CN112082900B - Testing device and method for improving gas injection accuracy of long core of low-permeability reservoir - Google Patents
Testing device and method for improving gas injection accuracy of long core of low-permeability reservoir Download PDFInfo
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- 239000007924 injection Substances 0.000 title claims abstract description 90
- 238000012360 testing method Methods 0.000 title claims abstract description 24
- 238000000034 method Methods 0.000 title claims abstract description 20
- 238000006073 displacement reaction Methods 0.000 claims abstract description 31
- 239000012530 fluid Substances 0.000 claims abstract description 20
- 239000011148 porous material Substances 0.000 claims abstract description 18
- 230000035699 permeability Effects 0.000 claims abstract description 16
- 230000008859 change Effects 0.000 claims abstract description 11
- 239000011435 rock Substances 0.000 claims abstract description 11
- 238000005259 measurement Methods 0.000 claims abstract description 5
- 239000007789 gas Substances 0.000 claims description 105
- 239000003921 oil Substances 0.000 claims description 52
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 19
- 238000004088 simulation Methods 0.000 claims description 17
- 238000007789 sealing Methods 0.000 claims description 12
- 230000015572 biosynthetic process Effects 0.000 claims description 8
- 238000001914 filtration Methods 0.000 claims description 8
- 230000000704 physical effect Effects 0.000 claims description 8
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 7
- 230000033558 biomineral tissue development Effects 0.000 claims description 5
- 239000010779 crude oil Substances 0.000 claims description 5
- 238000004458 analytical method Methods 0.000 claims description 4
- 238000007872 degassing Methods 0.000 claims description 4
- 238000001035 drying Methods 0.000 claims description 4
- 238000005070 sampling Methods 0.000 claims description 4
- 238000005406 washing Methods 0.000 claims description 4
- 229910052757 nitrogen Inorganic materials 0.000 claims description 3
- 229910001873 dinitrogen Inorganic materials 0.000 claims 1
- 238000011161 development Methods 0.000 abstract description 6
- 238000013461 design Methods 0.000 abstract description 3
- 230000007547 defect Effects 0.000 abstract description 2
- 238000011234 economic evaluation Methods 0.000 abstract description 2
- 238000011084 recovery Methods 0.000 description 9
- 238000010998 test method Methods 0.000 description 7
- 230000018109 developmental process Effects 0.000 description 5
- 229930195733 hydrocarbon Natural products 0.000 description 5
- 150000002430 hydrocarbons Chemical class 0.000 description 5
- 239000004215 Carbon black (E152) Substances 0.000 description 4
- 238000012937 correction Methods 0.000 description 4
- 230000000694 effects Effects 0.000 description 4
- 238000005516 engineering process Methods 0.000 description 3
- 238000002474 experimental method Methods 0.000 description 3
- 230000008569 process Effects 0.000 description 3
- 239000000243 solution Substances 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 238000011156 evaluation Methods 0.000 description 2
- 241000237858 Gastropoda Species 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
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- 239000003208 petroleum Substances 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N7/00—Analysing materials by measuring the pressure or volume of a gas or vapour
- G01N7/10—Analysing materials by measuring the pressure or volume of a gas or vapour by allowing diffusion of components through a porous wall and measuring a pressure or volume difference
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
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Abstract
The invention discloses a testing device and a testing method for improving the gas injection quantity precision of a low permeability reservoir core, wherein the testing method comprises the following steps: preparing a core for testing and fluid; establishing an air-driven fluid model; the pressure controller 9 sets a pressure value higher than the highest displacement pressure, and gas is injected into the rock core at a constant speed; every 0.05 times of pore volume change, recording corresponding data; the pore volume is plotted against the injection time value. The invention provides a method for improving the accuracy of gas injection by considering the defect that the gas has stronger compressibility and thus inaccurate gas injection amount measurement, and provides a method for arranging a pressure controller at the front end of the inlet of a core holder, thereby improving the accuracy of gas injection amount measurement and providing reliable data support for later economic evaluation and development scheme design.
Description
Technical Field
The invention relates to the technical field of oil gas development gas drive and recovery ratio improvement, in particular to a testing device and method for improving the core gas injection accuracy of a low-permeability reservoir.
