CN110530768B - Experimental simulation device and simulation method for removing near-well blockage of condensate gas well - Google Patents
Experimental simulation device and simulation method for removing near-well blockage of condensate gas well Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 47
- 238000004088 simulation Methods 0.000 title claims abstract description 45
- 239000007789 gas Substances 0.000 claims abstract description 136
- 239000011435 rock Substances 0.000 claims abstract description 88
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims abstract description 84
- 238000003860 storage Methods 0.000 claims abstract description 26
- 239000004576 sand Substances 0.000 claims abstract description 25
- 238000012544 monitoring process Methods 0.000 claims abstract description 21
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims abstract description 18
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- 229910052757 nitrogen Inorganic materials 0.000 claims abstract description 9
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 24
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- 238000005086 pumping Methods 0.000 claims description 6
- 238000009738 saturating Methods 0.000 claims description 5
- 229920001971 elastomer Polymers 0.000 claims description 4
- 238000002156 mixing Methods 0.000 claims description 4
- 238000012163 sequencing technique Methods 0.000 claims description 3
- 238000001704 evaporation Methods 0.000 claims description 2
- 229920006395 saturated elastomer Polymers 0.000 claims description 2
- 230000008020 evaporation Effects 0.000 claims 1
- 238000001035 drying Methods 0.000 abstract 1
- 238000002474 experimental method Methods 0.000 description 11
- 230000006378 damage Effects 0.000 description 5
- 230000000903 blocking effect Effects 0.000 description 4
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- 239000000243 solution Substances 0.000 description 3
- 238000009833 condensation Methods 0.000 description 2
- 230000005494 condensation Effects 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
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- 239000003345 natural gas Substances 0.000 description 1
- 239000003209 petroleum derivative Substances 0.000 description 1
- 239000002244 precipitate Substances 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 238000001223 reverse osmosis Methods 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
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Abstract
The invention provides an experimental simulation device and a simulation method for removing near-well blockage of a condensate gas well, wherein the device comprises an adjustable constant-temperature drying oven, a long rock core holder, a sand-filled thin tube, a condensate gas sample storage tank, an ethanol sample storage tank, a condensate oil collecting tube, a liquid nitrogen cooling system and a full-automatic gas meter; the long core holder is used for placing a target long core simulating a near wellbore zone; the condensate gas sample storage tank is connected with a sand filling thin tube through a pipeline, the sand filling thin tube is connected with the inlet end of the long rock core holder through a first high-precision pressure monitoring meter through a pipeline, and the outlet end of the long rock core holder is respectively connected with the ethanol sample storage tank and a condensate oil collecting tube through a capillary tube through a second high-precision pressure monitoring meter and a back pressure valve in sequence through pipelines; the long rock core holder and the sand filling tubule are positioned in an adjustable constant-temperature oven, and the condensate collecting pipe is positioned in a liquid nitrogen cooling system; the middle part of the long rock core holder is also connected with a confining pressure gauge.
Description
Technical Field
The invention relates to an experimental simulation device and method for removing near-well blockage of a condensate gas well, and belongs to the technical field of condensate gas reservoir retrograde condensate solution blockage removal in the petroleum and natural gas industry.
Background
The pressure of the condensate gas is gradually reduced in the process of mining, when the pressure is reduced to dew point pressure, retrograde condensate oil is separated out, and along with the continuous separation and accumulation of the retrograde condensate oil, the blockage of the formation pores in the near-wellbore area can be causedPlugs cause the gas well productivity to drop and consequently cause significant losses in production. The research on the removal of the blockage of the pores by the condensate liquid of the condensate gas reservoir is a crucial problem in the exploitation process of the condensate gas reservoir. At present, a far-well-zone gas source layer is not simulated in a condensate gas blockage removal experiment, or a simulated seepage channel is very short and does not accord with the actual stratum condition, and the condensate gas blockage removal damage is basically dry gas injection and CO injection 2 Isogas, but where dry gas has difficulty in efficiently pushing reverse osmosis water far into the formation and CO is present 2 Has certain corrosivity and high Ca content for high mineralization 2+ 、Mg 2+ Ionic formation water may precipitate. Thus, only dry gas or CO is used 2 The reverse condensation effect of gas treatment gas wells in the near wellbore region is not ideal.
