CN114622904B - Device and method for simulating formation-wellbore multiphase coupled flow wellbore pressure distribution - Google Patents
Device and method for simulating formation-wellbore multiphase coupled flow wellbore pressure distribution Download PDFInfo
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- 238000004088 simulation Methods 0.000 claims abstract description 135
- 239000007788 liquid Substances 0.000 claims abstract description 67
- 238000002347 injection Methods 0.000 claims abstract description 47
- 239000007924 injection Substances 0.000 claims abstract description 47
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 41
- 238000002474 experimental method Methods 0.000 claims abstract description 41
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 18
- 238000012360 testing method Methods 0.000 claims abstract description 16
- 230000009545 invasion Effects 0.000 claims abstract description 15
- 239000012530 fluid Substances 0.000 claims abstract description 13
- 239000007791 liquid phase Substances 0.000 claims description 45
- 239000012071 phase Substances 0.000 claims description 19
- 230000005514 two-phase flow Effects 0.000 claims description 6
- 230000001105 regulatory effect Effects 0.000 claims description 5
- 239000012780 transparent material Substances 0.000 claims description 3
- 238000005553 drilling Methods 0.000 abstract description 19
- 239000007789 gas Substances 0.000 description 71
- 230000008878 coupling Effects 0.000 description 20
- 238000010168 coupling process Methods 0.000 description 20
- 238000005859 coupling reaction Methods 0.000 description 20
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- 238000004364 calculation method Methods 0.000 description 5
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- 238000009530 blood pressure measurement Methods 0.000 description 4
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- 230000000087 stabilizing effect Effects 0.000 description 4
- 238000010586 diagram Methods 0.000 description 3
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- 238000004519 manufacturing process Methods 0.000 description 3
- 238000013178 mathematical model Methods 0.000 description 3
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
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Abstract
本发明提供了一种模拟地层‑井筒多相耦合流动井筒压力分布装置及方法，所述装置包括高压往复泵、空气压缩机、气体流量计、第一液体流量计、第二液体流量计、井口压力传感器、井底压力传感器、供气溢漏测试管路、排出阀和模拟实验管路，其中，模拟实验管路包括同轴设置模拟井筒和模拟钻杆；模拟井筒底部设置有第一、第二地层模拟孔眼和注水孔眼；高压往复泵与注水孔眼连接以泵注液体；空气压缩机通过第二管路与供气溢漏测试管路连接以向地层模拟孔眼泵注气体；井口压力传感器和井底压力传感器分贝设置在模拟井筒上部和底部。本发明具有既可进行钻井液漏失单相井筒‑地层耦合流动实验，也可进行溢漏同存、气侵井筒‑地层耦合多相流动实验等优点。
The present invention provides a device and method for simulating formation-wellbore multiphase coupled flow wellbore pressure distribution, the device includes a high-pressure reciprocating pump, an air compressor, a gas flowmeter, a first liquid flowmeter, a second liquid flowmeter, a wellhead pressure sensor, a bottom hole pressure sensor, a gas supply leakage test pipeline, a discharge valve and a simulation experiment pipeline, wherein the simulation experiment pipeline includes a coaxially arranged simulated wellbore and a simulated drill pipe; the bottom of the simulated wellbore is provided with first and second formation simulation holes and water injection holes; the high-pressure reciprocating pump is connected to the water injection holes to pump liquid; the air compressor is connected to the gas supply leakage test pipeline through the second pipeline to pump gas into the formation simulation hole; the wellhead pressure sensor and the bottom hole pressure sensor are arranged at the top and bottom of the simulated wellbore. The present invention has the advantages of being able to conduct drilling fluid leakage single-phase wellbore-formation coupled flow experiments, as well as leakage coexistence, gas invasion wellbore-formation coupled multiphase flow experiments, etc.
Description
Technical Field
The invention relates to the technical field of petroleum and natural gas drilling, in particular to a device and a method for simulating stratum-shaft multiphase coupling flow shaft pressure distribution.
Background
In the development of deep fractured carbonate reservoirs, the complex multiphase flow characteristics and pressure change rules of the well shafts under the multiphase coupling flow condition of the fractured stratum and the well shafts are accurately recognized, and the pressure control of the well shafts is realized, so that the preconditions of a series of technologies such as safe and active pressure control drilling of the deep fractured carbonate, intelligent well control and risk-free drilling of the fractured stratum, plugging while drilling, evaluation of the reservoir while drilling, reservoir protection and the like are realized. At present, the well bore pressure distribution rule is mostly obtained by establishing a stratum-well bore multiphase coupling flow mathematical model and combining proper boundary condition expansion numerical calculation aiming at the research of the stratum and well bore multiphase coupling flow rule.