Background
The low permeability hydrocarbon reservoir has the remarkable characteristics of low permeability of the reservoir, insufficient natural energy, fast failure of elastic energy, fast conversion into a low-benefit and long-period solution gas flooding development stage, fast decrease of oil well yield, low development level and difficult low permeability water injection. The gas injection is not affected by the mineralization degree of stratum water, the problems of difficult water injection or a plurality of water-sensitive oil reservoirs can be solved, the most favorable factors of the gas injection are that the gas is easy to permeate, the reasonable injection amount is added, the viscosity of oil in the gas injection process is reduced, the volume is expanded, and the pressure exploitation of the stratum can be kept after the gas injection. In a hypotonic oil reservoir, the gas injection enhanced recovery technology is a technology which is theoretically higher than water injection enhanced recovery, gas injection drives develop rapidly in recent foreign countries, and the gas injection enhanced recovery technology becomes the most important enhanced recovery method except heat recovery, and is a technological revolution with the most potential and the most prospect in the worldwide petroleum exploitation industry.
The long core gas injection displacement experiment is an important method for evaluating secondary oil recovery and tertiary oil recovery, and is used for evaluating gas injection effect and recovery ratio after gas injection, experimental simulation is closer to the actual condition of stratum, in the long core displacement experiment process, the gas injection effect is mainly influenced by fluid property and gas injection parameters, if key gas injection parameters such as inaccurate metering of injection quantity cause deviation of injection multiple and injection time, the evaluation effect of gas injection is influenced, and finally, the design of a development scheme and the evaluation of economic benefit are not facilitated, an original oil field is subjected to indoor pilot practice for decades, and the fact that in the long core gas injection displacement process, particularly gas and water alternate flooding (the resistance at two ends of a core is larger due to gas and water slugs) is found, because the gas has stronger compressibility, low-permeability long core pressure difference is large, partial gas volume compression is generated for boosting when a gas injection stage is started by a high-pressure constant-speed pump, and the actual injection core displacement gas quantity is low; after the gas is dissolved in crude oil and the fluid resistance is reduced through breakthrough, namely, in the pressure reduction stage, the gas is injected by a high-temperature high-pressure constant-speed pump, the pressure is released, and the actual gas quantity injected into the rock core is higher; the continuous fluctuation and variation of the pressure can not accurately measure the instantaneous injection quantity, injection time and the like, the injection multiple and the injection time are parameters of the most relation of the gas drive, and if the record of the injection multiple and the injection time is inaccurate, the accuracy of the gas drive experiment can be greatly reduced.
Disclosure of Invention
The invention aims to solve the technical problem of inaccurate metering of the injected gas amount due to compressibility of gas.
In order to solve the technical problems, the invention provides a testing device and a method for improving the gas injection accuracy of a long core of a low permeability reservoir, wherein the accuracy testing device comprises: an injection system, a formation simulation system, and a metering system; wherein:
the injection system includes: the high-temperature high-pressure plunger displacement pump comprises a high-temperature high-pressure plunger displacement pump oil sample (1), oil sample inlet end control valves (3) and (6), a high-temperature high-pressure plunger displacement pump gas sample (4) and an injection end control main valve (7); the high-temperature high-pressure plunger displacement pump oil sample (1) is connected with an oil sample inlet end control valve (3); the high-temperature high-pressure plunger displacement pump gas sample (4) is connected with an oil sample inlet end control valve (6); the injection end control main valve (7) is connected with the output ends of the oil sample inlet end control valves (3) and (6);
the formation simulation system includes: the device comprises a pressure controller (9), a core holder (12), a back pressure valve (17), a confining pressure tracking pump (27), a pressure control pump (23), a back pressure control pump (25), a fourth pressure gauge (11), a fifth pressure gauge (13), a sixth pressure gauge (15), a seventh pressure gauge (19), an eighth pressure gauge (22), a ninth pressure gauge (24) and a tenth pressure gauge (26); the pressure controller (9) is connected with the inlet end of the core holder (12); the confining pressure tracking pump (27) is connected with the confining pressure control valve (14); the pressure control pump is connected with a pressure control valve (9); the back pressure control pump is connected with a back pressure valve (17);
the metering system comprises: an oil-gas separator (29), an oil meter (30), a gas flow meter control valve (31) and a gas flow meter (32); wherein: one end of the oil-gas separator (29) is connected with an oil metering meter (30), and the other end is connected with a gas flowmeter control valve (31); the gas flowmeter control valve (31) is connected with the gas flowmeter (32);
the injection system is connected with the input end of the stratum simulation system; and the output end of the stratum simulation system is connected with the input end of the metering system.