Therefore, it is an urgent technical problem in the art to provide a novel experimental simulation device and a simulation method for relieving the near-well blockage of the condensate gas well.
Disclosure of Invention
In order to solve the above disadvantages and shortcomings, it is an object of the present invention to provide an experimental simulation apparatus for relieving the near-well plugging of condensate wells.
The invention also aims to provide an experimental simulation method for removing the blockage of the condensate gas well near the well.
In order to achieve the above object, in one aspect, the present invention provides an experimental simulation device for removing the near-well plugging of a condensate gas well, wherein the experimental simulation device for removing the near-well plugging of the condensate gas well comprises:
the system comprises an adjustable constant-temperature oven, a long rock core holder (used for simulating near-wellbore zone strata), a sand-filled thin tube, a condensate gas sample storage tank, an ethanol sample storage tank, a condensate oil collecting tube, a liquid nitrogen cooling system and a full-automatic gas meter;
the long core holder is used for placing a target long core simulating a near wellbore zone; the condensate gas sample storage tank is connected with the sand filling tubule through a pipeline, the sand filling tubule is connected with the inlet end of the long rock core holder through a first high-precision pressure monitoring meter through a pipeline, and the outlet end of the long rock core holder is connected with the ethanol sample storage tank through a second high-precision pressure monitoring meter and a back pressure valve in sequence through pipelines; the outlet end of the long rock core holder is connected with the condensate collecting pipe through a capillary tube after sequentially passing through a second high-precision pressure monitoring meter and a back pressure valve through a pipeline;
the long rock core holder and the sand filling tubule are positioned in the adjustable constant-temperature oven, and the condensate oil collecting pipe is positioned in a liquid nitrogen cooling system;
and the middle part of the long rock core holder is also connected with a confining pressure gauge.
According to the embodiment of the invention, in the experimental simulation device for removing the blockage of the condensate gas well near the well, preferably, the condensate gas sample storage tank is also connected with a first high-precision displacement pump.
According to the embodiment of the invention, in the experimental simulation device for removing the blockage of the condensate gas well near the well, preferably, the ethanol sample storage tank is connected with a second high-precision displacement pump.
According to the embodiment of the invention, in the experimental simulation device for removing the near-well blockage of the condensate gas well, the back-pressure valve is preferably connected with a fourth high-precision displacement pump.
According to the embodiment of the invention, in the experimental simulation device for removing the blockage of the condensate gas well near the well, preferably, the confining pressure gauge is connected with a fifth high-precision displacement pump.
The confining pressure meter is used for monitoring confining pressure of the target long rock core, and the fifth high-precision displacement pump is used for providing confining pressure for the target long rock core.
According to the experimental simulation device for removing the near-well blockage of the condensate gas well, preferably, the condensate gas sample storage tank is connected with the sand filling tubule through an air inlet valve and a third high-precision pressure monitoring meter in sequence through a pipeline.
In the experimental simulation device for removing the near well blockage of the condensate gas well, the condensate gas sample and the sand-filled tubule are used for simulating the seepage of the condensate gas source layer in the far well zone; the process that condensate oil is precipitated and continuously accumulated in a near-wellbore area to block pores is simulated by long core displacement equipment, and the blockage removal experiment is simulated by injecting ethanol into the outlet end of the long core and then condensing gas. The adjustable constant-temperature oven for placing the long rock core holder can be used for setting different formation temperatures, the high-precision pressure monitoring meters are respectively arranged at the two ends of the long rock core holder and can be used for monitoring the pressure change at the inlet and the outlet of the long rock core, the outlet end of the long rock core is connected with a condensate collecting pipe through a capillary tube, the amount of condensate oil produced by metering can be observed, the capillary tube is convenient to observe, the retention amount of the condensate oil in a pipeline can be reduced, and the testing precision is improved.
