CN114439462A - Research method for composition change of multiple injection-production fluid of condensate gas reservoir reconstruction gas storage - Google Patents
Research method for composition change of multiple injection-production fluid of condensate gas reservoir reconstruction gas storage Download PDFInfo
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- 239000012530 fluid Substances 0.000 title claims abstract description 41
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 37
- 230000008859 change Effects 0.000 title claims abstract description 29
- 238000000034 method Methods 0.000 title claims abstract description 22
- 239000000203 mixture Substances 0.000 title claims abstract description 21
- 238000003860 storage Methods 0.000 title claims abstract description 19
- 238000011160 research Methods 0.000 title claims abstract description 10
- 239000011435 rock Substances 0.000 claims abstract description 57
- 238000002347 injection Methods 0.000 claims abstract description 38
- 239000007924 injection Substances 0.000 claims abstract description 38
- 239000008398 formation water Substances 0.000 claims abstract description 21
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 19
- 238000005065 mining Methods 0.000 claims abstract description 12
- 238000004140 cleaning Methods 0.000 claims abstract description 8
- 239000011148 porous material Substances 0.000 claims abstract description 6
- 238000012360 testing method Methods 0.000 claims abstract description 6
- 238000001035 drying Methods 0.000 claims abstract description 4
- 238000009738 saturating Methods 0.000 claims abstract description 4
- 238000006073 displacement reaction Methods 0.000 claims description 20
- 239000007788 liquid Substances 0.000 claims description 11
- 230000008569 process Effects 0.000 claims description 6
- 238000011161 development Methods 0.000 abstract description 4
- 239000007789 gas Substances 0.000 description 95
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 description 10
- 238000002474 experimental method Methods 0.000 description 8
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 6
- 239000003208 petroleum Substances 0.000 description 5
- 239000002253 acid Substances 0.000 description 3
- 229910052757 nitrogen Inorganic materials 0.000 description 3
- 238000010438 heat treatment Methods 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 229920006395 saturated elastomer Polymers 0.000 description 2
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 1
- 238000009833 condensation Methods 0.000 description 1
- 230000005494 condensation Effects 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 239000004088 foaming agent Substances 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 230000001932 seasonal effect Effects 0.000 description 1
- 230000035945 sensitivity Effects 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 238000002791 soaking Methods 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
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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
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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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
- E21B43/168—Injecting a gaseous medium
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Abstract
The invention relates to a research method for the composition change of multiple injection-production fluids of a condensate gas reservoir reconstruction gas storage, which comprises the following steps: (1) cleaning and drying the rock core, the rock core holder, the intermediate container and the pipeline; (2) filling the core into a holder, vacuumizing, saturating formation water, and establishing formation pressure for the core by using the formation water; (3) transferring the gas condensate sample into a rock core, and displacing formation water in pores of the rock core until the gas-oil ratio of an outlet of the rock core is consistent with the gas-oil ratio of the gas condensate sample to form an original gas reservoir; (4) failure mining is carried out, and oil production, gas production and corresponding failure pressure of each level of failure are recorded; (5) performing dry gas injection and huff-and-puff exploitation for multiple times until the gas-oil ratio of the fluid to be exploited is stable; (6) and recording the oil production and the gas production of each stage of the injected dry gas huff-puff exploitation, and testing the composition change of the produced well fluid by using a chromatograph. The method is simple to operate and high in applicability, and has important guiding significance for condensate gas reservoir gas injection development.
Description
Technical Field
The invention belongs to the field of oil and gas field exploration and development, and particularly relates to a method for researching a change rule of a component of a fluid produced by multiple injection and production of a condensate gas reservoir reconstruction gas storage.
Background
The running mode of the condensate gas reservoir after the gas reservoir is reconstructed is changed from depletion type mining to multi-cycle huff-puff injection and mining, and because urban seasonal peak regulation is often expressed as 'summer injection and winter mining', in the process of gas injection and well plugging, injected gas can be fully contacted with reservoir fluid to generate component exchange, and the component structure of the fluid extracted by the gas reservoir is influenced. Therefore, in order to ensure normal construction and operation of the gas storage, it is necessary to research the change rule of the components of the fluid produced by multiple injection and production of the gas storage reconstructed from the condensate gas reservoir.
