A turbodrill wellhead testing monitoring system

Abstract

The application discloses a turbine drilling wellhead testing monitoring system and belongs to the technical field of turbine drilling tools. The system comprises a testing monitoring device installed between a conventional drill pipe and a turbine drilling tool, the upper and lower ends of the shell of the device are connected with the conventional drill pipe and the turbine drilling tool respectively, a lower bevel gear seat is fixed to the inner side of the shell, a lower bevel gear is rotatably installed on the lower bevel gear seat, the gear shaft of the lower bevel gear is connected with a compression nut at the upper end of the turbine drilling tool, the rotation of the rotor blade drives the rotation of the lower bevel gear, a rotating speed output bevel gear is rotatably installed on the side wall of the shell, the gear part of the rotating speed output bevel gear is engaged with the lower bevel gear, the gear shaft penetrates through the shell and is connected with an encoder, so that the rotating speed of the rotor is guided out and is monitored in real time. The application realizes the on-line quantitative measurement of the rotating speed of the turbine drilling tool, replaces the traditional fuzzy judgment of artificial hand touch sensing, and significantly improves the accuracy, safety and intelligent level of the wellhead testing.

Description

Technical Field

[0001] This invention relates to the field of turbine drilling technology, and more specifically to a turbine drilling wellhead testing and monitoring system. Background Technology

[0002] Turbine drills, as a type of downhole power drill that uses drilling fluid as the power medium, are widely used in drilling operations in deep hard rock formations. Their working principle involves installing multiple turbine blades in series. High-pressure drilling fluid pumped from the surface drives the turbine rotor to rotate, thereby converting fluid energy into mechanical energy to propel the drill bit to break rock. Because turbine drills operate under complex conditions such as high temperature, high pressure, and strong vibration downhole, wellhead testing before deployment is a crucial step in ensuring drilling safety and operational efficiency.

[0003] Currently, the common method for judging whether turbine drill strings are rotating normally in field wellhead testing is to have operators touch the surface of the drill string after starting the pump to sense its vibration, thus indirectly determining whether the internal rotor is rotating normally. This method has the following drawbacks: First, it cannot quantitatively obtain key operating parameters such as drill string speed and pressure drop, leading to a highly subjective judgment; second, it heavily relies on the operator's experience, lacking replicability and scalability; and third, it requires operators to remain in high-risk areas on the drilling platform for extended periods, posing significant safety hazards.

[0004] Furthermore, in actual operation, the internal pressure drop of turbine drilling tools is an important indicator reflecting energy conversion efficiency and operating status. However, currently, field tests typically only refer to the readings of the surface vertical pressure gauge as the basis for drilling tool pressure drop, ignoring pressure losses from surface pipelines and wellhead equipment. This leads to significant deviations in test results, making it difficult to accurately reflect the internal working conditions of the drilling tool.

[0005] In summary, existing wellhead testing methods for turbine drilling tools have significant shortcomings in terms of data acquisition, safety, and accuracy. There is an urgent need to develop a wellhead testing system that can monitor the drilling tool's operating status in real time and accurately, and has safety control functions, in order to improve the automation level and safety of the testing process, reduce human judgment errors, and ensure the smooth progress of drilling operations. Summary of the Invention

[0006] In view of this, the present invention provides a turbine drilling tool wellhead testing and monitoring system, which aims to solve the above-mentioned technical problems.

[0007] To achieve the above objectives, the present invention adopts the following technical solution:

[0008] A turbine drill string wellhead testing and monitoring system includes a testing and monitoring device installed between a conventional drill pipe and a turbine drill string, the testing and monitoring device comprising:

[0009] The housing is connected at its upper and lower ends to the conventional drill pipe and the turbine drill bit, respectively.

