CN111335874B - Oil-gas well cementing cement packing capacity detection device and detection method thereof - Google Patents
Oil-gas well cementing cement packing capacity detection device and detection method thereof Download PDFInfo
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- CN111335874B CN111335874B CN202010200438.XA CN202010200438A CN111335874B CN 111335874 B CN111335874 B CN 111335874B CN 202010200438 A CN202010200438 A CN 202010200438A CN 111335874 B CN111335874 B CN 111335874B
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Abstract
The application provides a detection device and a detection method for cementing cement packing capacity of an oil-gas well, wherein the detection device comprises: a simulated formation having a simulated wellbore disposed therein; the simulation casing is arranged in the simulation borehole in a penetrating mode; a first annular space is formed between the simulation casing and the simulation stratum; the simulation sleeve is provided with at least one first through hole communicated with the first annular space; well cementation cement, it packs in the first annular space; the piston is arranged in the simulation sleeve in a penetrating way; a second annular space can be formed between the piston and the simulation sleeve; a first channel communicated with the first through hole is arranged in the piston; a pressure loading mechanism in communication with the second annular space; for applying pressure into the second annular space; an earth stress simulation mechanism for applying earth stress to the simulated formation, the simulated casing and the cementing cement; the application embodiment provides an oil and gas well cementing cement packing capacity detection device capable of measuring the longitudinal packing capacity of a cement sheath and a detection method thereof.
Description
Technical Field
The application relates to a detection device and a detection method for cementing cement packing capacity of an oil-gas well.
Background
The well cementation cement is used for firmly consolidating the casing string and the rock on the well wall, and can pack oil, gas and water layers and complex layers to be beneficial to further drilling or exploitation. The cement sheath with good cementation can effectively reduce the deformation risk of the casing, can prevent oil-gas water from entering a simulated shaft or jumping up along the annulus, can prolong the service life of one well and increase the yield, and is an important factor for measuring the well cementation quality. And the underground operation of oil field production after well cementation, especially the technical construction such as fracturing and acidizing, can cause the pressure in the simulated shaft to fluctuate by a wide margin, and then influence cement sheath stress state, increase the risk that cement sheath packing ability became invalid.
The cement sheath packing capacity includes a longitudinal packing capacity. Specifically, the longitudinal packing capability of the cement sheath refers to the capability of preventing oil, gas and water from channeling upwards along two interfaces of a well cementation, and the main failure mode is that when the cementing interface is changed from a pressed state to a pulled state, the acting force of the interface is opposite to the direction of cementing force, so that the cementing interface is separated, and the packing failure of the cement sheath is caused. The influence factors of the packing capacity of the cement sheath are complex, and the actual underground condition is difficult to observe, so that the establishment of a set of detection device for the packing capacity of the cement sheath has important significance for researching the change mechanism of the packing capacity of the cement sheath along with the fluctuation of the internal pressure. Most of the existing researches on the packing capacity of the cement sheath are from the viewpoint of simulating the integrity of a wellbore or the sealing performance of the cement sheath, and the researches on the longitudinal packing capacity of the cement sheath are less.
Therefore, it is necessary to provide a device and a method for detecting cementing cement packing capacity of an oil and gas well, so as to solve the above problems.
Disclosure of Invention
In view of this, the embodiment of the present application provides an oil and gas well cementing cement packing capability detection device capable of measuring the longitudinal packing capability of a cement sheath and a detection method thereof.
In order to achieve the purpose, the application provides the following technical scheme: a detection device for cementing cement packing capacity of an oil and gas well comprises: the simulated formation is internally provided with a simulated borehole extending along the up-down direction; a simulation casing disposed through the simulation wellbore; a first annular space is formed between the simulation casing and the simulation stratum; the simulation sleeve is provided with at least one first through hole communicated with the first annular space; a cementing cement filled within the first annular space; a first interface is formed between the well cementation cement and the simulation casing; a second interface is formed between the well cementation cement and the simulated formation; the piston is movably arranged in the simulation sleeve in a penetrating way; the piston can form a second annular space with the simulation sleeve; a first channel communicated with the first through hole is arranged in the piston; to enable high pressure gas to flow through the first passage to the first interface or the second interface; a pressure loading mechanism in communication with the second annular space; for applying pressure into said second annular space; an geostress simulation mechanism for applying a geostress to the simulated formation, the simulated casing, and the cementing cement.
In a preferred embodiment, a second through hole is formed in the well cement; the number of the first through holes is two; one of the first through holes is not communicated with the second through hole; the other first through hole is communicated with the second through hole in a sealing way; one end of the second through hole, which is back to the first through hole, is opened towards the simulated formation.
As a preferred embodiment, a pipe body having the second through hole is provided in the well cement; one end of the pipe body is connected to the side wall around the outer end of the other first through hole in a sealing mode.
As a preferred embodiment, the piston includes a reduced diameter section and an enlarged diameter section having a larger cross-sectional area than the reduced diameter section; the diameter expanding section is positioned below the diameter reducing section; the second annular space is formed between the reducing section and the simulation sleeve; the outer wall of the diameter expanding section is in sealing fit with the inner wall of the simulation sleeve.
As a preferred embodiment, the first channel comprises a vertically extending section disposed in the reduced diameter section and a horizontally extending section disposed in the enlarged diameter section; one end of the horizontal extension section, which is back to the vertical extension section, is communicated with the first through hole.
As a preferred embodiment, a pressing cap for sealing the second annular space is further arranged in the upper end of the simulation sleeve; a second channel communicated with the second annular space is arranged on the pressing cap; the pressure loading mechanism is in communication with the second annular space through the second passage.
