A device and method for quantitatively monitoring well kick and loss

Abstract

The present application provides a kind of well gushing well leakage quantitative monitoring device, it includes: rectifier, for the drilling fluid flowing out of the horn mouth is rectified, to reduce flow state distortion;Degasser is connected with rectifier, for the drilling fluid flowing out of rectifier is degassed;Gas remover is connected with degasser, for the drilling fluid flowing out of degasser is gas removal treatment, to reduce the influence of gas on measurement accuracy;The outlet of gas remover exists three pipelines, the first pipeline is straight-through pipe, the second pipeline is anti-overflow pipe, the third pipeline passes through flowmeter, the drilling fluid in three pipelines is together into observation tank, wherein, flowmeter is used for the volume flow of drilling fluid is quantitatively monitored.The present application solves the problems such as flowmeter precision reduction or even non-working caused by more drilling fluid bubbles due to pipeline modification without affecting the on-site drilling and logging operation.

Description

Technical Field

[0001] This invention relates to the field of drilling engineering technology, and more specifically, to a device and method for quantitative monitoring of well kick and well leakage. Background Technology

[0002] Well kicks and lost circulation are frequent engineering accidents in drilling operations, causing huge property losses and even casualties in the oil drilling industry. Therefore, well kick and lost circulation monitoring is particularly important for drilling safety.

[0003] Monitoring drilling fluid pool volume and drilling fluid outlet flow rate is a crucial method for detecting well kicks and well losses at drilling sites. Drilling fluid pool volume monitoring primarily utilizes volumetric sensors or ultrasonic level sensors, while target flow meters are commonly used for measuring drilling fluid outlet flow rate. However, in practice, none of these methods can achieve quantitative flow rate detection, resulting in inaccurate measurement results and hindering the timely detection of abnormal events such as well kicks and well losses.

[0004] Currently, quantitative monitoring of drilling fluid outlet flow anomalies for well kick and well leakage detection has become a research focus for various petroleum research institutions. Quantitative monitoring equipment mainly includes mass flow meters and electromagnetic flow meters. However, due to the limitations of the working principles of mass flow meters and electromagnetic flow meters, it is necessary to ensure the measuring tube is full and avoid working conditions involving two or more phases of media. Based on the actual drilling operations, the following are the main challenges:

[0005] (1) In order to achieve full pipe measurement, the original pipeline needs to be modified. After the modification, the flow state is changed. When the flow meter is used, bubbles accumulate, the flow meter accuracy is low or even cannot work properly.

[0006] (2) The outlet pipeline is open pressure flow. Due to the redesign of the pipeline, the pipeline resistance has increased. In particular, when the gas content in the outlet drilling fluid increases, the drilling fluid cannot flow out in time and overflows from the bell mouth, causing problems in safety and environmental protection.

[0007] To address the problems of existing technologies, this invention provides a device and method for quantitative monitoring of well kicks and well leakage. Summary of the Invention

[0008] To address the problems in the prior art, the present invention provides a quantitative monitoring device for well kick and well leakage, the device being placed on the outlet pipeline and comprising:

[0009] A rectifier is used to rectify the drilling fluid flowing out of the funnel to reduce flow distortion.

[0010] A degasser, located after the rectifier, is used to degas the drilling fluid flowing out of the rectifier;

[0011] A degasser, located after the degasser, is used to degas the drilling fluid flowing out of the degasser in order to reduce the impact of gas on measurement accuracy.

[0012] The degasser has three outlets: the first is a straight pipe, the second is an overflow prevention pipe, and the third passes through a flow meter. The drilling fluid in the three pipes flows together into the observation tank. The flow meter is used to quantitatively monitor the volumetric flow rate of the drilling fluid.

[0013] According to one embodiment of the present invention, the rectifier is a tube bundle structure, a perforated plate structure, or a combination of a tube bundle structure and a perforated plate structure.

[0014] According to one embodiment of the present invention, the degasser uses the degassing device of the original logging gas detection system, and is installed in the outlet direction of the rectifier to ensure a stable degassing liquid level.

[0015] According to one embodiment of the present invention, the rectifier, the degasser, and the degasser are placed in a square groove, which should be placed as close as possible to the flared end to reduce the change in the flow state of the drilling fluid.

[0016] According to one embodiment of the present invention, when the pipeline where the flow meter is located is blocked or the flow capacity is insufficient, the drilling fluid can flow through the overflow prevention pipe to prevent the drilling fluid from overflowing from the flared end. The highest point of the overflow prevention pipe is lower than the height of the baffle of the first square channel and the outlet height of the flared end to prevent the drilling fluid from overflowing from the first square channel.

[0017] According to one embodiment of the present invention, the observation groove is located inside the square groove two, which is used for pressure release, so that the air bubbles in the drilling fluid are released, which is beneficial to the normal operation of the flow meter.

[0018] According to one embodiment of the present invention, the device includes a buffer tank connected to the outlet of the observation slot.

[0019] According to another aspect of the present invention, a method for quantitative monitoring of well kicks and well leakage is also provided, performed by the apparatus described in any of the preceding claims, the method comprising the following steps:

[0020] After each change in drilling fluid properties and before drilling begins, an instantaneous standard flow rate test is performed to obtain the instantaneous standard volumetric flow rate.

[0021] Determine the current working state, which includes drilling state, single-joint connection state, tripping state, and drilling down state.

[0022] Under the current operating conditions, the volumetric flow rate data of the flow meter is read, and combined with the instantaneous standard volumetric flow rate, quantitative monitoring of well inrush and well leakage is performed.

[0023] According to an embodiment of the present invention, in the drilling state, the method includes the following steps:

[0024] The instantaneous standard volumetric flow rate and the measured instantaneous volumetric flow rate of the flow meter are read, and the instantaneous volumetric flow rate difference is calculated.

[0025] The cumulative time from the start of drilling to the current time is determined, and the cumulative volumetric flow rate difference in the drilling state is calculated by combining the instantaneous volumetric flow rate difference.

[0026] The cumulative volumetric flow rate difference in the drilling state is compared with a first set threshold to determine whether a well kick or well leakage has occurred.