In another aspect, the present invention further provides an experimental simulation method for removing the near-well plugging of the condensate gas well, wherein the method uses the above experimental simulation device for removing the near-well plugging of the condensate gas well, and the method includes the following steps:
(1) at the temperature of an experimental stratum, short rock cores are placed into a rubber barrel after being subjected to blending average sequencing, then long rock core holders are placed (a target long rock core for simulating a near-wellbore area is obtained), dry gas is used for building pressure on a sand filling tubule and the target long rock core to the stratum pressure, the pressure of a back pressure valve is controlled to be higher than the dew point pressure of condensate gas, a condensate gas sample is pumped into the sand filling tubule and then enters the target long rock core for displacement, the dry gas is replaced, and when the composition and parameters of gas discharged from an outlet end are consistent with the composition and corresponding parameters of flash gas of the condensate gas, the target long rock core is completely saturated with the condensate gas;
(2) the pressure in the target long rock core is reduced from the dew point pressure of the condensate gas, the outlet pressure of the long rock core holder is respectively controlled to be sequentially reduced reasonable pressure through a back pressure valve, and the pressure difference between the inlet and the outlet of the long rock core holder is determined according to the gas quantity at the outlet end; under each outlet pressure, after the outlet flow and the inlet pressure are stable, the condensate gas under the inlet pressure is used for displacement; recording outlet flow, inlet pressure and outlet pressure at different time in the displacement process, and calculating to obtain the permeability change of the long core under each reasonable pressure (namely, under each outlet pressure, after the outlet flow and the inlet pressure are stable, the permeability change of the long core in the displacement process is carried out by using condensate gas under the inlet pressure); stopping injecting the condensate gas sample when the permeability of the long rock core is basically unchanged under each reasonable pressure;
(3) injecting a certain amount of ethanol sample from the outlet end of the long core holder, closing the back pressure valve after complete injection, and stewing for a period of time until the inlet and outlet pressure of the target long core is stable, and then continuously pumping the condensate gas sample from the inlet end of the target long core; recording outlet flow, inlet pressure and outlet pressure at different time in the experimental process, and testing the permeability change of the mined long rock core after ethanol is injected by controlling the inlet pressure and the pressure of a back pressure valve; stopping injecting the condensate gas sample when the permeability of the long rock core measured in the step (3) is consistent with the permeability of the long rock core in the step (2) when the permeability of the long rock core is basically unchanged;
(4) and (4) repeating the step (3), and continuously injecting a certain amount of ethanol samples from the outlet end of the long core holder until no condensate oil drips from the capillary tube at the outlet end of the long core holder after the last batch of ethanol samples are injected.
According to a specific embodiment of the invention, before the step (1), the experimental simulation method for removing the near-well blockage of the condensate gas well preferably further comprises an operation of testing the porosity of the target long core and the permeability of the target long core under the irreducible water saturation.
According to a specific embodiment of the invention, in the experimental simulation method for removing the near-well blockage of the condensate gas well, preferably, the step of testing the permeability of the target long core under the irreducible water saturation specifically comprises the following steps:
testing the porosity of the rock core, vacuumizing a target long rock core, setting the temperature of an adjustable constant-temperature oven as the temperature of an experimental stratum, fully saturating the rock core with a stratum water sample, and centrifuging the rock core by using a centrifugal pump to remove movable water in the rock core and establish the saturation of bound water; and the permeability of the target long core at irreducible water saturation was measured.
In a specific embodiment of the present invention, the method for testing the permeability of the target long core under the irreducible water saturation specifically comprises the following steps:
weighing the core and testing the porosity of the core, vacuumizing a target core and fully saturating formation water, centrifuging by using a centrifugal machine to remove movable water in the core and then weighing until the core meets the saturation requirement of the bound water, then loading short cores into a long core holder according to the blending average sequence, and measuring the permeability of the target long core under the saturation of the bound water.
According to the specific embodiment of the invention, in the experimental simulation method for removing the near well blockage of the condensate gas well, the pressure of the back pressure valve is preferably controlled to be 300-500psi higher than the dew point pressure of the condensate gas in the step (1).
According to the embodiment of the invention, in the experimental simulation method for removing the near-well blockage of the condensate gas well, preferably, in the step (1), the amount of the condensate gas sample used for displacement is 4-6 times of the pore volume of the target long core.
According to the embodiment of the invention, in the experimental simulation method for removing the near-well blockage of the condensate gas well, preferably, in the step (1), the amount of the condensate gas sample used for displacement is 5 times of the target long core pore volume.
According to a specific embodiment of the invention, in the experimental simulation method for removing the blockage of the condensate gas well near well, preferably, in the step (1), the parameter comprises a gas-oil ratio.