In a preferred embodiment, the pressing cap is in a ring shape with a central hole; the piston is arranged in the central hole in a sealing mode in a penetrating mode.
A detection method utilizing the oil and gas well cementing cement packing capacity detection device comprises the following steps: step S11: applying, by the ground stress simulation mechanism, ground stress to the simulated formation, the simulated casing, and the cementing cement; step S13: communicating the first passage with the first through hole and forming the second annular space between the piston and the simulation sleeve; step S15: applying pressure into the second annular space by the pressure loading mechanism until the pressure in the second annular space rises to a first current loading pressure; step S17: depressurizing said second annular space to reduce the pressure in said second annular space to substantially equal atmospheric pressure; step S19: injecting high pressure gas into the first channel so that the high pressure gas can flow to the first interface between the well cementation cement and the simulation casing through a first through hole; and judging whether the high-pressure gas can leak from the first interface between the well cementation cement and the simulation casing; step S21: when there is no gas leakage at the first interface between the cementing cement and the simulation casing, increasing a predetermined pressure on the basis of the first current loading pressure and repeating the above steps S15 to S19.
As a preferred embodiment, the method further comprises: step S21: moving the piston to place the first channel in communication with the other first through hole and to form the second annular space between the piston and the simulation sleeve; wherein, a second through hole is arranged in the well cementation cement; the other first through hole is communicated with the second through hole in a sealing way; one end of the second through hole, which is back to the first through hole, is opened towards the simulated formation; step S23: applying pressure into the second annular space by the pressure loading mechanism until the pressure in the second annular space rises to a second current loading pressure; step S25: depressurizing said second annular space to reduce the pressure in said second annular space to substantially equal atmospheric pressure; step S27: injecting high-pressure gas into the first channel so that the high-pressure gas can flow to the second interface between the well cementation cement and the simulated formation through a second through hole; and judging whether the high-pressure gas can leak from the second interface between the well cementation cement and the simulated formation; step S29: when there is no gas leakage at the second interface between the cementing cement and the simulated formation, increasing a predetermined pressure based on the second current loading pressure and repeating the above steps S23 to S27.
As a preferred embodiment, true triaxial stress is applied to the simulated formation, the simulated casing and the cementing cement by the ground stress simulation mechanism.
By means of the technical scheme, the oil and gas well cementing cement packing capacity detection device and the detection method thereof have the advantages that the simulated stratum, the simulated casing, the cementing cement, the piston, the pressure loading mechanism and the ground stress simulation mechanism are arranged, so that ground stress can be applied to the simulated stratum, the simulated casing and the cementing cement through the ground stress simulation mechanism during detection, and the real stratum is simulated; and the pressure loading mechanism applies pressure to the sealed second annular space, so that the change of the pressure in the second annular space can approximately reflect the fluctuation of the pressure in the simulated casing, and the fluctuation of the pressure in the simulated casing can be used for simulating the underground operation in the actual production of the oil field after the well cementation is finished, such as the fluctuation of the pressure in the shaft of the oil field caused by the technical construction of fracturing, acidizing and the like. And the pressure fluctuation in the oil field well bore can influence the stress state of the cement sheath outside the oil field well bore. Thus a change in pressure in the second annular space will affect the stress state of the cement being cemented. Finally, injecting high-pressure gas between the well cementation cement and the simulation casing through a first channel in the piston so as to detect the cementing capacity of a first interface between the well cementation cement and the simulation casing; and injecting high-pressure gas between the well cementation cement and the simulated formation through the first channel in the piston to detect the cementing capacity of a second interface between the well cementation cement and the simulated formation, so that the longitudinal packing capacity of the well cementation cement is detected. Therefore, the embodiment of the application provides an oil and gas well cementing cement packing capacity detection device capable of measuring the longitudinal packing capacity of a cement sheath and a detection method thereof.
Drawings
The drawings described herein are for illustration purposes only and are not intended to limit the scope of the present disclosure in any way. In addition, the shapes, the proportional sizes, and the like of the respective members in the drawings are merely schematic for assisting the understanding of the present application, and are not particularly limited to the shapes, the proportional sizes, and the like of the respective members in the present application. Those skilled in the art, having the benefit of the teachings of this application, may select various possible shapes and proportional sizes to implement the present application, depending on the particular situation. In the drawings:
FIG. 1 is a schematic structural diagram of a device for detecting cementing cement packing capacity of an oil and gas well according to an embodiment of the present application;
FIG. 2 is a flow chart of a detection method of the detection device for the cementing cement packing capacity of the oil and gas well according to the embodiment of the application.
Description of reference numerals:
11. simulating a formation; 13. simulating a borehole; 15. simulating a casing; 17. a first annular space; 19. a first through hole; 21. cementing cement; 29. a piston; 31. a first channel; 33. a second annular space; 35. a second through hole; 37. a reducing section; 39. a diameter expanding section; 41. pressing the cap; 43. a second channel; 45. a central bore.
Detailed Description
The technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the drawings in the embodiments of the present application, and it is obvious that the described embodiments are only a part of the embodiments of the present application, and not all of the embodiments. All other embodiments obtained by a person of ordinary skill in the art without any inventive work based on the embodiments in the present application are within the scope of protection of the present application.
Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs. The terminology used herein in the description of the present application is for the purpose of describing particular embodiments only and is not intended to be limiting of the application.