At present, most of researches on multiple injection and production of gas storage by scholars at home and abroad are focused on reservoir seepage capability, stress sensitivity, injection and production mechanisms and the like. Only a few scholars have studied the changes in the composition of the fluid produced after insufflation. Lvjian et al (Lvjian, Li Zhi, Pajianglong, Tangjing, Xue Wei, xi fei.) study on the gas component change law of produced gas from underground gas storage in acid gas reservoir, using Erdos basin Shaan 224 gas storage library as an example [ J ] natural gas industry, 2017,37(08): 96-101) take Erdos basin Shaan 224 gas storage library as an example, establish an acid gas component model, predict the component change law of acid gas in the injection and production process, and verify the component prediction result through the injection and production tests of vertical wells and horizontal wells.
On the basis, the invention adopts an indoor physical model experiment, comprehensively considers the influence of injected gas on well fluid components, and establishes an experimental method for injecting dry gas in a long rock core to huff and puff and exploit and test the composition of the exploited well fluid.
Disclosure of Invention
The invention aims to provide a research method for composition change of multiple injection-production produced fluid of a gas storage reconstructed from a condensate gas reservoir, which has the advantages of simple operation and strong applicability, can analyze the change rule of the fluid components of a condensate gas reservoir gas injection huff-puff production produced well, has important guiding significance for gas injection development of the condensate gas reservoir, and has wide application prospect.
In order to achieve the technical purpose, the invention adopts the following technical scheme.
The condensate gas is in a single gas phase under the reservoir condition, and when gas injection and pressure maintaining are carried out for exploitation, component exchange can be carried out between the condensate gas and the injected gas, so that the component change rule of the produced well flow can be tested and analyzed. Firstly, saturating a rock core with formation water; then displacing formation water in the core by using a prepared condensate gas sample under the formation condition until the gas-oil ratio of fluid at an outlet is consistent with that of the prepared condensate gas, and forming an original gas reservoir; then failure mining is carried out, the oil and gas amount produced at each level are recorded, and the composition change of the well flow is tested; after failure, the long core system is recovered to the formation pressure by injecting gas, the valve is closed to blank the well for more than 6 hours, and failure exploitation is carried out again through the inlet; the above processes are repeated until the gas-oil ratio of the produced well flow is stable.
The research method for the composition change of multiple injection and production fluids of a gas storage is reconstructed by a condensate gas reservoir and is completed by an injection and production device, the device comprises a rock core holder, a middle container, a displacement pump, a confining pressure pump, a back pressure valve, a gas-liquid separator and a gas meter, the inlet end of the rock core holder is connected with the middle container and the displacement pump, the outlet end of the rock core holder is connected with the back pressure valve, the back pressure valve is connected with the gas-liquid separator and the gas meter, pressure meters are arranged at the left end and the right end of the rock core holder, the confining pressure pump is connected at the middle end of the rock core holder, and the rock core holder and the middle container are positioned in a constant temperature box, and the method sequentially comprises the following steps:
(1) cleaning and drying the rock core, the rock core holder, the intermediate container and the pipeline by using petroleum ether;
(2) filling a rock core into a rock core holder, vacuumizing the rock core holder by using a vacuum pump, filling formation water into an intermediate container, saturating the rock core with the formation water by using a displacement pump, establishing formation pressure for the rock core by using the formation water, and opening a constant temperature box to enable the temperature to reach the formation temperature;
(3) filling the condensate gas sample into an intermediate container, transferring the prepared condensate gas sample into a rock core by using a displacement pump, and displacing the condensate gas sample out of formation water in pores of the rock core until the gas-oil ratio at the outlet of the rock core is consistent with the gas-oil ratio of the condensate gas sample to form an original gas reservoir;
(4) failure mining is carried out, the oil production, the gas production and the corresponding failure pressure of each level of failure are recorded, and composition change analysis is carried out on the extracted fluid by utilizing a chromatograph;
(5) carrying out dry gas injection huff-puff exploitation, filling dry gas into an intermediate container, transferring the dry gas into the rock core by using a displacement pump, recovering the rock core to the formation pressure by injecting the dry gas, closing a valve at the inlet end of the rock core to seal the well for more than 6h, carrying out exhaustion exploitation again, repeating the step (5), and carrying out dry gas injection huff-puff exploitation for multiple times until the gas-oil ratio of the produced fluid is stable;
(6) and recording the oil production and the gas production of each stage of the injected dry gas huff-puff exploitation, and testing the composition change of the produced well fluid by using a chromatograph.
