Compressor arrangement for a drilling instrument cooling system and drilling instrument
Patent Information
- Authority / Receiving Office
- CN · China
- Patent Type
- Applications(China)
- Current Assignee / Owner
- SINOPEC OILFIELD SERVICE CORPORATION
- Filing Date
- 2024-11-28
- Publication Date
- 2026-05-29
Smart Images
Figure CN122106880A_ABST
Abstract
Description
Technical Field
[0001] This invention relates to the field of drilling instrument cooling systems, and particularly to a compressor unit for a drilling instrument cooling system and a drilling instrument. Background Technology
[0002] Currently, my country's oil and gas exploration and development has rapidly extended to deep and ultra-deep formations, which places higher demands on drilling technology and presents enormous challenges to oil and gas drilling. Ultra-deep wells are 6,000-9,000 meters deep. The Earth's temperature gradient is such that the temperature increases by 2.55°C for every 100 meters of depth, and at a depth of 8,000 meters, the temperature can reach high temperatures of over 205°C.
[0003] Ultra-high temperature is one of the challenges in safely and efficiently drilling deep and ultra-deep wells. The high-temperature environment downhole affects the normal operation of electronic components and sensors in the bottom-hole drill string assembly, resulting in a very high failure rate for the drilling instrument. The operating temperature of the drilling instrument is typically between 150-175℃, making it difficult to ensure normal operation in ultra-high-temperature wells. The main reason is that the sensors and processor chips in the circuitry cannot meet the high-temperature resistance requirements. Related technologies employ active cooling techniques, such as adsorption cooling, thermoelectric cooling, and thermoacoustic cooling, to cool the ultra-high-temperature downhole drilling instrument and maintain it at a safe operating temperature. However, these cooling technologies usually require additional power, moving parts, and additional coolant, making the drilling system more complex. Summary of the Invention
[0004] This invention provides a compressor device for a cooling system for drilling instruments, as well as the drilling instrument itself. It operates without additional power or electricity, relying solely on the flow of drilling fluid to drive the cooling process. This allows the drilling instrument to cool down in ultra-high temperature well environments, thereby achieving stable operation over extended periods in high-temperature, high-pressure downhole environments.
[0005] In a first aspect, embodiments of this application provide a compressor device for a drilling instrument cooling system, comprising: a housing including a first chamber, a second chamber, and a liquid inlet channel, wherein the first chamber and the second chamber are respectively connected to the liquid inlet channel pipeline; a first compressor installed in the first chamber, the first compressor including a first turbine and a first compression assembly, the first turbine being drivenly connected to the first compression assembly; and a second compressor installed in the first chamber, the second compressor including a second turbine and a second compression assembly, the second turbine being drivenly connected to the second compression assembly; wherein the turbine diameter D1 of the first turbine is smaller than the turbine diameter D2 of the second turbine.
[0006] According to the foregoing implementation of the first aspect of the present application, the housing further includes a first control valve and a second control valve. The first chamber is connected to the liquid inlet channel pipeline through the first control valve, and the second chamber is connected to the liquid inlet channel pipeline through the second control valve.
[0007] According to any of the foregoing embodiments of the first aspect of this application, the first chamber includes a first receiving portion and a second receiving portion arranged sequentially, a first turbine is disposed in the first receiving portion, and the first receiving portion is connected to the liquid inlet channel via a pipeline through a first control valve; the second chamber includes a third receiving portion and a fourth receiving portion arranged sequentially, a second turbine is disposed in the third receiving portion, and the third receiving portion is connected to the liquid inlet channel via a pipeline through a second control valve.
[0008] According to any of the foregoing embodiments of this application, the housing further includes a first drain channel and a second drain channel. A first check valve is provided in the first drain channel, and a second check valve is provided in the second drain channel. The first drain channel is connected to the first receiving portion, and the second drain channel is connected to the third receiving portion.
[0009] According to any of the foregoing embodiments of the first aspect of this application, the first compressor further includes a first turbine drive shaft and a first turbine bearing sleeved on the first turbine drive shaft. The input end of the first turbine drive shaft is connected to the first turbine, and the output end of the first turbine drive shaft is connected to the first compressor assembly. The first turbine bearing is sleeved on the second receiving portion, and a first annular seal is provided between the circumferential sidewall of the first turbine bearing and the second receiving portion.