In terms of multiphase coupling flow rules of a fractured stratum and a shaft, the current research focus is on gas invasion of fixed gas flow and a well killing process thereof. The application number is CN200820080025.7, the name is that the oil gas well overflows, leaks experimental apparatus discloses by taking the pit shaft of piston, transparent crack simulation glass window and reservoir three major components oil gas well overflows, leaks experimental apparatus that the pit shaft part is in circular pit shaft, there is a screw rod in the lower extreme in circular pit shaft, the upper end of screw rod is connected at the piston, transparent crack simulation glass window is by two organic glass windows parallel fixation on the seam that pit shaft and reservoir were opened respectively and sealed, two organic glass window both ends communicate with pit shaft and reservoir respectively, be fixed with quick-operation joint on the reservoir pipe wall, the reservoir top is fixed with the air source interface. The device can simulate the reservoir drilling process more truly, and can observe the phenomena of gas invasion, lost circulation and gravity displacement in well control operation. Wearing, li Gao and the like simulate the gas-liquid gravity displacement phenomenon under the real fracture in a visual stratum-shaft coupling flow experiment frame in a flow experiment and simulation of the gas-liquid gravity displacement of the fracture.
In the aspects of complex multiphase flow characteristics and pressure change rules of a shaft, wei Na, meng Yingfeng, li Gao and the like, a gas-liquid-solid steady-state multiphase flow mathematical model under underbalanced normal drilling and a gas-liquid two-phase transient flow mathematical model of a stopped circulation shaft are established, an annular two-phase flow transient prediction model is established based on a Shi drifting model, and the bottom hole pressure under the working conditions of constant gas volume continuous gas invasion, variable gas volume continuous gas invasion, single-stranded gas invasion, intermittent gas invasion, pressure control drilling of a thin reservoir, a thick reservoir and the like and dynamic response characteristics among various flow parameters are obtained by adopting a numerical calculation method and experimental research. The experimental device or the research has the main defects that the formation-shaft coupling flow research and the complex multiphase flow characteristic of the shaft are not combined with the pressure change rule to form the shaft pressure distribution rule under the formation-shaft multiphase coupling flow condition, so that the requirement of on-site drilling operation is difficult to meet.
Disclosure of Invention
The present invention aims to address at least one of the above-mentioned deficiencies of the prior art. For example, one of the purposes of the present invention is to provide an experimental testing device for testing the evolution rule of the pressure of a well bore, which can study the gas production, the leakage and the overflow of the drilling fluid of the stratum. For another example, another object of the present invention is to provide an experimental test method for studying the pressure distribution rule of a well bore under the multiphase coupling flow condition of a stratum-well bore.
In order to achieve the above purpose, the invention provides a simulated stratum-shaft multiphase coupling flow shaft pressure distribution device, which comprises a high-pressure reciprocating pump, an air compressor, a gas flowmeter, a first liquid flowmeter, a second liquid flowmeter, a wellhead pressure sensor, a bottom hole pressure sensor, a first pipeline, a second pipeline, a third pipeline, a gas supply spillway test pipeline, a discharge valve and a simulated experiment pipeline, wherein the simulated experiment pipeline comprises a simulated shaft and a simulated drill rod, the lower part of the simulated drill rod is inserted into the simulated shaft and is coaxially arranged with the simulated shaft, the top of the simulated drill rod is sealed to form a first cavity with a downward opening, the top of the simulated shaft is sealed with the outer wall of the simulated drill rod, a second cavity is formed between the inner wall of the simulated shaft and the outer wall of the simulated drill rod, the second cavity is communicated with the first cavity, the bottom of the simulated shaft is provided with a first stratum simulation eyelet, a second stratum simulation eyelet and a water injection eyelet, the first simulated eyelet and the second stratum are respectively communicated with the second cavity, the upper part of the simulated drill rod is also arranged with the second pipeline, the gas supply valve is connected with the second pipeline through the first pipeline, the gas supply valve and the second pipeline through the second pipeline, the gas supply valve is connected with the second pipeline through the first pipeline and the second pipeline, the gas inlet valve is connected with the first pipeline and the second pipeline through the first pipeline, one end of a fourth pipeline is connected with a second pipeline, the other end of the fourth pipeline is connected with a first stratum simulation hole, one end of a fifth pipeline is connected with the second pipeline, the other end of the fifth pipeline is connected with the second stratum simulation hole, a first air inlet valve is arranged on the fourth pipeline, a second air inlet valve is arranged on the fifth pipeline, one end of a sixth pipeline is connected with a second liquid flowmeter, the other end of the sixth pipeline is connected with a part of the fourth pipeline, which is positioned between the first air inlet valve and the first stratum simulation hole, one end of a seventh pipeline is connected with the second liquid flowmeter, the other end of the seventh pipeline is connected with a part of the fifth pipeline, which is positioned between the second air inlet valve and the second stratum simulation hole, a first leakage valve is arranged on the sixth pipeline, a second leakage valve is arranged on the seventh pipeline, a wellhead pressure sensor is arranged on the upper portion of a simulated shaft, and a bottom pressure sensor is arranged on the bottom of the simulated shaft.