[0010] A lower bevel gear seat is fixed to the inner side of the housing. A lower bevel gear is rotatably mounted on the lower bevel gear seat. The gear part of the lower bevel gear is located above the lower bevel gear seat. The gear shaft of the lower bevel gear is connected to the clamping nut at the upper end of the turbine drill bit, so that the rotation of the rotor blades of the turbine drill bit can drive the lower bevel gear to rotate through the clamping nut.

[0011] A speed output bevel gear is rotatably mounted on the side wall of the housing. The gear portion of the speed output bevel gear meshes with the gear portion of the lower bevel gear. The gear shaft of the speed output bevel gear passes through the outer wall of the housing and is connected to an encoder, so that the rotation of the lower bevel gear is transmitted to the speed output bevel gear and the encoder monitors the speed.

[0012] Through the above technical solution, the present invention sets up a lower bevel gear and a speed output bevel gear that are linked with the turbine drill rotor, so as to smoothly guide the mechanical rotation of the downhole rotor to the outside of the housing and monitor it in real time by an encoder. This realizes online, quantitative and automated measurement of the turbine drill speed, completely changing the traditional subjective judgment method that relies on manual touch to sense vibration, and significantly improving the data accuracy, operational safety and intelligence level of wellhead testing.

[0013] Preferably, in the above-mentioned turbine drilling tool wellhead testing and monitoring system, an upper bevel gear seat is fixed inside the housing, an upper bevel gear is rotatably mounted on the upper bevel gear seat, and the gear portion of the upper bevel gear meshes with the gear portion of the speed output bevel gear.

[0014] Preferably, in the above-mentioned turbine drilling tool wellhead testing and monitoring system, an end cap is fixed on the top surface of the upper bevel gear seat, and the end cap covers the gear shaft of the upper bevel gear.

[0015] Preferably, in the above-mentioned turbine drilling tool wellhead testing and monitoring system, the gear shaft of the upper bevel gear is mounted on the upper bevel gear seat via a first angular contact ball bearing and a shaft retaining ring. The upper bevel gear seat is mounted on the housing via fixing bolts. The end cover is mounted on the top surface of the upper bevel gear seat via bolts, and a first sealing ring is installed on the contact end face between the end cover and the upper bevel gear seat.

[0016] Preferably, in the above-mentioned turbine drilling tool wellhead testing and monitoring system, a remote pressure gauge is installed on the side wall of the housing.

[0017] Preferably, in the above-mentioned turbine drill wellhead testing and monitoring system, a braking mechanism is connected between the gear shaft of the lower bevel gear and the housing. The braking mechanism is used to brake the lower bevel gear when the pressure drop inside the drill exceeds the design threshold.

[0018] Preferably, in the above-mentioned turbine drill string wellhead testing and monitoring system, the braking mechanism includes:

[0019] A worm gear seat is rotatably connected to the outside of the gear shaft of the lower bevel gear. The worm gear seat consists of an upper worm gear part and a lower disc part. Multiple arc-shaped grooves are evenly distributed around the lower bevel gear on the disc part.

[0020] A brake motor is fixed on the outer wall of the housing. The power output shaft of the brake motor passes through the side wall of the housing and is rotatably connected to the side wall of the housing. A worm is fixed on the power output shaft of the brake motor, and the worm meshes with the worm wheel portion on the upper part of the worm wheel seat.

[0021] A bracket fixed to the inner wall of the housing, the bracket being located below the worm gear seat;

[0022] The limiting rods are the same number as the arc-shaped sliding grooves. The tops of the multiple limiting rods are slidably connected to the multiple arc-shaped sliding grooves, and the multiple limiting rods are radially slidably connected to the bracket, so that when the brake motor drives the worm gear to rotate the worm wheel seat, it can drive the limiting rods to make radial movements relative to the gear shaft of the lower bevel gear.

[0023] Preferably, in the above-mentioned turbine drilling tool wellhead testing and monitoring system, a tension spring is connected between the end of the limiting rod away from the lower bevel gear shaft and the bracket.