Referring to fig. 1, the present embodiment provides a device for detecting cementing cement packing capacity of an oil and gas well, including: a simulated formation 11 in which a simulated borehole 13 extending in the vertical direction is provided; a simulation casing 15 which is arranged in the simulation borehole 13; a first annular space 17 is formed between the simulation casing 15 and the simulated formation 11; the simulation sleeve 15 is provided with at least one first through hole 19 communicated with the first annular space 17; cementing cement 21 filled in the first annular space 17; a first interface is formed between the cementing cement 21 and the simulation casing 15; a second interface is formed between the cementing cement 21 and the simulated formation 11; a piston 29 movably disposed through the dummy sleeve 15; the piston 29 can form a second annular space 33 with the dummy sleeve 15; a first channel 31 communicated with the first through hole 19 is arranged in the piston 29; so that high pressure gas can flow through the first passage 31 to the first interface or the second interface; a pressure loading mechanism in communication with said second annular space 33; for applying pressure into said second annular space 33; an earth stress simulation mechanism for applying an earth stress to the simulated formation 11, the simulated casing 15 and the cementing cement 21.
According to the scheme, the device for detecting the packing capacity of the cementing cement 21 of the oil and gas well has the advantages that the simulated formation 11, the simulated casing 15, the cementing cement 21, the piston 29, the pressure loading mechanism and the ground stress simulation mechanism are arranged, so that ground stress can be applied to the simulated formation 11, the simulated casing 15 and the cementing cement 21 through the ground stress simulation mechanism during detection, and a real formation can be simulated; and the pressure loading mechanism applies pressure to the sealed second annular space 33, so that the change of the pressure in the second annular space 33 can approximately reflect the fluctuation of the pressure in the simulated casing 15, and the fluctuation of the pressure in the simulated casing 15 can be used for simulating the downhole operation in the actual production of the oil field after the well cementation is finished, such as the fluctuation of the pressure in the shaft of the oil field caused by the technical construction of fracturing, acidizing and the like. And the pressure fluctuation in the oil field well bore can influence the stress state of the cement sheath outside the oil field well bore. Thus a change in pressure in the second annular space 33 will affect the stress state of the cement 21. Finally, injecting high-pressure gas between the cementing cement 21 and the simulation casing 15 through a first passage 31 in the piston 29 to detect the cementing capacity of a first interface between the cementing cement 21 and the simulation casing 15; and injecting high-pressure gas between the well cementation cement 21 and the simulated formation 11 through a first channel 31 in the piston 29 to detect the cementing capacity of a second interface between the well cementation cement 21 and the simulated formation 11, thereby detecting the longitudinal packing capacity of the well cementation cement 21.
As shown in fig. 1, in the present embodiment, the simulated formation 11 is used to simulate a formation in which a well cementation cement 21 to be measured is located. Specifically, the simulated formation 11 may be configured according to geological and physical parameters of the formation where the well cement 21 to be measured is located. Further, the simulated formation 11 may be configured with cement, quartz sand, special additives. Further, a simulated borehole 13 extending in the up-down direction is provided in the simulated formation 11. The simulated borehole 13 is used to simulate a borehole in the formation where the cementing cement 21 to be measured is located.
In the present embodiment, the dummy casing 15 is inserted into the dummy wellbore 13. And a first annular space 17 is formed between the simulated casing 15 and the simulated formation 11. So that cement can be injected into this first annular space 17 to form a cement sheath, so that a simulated wellbore for simulating the location of the cementing cement 21 to be measured is formed between the cement sheath and the simulated casing 15. Further, the dummy sleeve 15 is provided with at least one first through hole 19 communicating with the first annular space 17. The first through hole 19 is for allowing fluid to pass through. In this embodiment, there are two first through holes 19. For example, as shown in fig. 1, two first through holes 19 are arranged in the vertical direction. Of course, the two first through holes 19 are not limited to being arranged in the vertical direction, and may be arranged in the circumferential direction, and this is not intended to limit the present invention.
In the present embodiment, the cement 21 is filled in the first annular space 17. So that on the one hand the cementing cement 21 forms a cement sheath in the first annular space 17. On the other hand, the cementing cement 21 can firmly consolidate the simulated casing 15 and the simulated formation 11 together. Specifically, a first interface is formed between the cementing cement 21 and the simulation casing 15. The cementing cement 21 forms a second interface with the simulated formation 11. Further, the cement 21 may be configured according to the characteristics of the cement 21 to be applied in the field.
In one embodiment, a second through hole 35 is provided in the cement 21. For example, as shown in fig. 1, the second through hole 35 extends in the radial direction and penetrates the cement 21. Further, one of the two first through holes 19 is not communicated with the second through hole 35. For example, as shown in fig. 1, the first through hole 19 and the second through hole 35 located below do not communicate with each other. So that the gas in the lower first through hole 19 does not enter the second through hole 35, i.e. the gas in the lower first through hole 19 can only reach the first interface. So that the gas in the first through going hole 19 below is only located between the cementing cement 21 and the first interface of the simulation casing 15. And when the first interface between the well cement 21 and the simulation casing 15 is poorly cemented, gas in the lower first through hole 19 can be leached at the first interface between the well cement 21 and the simulation casing 15. And the other first through hole 19 is in sealed communication with the second through hole 35. For example, as shown in fig. 1, the first through hole 19 located above and the second through hole 35 are in sealed communication. So that the gas in the upper first through hole 19 can enter the second through hole 35, i.e. the gas in the upper first through hole 19 can reach the second interface. And when the second interface between the well cement 21 and the simulated formation 11 is poorly cemented, the gas in the upper first through hole 19 can be leached at the first interface between the well cement 21 and the simulated formation 11. Further, one end of the second through hole 35 facing away from the first through hole 19 is opened toward the simulated formation 11. For example, as shown in fig. 1, the right end of the second through hole 35 is open to the pseudo formation 11.
