The host computer is used to modulate the sound waves, analyze the echoes, calculate the liquid level depth, and determine the leakage status by combining the liquid level depth and logging data. The preamplifier is connected to the host computer and is used to amplify the voltage of the modulated audio signal output by the host computer. The rear power amplifier is connected to the preamplifier and is used to amplify the current of the audio signal output by the preamplifier. The electromagnetic acoustic wave transmitter is connected to a post-amplifier and is used to emit the audio signal output by the post-amplifier. The acoustic sensor is connected to the data acquisition unit and is used to collect the emitted acoustic waves and echo signals in the ring space. The temperature sensor is connected to the data acquisition unit and is used to collect the temperature in the channel where the acoustic sensor is located. The data acquisition unit is electrically connected to the host computer and is used to receive and execute data acquisition commands issued by the host computer. The filter is connected between the data acquisition unit and the host computer and is used to filter the signals uploaded by the data acquisition unit to the host computer.

10. The continuous monitoring system for leakage during tripping and running of pressure-controlled drilling heavy slurry caps as described in claim 9, characterized in that: It also includes a solenoid valve, which is connected to a host computer via a data acquisition unit and is used to open or close the channel connecting the electromagnetic acoustic wave transmitter to the annulus.

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