[0024] Preferably, in the above-mentioned turbine drill wellhead testing and monitoring system, the gear shaft of the lower bevel gear is mounted on the lower bevel gear seat via a third angular contact ball bearing and a locking nut, and the third angular contact ball bearing is limited by a retaining ring through a second hole.

[0025] Preferably, in the above-mentioned turbine drilling tool wellhead testing and monitoring system, the gear shaft of the speed output bevel gear is mounted on the housing via a second angular contact ball bearing. The second angular contact ball bearing is limited by a retaining ring through a first hole, and a double dynamic seal is achieved by using a skeleton seal and a U-shaped sealing ring.

[0026] As can be seen from the above technical solution, compared with the prior art, the present invention discloses a turbine drilling tool wellhead testing and monitoring system, which has the following beneficial effects:

[0027] 1. This monitoring system can accurately and in real time acquire engineering parameters such as rotational speed and pressure drop during turbine drill wellhead testing. By comparing the results with indoor test results, it can quickly determine whether the working status of the turbine drill wellhead meets the requirements of downhole operations. This improves the automation and intelligence of the turbine drill wellhead testing process, significantly improves the accuracy of judging the operating status of the turbine drill wellhead, and avoids the uncertainty of relying on human perception of drill wellhead vibration for experience-based judgment.

[0028] 2. This device relies on encoders to wirelessly transmit data, allowing on-site operators to conduct real-time monitoring and data analysis away from the drilling platform during wellhead testing. Currently, methods relying on touching the drill string to sense vibrations require operators to be at the wellhead. This device effectively reduces the personal risk to on-site personnel and completely avoids increased drilling costs caused by misjudging the turbine drill string's operating status.

[0029] 3. Increased safety of turbine drill string wellhead testing. During wellhead testing, the internal pressure of the drill string can be reflected in real time. When the internal pressure of the drill string becomes too high (exceeding the design threshold), the drill string output shaft can be braked to terminate the wellhead test. This improves upon the severe lag caused by manually adjusting the displacement to reduce pressure, avoiding drilling accidents caused by excessive internal pressure leading to leaks in surface equipment pipelines and the drill string itself, effectively ensuring the safety of drill string wellhead testing.

[0030] 4. This monitoring system directly tests the internal working pressure drop of the drill string, accurately reflecting the output parameters of the wellhead test. Currently, in the field application of turbine drill strings, the pressure drop is taken into account by referring to the value of the standby pressure gauge, ignoring the pressure loss caused by the surface pressure pipeline, and thus failing to accurately reflect the wellhead test pressure drop. This monitoring system effectively solves the above-mentioned problems, significantly improves the accuracy of the wellhead test pressure drop, and provides a strong basis for the final judgment of the wellhead operating status of the turbine drill string. Attached Figure Description

[0031] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on the provided drawings without creative effort.

[0032] Figure 1 The attached figure is a schematic diagram of the wellhead testing and monitoring system for turbine drilling tools provided by the present invention;

[0033] Figure 2 The attached figure is a schematic diagram of the structure of the testing and monitoring device provided by the present invention;

[0034] Figure 3 The attached figure is a schematic diagram of the upper bevel gear seat connection provided by the present invention;

[0035] Figure 4 The attached figure is provided by the present invention. Figure 1 Sectional view of AA;

[0036] Figure 5 The attached figure is a top view of the braking mechanism provided by the present invention in a test state;

[0037] Figure 6 The attached figure is provided by the present invention. Figure 5 Sectional view of BB;

[0038] Figure 7 The attached figure is a top view of the braking mechanism provided by the present invention in the braking state;

[0039] Figure 8 The attached figure is provided by the present invention. Figure 7 Sectional view of CC;

[0040] Figure 9 The attached figure is a schematic diagram of the data transmission principle of the monitoring system provided by the present invention.