In an exemplary embodiment of an aspect of the invention, the apparatus may further comprise a data acquisition module connected to the gas flow meter, the first liquid flow meter, the second liquid flow meter, the wellhead pressure sensor, the bottom hole pressure sensor, respectively, to acquire pressure and flow data.
In an exemplary embodiment of an aspect of the present invention, the apparatus may further include an eighth pipe having one end connected to the air compressor and the other end connected to the discharge valve, a third intake valve provided on the eighth pipe and a surge tank provided before the surge tank.
In an exemplary embodiment of an aspect of the present invention, the apparatus may further include a first pressure sensor disposed on the fourth line and a second pressure sensor disposed on the fifth line.
In an exemplary embodiment of an aspect of the present invention, the apparatus may further include a gas pressure regulating valve provided on the second pipe between the air compressor and the gas flow meter to control the pressure and flow rate of the gas experiment working medium.
In one exemplary embodiment of an aspect of the present invention, the apparatus may further include a throttle valve, a solenoid valve, and a third pressure sensor disposed on the third line, with the solenoid valve disposed between the discharge orifice and the throttle valve, and the third pressure sensor disposed between the throttle valve and the discharge valve.
In an exemplary embodiment of an aspect of the present invention, the simulated wellbore may be made of transparent material, the length of the simulated wellbore may be 20-50 m, and the diameter of the simulated wellbore may be 120-200 mm.
In an exemplary embodiment of an aspect of the present invention, the length of the simulation drill rod may be 20 to 50m, and the diameter of the simulation drill rod may be 40 to 110mm.
In an exemplary embodiment of an aspect of the present invention, the pressure-resistant range of the simulation experiment pipeline may be 1 to 15mpa.
In an exemplary embodiment of an aspect of the present invention, the apparatus may further include an axial pressure sensor and an axial pressure sensor, the axial pressure sensor may include 5 to 10 pressure sensors uniformly distributed along an axial direction of the simulated wellbore, and the circumferential pressure sensor may include 2 to 5 pressure sensors uniformly distributed along a circumferential direction of the simulated wellbore.
In an exemplary embodiment of an aspect of the invention, the diameters of the first and second simulated formation holes may be equal to the true formation equivalent diameter.
In another aspect the present invention provides a method of simulating formation-wellbore multiphase coupled flow wellbore pressure distribution, the method being achievable by a device for simulating formation-wellbore multiphase coupled flow wellbore pressure distribution as described in any one of the preceding claims, and the method comprising the steps of:
When single-phase overflow experiments are carried out, a liquid-phase experimental working medium is injected into a simulation experiment pipeline through a first pipeline by a high-pressure reciprocating pump, the injection quantity of the liquid-phase experimental working medium is measured by a first liquid flowmeter, the liquid-phase experimental working medium flows from the bottom of the simulation shaft to the upper part of the simulation shaft and is discharged to the outside from a discharge valve through a third pipeline by a discharge hole on the simulation shaft;
When gas invasion and overflow are carried out in a gas-liquid two-phase flow experiment, a liquid phase experiment working medium is injected into a simulation experiment pipeline through a first pipeline by a high-pressure reciprocating pump, the injection quantity of the liquid phase experiment working medium is measured by a first liquid flowmeter, the liquid phase experiment working medium flows from the bottom of the simulation shaft to the upper part of the simulation shaft and is discharged to the outside through a discharge hole on the simulation shaft and a third pipeline, the first air inlet valve and the second air inlet valve are opened, the first air inlet valve and the second air inlet valve are closed, or the second air inlet valve and the first air inlet valve are opened, the second air inlet valve and the first air inlet valve are closed, the gas experiment working medium is injected into the simulation experiment pipeline through a fourth pipeline or a fifth pipeline after passing through the second pipeline by an air compressor, the injection quantity of the gas experiment working medium is measured by the gas flowmeter, the liquid phase experiment working medium enters the second liquid flowmeter through a second stratum simulation hole, the fifth pipeline and a seventh pipeline or a first stratum simulation hole, the fourth pipeline and the sixth pipeline, the leakage quantity of the liquid experiment working medium is measured, the gas flow is injected into the gas flowmeter through the second liquid flowmeter, the gas flow meter measured by the second air inlet valve and the bottom hole pressure of the well pressure sensor is measured, and the bottom pressure of the well head and the bottom pressure of the gas overflow is measured.
Compared with the prior art, the invention has the beneficial effects that at least one of the following contents is included:
(1) The invention provides a device for simulating stratum-well bore multiphase coupling flow well bore pressure distribution, which can be used for carrying out a drilling fluid leakage single-phase well bore-stratum coupling flow experiment, and carrying out overflow and leakage simultaneous existence and gas invasion well bore-stratum coupling multiphase flow experiment, so as to truly simulate the complex substance exchange rule between a well bore and a stratum in the drilling process;
(2) The invention provides a method for simulating pressure distribution of a stratum-shaft multiphase coupling flowing shaft, which can discuss the relation between leakage and gas invasion amount and wellhead back pressure, gas injection pressure and gas content by changing wellhead back pressure, leakage pressure, gas injection amount and gas injection pressure, and calculate the pressure evolution rule of the whole shaft, thereby providing theoretical basis for high-precision calculation of the change rule of bottom hole pressure when drilling a production zone in petroleum engineering and realizing safe active pressure control drilling operation.