[0010] According to any of the foregoing embodiments of the first aspect of this application, the second compressor further includes a second turbine drive shaft and a second turbine bearing sleeved on the second turbine drive shaft. The input end of the second turbine drive shaft is connected to the second turbine, and the output end of the second turbine drive shaft is connected to the second compressor assembly. The second turbine bearing is sleeved on the third receiving portion, and a second annular seal is provided between the circumferential sidewall of the second turbine bearing and the third receiving portion.
[0011] According to any of the foregoing embodiments of the first aspect of this application, the first compression assembly and the second compression assembly are both scroll compression assemblies. The scroll compression assembly includes a moving scroll, a stationary scroll, a moving scroll bearing, a first end cover, and a second end cover. The moving scroll bearing is sleeved on the input shaft of the moving scroll and is fixedly connected to the housing. The end face of the first end cover is connected to the moving scroll, and the end face of the second end cover is connected to the stationary scroll.
[0012] According to any of the foregoing embodiments of the first aspect of this application, a third annular seal is provided between the outer peripheral surface of the moving scroll bearing and the housing.
[0013] According to any of the foregoing embodiments of the first aspect of this application, a first sealing groove is provided on the outer peripheral surface of the first end cap, and / or a second sealing groove is provided on the outer peripheral surface of the second end cap.
[0014] Secondly, embodiments of this application also provide a drilling instrument, including a compressor device according to any embodiment of the first aspect of this application.
[0015] According to the compressor device of the drilling instrument cooling system in this application embodiment, during operation, drilling fluid enters the first chamber and the second chamber through the inlet channel of the housing. The drilling fluid entering the first chamber and the second chamber can drive the first turbine of the first compressor and the second turbine of the second compressor to rotate, respectively. The rotation of the first turbine drives the first compression assembly to work, and the rotation of the second turbine drives the second compression assembly. The generated cooling capacity is used to cool the drilling instrument, ensuring its stable operation in ultra-high temperature well environments. Because the turbine diameter D1 of the first turbine is small, it is more easily driven by the flow of drilling fluid. Therefore, when the drilling fluid pressure and flow rate are low, the first turbine is driven to rotate first, thereby driving the first compression assembly to work and starting the initial compression and cooling process. Because the diameter D2 of the second turbine is large, it requires drilling fluid with higher pressure and flow rate to drive it. As the drilling fluid pressure and flow rate gradually increase, the second compressor is driven to rotate and generates a larger rotational torque. On the one hand, it avoids damage to the drilling instrument caused by high temperature when the drilling fluid pressure or flow rate is low, as the turbine hysteresis effect cannot drive the turbine in the compressor to rotate for cooling. On the other hand, the cold energy generated by the two-stage compression cooling process is used to cool the drilling instrument, ensuring its stable operation in ultra-high temperature well environments. At the same time, the two compressors work simultaneously, achieving efficient cooling in high temperature and high pressure environments, providing a strong guarantee for the stable operation of the drilling instrument. Attached Figure Description
[0016] The invention will now be described in more detail with reference to embodiments and the accompanying drawings.
[0017] Figure 1 This is a schematic diagram of the compressor unit of a drilling instrument cooling system according to an embodiment of this application;
[0018] Figure 2 This is a schematic diagram of the scroll compressor assembly in the compressor unit of the drilling instrument cooling system of the previous embodiment of this application.
[0019] Figure label:
[0020] 1000 - Compressor unit;
[0021] 100 - Housing; 110 - First chamber; 111 - First receiving part; 112 - Second receiving part; 120 - Second chamber; 121 - Third receiving part; 122 - Fourth receiving part; 130 - Liquid inlet channel; 140 - First control valve; 150 - Second control valve; 160 - First drain channel; 161 - First check valve; 170 - Second drain channel; 171 - Second check valve;
[0022] 200 - First compressor; 210 - First turbine; 220 - First compression assembly; 230 - First turbine drive shaft; 240 - First turbine bearing;
[0023] 300 - Second compressor; 310 - Second turbine; 320 - Second compression assembly; 330 - Second turbine drive shaft; 340 - Second turbine bearing;
[0024] 410 - Moving scroll; 420 - Stationary scroll; 430 - Moving scroll bearing; 440 - First end cover; 450 - Second end cover. Detailed Implementation
[0025] The invention will now be further described with reference to the accompanying drawings.