[0041] in:

[0042] 1-Housing; 2-End cover; 3-Bolt; 4-First sealing ring; 5-Upper bevel gear seat; 6-First angular contact ball bearing; 7-Shaft retaining ring; 8-Upper bevel gear; 9-Speed ​​output bevel gear; 10-Encoder; 11-Second angular contact ball bearing; 12-Skeleton seal; 13-U-shaped sealing ring; 14-First hole retaining ring; 15-Lower bevel gear seat; 16-Second hole retaining ring; 17-Third angular contact ball bearing; 18-Locking nut; 19-Lower bevel gear; 20-Remote pressure gauge; 21-Deep groove ball bearing; 22-Worm gear seat; 23-Setting sleeve; 24-Limit rod; 25-Tension spring; 26-Positioning bolt; 27-Bracket; 28-Brake motor; 29-Retaining ring; 30-Second sealing ring; 31-Tapered roller bearing; 32-Shaft sleeve; 33-Worm; 34-Fixing bolt; 35-Conventional drill pipe; 36-Turbine drill bit; 37-Clamping nut; 38-Arc-shaped groove. Detailed Implementation

[0043] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0044] See appendix Figure 1 and attachedFigure 2 This invention discloses a turbine drill string wellhead testing and monitoring system, including a testing and monitoring device installed between a conventional drill pipe 35 and a turbine drill string 36. The testing and monitoring device includes:

[0045] The housing 1 is connected to the conventional drill pipe 35 and the turbine drill string 36 at its upper and lower ends, respectively.

[0046] A lower bevel gear seat 15 is fixed inside the housing 1. A lower bevel gear 19 is rotatably mounted on the lower bevel gear seat 15. The gear part of the lower bevel gear 19 is located above the lower bevel gear seat 15. The gear shaft of the lower bevel gear 19 is connected to the clamping nut 37 at the upper end of the turbine drill 36, so that the rotation of the rotor blades of the turbine drill 36 can drive the lower bevel gear 19 to rotate through the clamping nut 37.

[0047] Rotary output bevel gear 9 is mounted on the side wall of housing 1. The gear part of the output bevel gear 9 meshes with the gear part of the lower bevel gear 19. The gear shaft of the output bevel gear 9 passes through the outer wall of housing 1 and is connected to an encoder 10, so that the rotation of the lower bevel gear 19 is transmitted to the output bevel gear 9 and the encoder 10 monitors the rotation speed.

[0048] In this embodiment, the lower end of the gear shaft of the lower bevel gear 19 is connected to the clamping nut 37 at the upper end of the turbine drill 36 via an external hexagonal connection.

[0049] During wellhead testing, drilling fluid is pumped into the drill pipe. The drilling fluid impacts the rotor blades of the turbine drill string 36, causing it to rotate. Under the connection of the clamping nut 37, the lower bevel gear 19 begins to rotate synchronously. Since the speed output bevel gear 9 and the lower bevel gear 19 mesh with each other via bevel gears, the speed of the turbine drill string 36 is derived through the speed output bevel gear 9. An encoder 10 is mounted on the outside of the speed output bevel gear 9 via a hollow shaft. The encoder 10 is fixed to the gear shaft of the speed output bevel gear 9 by a set screw. It wirelessly transmits the converted electrical signal to the human-machine interface (HMI) to display the speed of the turbine drill string.

[0050] See appendix Figure 3 An upper bevel gear seat 5 is fixed inside the housing 1, and an upper bevel gear 8 is rotatably mounted on the upper bevel gear seat 5. The gear part of the upper bevel gear 8 meshes with the gear part of the speed output bevel gear 9, thereby alleviating some of the abnormal axial pressure caused by the vibration of the turbine drill bit 36 ​​at the bottom of the well.

[0051] To further optimize the above technical solution, an end cover 2 is fixed on the top surface of the upper bevel gear seat 5, and the end cover 2 covers the gear shaft of the upper bevel gear 8.