[0027] According to an embodiment of the present invention, when lifting the drill string in the single-joint state, the method includes the following steps:

[0028] Determine the type and length of the current lifting drill string, and calculate the theoretical internal volume of the drill string.

[0029] The cumulative pump stroke count at the start of the lifting and the cumulative pump stroke count at the end of the lifting are read, and the cumulative volumetric flow rate of the lifting drill string is calculated by combining the instantaneous standard volumetric flow rate.

[0030] Read the cumulative volumetric flow rate of the flow meter at the start of the lifting process and the cumulative volumetric flow rate of the flow meter at the end of the lifting process, and calculate the actual cumulative flow rate of the flow meter during the lifting process of the drill bit;

[0031] Based on the cumulative volumetric flow rate of the drill string being lifted and the actual cumulative flow rate of the flow meter during the drill string lifting process, the actual change in the cumulative flow rate of the drill string being lifted due to the lifting of the drill string is calculated.

[0032] Based on the actual change in the cumulative flow of the drill string and the theoretical internal volume of the drill string, the difference in the cumulative volume flow of the drill string caused by the drill string being lifted is calculated.

[0033] The cumulative volumetric flow rate difference of the lifting drill string is compared with a second set threshold to determine whether a well kick or well leakage has occurred.

[0034] According to an embodiment of the present invention, when placing the drill string in the single-joint state, the method includes the following steps:

[0035] Determine the type and length of the drill string to be lowered, and calculate the theoretical external volume of the drill string.

[0036] The cumulative pump stroke count at the start of the descent and the cumulative pump stroke count at the end of the descent are read, and the cumulative volumetric flow rate of the drill bit is calculated by combining the instantaneous standard volumetric flow rate.

[0037] The cumulative volumetric flow rate of the flow meter at the start of the lowering process and the cumulative volumetric flow rate of the flow meter at the end of the lowering process are read, and the actual cumulative flow rate of the flow meter during the lowering process is calculated.

[0038] Based on the cumulative volumetric flow rate of the drill string and the actual cumulative flow rate of the flow meter during the drill string lowering process, the actual change in the cumulative flow rate of the drill string caused by the lowering of the drill string is calculated.

[0039] Based on the actual change in the cumulative flow of the drill string and the theoretical external volume of the drill string, the difference in the cumulative volumetric flow of the drill string caused by the lowering of the drill string is calculated.

[0040] The cumulative volumetric flow rate difference of the lowered drill string is compared with a third set threshold to determine whether a well kick or well leakage has occurred.

[0041] According to one embodiment of the present invention, in the tripping state, the method includes the following steps:

[0042] Read the volumetric flow rate of the constant flow pump per unit time;

[0043] Determine the length, inner diameter, and outer diameter of the drill string for this drilling operation, and calculate the theoretical drilling volume.

[0044] The cumulative volumetric flow rate of the flow meter when the drill string is started to be pulled up and the cumulative volumetric flow rate of the flow meter when the drill string is pulled up are read. Combined with the volumetric flow rate of the constant flow pump per unit time, the actual cumulative flow rate of the flow meter during the drill string pulling-out process is calculated.

[0045] Based on the actual cumulative flow of the flow meter during the drill string tripping process and the theoretical tripping volume, the cumulative volume flow rate difference of the drill string tripping is calculated.

[0046] The cumulative volumetric flow rate difference of the drill string is compared with a fourth preset threshold to determine whether a well kick or well leakage has occurred.

[0047] According to an embodiment of the present invention, in the drilling state, the method includes the following steps:

[0048] Determine the length, inner diameter, and outer diameter of the drill string for this drilling operation, and calculate the theoretical drilling volume.

[0049] Read the cumulative volumetric flow rate of the flow meter when the drilling tool is lowered and the cumulative volumetric flow rate of the flow meter when the drilling tool is lowered is finished, and calculate the actual cumulative flow rate of the flow meter during the drilling tool lowering process;

[0050] Based on the actual cumulative flow of the flow meter during the drilling process and the theoretical drilling volume, the cumulative volume flow difference of the drilling tool is calculated.

[0051] The cumulative volumetric flow rate difference of the lowered drill string is compared with the fifth preset threshold to determine whether a well kick or well leakage has occurred.

[0052] According to another aspect of the invention, a storage medium is also provided, which includes a series of instructions for performing the steps of the method described in any of the preceding claims.

[0053] This invention provides a device and method for quantitative monitoring of well kicks and leaks. Without affecting on-site drilling and logging operations, it solves problems such as reduced flow meter accuracy or even malfunction caused by excessive drilling fluid bubbles due to pipeline modifications, thus improving the flow meter's applicability and measurement accuracy in the field. For different operating conditions, well kick and leak monitoring methods are provided, enabling quantitative monitoring of well kicks and leaks under various complex conditions. This invention lays the foundation for quantitative monitoring of well kicks and leaks in drilling fluid outlet flow rates, effectively improving well control safety levels in drilling operations.

[0054] Other features and advantages of the invention will be set forth in the description which follows, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures particularly pointed out in the description, claims, and drawings. Attached Figure Description

[0055] The accompanying drawings are provided to further illustrate the invention and form part of the specification. They are used in conjunction with the embodiments of the invention to explain the invention and do not constitute a limitation thereof. In the drawings:

[0056] Figure 1 A schematic diagram of a well inrush and well leakage quantitative monitoring device according to an embodiment of the present invention is shown;

[0057] Figure 2 This diagram illustrates the drilling fluid flow direction of a well kick and leakage quantitative monitoring device according to an embodiment of the present invention.

[0058] Figure 3 A flowchart of a method for quantitative monitoring of well kick and well leakage according to an embodiment of the present invention is shown;

[0059] Figure 4 A flowchart of a drilling state well kick and well leakage determination method according to an embodiment of the present invention is shown;

[0060] Figure 5 A flowchart of a method for determining well inrush and well leakage according to an embodiment of the present invention is shown;

[0061] Figure 6 A flowchart of a well kick and leakage determination method according to an embodiment of the present invention is shown.