In the step (2), the confining pressure is kept higher than the back pressure by 2-3MPa and the back pressure is kept higher than the outlet pressure by 2-3MPa all the time in the pressure building process until the rock core reaches the formation pressure.
In the step (4), the exhaustion mining is performed, namely, from the formation pressure, the confining pressure and the back pressure are gradually reduced, each stage is reduced by 2-3MPa, the gas-liquid separator and the gas meter respectively collect the condensate oil and the condensate gas, and when no fluid is produced at an outlet, the confining pressure and the back pressure are continuously reduced until the pressure is exhausted to the target pressure (different pressure intervals for designing and operating different gas storage reservoirs, and the specific gas storage reservoirs have the target operating pressure).
In the step (5), dry gas injection huff-puff mining is carried out, namely dry gas is injected into the rock core from the inlet end, the confining pressure and the back pressure are sequentially increased, the confining pressure is kept to be higher than the back pressure by 2-3MPa, and the back pressure is kept to be higher than the outlet pressure by 2-3MPa, and gas injection is stopped until the pressures at the two ends of the rock core are raised to the formation pressure and kept stable; and (4) stewing for more than 6 hours to ensure that the injected gas is fully contacted with the fluid in the rock core and then failure mining is carried out until the pressure is failed to reach the target pressure.
The method is based on the change of the components of the produced well fluid after the gas injection is tested by the long core huff and puff experimental instrument, can research the influence of the gas injection under high temperature and high pressure on the produced well fluid of the condensate gas reservoir and the change rule of the components of the produced fluid, and provides a certain reference value for the gas injection development of the condensate gas reservoir.
Drawings
FIG. 1 is a diagram of the apparatus used in the experimental method for testing the gas formation bottom gas injection top mining.
In the figure: 1. 17, 22-displacement pump, confining pressure pump and back pressure pump; 2. 4, 6, 8, 10, 12, 13, 15, 19, 21, 24, 26-valves; 7. 11, 14, 20, 25-three-way valve; 3-an intermediate container; 9-a core holder; 5. 16, 18, 23-pressure gauge; 27-a back-pressure valve; 28-gas-liquid separator; 29-gas meter; 30-constant temperature oven.
Detailed Description
The following detailed description of the embodiments of the invention will be made with reference to the accompanying drawings.
The experimental method for the change rule of the components of the fluid produced by multiple injection and production of the condensate gas reservoir is completed by the aid of the device shown in the figure 1, the device comprises a core holder 9, an intermediate container 3, a displacement pump 1, a confining pressure pump 17, a back pressure valve 27, a gas-liquid separator 28 and a gas meter 29, wherein the inlet end of the core holder 9 is connected with the intermediate container 3 and the displacement pump 1, the outlet end of the core holder 9 is connected with the back pressure valve 27, the back pressure valve is connected with the gas-liquid separator 28 and the gas meter 29, pressure meters 5 and 18 are arranged at the left end and the right end of the core holder, the middle end of the core holder is connected with the confining pressure pump 17, and the core holder and the intermediate container are located in a constant temperature box 30.
The research method for the composition change of the fluid produced by multiple injection and production of the condensate gas reservoir reconstruction gas reservoir sequentially comprises the following steps:
(1) cleaning experimental instrument
And (3) cleaning and drying the rock core holder, the intermediate container and the three-way valve by using petroleum ether and absolute ethyl alcohol.
(2) Cleaning rock core
Putting the core into a core holder, filling petroleum ether in an intermediate container 3 according to a connecting pipeline shown in figure 1, opening valves 2, 4, 6, 8, 19 and 21, and cleaning the whole system connected with the core holder by using a displacement pump 1 (until the petroleum ether at the outlet is clear); after cleaning, the valves 6 and 8 are closed, the intermediate container 3 is cleaned again and filled with proper amount of nitrogen, then the valves 6 and 8 are opened, petroleum ether in the experimental environment is dried by the nitrogen, and in the process, the foaming agent is used for detecting leakage of the joints of all pipelines and the interfaces of the rock core holder.