[0052] To further optimize the above technical solution, the gear shaft of the upper bevel gear 8 is mounted on the upper bevel gear seat 5 through the first angular contact ball bearing 6 and the shaft retaining ring 7. The upper bevel gear seat 5 is mounted on the housing 1 through the fixing bolts 34. The end cover 2 is mounted on the top surface of the upper bevel gear seat 5 through the bolts 3. The contact end face between the end cover 2 and the upper bevel gear seat 5 is equipped with a first sealing ring 4 to prevent the upper bevel gear 8 from being severely eroded by the downward impact of the upper drilling fluid.

[0053] To further optimize the above technical solution, a remote pressure gauge 20 is installed on the side wall of the housing 1.

[0054] See appendix Figure 4 A braking mechanism is connected between the gear shaft of the lower bevel gear 19 and the housing 1. The braking mechanism is used to brake the lower bevel gear 19 when the pressure drop inside the drill exceeds the design threshold.

[0055] To further optimize the above technical solution, the braking mechanism includes:

[0056] The worm gear seat 22 is rotatably connected to the outside of the gear shaft of the lower bevel gear 19. The worm gear seat 22 consists of an upper worm gear part and a lower disc part. Multiple arc-shaped grooves 38 are evenly distributed around the lower bevel gear 19 on the disc part.

[0057] A brake motor 28 is fixed on the outer wall of the housing 1. The power output shaft of the brake motor 28 passes through the side wall of the housing 1 and is rotatably connected to the side wall of the housing 1. A worm 33 is fixed on the power output shaft of the brake motor 28. The worm 33 meshes with the worm wheel part on the upper part of the worm wheel seat 22.

[0058] A bracket 27 is fixed to the inner wall of the housing 1, and the bracket 27 is located below the worm gear seat 22;

[0059] The number of limiting rods 24 is the same as that of the arc-shaped slide grooves 38. The tops of the multiple limiting rods 24 are slidably connected to the multiple arc-shaped slide grooves 38 respectively, and the multiple limiting rods 24 are radially slidably connected to the bracket 27. This allows the limiting rods 24 to move radially relative to the gear shaft of the lower bevel gear 19 when the brake motor 28 drives the worm 33 to rotate the worm wheel seat 22.

[0060] To further optimize the above technical solution, a tension spring 25 is connected between the end of the limiting rod 24 away from the gear shaft of the lower bevel gear 19 and the bracket 27.

[0061] In turbine drill string wellhead testing, besides the output rotational speed, the internal pressure drop is also a crucial engineering parameter. In this embodiment, a remote pressure gauge 20 is installed on the housing 1 to convert the analog pressure signal into an electrical signal and wirelessly transmit it to the human-machine interface (HMI). This allows for real-time acquisition of pressure drop data during turbine drill string wellhead testing, such as… Figure 9As shown. Meanwhile, to ensure drill string testing safety, the internal pressure drop of the drill string must not exceed the design threshold. When the monitored pressure drop parameter exceeds the threshold, the human-machine interface (HMI) will trigger an alarm and feed the signal back to the brake motor 28, which will drive the worm gear 33 to mesh with the worm wheel seat 22 and rotate together. Six arc-shaped grooves 38 are evenly distributed on the lower end disc of the worm wheel seat 22. During rotation, the arc-shaped grooves 38 will drive the limit rod 24 to move radially until it engages with the outer hexagonal part at the bottom of the lower bevel gear 19, completing the drill string braking. The braking state can be released through a reset via the HMI.

[0062] In this embodiment, the worm gear seat 22 is mounted on the gear shaft of the lower bevel gear 19 via a deep groove ball bearing 21 and is secured and limited by a locking sleeve 23. A limiting rod 24 is installed inside the bracket 27, and the two are connected by a tension spring 25. The bracket 27 is mounted on the housing 1 via positioning bolts 26. The power output shaft of the brake motor 28 is mounted on the housing 1 via a tapered roller bearing 31. The tapered roller bearing 31 is limited at both ends by retaining rings 29 and bushings 32, and is sealed with a second sealing ring 30 to prevent leakage of drilling fluid inside the drill bit during testing.