[0062] In the accompanying drawings, the same parts use the same reference numerals. Also, the drawings are not drawn to scale.

[0063] The meanings of the reference numerals in the attached drawings are as follows: 1-Flame mouth, 2-Rectifier, 3-Deaerator, 4-Deaerator, 5-Flow meter, 6-Straight pipe, 7-Overflow prevention pipe, 8-Observation tank, 9-Buffer tank, 10-Square trough one, 11-Square trough two, 12-Valve one, 13-Valve two, 14-Valve three. Detailed Implementation

[0064] To make the objectives, technical solutions, and advantages of the present invention clearer, the embodiments of the present invention will be further described in detail below with reference to the accompanying drawings.

[0065] The prior art (CN204532177U) discloses a drilling fluid quantitative monitoring flow diversion device. However, it only realizes the monitoring of drilling fluid outlet flow rate, does not provide a quantitative monitoring method for well kick and well leakage, and requires modification of the original pipeline. After modification, the flow state is changed. When passing through the flow meter, bubbles accumulate, the flow meter accuracy is low or even cannot work properly.

[0066] The prior art (CN109751045A) discloses a method and device for monitoring overflow well leakage. However, it requires modification of the original pipeline. After modification, the flow pattern is changed. When passing through the flow meter, bubbles accumulate, resulting in low accuracy of the flow meter or even failure to work properly.

[0067] The prior art (CN114622899A) discloses an automatic grouting and leakage monitoring system and method. However, it judges whether there is leakage by the liquid level in the circulating tank, and does not provide a quantitative monitoring device and method for well kick and well leakage. As a result, the measurement results are not accurate enough and the occurrence of abnormal accidents such as well kick and well leakage cannot be detected in time.

[0068] The prior art (CN207261003U) discloses a drilling outlet flow measurement device. However, it uses an electromagnetic flow meter. In order to achieve full-pipe measurement, the original pipeline needs to be modified. After the modification, the flow state is changed. When passing through the flow meter, bubbles accumulate, resulting in low accuracy of the flow meter or even failure to work properly.

[0069] The prior art (CN211692412U) discloses a cementing return fluid monitoring device; however, it only provides a cementing return fluid monitoring scheme and does not provide a quantitative monitoring device and method for well kick and well leakage.

[0070] In view of the shortcomings of current quantitative monitoring devices for well kicks and well leakage, the purpose of this invention is to propose a new quantitative monitoring device and method for well kicks and well leakage, which can improve the applicability and accuracy of quantitative monitoring of well kicks and well leakage at drilling sites.

[0071] Figure 1 A schematic diagram of a well inrush and well leakage quantitative monitoring device according to an embodiment of the present invention is shown.

[0072] In one embodiment, a well kick and well leakage quantitative monitoring device is placed on the outlet pipeline and includes: a rectifier 2, a degasser 3, a degasser 4, a flow meter 5, a straight pipe 6, an overflow prevention pipe 7, and an observation slot 8.

[0073] like Figure 1 As shown, the rectifier 2 is used to rectify the drilling fluid flowing out of the bell mouth 1 to reduce flow distortion. In one embodiment, the rectifier 2 is a tube bundle structure, a perforated plate structure, or a combination of a tube bundle structure and a perforated plate structure, which can reduce the impact of drilling fluid flow distortion on measurement accuracy to meet the requirements of flow measurement accuracy.

[0074] like Figure 1 As shown, the degasser 3 is connected to the rectifier 2 and located after the rectifier 2, used to degas the drilling fluid flowing out of the rectifier 2. In one embodiment, the degasser 3 uses the existing degassing device of the logging gas system, eliminating the need for new degassing equipment and simplifying the modification. Furthermore, to ensure a stable degassing fluid level, it is installed in the outlet direction of the rectifier 2, i.e., after the rectifier 2. Alternatively, since the existing degassing device of the logging gas system is placed in the buffer tank 9, to ensure that the degassed drilling fluid is the original drilling fluid, the present invention installs the degasser 3 in the inlet direction of the degasser 4, i.e., before the degasser 4.

[0075] like Figure 1 As shown, the degasser 4 is connected to the degasser 3 and is located after the degasser 3. It is used to degas the drilling fluid flowing out of the degasser 3 to reduce the impact of gas on the measurement accuracy of the flow meter 5. In one embodiment, the degasser 4 uses a vacuum degasser. The vacuum degasser uses the suction action of a vacuum pump to create a negative pressure zone in the vacuum tank. Under atmospheric pressure, the drilling fluid enters the hollow shaft of the rotor through the suction pipe, and then is sprayed onto the tank wall through the windows around the hollow shaft. Due to the collision and the action of the separator wheel, the drilling fluid is separated into a thin layer, the air bubbles immersed in the drilling fluid are broken, and the gas escapes. Through the suction of the vacuum pump and the separation of the gas-water separator, the gas is discharged to a safe area through the exhaust pipe of the separator, while the drilling fluid is discharged out of the tank by the impeller. Since the main motor starts first, the impeller connected to the motor is rotating at high speed, so the drilling fluid can only enter the tank through the suction pipe and will not be sucked in through the discharge pipe.

[0076] like Figure 1As shown, there are three pipelines at the outlet of the degasser 4. The first pipeline is a straight pipe 6, the second pipeline is an overflow prevention pipe 7, and the third pipeline passes through a flow meter 5. The drilling fluid in the three pipelines flows into the observation tank 8 together. The flow meter 5 is used to quantitatively monitor the volumetric flow rate of the drilling fluid.

[0077] In one embodiment, such as Figure 1 As shown, the rectifier 2, degasser 3 and degasser 4 are placed in the square groove 10. The square groove 10 should be placed as close as possible to the bell mouth to reduce the change process of drilling fluid flow.

[0078] In one embodiment, such as Figure 1 As shown, in the pipeline modification, an overflow preventer 7 is installed. This allows drilling fluid to flow through the overflow preventer 7 when the pipeline containing the flow meter 5 is blocked or has insufficient flow capacity, preventing the drilling fluid from overflowing from the bell mouth 1. The highest point of the overflow preventer 7 is lower than the height of the baffle of the square groove 10 and the outlet height of the bell mouth to prevent drilling fluid from overflowing from the square groove 10. In one embodiment, the highest point of the overflow preventer 7 should not be too high, and should be lower than 80% of the height of the baffle of the square groove 10 to prevent drilling fluid from overflowing from the square groove 10.