In one embodiment, the cement 21 is provided with a tube having a second through hole 35 therein. One end of the tube is sealingly connected to the side wall around the outer end of the other first through hole 19. For example, as shown in fig. 1, the left end of the tube is sealingly connected to the sidewall around the outer end of the first through-hole 19 located above. In particular, the sealing connection may be a weld, an integral molding, or the like.
In this embodiment, the piston 29 is movably disposed through the dummy cartridge 15. For example, as shown in fig. 1, the piston 29 can be rotated in the vertical direction inside the dummy pipe 15. The piston 29 can form a second annular space 33 with the dummy sleeve 15. This second annular space 33 is used to apply varying pressure into the simulation casing 15 to simulate fluctuations in pressure in the wellbore of the oil field caused by technical work, such as fracturing, acidizing, etc., performed in the actual production of the oil field after cementing is completed.
In one embodiment, the piston 29 includes a reduced diameter section 37 and an enlarged diameter section 39 having a larger cross-sectional area than the reduced diameter section 37, with the enlarged diameter section 39 being located below the reduced diameter section 37. The reduced diameter section 37 forms a second annular space 33 with the dummy sleeve 15. The outer wall of the expanded diameter section 39 is in sealing engagement with the inner wall of the dummy casing 15. So that on the one hand fluid between the piston 29 and the dummy cartridge 15 cannot flow into the first through-opening 19; on the other hand, the lower end of the second annular space 33 formed between the reduced diameter section 37 and the dummy sleeve 15 can be sealed by the upper end surface of the enlarged diameter section 39, so as to prevent the fluid in the second annular space 33 from flowing downward, thereby facilitating accurate control of the pressure in the second annular space 33.
In the present embodiment, a first passage 31 for communicating with the first through hole 19 is provided in the piston 29. So that the fluid can be injected into the first through hole 19 through the first passage 31. Further, the aperture of the first passage 31 is substantially equal to the aperture of the first through hole 19. That is, the first channel 31 can communicate with only one first through hole 19 at a time, and cannot communicate with all first through holes 19 at a time. For example, as shown in fig. 1, the first channel 31 can communicate only with the first through hole 19 located below, but cannot communicate with the first through hole 19 located above. Thus, the first passage 31 can inject the fluid only into the first through hole 19 located below, but cannot inject the fluid into the first through hole 19 located above. Furthermore, the fluid in the first channel 31 can only reach the first interface through the first through hole 19, but not reach the second interface, so that the cementation of the first interface can only be detected by the fluid. Further, when the first channel 31 can only communicate with the first through hole 19 located above but cannot communicate with the first through hole 19 located below, the first channel 31 can only inject fluid into the first through hole 19 located above but cannot inject fluid into the first through hole 19 located below. Furthermore, the fluid in the first channel 31 can only reach the second interface through the first through hole 19, but not reach the first interface, so that the cementation of the second interface can only be detected by the fluid. This prevents the first channel 31 from communicating with the two first through holes 19 at the same time, which prevents the first interface and the second interface from being bonded together.
Further, the first channel 31 comprises a vertically extending section arranged in the reduced diameter section 37 and a horizontally extending section arranged in the enlarged diameter section 39. For example, as shown in fig. 1, the vertically extending section is located above the horizontally extending section. So that fluid can be injected into the horizontally extending section through the vertically extending section. Further, one end of the horizontal extension segment facing away from the vertical extension segment is used for communicating with the first through hole 19. As shown in fig. 1, the right end of the horizontally extending section is adapted to communicate with the first through hole 19. Further, in operation, the piston 29 is moved in the up-and-down direction so that the right end of the horizontally extending section can communicate with one of the first through holes 19.
In the present embodiment, the pressure loading mechanism communicates with the second annular space 33. The pressure loading mechanism is used to apply pressure into the second annular space 33. Therefore, variable pressure can be formed in the second annular space 33, and further downhole operation in actual production of the oil field after well cementation, such as pressure fluctuation in the shaft of the oil field caused by technical construction such as fracturing and acidizing, can be simulated. And the pressure fluctuation in the oil field well bore can influence the stress state of the cement sheath outside the oil field well bore. Thus a change in pressure in the second annular space 33 will affect the stress state of the cement 21. Further, the pressure loading mechanism may be a booster pump.
In one embodiment, a gland 41 for sealing the second annular space 33 is also provided within the upper end of the dummy sleeve 15. The pressing cap 41 is provided with a second passage 43 communicating with the second annular space 33. The pressure loading mechanism communicates with the second annular space 33 through a second passage 43. So that a sealed second annular space 33 can be formed by the gland 41, the piston 29 and the dummy sleeve 15. Further, as shown in fig. 1, a second passage 43 is provided on the right end of the pressure cap 41. And the outer end of the second channel 43 is adapted to be connected to a pressure loading mechanism so that the pressure loading mechanism can apply a varying pressure into the second annular space 33 through the second channel 43.
Further, the pressing cap 41 has a ring shape with a central hole 45. The outer wall of the annular gland 41 is in sealing engagement with the inner wall of the dummy sleeve 15. The piston 29 is sealingly disposed through the central bore 45. So that the gland 41 can seal the second annular space 33.
In the present embodiment, the ground stress simulation mechanism is used to apply ground stress to the simulated formation 11, the simulated casing 15, and the cementing cement 21. Further, the ground stress simulation mechanism is a true triaxial stress kettle. Therefore, the ground stress simulation mechanism can truly simulate the stress on the stratum where the well cementation cement 21 to be measured is located.