[0026] This invention provides a compressor device for a cooling system for drilling instruments, as well as the drilling instrument itself. It operates without additional power or electricity, relying solely on the flow of drilling fluid to drive the cooling process. This allows the drilling instrument to cool down in ultra-high temperature well environments, thereby achieving stable operation over extended periods in high-temperature, high-pressure downhole environments.
[0027] Figure 1 This is a schematic diagram of the compressor unit of a drilling instrument cooling system according to an embodiment of this application. Figure 1 As shown in the figure, this application provides a compressor device 1000 for a drilling instrument cooling system. The compressor device 1000 includes a housing 100, a first compressor 200, and a second compressor 300. The housing 100 includes a first chamber 110, a second chamber 120, and a liquid inlet channel 130. The first chamber 110 and the second chamber 120 are respectively connected to the liquid inlet channel 130 via pipelines. The first compressor 200 is installed in the first chamber 110 and includes a first turbine 210 and a first compression assembly 220. The first turbine 210 is drivenly connected to the first compression assembly 220. The second compressor 300 is installed in the first chamber 110. The second compressor 300 includes a second turbine 310 and a second compression assembly 320. The second turbine 310 is drivenly connected to the second compression assembly 320. The turbine diameter D1 of the first turbine 210 is smaller than the diameter D2 of the second turbine 310.
[0028] According to the compressor unit 1000 of the drilling instrument cooling system of the present application embodiment, during operation, drilling fluid enters the first chamber 110 and the second chamber 120 through the inlet channel 130 of the housing 100. The drilling fluid entering the first chamber 110 and the second chamber 120 can respectively drive the first turbine 210 of the first compressor 200 and the second turbine 310 of the second compressor 300 to rotate. The rotation of the first turbine 210 drives the first compression assembly 220 to work, and the rotation of the second turbine 310 drives the second compression assembly 320. The generated cooling capacity is used to cool the drilling instrument, ensuring its stable operation in ultra-high temperature well environments. Since the turbine diameter D1 of the first turbine 210 is small, it is more easily driven by the flow of drilling fluid. Therefore, when the drilling fluid pressure and flow rate are low, the first turbine 210 is driven to rotate first, thereby driving the first compression assembly 220 to work and starting the initial compression and cooling process. Because the second turbine 310 has a larger diameter D2, it requires drilling fluid with higher pressure and flow rate to drive it. As the drilling fluid pressure and flow rate gradually increase, the second compressor 300 is driven to rotate, generating a larger rotational torque. On the one hand, this avoids damage to the drilling instrument caused by high temperatures when the drilling fluid pressure or flow rate is low, as the turbine's hysteresis effect would prevent it from driving the turbine in the compressor to rotate for cooling. On the other hand, the cooling capacity generated through the two-stage compression cooling process is used to cool the drilling instrument, ensuring its stable operation in ultra-high temperature well environments. Simultaneously, the simultaneous operation of both compressors achieves efficient cooling under high temperature and high pressure conditions, providing a strong guarantee for the stable operation of the drilling instrument.
[0029] like Figure 1 As shown, in some embodiments, the housing 100 further includes a first control valve 140 and a second control valve 150. The first chamber 110 is connected to the inlet channel 130 via the first control valve 140, and the second chamber 120 is connected to the inlet channel 130 via the second control valve 150.