[0079] In one embodiment, such as Figure 1 As shown, the observation groove 8 is located inside the square groove 11. The square groove 11 is used for pressure release, which allows air bubbles in the drilling fluid to be released, which is beneficial for the normal operation of the flow meter 5.

[0080] In one embodiment, such as Figure 1 As shown, a well inrush and well leakage quantitative monitoring device includes a buffer tank 9 connected to the outlet of the observation tank 8.

[0081] In one embodiment, such as Figure 1 As shown, a well kick and well leakage quantitative monitoring device also includes valve one 12, valve two 13, and valve three 14. Specifically, valve one 12 is installed in the pipe section where the DC pipe 6 is located and is used to control the on / off state of the DC pipe 6. Valve two 13 is installed in the inlet direction of the flow meter 5, and valve three 14 is installed in the outlet direction of the flow meter 5. Valve two 13 and valve three 14 are used to control the on / off state of the flow meter 5.

[0082] Figure 2 A schematic diagram of drilling fluid flow is shown in a well kick and leakage quantitative monitoring device according to an embodiment of the present invention.

[0083] like Figure 2 As shown, a well kick and well leakage quantitative monitoring device includes a bell mouth 1, a rectifier 2, a degasser 3, a degasser 4, a flow meter 5, a straight pipe 6, an overflow prevention pipe 7, an observation tank 8, a buffer tank 9, a square groove one 10, a square groove two 11, a valve one 12, a valve two 13, and a valve three 14.

[0084] like Figure 2 As shown, the drilling fluid flows as follows: The drilling fluid flows out from the bell mouth 1, passes through the rectifier 2, degasser 3, and degasser 4, and enters the three-way pipeline. Controlled by valves, it has three possible paths: one flows through the flow meter 5, one through the straight pipe 6, and one through the overflow prevention pipe 7, all converging into the observation tank 8 and finally flowing into the buffer tank 9. The rectifier 2, degasser 3, and degasser 4 are located in square groove 10, and the observation tank 8 is located in square groove 11. Valve 12 controls the on / off state of the straight pipe 6, while valves 13 and 14 control the on / off state of the flow meter 5.

[0085] Figure 3 A flowchart of a method for quantitative monitoring of well kick and well leakage according to an embodiment of the present invention is shown.

[0086] like Figure 3 As shown, in step S1, after each change in drilling fluid properties and before drilling begins, an instantaneous standard flow rate test is performed to obtain the instantaneous standard volumetric flow rate (QDS). Specifically, the instantaneous standard (volume) flow rate test involves recording standard instantaneous volumetric flow rate data after each change in drilling fluid properties at different pump stroke rates, i.e., different displacements, to reduce flow measurement interference caused by factors such as drilling pump water supply efficiency, pipeline losses, and drilling fluid properties.

[0087] In one embodiment, when the instantaneous standard volumetric flow rate QDS is equal to the number of pump strokes S (S is the number of drilling pump strokes per minute), the instantaneous outlet flow rate through the flow meter 5 is expressed in m³ / s. 3 / min. Furthermore, instantaneous standard volumetric flow rate tests should be conducted at preset intervals (e.g., every 12 hours) to reduce flow rate measurement interference caused by other factors such as well depth and lithology changes.

[0088] like Figure 3 As shown, in step S2, the current working state is determined. The working state includes drilling state, single-joint connection state, tripping state, and down-the-hole state. Specifically, the single-joint connection state includes raising the drill string and lowering the drill string.

[0089] like Figure 3 As shown, in step S3, under the current working state, the volumetric flow rate data of flow meter 5 is read, and combined with the instantaneous standard volumetric flow rate, quantitative monitoring of well inrush and well leakage is performed.

[0090] Figure 4 A flowchart of a drilling state well kick and well leakage determination method according to an embodiment of the present invention is shown.

[0091] like Figure 4As shown, the initialization process involves determining the current initial working state. If the current working state is drilling, the instantaneous standard volumetric flow rate QDS and the measured instantaneous volumetric flow rate QDR from flowmeter 5 are read, and the instantaneous volumetric flow rate difference ΔQD is calculated. Specifically, in the drilling state, the instantaneous standard volumetric flow rate is read and assigned the value QDS, and the measured instantaneous volumetric flow rate from flowmeter 5 is read and assigned the value QDR (unit: m³). 3 / min), the instantaneous volumetric flow rate difference ΔQD = QDR - QDS (unit: m³ / min) is calculated. 3 / min).

[0092] like Figure 4 As shown, the cumulative time T from the start of drilling to the current time (T represents the cumulative time from the start of drilling to the current time, in minutes) is determined. Combined with the instantaneous volumetric flow rate difference ΔQD, the cumulative volumetric flow rate difference ΔVD during drilling is calculated. Specifically, the cumulative volumetric flow rate difference ΔVD during drilling is calculated as ΔQD × T.

[0093] like Figure 4 As shown, the cumulative volumetric flow rate difference ΔVD during drilling is compared with a first set threshold (for example, the first set threshold is 1m). 3 This is compared to determine whether a well kick or well leakage has occurred. Specifically, during drilling, when ΔVD is greater than 1m... 3 When this occurs, it is judged as an abnormal well kick and an alarm is issued; when ΔVD is less than -1m 3 When |△VD| is less than 1m, it is judged as an abnormal well leakage and an alarm message is issued; 3 At that time, it was judged to be normal.

[0094] In one embodiment, during the drilling process, the change in the outlet flow rate of flow meter 5 can be solved by integrating the peak area. The solution method includes, but is not limited to, interpolation and function fitting.

[0095] Figure 5 A flowchart of a method for determining well inrush and well leakage according to an embodiment of the present invention is shown.