(3) Establishing the experimental conditions
1) Vacuum conditions were established. Connecting a vacuum pump with a three-way valve 7, and vacuumizing the core holder (about 3-5 h);
2) saturated formation water. Filling the middle container 3 with formation water, opening valves 2, 4, 6 and 8, keeping the formation water at a constant pressure by using a displacement pump 1 to completely saturate the rock core, and raising the temperature to enable the formation water to enter small pores more quickly; when the speed of the displacement pump is displayed as 0, the saturation is finished;
3) the experimental pressure was established. Filling formation water in an intermediate container 3 to establish an experimental pressure (36.91 MPa), opening valves 10, 12, 13 and 15, adding a confining pressure of 5MPa to the core holder by using a confining pressure pump 17, then opening valves 24 and 26, adding a return pressure of 3MPa by using a return pressure pump 22, finally enabling the inlet pressure to reach 1MPa by using a displacement pump 1, keeping the inlet and outlet pressures consistent, continuously and sequentially pressurizing, and always keeping the confining pressure higher than the return pressure of 2-3MPa and the return pressure higher than the outlet pressure of 2-3MPa until the formation pressure is reached, and completing the establishment of the experimental pressure;
4) heating to form original gas reservoir. Adjusting pumps 1, 17 and 22 to respectively keep the inlet, the confining pressure and the back pressure in a constant pressure mode, and opening a constant temperature box to raise the temperature to 76 ℃ of the formation temperature (about 8-10 h); and after the temperature is stable, displacing the formation water in the pores by using the displacement pump 1, and measuring the pump inlet reading of the displacement pump 1 until the scale exceeds the pore volume, the measured ratio of the volume of the outlet formation water to the volume of the fully saturated formation water meets the saturation of the bound water, and the measured outlet gas-oil ratio is consistent with the sample gas-oil ratio to form an original gas reservoir.
(3) Carry out the experiment
1) Firstly, performing a failure experiment, closing valves 4 and 8, performing failure from the stratum pressure at an inlet end to 36.91MPa, gradually reducing confining pressure and back pressure by using pumps 17 and 22, reducing the confining pressure and the back pressure by 2-3MPa at each stage, respectively collecting condensate gas and condensate oil from a gas-liquid separation device 28 by using liquid nitrogen condensation, continuously reducing the confining pressure and the back pressure in sequence after the outlet does not produce any fluid and the speed of a back pressure displacement pump is 0, and stopping the failure until the pressure is failed to the target pressure of 15MPa (the pressure is the lowest pressure of the design and operation of a gas storage reservoir); recording the oil and gas produced by each stage of failure and the corresponding failure pressure, and analyzing the composition change of the produced oil-gas fluid by using a chromatograph;
2) carrying out a dry gas injection huff and puff experiment, filling the middle container 3 with dry gas and heating the dry gas to the formation temperature, closing the valve 21, opening the valves 2, 4, 6, 8 and 19, injecting the dry gas into the rock core from the inlet end, sequentially increasing the confining pressure and the back pressure (the process is equivalent to establishing pressure by using the dry gas), keeping the confining pressure higher than the back pressure by 2-3MPa and the back pressure higher than the outlet pressure by 2-3MPa, stopping injecting gas when the readings of the pressure gauges 5 and 18 are increased to 36.91MPa and kept stable, closing the valves 4 and 8, fully contacting the injected gas with the fluid in the rock core (soaking for more than 6 hours), carrying out failure exploitation until the pressure failure reaches 15MPa, recording the oil and gas produced in each failure and the corresponding failure pressure, and carrying out composition change analysis on the oil and gas fluid produced by using a chromatograph, thus completing one injection huff and puff. And repeating the next injection-production throughput until the gas-oil ratio of the finally produced fluid is stable.
(4) And recording the experiment temperature, the oil gas production amount and the corresponding failure pressure of each stage of failure and handling, and analyzing the component change rule of the gas/oil collected by each stage by using a chromatograph.
The present invention is not limited to the above-described embodiments, and various modifications are possible for those skilled in the art. Any modification, equivalent replacement, or improvement made within the spirit and principle of the present invention should be included in the protection scope of the present invention.