[0030] In this embodiment, by adding a first control valve 140 and a second control valve 150, the flow direction and flow rate of the drilling fluid can be precisely controlled, thereby optimizing cooling efficiency and improving the working performance and stability of the drilling instrument. When the first control valve 140 is open, the drilling fluid flows into the first chamber 110, driving the first turbine 210 transmission assembly to rotate, which in turn drives the first compression assembly 220 for initial cooling. When the second control valve 150 is open, the drilling fluid flows into the second chamber 120, driving the second turbine 310 transmission assembly to rotate, which drives the second compression assembly 320 for deeper cooling. By adjusting the opening degree of the first control valve 140 and the second control valve 150, the flow rate of the drilling fluid to each compressor can be precisely controlled, thereby adjusting the cooling effect and energy consumption. Under different downhole temperatures and operating conditions, the cooling efficiency can be optimized by adjusting the control valves. For example, when the temperature is not particularly high, only the first control valve 140 can be opened to use the first compressor 200 for cooling, saving energy. In ultra-high temperature environments, both control valves can be opened simultaneously, allowing both compressors to work at the same time and providing a stronger cooling effect. The addition of control valves also improves the safety and reliability of the system. In emergencies, the flow of drilling fluid can be cut off by quickly closing the control valves, preventing the system from overheating or being damaged.
[0031] like Figure 1 As shown, in some embodiments, the first chamber 110 includes a first receiving portion 111 and a second receiving portion 112 arranged sequentially. A first turbine 210 is disposed in the first receiving portion 111, and the first receiving portion 111 is connected to the liquid inlet channel 130 via a pipeline through a first control valve 140; the second chamber 120 includes a third receiving portion 121 and a fourth receiving portion 122 arranged sequentially, and a second turbine 310 transmission assembly includes a second turbine 310, which is disposed in the third receiving portion 121, and the third receiving portion 121 is connected to the liquid inlet channel 130 via a pipeline through a second control valve 150.
[0032] In this embodiment, drilling fluid enters the housing 100 through the inlet channel 130, and then, as needed, enters the first receiving portion 111 of the first chamber 110 and the third receiving portion 121 of the second chamber 120 through the first control valve 140 and the second control valve 150, respectively. In the first receiving portion 111, the drilling fluid directly impacts the first turbine 210, driving it to rotate. The rotation of the first turbine 210 then drives the first compression assembly 220 to perform preliminary compression and cooling. Simultaneously or independently, in the third receiving portion 121, the drilling fluid impacts the second turbine 310, driving it to rotate. The rotation of the second turbine 310 drives the second compression assembly 320 to perform deeper compression and cooling. The first receiving portion 111 and the third receiving portion 121 serve as the working chambers of the turbines, ensuring that the drilling fluid can effectively transfer energy to the turbines. The first compression assembly 220 is disposed in the second receiving section 112, and the second receiving section 112 is sealed to the first receiving section 111. The second compression assembly 320 is disposed in the fourth receiving section 122, and the third receiving section 121 is sealed to the fourth receiving section 122, while the second receiving section 112 is sealed to the first receiving section 111. Both the first chamber 110 and the second chamber 120 are divided into two successively disposed receiving sections, and each receiving section is connected to the fluid inlet channel 130 via an independent control valve. This design not only improves the modularity and maintainability of the system but also allows for more precise and efficient control of the drilling fluid flow and cooling process.
[0033] like Figure 1 As shown, in some embodiments, the housing 100 further includes a first drain channel 160 and a second drain channel 170. A first check valve 161 is provided in the first drain channel 160, and a second check valve 171 is provided in the second drain channel 170. The first drain channel 160 is connected to the first receiving portion 111, and the second drain channel 170 is connected to the third receiving portion 121.
[0034] In this embodiment, drilling fluid enters the first receiving section 111 from the inlet channel 130 through the first control valve 140, impacting the first turbine 210 and driving it to rotate. Subsequently, the drilling fluid is discharged through the first drain channel 160 and the first check valve 161, entering the next processing stage or being recycled. Similarly, drilling fluid can also enter the third receiving section 121 from the inlet channel 130 through the second control valve 150, impacting the second turbine 310 and driving it to rotate. Afterward, the drilling fluid is discharged through the second drain channel 170 and the second check valve 171. Due to the presence of the check valves, the drilling fluid can pass through the receiving section and impact the turbine more efficiently, thereby improving cooling efficiency and reducing energy consumption. The first check valve 161 and the second check valve 171 ensure unidirectional flow of the drilling fluid, allowing it to flow out of the receiving section but preventing backflow, thus maintaining system stability and cooling efficiency.