Drawings
The foregoing and other objects and/or features of the invention will become more apparent from the following description taken in conjunction with the accompanying drawings in which:
FIG. 1 illustrates a schematic diagram of an exemplary embodiment of a simulated formation-wellbore multiphase coupled flow wellbore pressure distribution device of the present invention;
FIG. 2 illustrates a schematic diagram of another exemplary embodiment of a simulated formation-wellbore multiphase coupled flow wellbore pressure distribution device of the present invention;
FIG. 3 shows a schematic diagram of the simulated experiment line of FIG. 1;
fig. 4 shows a bottom view illustrating fig. 3.
Reference numerals illustrate:
1. High pressure reciprocating pump, 2. Inlet valve, 3. Air compressor, 4. Gas pressure regulating valve, 5. Gas flow meter, 6. First inlet valve, 7. Second inlet valve, 8. First leakage valve, 9. Second leakage valve, 10. First liquid flow meter, 11. Third inlet valve, 12. Pressure stabilizing vessel, 13. Discharge valve, 14. Throttle valve, 15. Solenoid valve, 16. Simulated experiment pipe, 16-1. Simulated wellbore, 16-2. Simulated drill pipe, 16-3. First formation simulated hole, 16-4. Second formation simulated hole, 16-5. Pressure measuring hole, 16-6. Water injection hole, 17. Second liquid flow meter, A1. First pressure sensor, A2. Second pressure sensor, A3. Bottom hole pressure sensor, A4. Wellhead pressure sensor, A5. Third pressure sensor, 18. First pipe, 19. Second pipe, 20. Third pipe, 21. Fourth pipe, 22. Fifth pipe, 23. Sixth pipe, 24, seventh pipe, 25. Eighth pipe, and 26 data acquisition module.
Detailed Description
Hereinafter, the simulated formation-wellbore multiphase coupled flow wellbore pressure distribution apparatus and method of the present invention will be described in detail in connection with exemplary embodiments. It should be noted that the terms "first," "second," "third," "fourth," "fifth," "sixth," "seventh," "eighth," and the like are merely for convenience of description and convenience of distinction and are not to be construed as indicating or implying relative importance. "upper", "lower", "inner", "outer" are merely for convenience of description and constitute relative orientations or positional relationships, and do not indicate or imply that the components referred to must have that particular orientation or position.
Fig. 1 shows a schematic structural view of an exemplary embodiment of a simulated formation-wellbore multiphase coupled flow wellbore pressure distribution device of the present invention, fig. 2 shows a schematic structural view of another exemplary embodiment of a simulated formation-wellbore multiphase coupled flow wellbore pressure distribution device of the present invention, fig. 3 shows a schematic structural view of a simulated experimental pipeline of fig. 1, and fig. 4 shows a bottom view of fig. 3.
In a first exemplary embodiment of the present invention, as shown in fig. 1, a simulated formation-wellbore multiphase coupled flow wellbore pressure distribution device includes a high pressure reciprocating pump 1, an air compressor 3, a gas flow meter 5, a first liquid flow meter 10, a second liquid flow meter 17, a wellhead pressure sensor A4, a bottom hole pressure sensor A3, a first line 18, a second line 19, a third line 20, a gas supply leak test line, a discharge valve 13, and a simulated experiment line 16.
The simulation experiment pipeline 16 comprises a simulation shaft 16-1 and a simulation drill rod 16-2, wherein the lower part of the simulation drill rod 16-2 is inserted into the simulation shaft 16-1 and is coaxially arranged with the simulation shaft 16-1, a first cavity with a downward opening is formed by sealing the top of the simulation drill rod 16-2, the top of the simulation shaft 16-1 is sealed with the outer wall of the simulation drill rod 16-2, the bottom of the simulation shaft 16-1 is sealed, a second cavity is formed between the inner wall of the simulation shaft and the outer wall of the simulation drill rod, and the second cavity is communicated with the first cavity. Specifically, the simulated experiment pipeline 16 is composed of a simulated well bore 16-1 and a simulated drill pipe 16-2 which are arranged inside and outside, wherein the simulated well bore 16-1 is an outer pipe, the simulated drill pipe 16-2 is an inner pipe, and the simulated drill pipe 16-2 is higher than the simulated well bore 16-1 by a distance. For example, the length of the part of the simulation drill pipe, which is not inserted into the simulation wellbore, can be 1-16 m.