[0063] To further optimize the above technical solution, the gear shaft of the lower bevel gear 19 is mounted on the lower bevel gear seat 15 through the third angular contact ball bearing 17 and the locking nut 18. The third angular contact ball bearing 17 is limited by the retaining ring 16 through the second hole.

[0064] To further optimize the above technical solution, the gear shaft of the speed output bevel gear 9 is mounted on the housing 1 through the second angular contact ball bearing 11. The second angular contact ball bearing 11 is limited by the retaining ring 14 through the first hole, and a double dynamic seal is achieved by using the skeleton seal 12 and the U-shaped sealing ring 13 to avoid leakage of internal drilling fluid and affect the output performance of the drill bit.

[0065] During normal testing, the limit lever 24 is in the open state, such as... Figure 5 and Figure 6 As shown. When the internal pressure of the drill bit exceeds the set threshold, the brake motor 28 is activated, and the limit rod 24 moves radially under the action of the worm gear seat 22, restricting the rotation of the lower bevel gear 19, as shown. Figure 7 and Figure 8 As shown.

[0066] See appendix Figure 9 The encoder 10 and the remote pressure gauge 20 convert the collected analog signals into electrical signals and transmit them wirelessly to the monitoring system's human-machine interface (HMI) in real time. After obtaining the measured data at the wellhead, the HMI can retrieve relevant data from the turbine drill string's indoor test to compare the rotational speed and pressure drop, thereby intuitively and quickly determining whether the turbine drill string's wellhead operating status meets the conditions for downhole operation.

[0067] Since the indoor test fluid medium differs from the drilling fluid at the work site in terms of specific gravity, viscosity and other performance parameters, a proportional coefficient can be set in the coefficient settings of the human-machine interface (HMI) before comparative analysis to ensure the accuracy of the comparative analysis of test results.

[0068] If the internal pressure of the drill string exceeds the set threshold during testing, the human-machine interface (HMI) will display an alarm and brake the drill string output shaft. After braking, if a second test is required, a reset operation can be performed on the interface to release the braking state.

[0069] After comparative analysis, if you need to save the test results, you can export the file using the export button in the human-machine interface (HMI).

[0070] The various embodiments in this specification are described in a progressive manner, with each embodiment focusing on its differences from other embodiments. Similar or identical parts between embodiments can be referred to interchangeably. For the apparatus disclosed in the embodiments, since they correspond to the methods disclosed in the embodiments, the description is relatively simple; relevant parts can be referred to the method section.

[0071] The above description of the disclosed embodiments enables those skilled in the art to make or use the invention. Various modifications to these embodiments will be readily apparent to those skilled in the art, and the general principles defined herein may be implemented in other embodiments without departing from the spirit or scope of the invention. Therefore, the invention is not to be limited to the embodiments shown herein, but is to be accorded the widest scope consistent with the principles and novel features disclosed herein.