[0035] like Figure 1 As shown, in some embodiments, the first compressor 200 further includes a first turbine 210 drive shaft and a first turbine 210 bearing sleeved on the first turbine 210 drive shaft. The input end of the first turbine 210 drive shaft is connected to the first turbine 210, and the output end of the first turbine 210 drive shaft is connected to the first compressor 200 assembly. The first turbine 210 bearing is sleeved on the second receiving portion 112, and a first annular seal is provided between the circumferential sidewall of the first turbine 210 bearing and the second receiving portion 112.
[0036] In this embodiment, when drilling fluid enters the first receiving portion 111 through the first control valve 140 and impacts the first turbine 210, the turbine begins to rotate. The drive shaft of the first turbine 210 transmits the rotational power of the turbine to the first compressor 200 assembly, driving it to perform compression and refrigeration. A first annular seal is disposed between the circumferential sidewall of the bearing of the first turbine 210 and the second receiving portion 112, effectively preventing drilling fluid from entering the second receiving portion 112 and damaging the compression assembly.
[0037] like Figure 1 As shown in Figure 6, in some embodiments, the second compressor 300 further includes a second turbine 310 drive shaft and a second turbine 310 bearing sleeved on the second turbine 310 drive shaft. The input end of the second turbine 310 drive shaft is connected to the second turbine 310. The output end of the second turbine 310 drive shaft is connected to the second compressor 300 assembly. The second turbine 310 bearing is sleeved on the third receiving portion 121, and a second annular seal is provided between the circumferential sidewall of the second turbine 310 bearing and the third receiving portion 121.
[0038] In this embodiment, when drilling fluid enters the third containment 121 through the corresponding control valve, it impacts the second turbine 310, causing the turbine to start rotating. The drive shaft of the second turbine 310 transmits the rotational power of the turbine to the second compressor 300 assembly, driving it to perform compression and refrigeration. During this process, the second annular seal remains in a tight sealing state, ensuring that impurities do not seep into the third containment 121 and damage the compressor assembly.
[0039] like Figure 1-2 As shown, in some embodiments, both the first compression assembly 220 and the second compression assembly 320 are scroll-type compression assemblies. The scroll-type compression assembly includes a moving scroll 410, a stationary scroll 420, a bearing for the moving scroll 410, a first end cover 440, and a second end cover 450. The bearing for the moving scroll 410 is sleeved on the input shaft of the moving scroll 410 and is fixedly connected to the housing 100. The end face of the first end cover 440 is connected to the moving scroll 410, and the end face of the second end cover 450 is connected to the stationary scroll 420.
[0040] In this embodiment, the vortex compressor assembly has fewer main components and a compact structure, making it easy to manufacture and maintain. A compression chamber is formed between the moving vortex 410 and the stationary vortex 420. As the moving vortex 410 revolves, the volume of the compression chamber gradually decreases, thereby achieving gas compression.
[0041] like Figure 2 As shown, in some embodiments, a third annular seal is provided between the outer peripheral surface of the moving scroll 410 bearing and the housing 100.
[0042] In this embodiment, the third annular seal further blocks the drilling fluid, preventing it from damaging the compressor's compression components.
[0043] like Figure 2 As shown, in some embodiments, the outer peripheral surface of the first end cap 440 is provided with a first sealing groove, and / or the outer peripheral surface of the second end cap 450 is provided with a second sealing groove.
[0044] In this embodiment, the first and second sealing grooves are located on the outer peripheral surfaces of the first end cap 440 and the second end cap 450, respectively. They cooperate with corresponding sealing elements (such as O-rings, lip seals, etc.) to form an effective sealing barrier. The dimensions (such as width and depth) and shape (such as rectangular, trapezoidal, circular, etc.) of the sealing grooves need to be precisely designed according to the type and size of the sealing elements. Simultaneously, when drilling fluid enters the sealing groove, due to the surface tension of the liquid and the special design of the sealing groove, a liquid seal can be formed within the sealing groove. This liquid seal further prevents drilling fluid or other liquid media from penetrating into the compressor, thereby protecting the internal components of the compression assembly from damage.