In this embodiment, as shown in fig. 1 and 3-4, a first formation simulation hole 16-3, a second formation simulation hole 16-4 and a water injection hole 16-6 are disposed at the bottom of the simulation wellbore 16-1, and the second cavities of the first formation simulation hole 16-3, the second formation simulation hole 16-4 and the water injection hole 16-6 are respectively communicated. Specifically, four holes, a first formation simulation hole 16-3, a second formation simulation hole 16-4, a pressure measurement hole 16-5, and a water injection hole 16-6, are provided at the bottom of the simulation wellbore 16-1 for simulating the formation and installing pressure measurement instruments. Wherein the first formation-simulating perforation 16-3 and the second formation-simulating perforation 16-4 are used for simulating the formation, and the diameter of the first formation-simulating perforation is equal to the equivalent diameter of the real formation. The pressure measuring hole 16-5 is used for installing a bottom hole pressure sensor A3 and measuring bottom hole pressure, and the water injection hole 16-6 is used for injecting liquid experimental working medium into the simulation experimental pipeline.
In this embodiment, as shown in fig. 1, a discharge hole is further provided at the upper portion of the simulated wellbore 16-1, and the discharge hole is connected to the discharge valve 13 through the third pipe 20 to discharge the liquid-phase experimental working medium.
In this embodiment, the high-pressure reciprocating pump 1 is connected to the water injection hole 16-6 through a first pipe 18 to pump the liquid-phase experimental working medium into the simulation experiment pipe 16, and the first liquid flow meter 10 is provided on the first pipe 18 to measure the injection amount of the liquid-phase experimental working medium.
In this embodiment, the air compressor 3 is connected to the air supply overflow and leakage test pipeline through a second pipeline 19, and the gas flowmeter 5 is disposed on the second pipeline 19 to measure the injection amount of the gas-phase experimental working medium.
In this embodiment, as shown in fig. 1, the supply air overflow test line includes a fourth line 21, a fifth line 22, a sixth line 23, a seventh line 24, a first intake valve 6, a second intake valve 7, a first leakage valve 8, a second leakage valve 9, and a second liquid flow meter 17. Wherein, one end of the fourth pipeline 21 is connected with the second pipeline 19, the other end is connected with the first stratum simulation hole 16-3, one end of the fifth pipeline 22 is connected with the second pipeline 19, and the other end is connected with the second stratum simulation hole 16-4. The first inlet valve 6 is arranged on the fourth line 21 and the second inlet valve 7 is arranged on the fifth line 22. One end of the sixth pipeline 23 is connected to the second fluid flow meter 17, the other end is connected to a portion of the fourth pipeline 21 located between the first intake valve 6 and the first formation-simulating hole 16-3, one end of the seventh pipeline 24 is connected to the second fluid flow meter 17, and the other end is connected to a portion of the fifth pipeline 22 located between the second intake valve 7 and the second formation-simulating hole 16-4. The first leakage valve 8 is arranged on the sixth line 23 and the second leakage valve 9 is arranged on the seventh line 24. Specifically, the gas-phase experimental working medium is divided into two channels connected in parallel, and the two channels enter the simulation experiment pipeline 16 from the first stratum simulation hole 16-3 and the second stratum simulation hole 16-4 respectively, and an air inlet valve is further arranged on the two channels to control the opening and closing of the channels. Meanwhile, the two channels are respectively connected with the second liquid flow meter, so that the second liquid flow meter 17 can measure the leakage amount of the liquid phase experimental working medium which is leaked through the first stratum simulation hole 16-3 and/or the second stratum simulation hole 16-4.
In this embodiment, a wellhead pressure sensor A4 is disposed at the upper portion of the simulated wellbore 16-1 and a bottom hole pressure sensor A3 is disposed at the bottom of the simulated wellbore 16-1 to enable measurement of wellhead pressure and bottom hole pressure when performing experiments.
In a second exemplary embodiment of the present invention, as shown in fig. 2, the simulated formation-wellbore multiphase coupling flow wellbore pressure distribution device includes a high pressure reciprocating pump 1, an air compressor 3, a gas flow meter 5, a first liquid flow meter 10, a second liquid flow meter 17, a wellhead pressure sensor A4, a downhole pressure sensor A3, a first pipe 18, a second pipe 19, a third pipe 20, a gas supply overflow test pipe, a surge tank 12, a discharge valve 13, a data acquisition module 26, and a simulation experiment pipe 16.