[0096] In one embodiment, when raising the drill string in a single-joint state, the well kick and leakage detection method includes the following steps:

[0097] like Figure 5 As shown, the type and length of the current lifting drill string are determined, and the theoretical internal volume VCOT (unit: m³) of the drill string is calculated. 3 Specifically, when connecting a single drill string, the drill string is raised, and the current drill string type and length are read (e.g., via WITS) from the integrated logging system. The theoretical internal volume VCOT (unit: m³) of the drill string is then calculated. 3 ).

[0098] like Figure 5 As shown, the cumulative pump stroke count SOA1 at the start of the pull-up and SOA2 at the end of the pull-up are read, and combined with the instantaneous standard volumetric flow rate QDS, the cumulative volumetric flow rate VCOR1 of the drill string is calculated. Specifically, in the single-joint connection state, when the drill string is pulled up, the cumulative pump stroke count SOA1 at the start of the pull-up and SOA2 at the end of the pull-up are read, and the instantaneous standard volumetric flow rate QDS (unit: m³) under the current conditions is read. 3 The cumulative volumetric flow rate VCOR1 for raising the drill string is calculated from the calculated flow rate ( / min). Specifically, the cumulative volumetric flow rate VCOR1 for raising the drill string is calculated as follows: VCOR1 = QDS × (SOA2 - SOA1) / S (unit: m³ / min). 3 ).

[0099] like Figure 5 As shown, the cumulative volumetric flow rate VCO1 of flowmeter 5 at the start of the lifting process and the cumulative volumetric flow rate VCO2 of flowmeter 5 at the end of the lifting process are read to calculate the actual cumulative flow rate VCO2 of flowmeter 5 during the lifting process. Specifically, in the single-joint connection state, when lifting the drill string, the cumulative volumetric flow rate VCO1 (unit: m³) of flowmeter 5 at the start of the lifting process is read. 3 ) and the cumulative volumetric flow rate VCO2 (unit m³) of flow meter 5 at the end of the lifting operation. 3 The actual cumulative flow rate VCOR2 of the drilling tool lifting process flow meter 5 is calculated. Specifically, the actual cumulative flow rate VCOR2 of the drilling tool lifting process flow meter 5 is calculated as follows: VCO2 = VCO2 - VCO1 (unit: m³ / s). 3 ).

[0100] like Figure 5 As shown, based on the cumulative volumetric flow rate VCOR1 of the drill string being lifted and the actual cumulative flow rate VCOR2 of the process flow meter 5 during the drill string lifting process, the actual change in the cumulative flow rate VCOR caused by lifting the drill string is calculated. Specifically, in the single-joint connection state, when the drill string is lifted, the actual change in the cumulative flow rate VCOR caused by lifting the drill string is calculated as follows: VCOR = VCOR1 - VCOR2 (unit: m³). 3 ).

[0101] like Figure 5 As shown, based on the actual change in cumulative flow rate (VCOR) and the theoretical internal volume (VCOT) of the drill string, the difference in cumulative flow rate (ΔVCO) caused by the drill string being pulled up is calculated. Specifically, in the case of a single connection, when the drill string is pulled up, the difference between the actual and theoretical change in flow rate (ΔVCO) caused by the drill string being pulled up is calculated. Specifically, ΔVCO = VCOR - VCOT (unit: m³). 3 ).

[0102] like Figure 5 As shown, the cumulative volumetric flow rate difference ΔVCO from the drill string is compared with a second set threshold to determine whether a well kick or well leakage has occurred. Specifically, when a single drill string is connected, the drill string is raised. If the absolute value of ΔVCO is less than the set value (e.g., the second set threshold is 5% of VCOT), it is considered within the normal fluctuation range. If ΔVCO is greater than the set value, it is considered an abnormal well leakage, and an alarm is issued. If ΔVCO is less than a negative set value (-set value, e.g., -5% VCOT), it is considered an abnormal well kick, and an alarm is issued.

[0103] In one embodiment, when the drill string is deployed in a single-joint state, the well kick and leakage determination method includes the following steps:

[0104] like Figure 5 As shown, the type and length of the drill string being lowered are determined, and the theoretical external volume (VCIT) of the drill string is calculated. Specifically, in the single-string connection state, the drill string is lowered, and the type and length of the drill string are read to theoretically calculate the theoretical external volume (VCIT) of the drill string (unit: m). 3 ).

[0105] like Figure 5 As shown, the cumulative pump stroke count SIA1 at the start of lowering and the cumulative pump stroke count SIA2 at the end of lowering are read, and combined with the instantaneous standard volumetric flow rate QDS, the cumulative volumetric flow rate VCIR1 of lowering the drill string is calculated. Specifically, in the single-joint connection state, when lowering the drill string, the cumulative pump stroke count SIA1 at the start of lowering and the cumulative pump stroke count SIA2 at the end of lowering are read, and the instantaneous standard volumetric flow rate QDS (unit: m³) under the current conditions is read. 3 The cumulative volumetric flow rate VCIR1 of the drill string is calculated from the flow rate ( / min). Specifically, the cumulative volumetric flow rate VCIR1 of the drill string is calculated as follows: VCIR1 = QDS × (SIA2 - SIA1) / S (unit: m³ / min). 3 ).

[0106] like Figure 5 As shown, the cumulative volumetric flow rate VCI1 of flowmeter 5 at the start of lowering and the cumulative volumetric flow rate VCI2 of flowmeter 5 at the end of lowering are read, and the actual cumulative flow rate VCIR2 of flowmeter 5 during the lowering process is calculated. Specifically, in the single-joint state, when lowering the drill string, the cumulative volumetric flow rate VCI1 of flowmeter 5 at the start of lowering is read (unit: m). 3 ) and the cumulative volumetric flow rate VCI2 (unit m) of flowmeter 5 at the end of the deportation. 3 The actual cumulative flow rate VCIR2 of the flow meter 5 during the drilling process is calculated. Specifically, the actual cumulative flow rate VCIR2 of the flow meter 5 during the drilling process is calculated as follows: VCIR2 = VCI2 - VCI1 (unit: m³ / s). 3 ).