According to the embodiment of the invention, in the experimental simulation method for removing the blockage of the condensate gas well near well, preferably, in the step (3) and the step (4), the injection amount of the ethanol sample is 0.3PV, 0.5PV, 0.7PV and 1PV in sequence.
According to the experimental simulation method for removing the near-well blockage of the condensate gas well, the permeability change is calculated by using a conventional gas logging permeability formula used in the field.
According to the experimental simulation method for removing the near-well blockage of the condensate gas well, the injected blocking remover is ethanol, the ethanol is clean and environment-friendly, the stratum is free of pollution, the ethanol evaporates and absorbs water, partial stratum water lock can be effectively improved and even removed, different PV ethanol can be injected to observe the blocking removal condition in the experimental process, and the relationship between the injection amount and the blocking removal effect can be tested by injecting the ethanol according to PV times.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings needed to be used in the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are some embodiments of the present invention, and it is obvious for those skilled in the art that other drawings can be obtained according to these drawings without creative efforts.
Fig. 1 is a schematic structural diagram of the experimental simulation device for removing the near-well blockage of the condensate gas well provided in the embodiment of the present invention.
The main reference numbers indicate:
1. an adjustable constant-temperature oven;
2. a long core holder;
3. a first high-precision pressure monitoring meter;
4. a back pressure valve;
5. a condensate gas sample storage tank;
6. a first high-precision displacement pump;
7. filling a sand thin tube;
8. a condensate collecting pipe;
9. an ethanol sample storage tank;
10. a liquid nitrogen cooling system;
11. a full-automatic gas meter;
12. a second high-precision pressure monitoring meter;
13. a confining pressure meter;
14. a second high precision displacement pump;
15. a fourth high-precision displacement pump;
16. a fifth high-precision displacement pump;
17. an air intake valve;
18. and a third high-precision pressure monitoring meter.
Detailed Description
In order to clearly understand the technical features, objects and advantages of the present invention, the following detailed description of the technical solutions of the present invention will be made with reference to the following specific examples, which should not be construed as limiting the implementable scope of the present invention.
Example 1
The embodiment provides an experimental simulation device for removing the blockage of a condensate gas well near a well, the structural schematic diagram of the device is shown in fig. 1, and as can be seen from fig. 1, the experimental simulation device comprises:
the system comprises an adjustable constant-temperature oven 1, a long rock core holder 2, a sand-filled thin tube 7, a condensate gas sample storage tank 5, an ethanol sample storage tank 9, a condensate oil collecting pipe 8, a liquid nitrogen cooling system 10 and a full-automatic gas meter 11;
the long rock core holder 2 is used for placing a target long rock core simulating a near wellbore zone; the condensate gas sample storage tank 5 is connected with the sand-filling thin tube 7 through a pipeline sequentially via an air inlet valve 17 and a third high-precision pressure monitoring meter 18, the sand-filling thin tube 7 is connected with the inlet end of the long core holder 2 through a pipeline sequentially via a first high-precision pressure monitoring meter 3, and the outlet end of the long core holder 2 is connected with the ethanol sample storage tank 9 through a pipeline sequentially via a second high-precision pressure monitoring meter 12 and a back pressure valve 4; the outlet end of the long rock core holder 2 is connected with the condensate collecting pipe 8 through a capillary tube after sequentially passing through a second high-precision pressure monitoring meter 12 and a back pressure valve 4 through a pipeline;
the long rock core holder 2 and the sand-filled tubule 7 are positioned in the adjustable constant-temperature oven 1, and the condensate oil collecting pipe 8 is positioned in a liquid nitrogen cooling system 10;
and the middle part of the long rock core holder 2 is also connected with a confining pressure gauge 13.
In this embodiment, the condensate gas sample storage tank 5 is further connected to a first high-precision displacement pump 6.
In this embodiment, the ethanol sample storage tank 9 is connected to a second high-precision displacement pump 14.
In this embodiment, the back pressure valve 4 is connected to a fourth high-precision displacement pump 15.
In this embodiment, the confining pressure gauge 13 is connected with a fifth high-precision displacement pump 16.