The simulation experiment pipeline 16 comprises a simulation shaft 16-1 and a simulation drill rod 16-2, wherein the lower part of the simulation drill rod 16-2 is inserted into the simulation shaft 16-1 and is coaxially arranged with the simulation shaft 16-1, a first cavity with a downward opening is formed by sealing the top of the simulation drill rod 16-2, the top of the simulation shaft 16-1 is sealed with the outer wall of the simulation drill rod 16-2, the bottom of the simulation shaft 16-1 is sealed, a second cavity is formed between the inner wall of the simulation shaft and the outer wall of the simulation drill rod, and the second cavity is communicated with the first cavity. Specifically, the simulated experiment pipeline 16 is composed of a simulated well bore 16-1 and a simulated drill pipe 16-2 which are arranged inside and outside, wherein the simulated well bore 16-1 is an outer pipe, the simulated drill pipe 16-2 is an inner pipe, and the simulated drill pipe 16-2 is higher than the simulated well bore 16-1 by a distance. For example, the length of the part of the simulation drill pipe, which is not inserted into the simulation wellbore, can be 1-16 m. In this embodiment, as shown in fig. 2 and 3-4, a first formation simulation hole 16-3, a second formation simulation hole 16-4 and a water injection hole 16-6 are disposed at the bottom of the simulation wellbore 16-1, and the first formation simulation hole 16-3, the second formation simulation hole 16-4 and the water injection hole 16-6 are all communicated with the second cavity. Specifically, four holes, a first formation simulation hole 16-3, a second formation simulation hole 16-4, a pressure measurement hole 16-5, and a water injection hole 16-6, are provided at the bottom of the simulation wellbore 16-1 for simulating the formation and installing pressure measurement instruments. Wherein the first formation-simulating perforation 16-3 and the second formation-simulating perforation 16-4 are used for simulating the formation, and the diameter of the first formation-simulating perforation is equal to the equivalent diameter of the real formation. The pressure measuring hole 16-5 is used for installing a bottom hole pressure sensor A3 and measuring bottom hole pressure, and the water injection hole 16-6 is used for injecting liquid experimental working medium into the simulation experimental pipeline.
In this embodiment, as shown in fig. 2, a discharge hole is further provided at the upper portion of the simulated wellbore 16-1, and the discharge hole is connected to the discharge valve 13 through the third pipe 20 to discharge the liquid-phase experimental working medium.
In this embodiment, the high-pressure reciprocating pump 1 is connected to the water injection hole 16-6 through a first pipe 18 to pump the liquid-phase experimental working medium into the simulation experiment pipe 16, and the first liquid flow meter 10 is provided on the first pipe 18 to measure the injection amount of the liquid-phase experimental working medium.
In this embodiment, the air compressor 3 is connected to the air supply overflow and leakage test pipeline through a second pipeline 19, and the gas flowmeter 5 is disposed on the second pipeline 19 to measure the injection amount of the gas-phase experimental working medium.
The air supply overflow leakage test pipeline comprises a fourth pipeline 21, a fifth pipeline 22, a sixth pipeline 23, a seventh pipeline 24, a first air inlet valve 6, a second air inlet valve 7, a first leakage valve 8, a second leakage valve 9 and a second liquid flowmeter 17. Wherein, one end of the fourth pipeline 21 is connected with the second pipeline 19, the other end is connected with the first stratum simulation hole 16-3, one end of the fifth pipeline 22 is connected with the second pipeline 19, and the other end is connected with the second stratum simulation hole 16-4. The first inlet valve 6 is arranged on the fourth line 21 and the second inlet valve 7 is arranged on the fifth line 22. One end of the sixth pipeline 23 is connected to the second fluid flow meter 17, the other end is connected to a portion of the fourth pipeline 21 located between the first intake valve 6 and the first formation-simulating hole 16-3, one end of the seventh pipeline 24 is connected to the second fluid flow meter 17, and the other end is connected to a portion of the fifth pipeline 22 located between the second intake valve 7 and the second formation-simulating hole 16-4. The first leakage valve 8 is arranged on the sixth line 23 and the second leakage valve 9 is arranged on the seventh line 24. Specifically, the gas-phase experimental working medium is divided into two channels connected in parallel, and the two channels enter the simulation experiment pipeline 16 from the first stratum simulation hole 16-3 and the second stratum simulation hole 16-4 respectively, and an air inlet valve is further arranged on the two channels to control the opening and closing of the channels. Meanwhile, the two channels are respectively connected with the second liquid flow meter, so that the second liquid flow meter 17 can measure the leakage amount of the liquid phase experimental working medium which is leaked through the first stratum simulation hole 16-3 and/or the second stratum simulation hole 16-4.
In this embodiment, as shown in fig. 2, the apparatus further includes a surge tank 12. The surge tank 12 is connected to the air compressor 3 and the discharge valve 13 via an eighth line 25. One end of an eighth pipeline 25 is connected with the outlet pipeline of the air compressor 3, the other end of the eighth pipeline is connected with the wellhead pipeline of the discharge valve 13, the pressure stabilizing container 12 is arranged on the eighth pipeline 25, and the third air inlet valve 11 is arranged in front of the pressure stabilizing container 12 to control the pressure and flow of the gas-phase working medium entering the pressure stabilizing container 12. Through setting up the steady voltage container, can keep test system's pressure stability, ensure that test system's gas injection pressure and gas injection volume do not receive the influence that air compressor operating condition changes, also can prevent simultaneously that liquid from flowing back because of misoperation from taking place, thereby also can not influencing the operation of air compressor and cause danger.