Claims

1. A turbine drilling tool wellhead testing and monitoring system, characterized in that, Includes a test and monitoring device installed between the conventional drill pipe (35) and the turbine drill string (36), the test and monitoring device comprising: The housing (1) is connected to the conventional drill rod (35) and the turbine drill (36) at its upper and lower ends, respectively. A lower bevel gear seat (15) is fixed inside the housing (1). A lower bevel gear (19) is rotatably mounted on the lower bevel gear seat (15). The gear part of the lower bevel gear (19) is located above the lower bevel gear seat (15). The gear shaft of the lower bevel gear (19) is connected to the clamping nut (37) at the upper end of the turbine drill (36), so that the rotation of the rotor blades of the turbine drill (36) can drive the lower bevel gear (19) to rotate through the clamping nut (37). Rotary speed output bevel gear (9) is mounted on the side wall of the housing (1). The gear part of the speed output bevel gear (9) meshes with the gear part of the lower bevel gear (19). The gear shaft of the speed output bevel gear (9) passes through the outer wall of the housing (1) and is connected to an encoder (10). This allows the rotation of the lower bevel gear (19) to be transmitted to the speed output bevel gear (9), and the encoder (10) monitors the speed. A remote pressure gauge (20) is installed on the side wall of the housing (1). A braking mechanism is connected between the gear shaft of the lower bevel gear (19) and the housing (1). The braking mechanism is used to brake the lower bevel gear (19) when the pressure drop inside the drill exceeds the design threshold. The braking mechanism includes: A worm gear seat (22) is rotatably connected to the outside of the gear shaft of the lower bevel gear (19). The worm gear seat (22) consists of an upper worm gear part and a lower disc part. Multiple arc-shaped grooves (38) are evenly distributed around the lower bevel gear (19) on the disc part. A brake motor (28) is fixed on the outer wall of the housing (1). The power output shaft of the brake motor (28) passes through the side wall of the housing (1) and is rotatably connected to the side wall of the housing (1). A worm (33) is fixed on the power output shaft of the brake motor (28). The worm (33) meshes with the worm wheel part on the upper part of the worm wheel seat (22). A bracket (27) is fixed on the inner wall of the housing (1), and the bracket (27) is located below the worm gear seat (22); The same number of limiting rods (24) as the arc-shaped slide grooves (38) are provided. The tops of the multiple limiting rods (24) are slidably connected to the multiple arc-shaped slide grooves (38), and the multiple limiting rods (24) are radially slidably connected to the bracket (27). This allows the limiting rods (24) to move radially relative to the gear shaft of the lower bevel gear (19) when the brake motor (28) drives the worm (33) to rotate the worm gear seat (22).

2. The turbine drilling tool wellhead testing and monitoring system according to claim 1, characterized in that, The housing (1) has an upper bevel gear seat (5) fixed inside. An upper bevel gear (8) is rotatably mounted on the upper bevel gear seat (5). The gear part of the upper bevel gear (8) meshes with the gear part of the speed output bevel gear (9).

3. The turbine drilling tool wellhead testing and monitoring system according to claim 2, characterized in that, An end cap (2) is fixed to the top surface of the upper bevel gear seat (5), and the end cap (2) covers the gear shaft of the upper bevel gear (8).

4. The turbine drilling tool wellhead testing and monitoring system according to claim 3, characterized in that, The gear shaft of the upper bevel gear (8) is mounted on the upper bevel gear seat (5) via a first angular contact ball bearing (6) and a shaft retaining ring (7). The upper bevel gear seat (5) is mounted on the housing (1) via fixing bolts (34). The end cover (2) is mounted on the top surface of the upper bevel gear seat (5) via bolts (3), and a first sealing ring (4) is installed on the contact end face between the end cover (2) and the upper bevel gear seat (5).

5. The turbine drilling tool wellhead testing and monitoring system according to claim 1, characterized in that, A tension spring (25) is connected between the end of the limiting rod (24) away from the gear shaft of the lower bevel gear (19) and the bracket (27).

6. The turbine drilling tool wellhead testing and monitoring system according to claim 1, characterized in that, The gear shaft of the lower bevel gear (19) is mounted on the lower bevel gear seat (15) via a third angular contact ball bearing (17) and a locking nut (18). The third angular contact ball bearing (17) is limited by a retaining ring (16) through a second hole.

7. The wellhead testing and monitoring system for turbine drilling tools according to claim 1, characterized in that, The gear shaft of the speed output bevel gear (9) is mounted on the housing (1) via a second angular contact ball bearing (11). The second angular contact ball bearing (11) is limited by a retaining ring (14) through a first hole, and a double dynamic seal is achieved by using a skeleton seal (12) and a U-shaped seal ring (13).

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