As shown in fig. 2, the present application further provides a detection method using the above detection device for the packing capacity of cementing cement 21 in an oil and gas well, which includes: step S11: applying an earth stress to the simulated formation 11, the simulated casing 15 and the cementing cement 21 by the earth stress simulation mechanism; step S13: placing the first channel 31 in communication with the first through hole 19 and the second annular space 33 between the piston 29 and the dummy sleeve 15; step S15: applying pressure into the second annular space 33 by the pressure loading mechanism; step S17: when the pressure in the second annular space 33 is at the first current loading pressure; depressurizing said second annular space 33 until the pressure in said second annular space 33 is substantially equal to atmospheric pressure; step S19: injecting high pressure gas into the first channel 31 to enable the high pressure gas to flow through the first through hole 19 to the first interface between the well cement 21 and the simulation casing 15; and judging whether the high-pressure gas can leak from a first interface between the well cementation cement 21 and the simulation casing 15; step S21: when there is no gas leakage at the first interface between the cementing cement 21 and the simulation casing 15, the first current loading pressure is increased by a predetermined pressure and the above steps S15 to S19 are repeated.
According to the scheme, the detection method utilizing the oil-gas well cementing cement 21 packing capacity detection device applies the ground stress to the simulated stratum 11, the simulated casing 15 and the cementing cement 21 through the ground stress simulation mechanism so as to simulate a real stratum; and the pressure loading mechanism applies pressure to the sealed second annular space 33, so that the change of the pressure in the second annular space 33 can approximately reflect the fluctuation of the pressure in the simulated casing 15, and the fluctuation of the pressure in the simulated casing 15 can be used for simulating the downhole operation in the actual production of the oil field after the well cementation is finished, such as the fluctuation of the pressure in the shaft of the oil field caused by the technical construction of fracturing, acidizing and the like. And the pressure fluctuation in the oil field well bore can influence the stress state of the cement sheath outside the oil field well bore. Thus a change in pressure in the second annular space 33 will affect the stress state of the cement 21. Finally, injecting high-pressure gas between the cementing cement 21 and the simulation casing 15 through a first passage 31 in the piston 29 to detect the cementing capacity of a first interface between the cementing cement 21 and the simulation casing 15; and injecting high-pressure gas between the well cementation cement 21 and the simulated formation 11 through a first passage 31 in the piston 29 to detect the cementing capability of a second interface between the well cementation cement 21 and the simulated formation 11, thereby detecting the longitudinal packing capability of the well cementation cement 21.
In the present embodiment, step S11: the ground stress is applied to the simulated formation 11, the simulated casing 15 and the cementing cement 21 by a ground stress simulation mechanism. Specifically, true triaxial stress is applied to the simulated formation 11, the simulated casing 15 and the cement 21 by the ground stress simulation mechanism. More specifically, a true triaxial stress kettle may be employed to apply true triaxial stress to the simulated formation 11, the simulated casing 15, and the cement 21. Furthermore, the confining pressure of 0.8MPa can be set in the true triaxial stress kettle for force application.
Further, at step S11: applying the ground stress to the simulated formation 11, the simulated casing 15 and the cementing cement 21 by a ground stress simulation mechanism, previously comprising:
step S5: manufacturing a simulated stratum 11; wherein, the simulated stratum 11 is provided with a simulated borehole 13;
step S7: running a simulated casing 15 into a simulated borehole 13 of a simulated formation 11; wherein, the simulation sleeve 15 is provided with at least one first through hole 19;
step S9: a first annular space 17 between the simulated casing 15 and the simulated formation 11 is filled with a cementing cement 21.
Specifically, in step S5, the simulated formation 11 may be configured by cement, quartz sand, and special additives according to geological and physical parameters of the formations in different regions. Further, the simulated formation 11 may be a cube with a side length of 400mm or 300 mm. Further, the specific dimensions of the simulated formation 11 may be adjusted accordingly based on experimental equipment, conditions, and study scale. Further, a cylindrical space with a diameter of 90mm and a length of 350mm is left in the middle of the simulated formation 11 to serve as the simulated borehole 13. Specifically, the process of making the simulated borehole 13 can adopt the following two methods: firstly, reserving the position of a simulated borehole 13 in the manufacturing process of the simulated formation 11; second, a borehole is drilled in the completed simulated formation 11 to simulate the actual drilling process.
Further, in step S7, a simulated casing 15 is first lowered into the simulated wellbore 13 simulating the formation 11. Then, two first through holes 19 are drilled in the lower end of the dummy casing 15 in the up-down direction. Further, a first through hole 19 is provided at a lower end position of the dummy pipe 15. The first through hole 19 is 4cm to 5cm from the bottom of the dummy pipe 15. The second first through-hole 19 is provided above the first through-hole 19. Of course, the two first through holes 19 may be provided in the circumferential direction.
Further, in step S9, in order to form the second through hole 35 in the cement 21, a cylindrical tube made of plastic or steel pipe having an inner diameter of about 2mm and an outer diameter of about 2.5mm may be stuck between the pseudo casing 15 and the pseudo ground layer 11 in step S7. Further, the number of the cylindrical barrels may be two. The two cylinders can be symmetrically arranged at two ends of the simulation sleeve 15, or the corresponding positions can be changed according to actual needs, then the simulation sleeve 15 is provided with a first through hole 19 at the corresponding position, and a first through hole 19 is drilled below the first through hole 19 which is just drilled.
Further, in step S9, the cementing cement 21 is formed by injecting cement between the simulated casing 15 and the simulated formation 11 so that the cement can firmly consolidate the simulated casing 15 and the simulated formation 11 together. Because two cylinders are arranged at two ends of the simulation sleeve 15; therefore, after the well cementation cement 21 is formed, the well cementation cement 21 is wrapped around the cylindrical barrel; the cylindrical barrel thus forms a second through-hole 35 in the cement 21.