A test method for improving the gas injection precision of a low-permeability reservoir core is provided, which adopts a test device for improving the gas injection precision of the low-permeability reservoir core and comprises the following steps:
s1: preparing a core for testing and fluid;
s2: establishing a gas-driven fluid model, and controlling an injection system to convey oil gas quantity to a stratum simulation system according to parameters obtained by the model;
s3: the pressure controller (9) sets a pressure value higher than the highest displacement pressure, and gas is injected into the rock core at a constant speed;
s4: every 0.05 times of pore volume change, record injection time, pump reading, ambient temperature and pressure, displacement pressure, back pressure, ring pressure, gas and oil;
s5: and drawing a relation graph of the pore volume relative to the injection time value, and judging the metering accuracy of the gas injection quantity by observing the change rate of the pore volume.
The step S1 comprises the following sub-steps:
s11: washing oil, drying and testing porosity and air permeability of the rock core;
s12: ordering the cores according to the Brad rule, and loading the cores into a core holder 12 for sealing;
s13: preparing stratum water compatible with stratum mineralization degree;
s14: sampling the water injected into the target block, filtering and measuring the water quality;
s15: degassing oil in a high-temperature high-pressure kettle, and sealing and filtering;
s16: the physical properties of crude oil were measured by preparing a formation fluid according to GB/T26981-2011 "analysis method for physical properties of reservoir fluid".
In step S12, the sealing is performed with high-pressure nitrogen.
The beneficial effects of the invention are as follows: the invention provides a method for improving the accuracy of gas injection by considering the defect that the gas has stronger compressibility and thus inaccurate gas injection amount measurement, and provides a method for arranging a pressure controller at the front end of the inlet of a core holder, thereby improving the accuracy of gas injection amount measurement and providing reliable data support for later economic evaluation and development scheme design.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings that are required in the embodiments or the description of the prior art will be briefly described, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and other drawings may be obtained according to the structures shown in these drawings without inventive effort for a person skilled in the art.
FIG. 1 is a schematic diagram of an apparatus of the present invention;
FIG. 2 is a graph showing the comparison of the present invention with the pre-calibration method.
In the figure: 1-high temperature and high pressure plunger displacement pump oil sample, 3, 6-oil sample inlet end control valve, 4-high temperature and high pressure plunger displacement pump gas sample, 2-first pressure gauge, 5-second pressure gauge, 8-third pressure gauge, 11-fourth pressure gauge, 13-fifth pressure gauge, 15-sixth pressure gauge, 19-seventh pressure gauge, 22-eighth pressure gauge, 24-ninth pressure gauge, 26-tenth pressure gauge, 7-injection end control master valve, 9-pressure controller, 12-core holder, 14-confining pressure control valve, 17-back pressure valve, 23-pressure control pump, 25-back pressure control pump, 27-confining pressure tracking pump, 10-first control valve, 16-second control valve, 18-third control valve, 20-fourth control valve, 21-fifth control valve, 28-sixth control valve, 29-oil separator, 30-oil meter, 31-gas flow control valve, 32-gas flow meter;
the achievement of the objects, functional features and advantages of the present invention will be further described with reference to the accompanying drawings, in conjunction with the embodiments.
Detailed Description
The technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings.
As shown in fig. 1, a device for improving the accuracy testing method of the gas injection amount of a low permeability reservoir core, the accuracy testing device comprises: an injection system, a formation simulation system, and a metering system; wherein:
the injection system includes: the high-temperature high-pressure plunger displacement pump comprises a high-temperature high-pressure plunger displacement pump oil sample (1), oil sample inlet end control valves (3) and (6), a high-temperature high-pressure plunger displacement pump gas sample (4) and an injection end control main valve (7); the high-temperature high-pressure plunger displacement pump oil sample (1) is connected with an oil sample inlet end control valve (3); the high-temperature high-pressure plunger displacement pump gas sample (4) is connected with an oil sample inlet end control valve (6); the injection end control main valve (7) is connected with the output ends of the oil sample inlet end control valves (3) and (6);
the formation simulation system includes: a pressure controller (9), a core holder (12), a back pressure valve (17), a confining pressure tracking pump (27), a pressure control pump (23), a back pressure control pump (25) and pressure gauges (11), (13), (15), (19), (22), (24), (26); the pressure controller (9) is connected with the inlet end of the core holder (12); the confining pressure tracking pump (27) is connected with the confining pressure control valve (14); the pressure control pump is connected with a pressure control valve (9); the back pressure control pump is connected with a back pressure valve (17);
the metering system comprises: an oil-gas separator (29), an oil meter (30), a gas flow meter control valve (31) and a gas flow meter (32); wherein: one end of the oil-gas separator (29) is connected with an oil metering meter (30), and the other end is connected with a gas flowmeter control valve (31); the gas flowmeter control valve (31) is connected with the gas flowmeter (32).