Example 2
The embodiment provides an experimental simulation method for removing the near-well blockage of a condensate gas well, wherein the method utilizes the experimental simulation device for removing the near-well blockage of the condensate gas well provided in the embodiment 1, and the method specifically comprises the following steps:
(1) weighing a plurality of short rock cores in sequence and testing the porosity of the rock cores, vacuumizing the short rock cores and fully saturating formation water (generally, the formation water is used for one day), centrifuging by using a centrifuge to remove movable water in the rock cores and then weighing until the rock cores meet the requirement of irreducible water saturation, then placing the short rock cores into a rubber barrel and loading the rubber barrel into a long rock core holder after the short rock cores are subjected to blending average sequencing, setting the temperature of a constant temperature box (1) as an experimental formation temperature, and measuring the permeability of a target long rock core under the irreducible water saturation;
the relevant parameters of the cores used in this example are shown in table 1 below.
TABLE 1
Building pressure on the sand filling tubules and the target long core to the formation pressure by using dry gas, and controlling the pressure of the back pressure valve to be higher than the dew point pressure of the condensate gas (for example, the pressure of the back pressure valve can be controlled to be 300-500psi higher than the dew point pressure of the condensate gas) so as to ensure that the condensate gas is in a gas phase state when passing through the target long core; pumping a condensate gas sample into a sand-filled tubule, then entering a target long core for displacement, wherein the amount of the condensate gas sample used for displacement is about 5 times of the pore volume of the target long core, displacing dry gas, and when the composition and parameters (such as gas-oil ratio and the like, in the embodiment, the gas-oil ratio is 2023) of gas discharged from an outlet end are consistent with the composition and corresponding parameters of flash gas of the condensate gas, completely saturating the condensate gas by the target long core;
(2) the pressure in the target long core starts to be reduced from the dew point pressure of condensate gas (the dew point pressure of the condensate gas used in the embodiment is 38MPa, and the temperature is 85 ℃), and the outlet pressure of the long core holder is respectively controlled to be reasonable pressure which is sequentially reduced by a back pressure valve, wherein in the embodiment, the outlet pressure of the long core holder is respectively 5000Psi, 4150Psi, 3300Psi, 2450Psi, 1600Psi and 750 Psi; the pressure difference between the inlet and the outlet of the long rock core holder is determined according to the gas quantity at the outlet end; under each outlet pressure, after the outlet flow and the inlet pressure are stable, the condensate gas under the inlet pressure is used for displacement; recording outlet flow, inlet pressure and exhaustion pressure (outlet pressure, namely the pressure measured by a second high-precision pressure monitoring meter) at different times in the displacement process, and calculating to obtain the permeability change of the long rock core at each pressure point of the exhaustion test; when the permeability of each pressure point of the failure test is basically unchanged, considering that the reverse condensation injury reaches the maximum value, and stopping injecting the condensate gas sample;
the experimental data in step (2) of this example are shown in Table 2 below.
TABLE 2
(3) Injecting a certain amount of ethanol samples (the injection amount of ethanol is 0.3PV, 0.5PV, 0.7PV and 1PV respectively in sequence) from the outlet end of the long core holder, firstly injecting 0.3PV ethanol, closing a back pressure valve after complete injection, stewing for a period of time until the pressure of the inlet and the outlet of the target long core is stable, and then continuously pumping condensate gas samples from the inlet end of the target long core; recording outlet flow, inlet pressure and outlet pressure at different time in the experiment process; testing the permeability change of the mined long rock core after ethanol is injected by controlling the inlet pressure and the pressure of a back pressure valve; when the permeability of the long core measured in step (3) is consistent with the permeability of the long core in step (2) with substantially no change in permeability, the permeability obtained in the third set of experiments in Table 3 (0.0664810) -3 μm 2 ) Permeability (0.0642110) obtained from experiment in the fifth group of Table 2 -3 μm 2 ) If the condensate gas is basically consistent, the reverse condensate damage is considered to reach the maximum value again, and the condensate gas sample is stopped being injected;