In the present embodiment, step S13: the first passage 31 is made to communicate with the first through hole 19 and the second annular space 33 is formed between the piston 29 and the dummy sleeve 15. Specifically, the piston 29 is fitted into the dummy cartridge 15, and the outlet at the lower end of the first passage 31 in the piston 29 communicates with the first through hole 19 at the lowermost end, and the dummy cartridge 15 is sealed with the press cap 41. So that a sealed second annular space 33 is formed between the gland 41, the piston 29 and the dummy sleeve 15.
In the present embodiment, step S15: pressure is applied to the second annular space 33 by the pressure loading mechanism until the pressure in the second annular space 33 rises to the first current loading pressure. Specifically, a pressure loading mechanism is connected to the outer end of the second passage 43 in the pressure cap 41 to apply pressure into the second annular space 33. Further, a gradually increasing pressure may be applied into the second annular space 33 by a pressure loading mechanism. For example, the first initial pressure within the second annular space 33 is approximately equal to atmospheric pressure. The application of a gradually increasing pressure into the second annular space 33 by the pressure loading mechanism causes the pressure in the second annular space 33 to rise to 2 Mpa. Since the production of the oil field after completion of cementing is performed by downhole operations, such as fracturing, acidizing, etc., which cause fluctuations in the pressure in the well casing and thereby affect the cement sheath stress state, the effect of the downhole operations performed on the production of the oil field after completion of actual cementing on the cement sheath is simulated by applying pressure to the second annular space 33. Since the pressure in the oil well casing is generally increased and then decreased during the construction of the downhole operation, such as fracturing, acidizing, etc., step S15 is used to simulate the process of increasing the pressure in the oil well casing.
In the present embodiment, step S17: the second annular space 33 is depressurized so that the pressure in the second annular space 33 is reduced to substantially equal atmospheric pressure. Specifically, after the internal pressure of the dummy tube 15 reached 2MPa and the holding time reached 1 hour, pressure release was performed to reduce the pressure inside the dummy tube 15 to atmospheric pressure. The step S17 is to simulate the process of decreasing the pressure in the oil well casing, so that the process of changing the pressure in the oil well casing during the construction process can be completely simulated through the steps S15 and S17.
In the present embodiment, step S19: injecting high pressure gas into the first channel 31 so that the high pressure gas can flow to a first interface between the well cement 21 and the simulation casing 15 through the first through hole 19; and judges whether or not high-pressure gas can leak from the first interface between the cementing cement 21 and the dummy casing 15. Specifically, the inlet at the upper end of the first passage 31 of the piston 29 is first connected to high-pressure gas. The outer wall of the expanding section 39 at the lower end of the piston 29 is tightly fitted with the inner wall of the dummy pipe 15. The high-pressure gas in the first passage 31 cannot flow out from the outlet at the lower end of the first passage 31 of the piston 29. Subsequently, the piston 29 is rotated or moved up and down so that the outlet at the lower end of the first passage 31 of the piston 29 can communicate with the first through hole 19 at the lowermost end of the dummy pipe 15, and at this time, the outlet at the lower end of the first passage 31 of the piston 29 can communicate with the first interface. If the packing capacity of the first interface is poor, high-pressure gas can be caused to directly flow from the first interface to the upper end of the packing capacity detection device of the cementing cement 21 of the oil-gas well. Furthermore, the pumping pressure of the high-pressure gas is set to be 0.8MPa, which is equivalent to the detection of 16MPa on site. Further, the presence or absence of a gas leak may be detected at the upper end of the first interface by a gas flow meter. Or the presence or absence of gas leakage may be detected at the upper end of the first interface by the naked eye.
In the present embodiment, step S21: when there is no gas leakage between the cementing cement 21 and the simulation casing 15, a predetermined pressure is increased on the basis of the first current loading pressure and the above-described steps S15 to S19 are repeated. Since high pressure gas can leak out from between the cementing cement 21 and the simulation casing 15 after the first interface between the cementing cement 21 and the simulation casing 15 fails. It is therefore indicated that the cementing capability of the first interface between the cementing cement 21 and the simulation casing 15 has not failed when there is no gas leak between the cementing cement 21 and the simulation casing 15. It is therefore necessary to repeat steps S15 to S19 until there is a gas leak between the cement 21 and the simulation casing 15. It is necessary to increase the predetermined pressure based on the first current loading pressure before repeating the steps S15 to S19, so that the first current loading pressure in the process of repeating the steps S15 to S19 next time is increased by the predetermined pressure compared to the first current loading pressure in the steps S15 to S19 last time, that is, after the cementing capability of the first interface between the cementing cement 21 and the simulation casing 15 is not failed, the second annular space 33 is pressurized with the larger first current loading pressure, so that the cementing capability of the first interface between the cementing cement 21 and the simulation casing 15 is failed. Of course, to ensure the accuracy of the experiment, the predetermined pressure should not be too great to ensure an accurate pressure gradient.
Further, the detection method of the device for detecting the packing capacity of the cementing cement 21 in the oil and gas well according to the embodiment of the application further comprises the following steps:
step S21: moving the piston 29 so that the first channel 31 communicates with the further first through hole 19 and so that a second annular space 33 is formed between the piston 29 and the simulation sleeve 15; wherein, a second through hole 35 is arranged in the well cementation cement 21; the other first through hole 19 is in sealed communication with the second through hole 35; one end of the second through hole 35 facing away from the first through hole 19 is open toward the simulated formation 11. Specifically, the piston 29 is rotated or moved in the vertical direction so that the outlet at the lower end of the first passage 31 of the piston 29 can communicate with the uppermost first through hole 19 of the dummy cartridge 15, and at this time, the outlet at the lower end of the first passage 31 of the piston 29 can communicate with the second interface through the second through hole 35.