Claims (5)
1. The research method for the composition change of multiple injection and production fluids of a gas storage is reconstructed by a condensate gas reservoir and is completed by an injection and production device, the device comprises a rock core holder, a middle container, a displacement pump, a confining pressure pump, a back pressure valve, a gas-liquid separator and a gas meter, the inlet end of the rock core holder is connected with the middle container and the displacement pump, the outlet end of the rock core holder is connected with the back pressure valve, the back pressure valve is connected with the gas-liquid separator and the gas meter, pressure meters are arranged at the left end and the right end of the rock core holder, the confining pressure pump is connected at the middle end of the rock core holder, and the rock core holder and the middle container are positioned in a constant temperature box, and the method sequentially comprises the following steps:
(1) cleaning and drying the rock core, the rock core holder, the intermediate container and the pipeline;
(2) filling a rock core into a rock core holder, vacuumizing the rock core holder by using a vacuum pump, filling formation water into an intermediate container, saturating the rock core with the formation water by using a displacement pump, establishing formation pressure for the rock core by using the formation water, and opening a constant temperature box to enable the temperature to reach the formation temperature;
(3) filling the condensate gas sample into an intermediate container, transferring the condensate gas sample into a rock core by using a displacement pump, and displacing formation water in pores of the rock core by using the condensate gas sample until the gas-oil ratio of an outlet of the rock core is consistent with the gas-oil ratio of the condensate gas sample to form an original gas reservoir;
(4) failure mining is carried out, the oil production, the gas production and the corresponding failure pressure of each level of failure are recorded, and composition change analysis is carried out on the extracted fluid by utilizing a chromatograph;
(5) carrying out dry gas injection huff-puff exploitation, filling dry gas into an intermediate container, transferring the dry gas into the rock core by using a displacement pump, recovering the rock core to the formation pressure by injecting the dry gas, closing a valve at the inlet end of the rock core to seal the well for more than 6h, carrying out exhaustion exploitation again, repeating the step (5), and carrying out dry gas injection huff-puff exploitation for multiple times until the gas-oil ratio of the produced fluid is stable;
(6) and recording the oil production and the gas production of each stage of the injected dry gas huff-puff exploitation, and testing the composition change of the produced well fluid by using a chromatograph.
2. The method for researching composition change of the fluid produced by multiple injection and production of the condensate gas reservoir reconstruction gas storage according to claim 1, wherein in the step (2), the confining pressure is always kept higher than the back pressure by 2-3MPa in the pressure building process, and the back pressure is kept higher than the outlet pressure by 2-3MPa until the rock core reaches the formation pressure.
3. The method for researching the composition change of the condensate gas reservoir reconstruction gas storage bank multiple injection and production fluids according to claim 1, wherein in the step (4), the depletion production is performed, namely, the confining pressure and the back pressure are gradually reduced from the formation pressure, each stage is reduced by 2-3MPa, the gas-liquid separator and the gas meter respectively collect condensate oil and condensate gas, and when no fluid is produced at an outlet, the confining pressure and the back pressure are continuously reduced until the pressure is depleted to the target pressure.
4. The method for researching composition change of fluid produced by multiple injection and production of a gas storage reconstructed from a condensate gas reservoir as claimed in claim 1, wherein in the step (5), dry gas injection huff-puff production is performed, that is, dry gas is injected into the core from the inlet end, the confining pressure and the back pressure are sequentially increased, the confining pressure is kept higher than the back pressure by 2-3MPa, and the back pressure is kept higher than the outlet pressure by 2-3MPa, and gas injection is stopped until the pressures at the two ends of the core are raised to the formation pressure and kept stable; and (4) stewing for more than 6 hours to ensure that the injected gas is fully contacted with the fluid in the rock core and then failure mining is carried out until the pressure is failed to reach the target pressure.
5. The method of studying the composition change of the condensate gas reservoir rebuilding gas reservoir multiple injection and production fluids according to claim 3 or 4, wherein the target pressure is the lowest pressure at which the gas reservoir is designed to operate.
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| CN115078355A (en) * | 2022-05-17 | 2022-09-20 | 西南石油大学 | Visualization device and method for simulating gas injection phase state characteristics of crude oil in porous medium |
| CN114965960A (en) * | 2022-05-30 | 2022-08-30 | 西南石油大学 | Multi-period injection-production seepage simulation experiment evaluation method for oil reservoir reconstruction gas storage |
| CN114965960B (en) * | 2022-05-30 | 2023-09-19 | 西南石油大学 | Multi-period injection-production seepage simulation experiment evaluation method for reservoir reconstruction gas storage |
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