In this embodiment, a wellhead pressure sensor A4 is disposed at the upper portion of the simulated wellbore 16-1 and a bottom hole pressure sensor A3 is disposed at the bottom of the simulated wellbore 16-1 to enable measurement of wellhead pressure and bottom hole pressure when performing experiments. The data acquisition module 26 is respectively connected with the gas flowmeter 5, the first liquid flowmeter 10, the second liquid flowmeter 17, the wellhead pressure sensor A4 and the bottom hole pressure sensor A3 to acquire data such as pressure of a simulation experiment pipeline, liquid phase experiment working medium injection quantity, gas phase experiment working medium injection quantity, liquid phase experiment working medium leakage quantity and the like in the experiment process. For example, the data acquisition module may be a computer, and the computer may acquire and display the bottom hole pressure and the wellhead pressure, and data such as the injection amount of the liquid phase experimental working medium, the injection amount of the gas phase experimental working medium, and the leakage amount of the liquid phase experimental working medium.
In the present exemplary embodiment, as shown in fig. 2, the apparatus may further include a first pressure sensor A1 and a second pressure sensor A2 on the basis of the above-described first exemplary embodiment, the first pressure sensor A1 being provided on the fourth pipe 21 to measure the pressure of the gas-phase working substance or the liquid-phase working substance in the fourth pipe, and the second pressure sensor A2 being provided on the fifth pipe 22 to measure the pressure of the gas-phase working substance or the liquid-phase working substance in the fifth pipe.
In the present exemplary embodiment, as shown in fig. 2, the apparatus may further include a gas pressure regulating valve 4 on the basis of the above first exemplary embodiment, and the gas pressure regulating valve 4 is disposed on the second pipe 19 and between the air compressor 3 and the gas flowmeter 5 to control the pressure and flow rate of the injected gas experimental working medium.
In the present exemplary embodiment, as shown in fig. 2, the apparatus may further include a throttle valve 14, a solenoid valve 15, and a third pressure sensor A5, the throttle valve 14, the solenoid valve 15, and the third pressure sensor A5 being disposed on the third pipe 20 with the solenoid valve 15 being disposed between the discharge hole and the throttle valve 14, and the third pressure sensor A5 being disposed between the throttle valve 14 and the discharge valve 13. Here, the solenoid valve 15 is used to adjust the opening degree of the throttle valve 14 to control the pressure of the simulation experiment line 16.
In this exemplary embodiment, the simulated wellbore may be made of a transparent material, the length of the simulated wellbore may be 20-50 m, and the diameter of the simulated wellbore may be 120-200 mm. For example, the simulated well bore is made of glass fiber reinforced plastic, the length of the simulated well bore is 36m, and the diameter of the simulated well bore is 160mm.
In this exemplary embodiment, the length of the simulated drill rod may be 20-50 m, and the diameter of the simulated drill rod may be 40-110 mm.
In this exemplary embodiment, the withstand voltage range of the simulation experiment pipeline may be 0 to 15mpa. In this exemplary embodiment, the apparatus may further include an axial pressure sensor and an axial pressure sensor (not shown in fig. 1 and 2), the axial pressure sensor may include 5 to 10 pressure sensors uniformly distributed along the axial direction of the simulated wellbore, and the circumferential pressure sensor may include 2 to 5 pressure sensors uniformly distributed along the circumferential direction of the simulated wellbore. Through setting up axial pressure sensor and circumference pressure sensor, can survey the axial of pit shaft and axial pressure change law when simulation experiment.
In the present exemplary embodiment, the diameters of the first and second formation-simulating apertures may be equal to the true formation equivalent diameter to better simulate the formation.
In a third exemplary embodiment of the present invention, a method of simulating formation-wellbore multiphase coupled flow wellbore pressure distribution, the method being achievable by the simulated formation-wellbore multiphase coupled flow wellbore pressure distribution device described in the first or second exemplary embodiments above, and the method comprising the steps of:
The single-phase overflow leakage experiment comprises the following steps:
the water inlet valve 2 is opened, the first air inlet valve 6, the second air inlet valve 7, the first leakage valve 8 and the second leakage valve 9 are closed, and the liquid phase experimental working medium is injected into the simulation experiment pipeline 16 through the first pipeline 18 by the high-pressure reciprocating pump 1. Meanwhile, the first liquid flow meter 10 measures the injection amount of the liquid phase experimental working medium. The liquid phase experimental working medium flows from the bottom of the simulated well bore 16-1 to the upper part of the simulated well bore 16-1, passes through the third pipeline 20 through the discharge hole on the simulated well bore 16-1 and is discharged to the outside from the discharge valve 13.