[0107] like Figure 5 As shown, based on the cumulative volumetric flow rate VCIR1 of the drill string and the actual cumulative flow rate VCIR2 of the flow meter 5 during the drill string lowering process, the actual change in the cumulative flow rate VCIR caused by the lowering of the drill string is calculated. Specifically, in the single-connection state, when lowering the drill string, the actual change in the cumulative flow rate VCIR caused by the lowering of the drill string is calculated as follows: VCIR = VCIR2 - VCIR1 (unit: m³). 3 ).

[0108] like Figure 5 As shown, based on the actual change in cumulative flow rate (VCIR) and the theoretical external volume (VCIT) of the drill string, the difference in cumulative flow rate (ΔVCI) caused by the drill string descent is calculated. Specifically, in the case of a single connection, when the drill string is lowered, the difference between the actual and theoretical changes in flow rate caused by the drill string descent is calculated as ΔVCI = VCIR - VCIT (unit: m³). 3 ).

[0109] like Figure 5 As shown, the cumulative volumetric flow rate difference ΔVCI of the lowered drill string is compared with a third preset threshold to determine whether a well kick or well leakage has occurred. Specifically, when a single drill string is connected, the drill string is lowered. If the absolute value of ΔVCI is less than the preset value (e.g., the third preset threshold is 5% of VCIT), it is considered to be within the normal fluctuation range. If ΔVCI is greater than the preset value, it is considered a well kick anomaly, and an alarm message is issued. If ΔVCI is less than a negative preset value (-set value, e.g., -5% VCIT), it is considered a well leakage anomaly, and an alarm message is issued.

[0110] In one embodiment, when connected to a single branch, the change in the outlet flow rate of flow meter 5 can be solved by integrating the peak area. The solution method includes, but is not limited to, interpolation and function fitting.

[0111] Figure 6 A flowchart of a well kick and leakage determination method according to an embodiment of the present invention is shown.

[0112] In one embodiment, the well kick and leakage determination method during tripping out of the drilling site includes the following steps:

[0113] like Figure 6 As shown, the volumetric flow rate QCFP of the constant flow pump per unit time is read. Specifically, during the tripping-out phase, the volumetric flow rate of the constant flow pump per unit time is read and assigned the value QCFP (unit: m³ / s). 3 ( / min). The constant flow pump is used during the tripping process. It pumps drilling fluid from the tripping container into the wellbore to compensate for the drop in wellbore fluid level caused by tripping. Excess drilling fluid flows out through the overhead trough.

[0114] like Figure 6 As shown, the length, inner diameter, and outer diameter of the drill string to be pulled out are determined, and the theoretical pull-out volume VTOT is calculated. Specifically, during the pull-out process, parameters such as the length, inner diameter, and outer diameter of the drill string are read, and the internal volume of the corresponding drill string pulled out (using the inner diameter) is calculated and assigned as the theoretical pull-out volume VTOT (unit: m). 3 ).

[0115] like Figure 6 As shown, the cumulative volumetric flow rate VTOR1 of flowmeter 5 at the start of drill string hoisting and the cumulative volumetric flow rate VTOR2 of flowmeter 5 at the end of drill string hoisting are read. Combined with the volumetric flow rate QCFP of the constant flow pump per unit time, the actual cumulative flow rate ΔVTOR of flowmeter 5 during the drill string hoisting process is calculated. Specifically, in the hoisting state, the cumulative volumetric flow rate VTOR1 (unit: m³) of flowmeter 5 at the start of this drill string hoisting is read. 3 The time is T1, and the cumulative volumetric flow rate VTOR2 (unit: m³) of flowmeter 5 is recorded when the drill string is pulled up at the end of this operation. 3 The actual flow rate change ΔVTOR caused by pulling out the drill string at time T2 is calculated as follows: ΔVTOR = VTOR2 - VTOR1 - QCFP(T2 - T1) (unit: m³ / s). 3 ).

[0116] like Figure 6 As shown, based on the actual cumulative flow rate △VTOR of the drill string tripping process flow meter 5 and the theoretical tripping volume VTOT, the cumulative volumetric flow rate difference △VTO is calculated. Specifically, in the tripping state, the difference between the theoretical and actual volumetric flow rates △VTO is calculated as △VTOR - VTOT (unit: m³). 3 ).

[0117] like Figure 6 As shown, the cumulative volumetric flow rate difference ΔVTO from the drill string is compared with a fourth preset threshold to determine whether a kick or leakage has occurred. Specifically, during the tripping phase, if the absolute value of ΔVTO is less than the preset value (e.g., the fourth preset threshold is 5% of VTOT), it is considered within the normal fluctuation range; if ΔVTO is greater than the preset value, it is considered a kick anomaly, and an alarm is issued; if ΔVTO is less than a negative preset value (-set value, e.g., -5% VTOT), it is considered a leakage anomaly, and an alarm is issued.

[0118] In one embodiment, the well kick and leakage detection method during drilling includes the following steps:

[0119] like Figure 6As shown, the length, inner diameter, and outer diameter of the drill string to be run in this drilling operation are determined, and the theoretical drilling volume VTIT is calculated. Specifically, during the drilling process, by reading parameters such as the length, inner diameter, and outer diameter of the drill string to be run in this operation, the external volume of the corresponding drill string (using the outer diameter to calculate the volume) is calculated and assigned as the theoretical drilling volume VTIT (unit: m). 3 ).

[0120] like Figure 6 As shown, the cumulative volumetric flow rate VTIR1 of flowmeter 5 at the start of drilling tool lowering and the cumulative volumetric flow rate VTIR2 of flowmeter 5 at the end of drilling tool lowering are read to calculate the actual cumulative flow rate VTIR of flowmeter 5 during the drilling tool lowering process. Specifically, during the drilling process, the cumulative volumetric flow rate VTIR1 (unit: m³) of flowmeter 5 at the start of drilling tool lowering is read. 3 The cumulative volumetric flow rate VTIR2 (unit: m³) of flowmeter 5 at the end of this drilling operation. 3 The measured cumulative flow difference VTIR = VTIR2 - VTIR1 (unit: m³) 3 ).