Step S23: pressure is applied to the second annular space 33 by the pressure loading mechanism until the pressure in the second annular space 33 rises to a second current loading pressure. Specifically, a pressure loading mechanism is connected to the outer end of the second passage 43 in the pressure cap 41 to apply pressure into the second annular space 33. Further, a gradually increasing pressure may be applied into the second annular space 33 by a pressure loading mechanism. For example, the second initial pressure within the second annular space 33 is approximately equal to atmospheric pressure. The application of a gradually increasing pressure into the second annular space 33 by the pressure loading mechanism causes the pressure in the second annular space 33 to rise to 2 Mpa. Since the production of the oil field after completion of cementing is performed by downhole operations, such as fracturing, acidizing, etc., which cause fluctuations in the pressure in the well casing and thereby affect the cement sheath stress state, the effect of the downhole operations performed on the production of the oil field after completion of actual cementing on the cement sheath is simulated by applying pressure to the second annular space 33. Since the pressure in the oil well casing is generally increased and then decreased during the construction of the downhole operation, such as fracturing, acidizing, etc., step S23 is used to simulate the process of increasing the pressure in the oil well casing.
Step S25: the second annular space 33 is depressurized so that the pressure in the second annular space 33 is reduced to substantially equal atmospheric pressure. Specifically, after the internal pressure of the dummy tube 15 reached 2MPa and the holding time reached 1 hour, pressure release was performed to reduce the pressure inside the dummy tube 15 to atmospheric pressure. The step S25 is to simulate the process of decreasing the pressure in the oil well casing, so that the process of changing the pressure in the oil well casing during the construction process can be completely simulated through the steps S23 and S25.
Step S27: injecting high pressure gas into the first channel 31 so that the high pressure gas can flow to a second interface between the well cement 21 and the simulated formation 11 through the second through hole 35; and determines whether high pressure gas can leak from the second interface between the cement 21 and the simulated formation 11. The outlet at the lower end of the first passage 31 due to the piston 29 can communicate with the second interface through the second through hole 35; so if the packing capacity of the second interface is poor, high-pressure gas can be caused to directly flow from the second interface to the upper end of the packing capacity detection device of the cementing cement 21 of the oil-gas well. Furthermore, the pumping pressure of the high-pressure gas is set to be 0.8MPa, which is equivalent to the detection of 16MPa on site. Further, the presence or absence of a gas leak may be detected at the upper end of the second interface by a gas flow meter. Or the presence or absence of gas leakage can be detected at the upper end of the second interface by the naked eye.
Step S29: when there is no gas leakage at the second interface between the cementing cement 21 and the simulated formation 11, a predetermined pressure is increased on the basis of the second current loading pressure and the above-described steps S23 to S27 are repeated. Since high pressure gas can leak out from between the well cement 21 and the simulated formation 11 when the cementing capability of the second interface between the well cement 21 and the simulated formation 11 is lost. It is therefore indicated that the cementing capability of the second interface between the cementing cement 21 and the simulated formation 11 has not failed when there is no gas leak between the cementing cement 21 and the simulated formation 11. It is therefore necessary to repeat steps S23 to S27 until there is a gas leak between the cement 21 and the simulated formation 11. It is necessary to increase the predetermined pressure based on the second current loading pressure before repeating the steps S23 to S27, so that the second current loading pressure in the process of repeating the steps S23 to S27 next time is increased by the predetermined pressure compared to the second current loading pressure in the steps S23 to S27 last time, that is, after the cementing capability of the second interface between the well cement 21 and the simulated formation 11 is not failed, the second annular space 33 is pressurized with the second current loading pressure which is larger so that the cementing capability of the second interface between the well cement 21 and the simulated formation 11 is failed. Of course, to ensure the accuracy of the experiment, the predetermined pressure should not be too great to ensure an accurate pressure gradient.
Further, since the second through hole 35 is in sealed communication with the upper first through hole 19, the detection order of the first interface and the second interface is not fixed, that is, the outlet at the lower end of the first channel 31 of the piston 29 is firstly communicated with the lower first through hole 19 to detect whether the bonding capability of the first interface is failed, and then the outlet at the lower end of the first channel 31 of the piston 29 is communicated with the upper first through hole 19 to detect whether the bonding capability of the second interface is failed. It is also possible to first connect the outlet at the lower end of the first channel 31 of the piston 29 to the first through hole 19 above to detect whether the bonding capability of the second interface is failed, and then connect the outlet at the lower end of the first channel 31 of the piston 29 to the first through hole 19 below to detect whether the bonding capability of the first interface is failed.
It should be noted that, in the description of the present application, the terms "first", "second", and the like are used for descriptive purposes only and for distinguishing similar objects, and no precedence between the two is intended or should be construed to indicate or imply relative importance. In addition, in the description of the present application, "a plurality" means two or more unless otherwise specified.
It is to be understood that the above description is intended to be illustrative, and not restrictive. Many embodiments and many applications other than the examples provided will be apparent to those of skill in the art upon reading the above description. The scope of the present teachings should, therefore, be determined not with reference to the above description, but should instead be determined with reference to the appended claims, along with the full scope of equivalents to which such claims are entitled. The disclosures of all articles and references, including patent applications and publications, are hereby incorporated by reference for all purposes. The omission in the foregoing claims of any aspect of subject matter that is disclosed herein is not intended to forego the subject matter and should not be construed as an admission that the applicant does not consider such subject matter to be part of the disclosed subject matter.