The first leakage valve 8 and/or the second leakage valve 9 are/is opened, the first air inlet valve 6 and the second air inlet valve 7 are/is closed, the liquid phase experimental working medium enters the second liquid flow meter 17 after passing through the first stratum simulation hole 16-3, the fourth pipeline 21 and the sixth pipeline 23, and/or the liquid phase experimental working medium enters the second liquid flow meter 17 after passing through the second stratum simulation hole 16-4, the fifth pipeline 22 and the seventh pipeline 24, and the second liquid flow meter 17 measures the leakage amount of the liquid phase working medium and then is discharged to the outside. The wellhead pressure and the bottom hole pressure are measured by the wellhead pressure sensor A4 and the bottom hole pressure sensor A3 during a single-phase overflow leakage experiment. Namely, when the one-way overflow and leak experiment is carried out, the liquid-phase experimental working medium can be carried out through the first stratum simulation hole 16-3, can be carried out through the second stratum simulation hole 16-4, and can also be carried out simultaneously through the first stratum simulation hole 16-3 and the second stratum simulation hole 16-4.
The gas-liquid two-phase flow experiment for gas invasion and overflow and leakage simultaneously comprises the following steps:
The liquid phase experimental working medium is injected into the simulation experiment pipeline 16 through the first pipeline 18 by the high-pressure reciprocating pump 1. Meanwhile, the first liquid flow meter 10 measures the injection amount of the liquid phase experimental working medium. The liquid phase experimental working medium flows from the bottom of the simulated well bore 16-1 to the upper part of the simulated well bore 16-1, passes through the third pipeline 20 through the discharge hole on the simulated well bore 16-1 and is discharged to the outside from the discharge valve 13.
The first air inlet valve 6 and the second leakage valve 9 are opened, the first leakage valve 8 and the second air inlet valve 7 are closed, and the air experimental working medium is injected into the simulation experiment pipeline 16 through the fourth pipeline 21 after passing through the second pipeline 19 by the air compressor 3. The gas experimental working medium injection quantity is measured by a gas flowmeter 5. The liquid phase experimental working medium enters the second liquid flowmeter 17 through the second stratum simulation hole 16-4, the fifth pipeline 22 and the seventh pipeline 24, and is discharged outside the boundary after the leakage of the liquid phase experimental working medium is measured. Or opening the second air inlet valve 7 and the first leakage valve 8, closing the second leakage valve 9 and the first air inlet valve 6, and injecting the gas experimental working medium into the simulation experimental pipeline 16 through the fifth pipeline 22 by the air compressor 3. The gas experimental working medium injection quantity is measured by a gas flowmeter 5. The liquid phase experimental working medium enters the second liquid flowmeter 17 through the first stratum simulation hole 16-3, the fourth pipeline 21 and the sixth pipeline 23, and is discharged outside the boundary after the leakage of the liquid phase experimental working medium is measured. When gas-liquid two-phase flow experiments of gas invasion and overflow are carried out, gas-phase working media can only enter from one of the first stratum simulation holes 16-3 or the second stratum simulation holes 16-4, and correspondingly, liquid-phase experimental working media can only leak from the second stratum simulation holes 16-4 or the first stratum simulation holes 16-3.
And calculating the gas content by the liquid leakage measured by the second liquid flowmeter and the gas working medium injection measured by the gas flowmeter. The calculation formula of the air content is as follows:
Wherein alpha g is the gas content, Q g is the gas injection amount, m 3/h;Ql is the liquid injection amount, and m 3/h.
The wellhead pressure and the bottom hole pressure are measured by the wellhead pressure sensor A4 and the bottom hole pressure sensor A3 during a single-phase overflow leakage experiment.
In summary, the beneficial effects of the present invention include at least one of the following:
(1) The invention provides a device for simulating stratum-well bore multiphase coupling flow well bore pressure distribution, which can be used for carrying out a drilling fluid leakage single-phase well bore-stratum coupling flow experiment, and carrying out overflow and leakage simultaneous existence and gas invasion well bore-stratum coupling multiphase flow experiment, so as to truly simulate the complex substance exchange rule between a well bore and a stratum in the drilling process;
(2) The invention provides a method for simulating pressure distribution of a stratum-shaft multiphase coupling flowing shaft, which can discuss the relation between leakage and gas invasion amount and wellhead back pressure, gas injection pressure and gas content by changing wellhead back pressure, leakage pressure, gas injection amount and gas injection pressure, and calculate the pressure evolution rule of the whole shaft, thereby providing theoretical basis for high-precision calculation of the change rule of bottom hole pressure when drilling a production zone in petroleum engineering and realizing safe active pressure control drilling operation.
Although the present invention has been described above with reference to the exemplary embodiments and the accompanying drawings, it should be apparent to those of ordinary skill in the art that various modifications can be made to the above-described embodiments without departing from the spirit and scope of the claims.
Claims (11)
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| CN106640061B (en) * | 2016-12-06 | 2019-08-02 | 西南石油大学 | A kind of pit shaft and formation fracture Coupled Flow imitative experimental appliance and method |
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