[0121] like Figure 6 As shown, based on the actual cumulative flow rate VTIR of the flow meter 5 during the drilling process and the theoretical drilling volume VTIT, the cumulative volumetric flow rate difference ΔVTI of the drilling tool is calculated. Specifically, during the drilling process, the difference between the theoretical and actual volumetric flow rates ΔVTI is calculated as: ΔVTI = VTIR - VTIT (unit: m³). 3 ).

[0122] like Figure 6 As shown, the cumulative volumetric flow rate difference ΔVTI during drilling is compared with a fifth preset threshold to determine whether a well kick or well leakage has occurred. Specifically, during drilling, if the absolute value of ΔVTI is less than the preset value (e.g., the fifth preset threshold is 5% of VTIT), it is considered within the normal fluctuation range; if ΔVTI is greater than the preset value, it is considered a well kick anomaly, and an alarm message is issued; if ΔVTI is less than a negative preset value (-set value, e.g., -5% VTIT), it is considered a well leakage anomaly, and an alarm message is issued.

[0123] In one embodiment, during the drilling start-up and start-up phases, the change in the outlet flow rate of flow meter 5 can be solved by integrating the peak area method. The solution method includes, but is not limited to, interpolation method, function fitting method, etc.

[0124] In one embodiment, the present invention provides a method for quantitative monitoring of well kick and well leakage. During the monitoring process, the actual volumetric flow rate of drilling fluid measured by the flow meter 5 is compared with the theoretical volumetric flow rate. Changes within a certain range are considered normal fluctuations, while increases or decreases indicate well kick or well leakage abnormalities.

[0125] The well kick and leakage quantitative monitoring device and method provided by this invention can also be used in conjunction with a computer-readable storage medium. The storage medium stores a computer program, and executing the computer program runs the well kick and leakage quantitative monitoring method. The computer program can execute computer instructions, which include computer program code. The computer program code can be in the form of source code, object code, executable file, or some intermediate form, etc.

[0126] Computer-readable storage media can include: any entity or device capable of carrying computer program code, recording media, USB flash drives, portable hard drives, magnetic disks, optical disks, computer memory, read-only memory (ROM), random access memory (RAM), electrical carrier signals, telecommunication signals, and software distribution media, etc.

[0127] It should be noted that the contents of computer-readable storage media may be appropriately added to or subtracted from the contents according to the requirements of legislation and patent practice in a jurisdiction. For example, in some jurisdictions, according to legislation and patent practice, computer-readable storage media may not include electrical carrier signals and telecommunication signals.

[0128] In summary, this invention provides a quantitative monitoring device and method for well kicks and leaks. Without affecting on-site drilling and logging operations, it solves the problems of reduced flow meter accuracy or even malfunction caused by excessive drilling fluid bubbles due to pipeline modifications, thus improving the flow meter's applicability and measurement accuracy in the field. For different operating conditions, well kick and leak monitoring methods are provided, enabling quantitative monitoring of well kicks and leaks under various complex conditions. This invention lays the foundation for quantitative monitoring of well kicks and leaks in drilling fluid outlet flow rates, effectively improving the well control safety level of drilling operations.

[0129] It should be understood that the embodiments disclosed herein are not limited to the specific structures, processing steps, or materials disclosed herein, but should be extended to equivalent substitutions of these features as understood by those skilled in the art. It should also be understood that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting.

[0130] In the description of this invention, unless otherwise stated, "a plurality of" means two or more; the terms "upper," "lower," "left," "right," "inner," "outer," "front end," "rear end," "head," "tail," etc., indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings, and are only for the convenience of describing the invention and simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, or be constructed and operated in a specific orientation, and therefore should not be construed as a limitation of the invention. Furthermore, the terms "first," "second," "third," etc., are used for descriptive purposes only and should not be construed as indicating or implying relative importance.

[0131] In the description of this invention, it should be noted that, unless otherwise explicitly specified and limited, the terms "connected" and "linked" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection; they can refer to a mechanical connection or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium. Those skilled in the art can understand the specific meaning of the above terms in this invention based on the specific circumstances.

[0132] The phrase "an embodiment" or "an embodiment" used in this specification means that a particular feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment of the invention. Therefore, the phrase "an embodiment" or "an embodiment" appearing in various places throughout the specification does not necessarily refer to the same embodiment.

[0133] The embodiments of the present invention are given for illustrative and descriptive purposes only, and are not intended to be exhaustive or to limit the invention to the forms disclosed. Many modifications and variations will be apparent to those skilled in the art. The embodiments were chosen and described in order to better illustrate the principles and practical application of the invention, and to enable those skilled in the art to understand the invention and to design various embodiments with various modifications suitable for a particular purpose.

[0134] While the embodiments disclosed in this invention are as described above, the content is merely for the purpose of facilitating understanding of the invention and is not intended to limit the invention. Any person skilled in the art to which this invention pertains may make any modifications and variations in form and detail of the implementation without departing from the spirit and scope disclosed herein; however, the scope of patent protection for this invention shall still be determined by the scope defined in the appended claims.

Claims

1. A quantitative monitoring device for well inrush and well leakage, characterized in that, The well kick and well leakage quantitative monitoring device includes: A rectifier is used to rectify the drilling fluid flowing out of the funnel to reduce flow distortion. A degasser, which is connected to the rectifier, is used to degas the drilling fluid flowing out of the rectifier; A degasser, connected to the degasser, is used to degas the drilling fluid flowing out of the degasser in order to reduce the impact of gas on measurement accuracy. The degasser has three outlets: the first is a straight pipe, the second is an overflow prevention pipe, and the third passes through a flow meter. The drilling fluid in the three pipes flows into the observation tank together. The flow meter is used to quantitatively monitor the volumetric flow rate of the drilling fluid. The rectifier is a tube bundle structure, a perforated plate structure, or a combination of a tube bundle structure and a perforated plate structure. The degasser uses the degassing device of the original logging gas detection system. In order to ensure a stable degassing liquid level, it is installed in the outlet direction of the rectifier. The rectifier, the degasser, and the degasser are placed in a square groove. The square groove should be placed as close as possible to the bell mouth to reduce the change in the flow state of the drilling fluid. When the pipeline where the flow meter is located is blocked or the flow capacity is insufficient, the drilling fluid can flow through the overflow prevention pipe to prevent the drilling fluid from overflowing from the bell mouth. The highest point of the overflow prevention pipe is lower than the height of the baffle of the square groove and the outlet height of the bell mouth to prevent the drilling fluid from overflowing from the square groove. The observation slot is located inside the square slot two, which is used for pressure release to allow air bubbles in the drilling fluid to be released, which is beneficial to the normal operation of the flow meter. The well inrush and well leakage quantitative monitoring device includes a buffer tank connected to the outlet of the observation tank.