Claims (9)
1. The utility model provides an oil gas well cementation cement packing ability detection device which characterized in that includes:
the simulated formation is internally provided with a simulated borehole extending along the up-down direction;
a simulation casing disposed through the simulation wellbore; a first annular space is formed between the simulation casing and the simulation stratum; the simulation sleeve is provided with at least one first through hole communicated with the first annular space;
a cementing cement filled within the first annular space; a first interface is formed between the well cementation cement and the simulation casing; a second interface is formed between the well cementation cement and the simulated formation;
the piston is movably arranged in the simulation sleeve in a penetrating way; the piston can form a second annular space with the simulation sleeve; a first channel communicated with the first through hole is arranged in the piston; to enable high pressure gas to flow through the first passage to the first interface or the second interface;
a pressure loading mechanism in communication with the second annular space; for applying pressure into said second annular space;
an earth stress simulation mechanism for applying an earth stress to the simulated formation, the simulated casing, and the cementing cement;
a second through hole is formed in the well cementation cement; the number of the first through holes is two; one of the first through holes is not communicated with the second through hole; the other first through hole is communicated with the second through hole in a sealing way; one end of the second through hole, which is back to the first through hole, is opened towards the simulated formation.
2. The oil and gas well cementing cement packing capacity detection device of claim 1, characterized in that: a pipe body with the second through hole is arranged in the well cementation cement; one end of the pipe body is connected to the side wall around the outer end of the other first through hole in a sealing mode.
3. The oil and gas well cementing cement packing capacity detection device of claim 1, characterized in that: the piston comprises a reducing section and an expanding section with the cross section area larger than that of the reducing section; the diameter expanding section is positioned below the diameter reducing section; the second annular space is formed between the reducing section and the simulation sleeve; the outer wall of the diameter expanding section is in sealing fit with the inner wall of the simulation sleeve.
4. The oil and gas well cementing cement packing capacity detection device of claim 3, characterized in that: the first channel comprises a vertical extension section arranged in the reducing section and a horizontal extension section arranged in the expanding section; one end of the horizontal extension section, which is back to the vertical extension section, is communicated with the first through hole.
5. The oil and gas well cementing cement packing capacity detection device of claim 3, characterized in that: a pressing cap used for sealing the second annular space is further arranged in the upper end of the simulation sleeve; a second channel communicated with the second annular space is arranged on the pressing cap; the pressure loading mechanism is in communication with the second annular space through the second passage.
6. The oil and gas well cementing cement packing capacity detection device of claim 5, characterized in that: the pressing cap is in a ring shape with a central hole; the piston is arranged in the central hole in a sealing mode in a penetrating mode.
7. A method for detecting the cementing cement packing capability of the oil and gas well according to the claim 1, which comprises the following steps:
step S11: applying, by the ground stress simulation mechanism, ground stress to the simulated formation, the simulated casing, and the cementing cement;
step S13: communicating the first passage with the first through hole and forming the second annular space between the piston and the simulation sleeve;
step S15: applying pressure into the second annular space by the pressure loading mechanism until the pressure in the second annular space rises to a first current loading pressure;
step S17: depressurizing said second annular space to reduce the pressure in said second annular space to substantially equal atmospheric pressure;
step S19: injecting high pressure gas into the first channel so that the high pressure gas can flow to the first interface between the well cementation cement and the simulation casing through a first through hole; and judging whether the high-pressure gas can leak from the first interface between the well cementation cement and the simulation casing;
step S21: when there is no gas leakage at the first interface between the cementing cement and the simulation casing, increasing a predetermined pressure on the basis of the first current loading pressure and repeating the above steps S15 to S19.
8. The detection method according to claim 7, further comprising:
step S21: moving the piston to place the first channel in communication with the other first through hole and to form the second annular space between the piston and the simulation sleeve; wherein, a second through hole is arranged in the well cementation cement; the other first through hole is communicated with the second through hole in a sealing way; one end of the second through hole, which is back to the first through hole, is opened towards the simulated formation;
step S23: applying pressure into the second annular space by the pressure loading mechanism until the pressure in the second annular space rises to a second current loading pressure;
step S25: depressurizing said second annular space to reduce the pressure in said second annular space to substantially equal atmospheric pressure;
step S27: injecting high-pressure gas into the first channel so that the high-pressure gas can flow to the second interface between the well cementation cement and the simulated formation through a second through hole; and judging whether the high-pressure gas can leak from the second interface between the well cementation cement and the simulated formation;
step S29: when there is no gas leakage at the second interface between the cementing cement and the simulated formation, increasing a predetermined pressure based on the second current loading pressure and repeating the above steps S23 to S27.
9. The detection method according to claim 7, characterized in that: applying true triaxial stress to the simulated formation, the simulated casing, and the cementing cement by the ground stress simulation mechanism.
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| CN111927435B (en) * | 2020-08-26 | 2022-03-25 | 西南石油大学 | High-temperature high-pressure casing cement sheath stratum seal integrity evaluation device and method |
| CN114427440B (en) * | 2020-10-14 | 2024-09-20 | 中国石油化工股份有限公司 | Well cementation cement sheath sealing detection device and method for simulating sleeve sliding sleeve fracturing |
| CN112855119B (en) * | 2021-01-15 | 2022-07-19 | 中国石油大学(北京) | Experiment method based on experiment device capable of being used for simulating well cementation fatigue limit |
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