[0045] This application also provides a drilling instrument, including the compressor device 1000 of any of the above embodiments. The drilling instrument provided by this invention has the technical effects of the compressor device 1000 in any of the above embodiments, and the explanations of the same or corresponding structures and terms as in the above embodiments will not be repeated here.
[0046] Although the invention has been described with reference to preferred embodiments, various modifications can be made and components can be replaced with equivalents without departing from the scope of the invention. In particular, the technical features mentioned in the various embodiments can be combined in any manner as long as there is no structural conflict. The invention is not limited to the specific embodiments disclosed herein, but includes all technical solutions falling within the scope of the claims.
Claims
1. A compressor unit for a drilling instrument cooling system, characterized in that, include: The housing includes a first chamber, a second chamber, and a liquid inlet channel, wherein the first chamber and the second chamber are respectively connected to the liquid inlet channel pipeline; A first compressor is installed in the first chamber. The first compressor includes a first turbine and a first compression assembly. The first turbine is drivenly connected to the first compression assembly. as well as A second compressor is installed in the first chamber. The second compressor includes a second turbine and a second compression assembly. The second turbine is drivenly connected to the second compression assembly. The turbine diameter D1 of the first turbine is smaller than the turbine diameter D2 of the second turbine.
2. The compressor unit of the drilling instrument cooling system according to claim 1, characterized in that, The housing also includes a first control valve and a second control valve. The first chamber is connected to the liquid inlet channel pipeline through the first control valve, and the second chamber is connected to the liquid inlet channel pipeline through the second control valve.
3. The compressor unit of the drilling instrument cooling system according to claim 2, characterized in that, The first chamber includes a first receiving part and a second receiving part arranged successively. The first turbine is disposed in the first receiving part. The first receiving part is connected to the liquid inlet channel through the first control valve via a pipeline. The second chamber includes a third and a fourth accommodating portion arranged sequentially, the second turbine being disposed in the third accommodating portion, and the third accommodating portion being connected to the inlet channel via a pipeline through the second control valve.
4. The compressor unit of the drilling instrument cooling system according to claim 3, characterized in that, The housing further includes a first drain channel and a second drain channel. A first check valve is provided in the first drain channel, and a second check valve is provided in the second drain channel. The first drain channel is connected to the first receiving portion, and the second drain channel is connected to the third receiving portion.
5. The compressor unit of the drilling instrument cooling system according to claim 4, characterized in that, The first compressor also includes a first turbine drive shaft and a first turbine bearing sleeved on the first turbine drive shaft. The input end of the first turbine drive shaft is connected to the first turbine, and the output end of the first turbine drive shaft is connected to the first compressor assembly. The first turbine bearing is sleeved on the second receiving portion, and a first annular seal is provided between the circumferential sidewall of the first turbine bearing and the second receiving portion.
6. The compressor unit of the drilling instrument cooling system according to claim 4, characterized in that, The second compressor further includes a second turbine drive shaft and a second turbine bearing sleeved on the second turbine drive shaft. The input end of the second turbine drive shaft is connected to the second turbine, and the output end of the second turbine drive shaft is connected to the second compressor assembly. The second turbine bearing is sleeved on the third receiving portion, and a second annular seal is provided between the circumferential sidewall of the second turbine bearing and the third receiving portion.
7. The compressor unit of the drilling instrument cooling system according to claim 1, characterized in that, Both the first compression assembly and the second compression assembly are scroll-type compression assemblies. The scroll-type compression assembly includes a moving scroll, a stationary scroll, a moving scroll bearing, a first end cover, and a second end cover. The moving scroll bearing is sleeved on the input shaft of the moving scroll and is fixedly connected to the housing. The end face of the first end cover is connected to the moving scroll, and the end face of the second end cover is connected to the stationary scroll.
8. The compressor unit of the drilling instrument cooling system according to claim 7, characterized in that, A third annular seal is provided between the outer circumferential surface of the moving scroll bearing and the housing.
9. The compressor unit of the drilling instrument cooling system according to claim 7, characterized in that, The outer peripheral surface of the first end cap is provided with a first sealing groove, and / or the outer peripheral surface of the second end cap is provided with a second sealing groove.
10. A drilling instrument, characterized in that, Includes the compressor device as described in any one of claims 1-9.