2. A method for quantitative monitoring of well kick and well leakage, characterized in that, Performed by the well kick and well leakage quantitative monitoring device as described in claim 1, the method comprises the following steps: After each change in drilling fluid properties and before drilling begins, an instantaneous standard flow rate test is performed to obtain the instantaneous standard volumetric flow rate. Determine the current working state, which includes drilling state, single-joint connection state, tripping state, and drilling down state. Under the current operating conditions, the volumetric flow rate data of the flow meter is read, and combined with the instantaneous standard volumetric flow rate, quantitative monitoring of well inrush and well leakage is performed.

3. The method for quantitative monitoring of well kick and well leakage as described in claim 2, characterized in that, In the drilling state, the method includes the following steps: The instantaneous standard volumetric flow rate and the measured instantaneous volumetric flow rate of the flow meter are read, and the instantaneous volumetric flow rate difference is calculated. The cumulative time from the start of drilling to the current time is determined, and the cumulative volumetric flow rate difference in the drilling state is calculated by combining the instantaneous volumetric flow rate difference. The cumulative volumetric flow rate difference in the drilling state is compared with a first set threshold to determine whether a well kick or well leakage has occurred.

4. The method for quantitative monitoring of well kick and well leakage as described in claim 2, characterized in that, When lifting the drill string in the single-joint state, the method includes the following steps: Determine the type and length of the current lifting drill string, and calculate the theoretical internal volume of the drill string. The cumulative pump stroke count at the start of the lifting and the cumulative pump stroke count at the end of the lifting are read, and the cumulative volumetric flow rate of the lifting drill string is calculated by combining the instantaneous standard volumetric flow rate. Read the cumulative volumetric flow rate of the flow meter at the start of the lifting process and the cumulative volumetric flow rate of the flow meter at the end of the lifting process, and calculate the actual cumulative flow rate of the flow meter during the lifting process of the drill bit; Based on the cumulative volumetric flow rate of the drill string being lifted and the actual cumulative flow rate of the flow meter during the drill string lifting process, the actual change in the cumulative flow rate of the drill string being lifted due to the lifting of the drill string is calculated. Based on the actual change in the cumulative flow of the drill string and the theoretical internal volume of the drill string, the difference in the cumulative volume flow of the drill string caused by the drill string being lifted is calculated. The cumulative volumetric flow rate difference of the lifting drill string is compared with a second set threshold to determine whether a well kick or well leakage has occurred.

5. The method for quantitative monitoring of well kick and well leakage as described in claim 2, characterized in that, When placing the drill string in the single-joint state, the method includes the following steps: Determine the type and length of the drill string to be lowered, and calculate the theoretical external volume of the drill string. The cumulative pump stroke count at the start of the descent and the cumulative pump stroke count at the end of the descent are read, and the cumulative volumetric flow rate of the drill bit is calculated by combining the instantaneous standard volumetric flow rate. The cumulative volumetric flow rate of the flow meter at the start of the lowering process and the cumulative volumetric flow rate of the flow meter at the end of the lowering process are read, and the actual cumulative flow rate of the flow meter during the lowering process is calculated. Based on the cumulative volumetric flow rate of the drill string and the actual cumulative flow rate of the flow meter during the drill string lowering process, the actual change in the cumulative flow rate of the drill string caused by the lowering of the drill string is calculated. Based on the actual change in the cumulative flow of the drill string and the theoretical external volume of the drill string, the difference in the cumulative volumetric flow of the drill string caused by the lowering of the drill string is calculated. The cumulative volumetric flow rate difference of the lowered drill string is compared with a third set threshold to determine whether a well kick or well leakage has occurred.

6. The method for quantitative monitoring of well kick and well leakage as described in claim 2, characterized in that, In the aforementioned tripping state, the method includes the following steps: Read the volumetric flow rate of the constant flow pump per unit time; Determine the length, inner diameter, and outer diameter of the drill string for this drilling operation, and calculate the theoretical drilling volume. The cumulative volumetric flow rate of the flow meter when the drill string is started to be pulled up and the cumulative volumetric flow rate of the flow meter when the drill string is pulled up are read. Combined with the volumetric flow rate of the constant flow pump per unit time, the actual cumulative flow rate of the flow meter during the drill string pulling-out process is calculated. Based on the actual cumulative flow of the flow meter during the drill string tripping process and the theoretical tripping volume, the cumulative volume flow rate difference of the drill string tripping is calculated. The cumulative volumetric flow rate difference of the drill string is compared with a fourth preset threshold to determine whether a well kick or well leakage has occurred.

7. The method for quantitative monitoring of well kick and well leakage as described in claim 2, characterized in that, In the drilling state, the method includes the following steps: Determine the length, inner diameter, and outer diameter of the drill string for this drilling operation, and calculate the theoretical drilling volume. Read the cumulative volumetric flow rate of the flow meter when the drilling tool is lowered and the cumulative volumetric flow rate of the flow meter when the drilling tool is lowered is finished, and calculate the actual cumulative flow rate of the flow meter during the drilling tool lowering process; Based on the actual cumulative flow of the flow meter during the drilling process and the theoretical drilling volume, the cumulative volume flow difference of the drilling tool is calculated. The cumulative volumetric flow rate difference of the lowered drill string is compared with the fifth preset threshold to determine whether a well kick or well leakage has occurred.

8. A storage medium, characterized in that, It includes a series of instructions for performing the method steps as described in any one of claims 2-7.

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