repeating the step (3), and continuously injecting from the outlet end of the long rock core holder in sequence0.5PV ethanol, closing a back pressure valve after the ethanol is completely injected, and stewing for a period of time until the pressure of an inlet and an outlet of the target long core is stable, and then continuously pumping a condensate gas sample from the inlet end of the target long core; recording outlet flow, inlet pressure and outlet pressure at different time in the experiment process; testing the permeability change of the mined long rock core after ethanol is injected by controlling the inlet pressure and the pressure of a back pressure valve; when the permeability of the long core measured in step (3) is consistent with the permeability of the long core in step (2) with substantially no change in permeability, that is, the permeability obtained in the third set of experiments in Table 4 (0.0671410) -3 μm 2 ) Permeability (0.0642110) obtained from experiment in the fifth group of Table 2 -3 μm 2 ) If the condensate gas is basically consistent, the reverse condensate damage is considered to reach the maximum value again, and the condensate gas sample is stopped being injected;
repeating the step (3), continuously and sequentially injecting 0.7PV ethanol from the outlet end of the long rock core holder, closing the back pressure valve after complete injection, and stewing for a period of time until the inlet and outlet pressure of the target long rock core is stable, and then continuously pumping the condensate gas sample from the inlet end of the target long rock core; recording outlet flow, inlet pressure and outlet pressure at different time in the experiment process; testing the permeability change of the mined long rock core after ethanol is injected by controlling the inlet pressure and the pressure of a back pressure valve; when the permeability of the long core measured in step (3) is consistent with the permeability of the long core in step (2) with substantially no change in permeability, the permeability obtained in the fourth set of experiments in Table 5 (0.0673510) -3 μm 2 ) Permeability (0.0642110) obtained from experiment in the fifth group of Table 2 -3 μm 2 ) If the condensate gas is basically consistent, the reverse condensate damage is considered to reach the maximum value again, and the condensate gas sample is stopped being injected;
(4) and (4) repeating the step (3), and continuously injecting the 1PV ethanol sample from the outlet end of the long rock core holder, and then mining until no condensate oil drips out of the capillary tube at the outlet end of the long rock core holder.
The experimental data obtained in step (3) and step (4) are shown in tables 3 to 6 below.
TABLE 3
TABLE 4
TABLE 5
TABLE 6
In conclusion, in the experimental simulation method for removing the near-well blockage of the condensate gas well, the injected blocking remover is ethanol, the ethanol is clean and environment-friendly, has no pollution to the stratum, can effectively improve or even remove part of stratum water lock by evaporating and absorbing water, can control the injection of different PV ethanol to observe the blockage removal condition in the experimental process, and can test the relation between the injection amount and the blockage removal effect by injecting the ethanol according to the PV times.
The above description is only exemplary of the invention and should not be taken as limiting the scope of the invention, so that the invention is intended to cover all modifications and equivalents of the embodiments described herein. In addition, the technical features and the technical inventions of the present invention, the technical features and the technical inventions, and the technical inventions can be freely combined and used.
Claims (7)
1. An experimental simulation method for removing the near-well blockage of a condensate gas well is characterized in that an experimental simulation device for removing the near-well blockage of the condensate gas well is used, and the experimental simulation device for removing the near-well blockage of the condensate gas well comprises the following steps: the device comprises an adjustable constant-temperature oven (1), a long rock core holder (2), a sand-filled thin tube (7), a condensate gas sample storage tank (5), an ethanol sample storage tank (9), a condensate oil collecting pipe (8), a liquid nitrogen cooling system (10) and a full-automatic gas meter (11);
the long core holder (2) is used for placing a target long core simulating a near wellbore zone; the condensate gas sample storage tank (5) is connected with the sand-filled tubule (7) through a pipeline so as to simulate the seepage of a condensate gas source layer of a far well zone by utilizing the condensate gas sample and the sand-filled tubule, the sand-filled tubule (7) is connected with the inlet end of the long core holder (2) through a first high-precision pressure monitoring meter through a pipeline, and the outlet end of the long core holder (2) is connected with the ethanol sample storage tank (9) through a second high-precision pressure monitoring meter and a back pressure valve (4) in sequence through pipelines; the outlet end of the long rock core holder (2) is connected with the condensate collecting pipe (8) through a capillary tube via a second high-precision pressure monitoring meter and a back pressure valve (4) in sequence through pipelines;
the long core holder (2) and the sand-filled tubule (7) are positioned in the adjustable constant-temperature oven (1), and the condensate oil collecting pipe (8) is positioned in a liquid nitrogen cooling system (10);
the middle part of the long rock core holder (2) is also connected with a confining pressure gauge (13);
the condensate gas sample storage tank (5) is connected with the sand filling tubule (7) through an air inlet valve (17) and a third high-precision pressure monitoring meter (18) in sequence through a pipeline;
the method comprises the following steps:
(1) at the experimental formation temperature, short rock cores are placed into a rubber barrel and then are placed into a long rock core holder after being subjected to blending average sequencing, dry gas is used for building pressure to the formation pressure for a sand filling tubule and a target long rock core, the pressure of a back pressure valve is controlled to be higher than the dew point pressure of condensate gas, a condensate gas sample is pumped into the sand filling tubule and then enters the target long rock core for displacement, the dry gas is displaced, and when the composition and parameters of gas discharged from an outlet end are consistent with the flash evaporation gas composition and corresponding parameters of the condensate gas, the target long rock core is completely saturated with the condensate gas;
in the step (1), the pressure of the back pressure valve is controlled to be 300-500psi higher than the dew point pressure of the condensate gas;
in the step (1), the amount of the condensate gas sample used for displacement is 4-6 times of the pore volume of the target long rock core;
(2) the pressure in the target long rock core is reduced from the dew point pressure of the condensate gas, the outlet pressure of the long rock core holder is respectively controlled to be sequentially reduced reasonable pressure through a back pressure valve, and the pressure difference between the inlet and the outlet of the long rock core holder is determined according to the gas quantity at the outlet end; under each outlet pressure, after the outlet flow and the inlet pressure are stable, the condensate gas under the inlet pressure is used for displacement; recording outlet flow, inlet pressure and outlet pressure at different time in the displacement process, and calculating to obtain permeability change of the long rock core under each reasonable pressure; stopping injecting the condensate gas sample when the permeability of the long rock core is basically unchanged under each reasonable pressure;
(3) injecting a certain amount of ethanol sample from the outlet end of the long core holder, closing the back pressure valve after complete injection, and stewing for a period of time until the inlet and outlet pressure of the target long core is stable, and then continuously pumping the condensate gas sample from the inlet end of the target long core; recording outlet flow, inlet pressure and outlet pressure at different time in the experimental process, and testing the permeability change of the mined long rock core after ethanol is injected by controlling the inlet pressure and the pressure of a back pressure valve; stopping injecting the condensate gas sample when the permeability of the long rock core measured in the step (3) is consistent with the permeability of the long rock core in the step (2) when the permeability of the long rock core is basically unchanged;
(4) repeating the step (3), and continuously injecting a certain amount of ethanol samples from the outlet end of the long rock core holder until no condensate oil drips from the capillary tube at the outlet end of the long rock core holder after the last batch of ethanol samples are injected;
before step (1), the method further comprises the operation of testing the porosity and permeability at irreducible water saturation of the target long core;
the method for testing the permeability of the target long core under the irreducible water saturation specifically comprises the following steps:
testing the porosity of the rock core, vacuumizing a target long rock core, setting the temperature of an adjustable constant-temperature oven as the temperature of an experimental stratum, fully saturating the rock core with a stratum water sample, and centrifuging the rock core by using a centrifugal pump to remove movable water in the rock core and establish the saturation of bound water; measuring the permeability of the target long rock core under the irreducible water saturation;
in the step (3) and the step (4), the injection amount of the ethanol sample is 0.3PV, 0.5PV, 0.7PV and 1PV in sequence.
2. The experimental simulation method for removing the near-well blockage of condensate wells as defined in claim 1, wherein in the step (1), the amount of the condensate gas sample used for displacement is 5 times of the pore volume of the target long core.
3. The experimental simulation method for the unblocking of a condensate gas well near the well according to claim 1, wherein in the step (1), the parameter includes a gas-oil ratio.
4. The experimental simulation method for the unblocking of a condensate gas well near the well according to claim 1, characterized in that the condensate gas sample storage tank (5) is further connected with a first high-precision displacement pump (6).
5. An experimental simulation method for the de-plugging of condensate gas wells near the well as defined in claim 1 wherein a second high precision displacement pump (14) is connected to the ethanol sample storage tank (9).
6. The experimental simulation method for relieving condensate gas well near-well plugging according to claim 1, characterized in that the back-pressure valve (4) is connected with a fourth high-precision displacement pump (15).
7. The experimental simulation method for the de-plugging of condensate gas wells near the well as recited in claim 1 wherein a fifth high precision displacement pump (16) is connected to the gage.
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