The injection system is connected with the input end of the stratum simulation system; and the output end of the stratum simulation system is connected with the input end of the metering system.
The test method for improving the gas injection accuracy of the low permeability reservoir core comprises the following steps:
s1: preparing a core for testing and fluid;
s2: establishing a gas-driven fluid model, and controlling an injection system to convey oil gas quantity to a stratum simulation system according to parameters obtained by the model;
s3: the pressure controller (9) sets a pressure value higher than the highest displacement pressure, and gas is injected into the rock core at a constant speed;
s4: every 0.05 times of pore volume change, record injection time, pump reading, ambient temperature and pressure, displacement pressure, back pressure, ring pressure, gas and oil;
s5: and drawing a relation graph of the pore volume relative to the injection time value, and judging the metering accuracy of the gas injection quantity by observing the change rate of the pore volume.
The step S1 comprises the following sub-steps:
s11: washing oil, drying and testing porosity and air permeability of the rock core;
s12: ordering the cores according to the Brad rule, and loading the cores into a core holder 12 for sealing;
s13: preparing stratum water compatible with stratum mineralization degree;
s14: sampling the water injected into the target block, filtering and measuring the water quality;
s15: degassing oil in a high-temperature high-pressure kettle, and sealing and filtering;
s16: the physical properties of crude oil were measured by preparing a formation fluid according to GB/T26981-2011 "analysis method for physical properties of reservoir fluid".
In step S12, the sealing is performed with high-pressure nitrogen.
In order to further understand the actual data change of the test method for improving the gas injection accuracy of the low permeability reservoir core, referring to table 1, table 1 is the data comparison of the injection times and time of the method for correcting the low permeability reservoir core.
Table 1, data comparing the injection times and time of the present invention with the pre-correction method
As shown in the table, the pore volume of hydrocarbons using the test method of the present invention increased at 0.0597 (HCPV) per hour at the same displacement pressure.
In order to further observe the effect change of the test method for improving the gas injection accuracy of the low permeability reservoir core, which is provided by the invention, reference is made to fig. 2, and fig. 2 is a comparison curve of the method and the pre-correction method.
As shown in fig. 2, the horizontal axis represents injection time, the vertical axis represents injected hydrocarbon pore volume multiple, the circular curve represents the hydrocarbon pore volume multiple variation trend of the test method of the present invention, the triangular curve represents the early correction injected hydrocarbon pore volume multiple variation trend, the circular curve is approximately a straight line, the triangular curve is an uneven broken line, and the precision of the test method of the present invention in injection multiple and injection time can be improved by 5% compared with the early correction method at the same injection speed.
Claims (2)
1. An improve low permeability reservoir rock core gas injection volume precision testing arrangement, its characterized in that solves because the compressibility that gas had leads to injecting the inaccurate technical problem of tolerance measurement, precision testing arrangement includes: an injection system, a formation simulation system, and a metering system; wherein:
the injection system includes: the high-temperature high-pressure plunger displacement pump comprises a high-temperature high-pressure plunger displacement pump oil sample (1), an oil sample inlet end control valve (3), a gas sample inlet end control valve (6), a high-temperature high-pressure plunger displacement pump gas sample (4) and an injection end control main valve (7); the high-temperature high-pressure plunger displacement pump oil sample (1) is connected with an oil sample inlet end control valve (3); the high-temperature high-pressure plunger displacement pump gas sample (4) is connected with a gas sample inlet end control valve (6); the injection end control main valve (7) is connected with the output ends of the oil sample inlet end control valve (3) and the gas sample inlet end control valve (6);
the formation simulation system includes: the device comprises a pressure controller (9), a core holder (12), a back pressure valve (17), a confining pressure tracking pump (27), a pressure control pump (23), a back pressure control pump (25), a fourth pressure gauge (11), a fifth pressure gauge (13), a sixth pressure gauge (15), a seventh pressure gauge (19), an eighth pressure gauge (22), a ninth pressure gauge (24) and a tenth pressure gauge (26); the pressure controller (9) is connected with the inlet end of the core holder (12); the confining pressure tracking pump (27) is connected with the confining pressure control valve (14); the pressure control pump is connected with a pressure controller (9); the back pressure control pump is connected with a back pressure valve (17);
the metering system comprises: an oil-gas separator (29), an oil meter (30), a gas flow meter control valve (31) and a gas flow meter (32); wherein: one end of the oil-gas separator (29) is connected with an oil metering meter (30), and the other end is connected with a gas flowmeter control valve (31); the gas flowmeter control valve (31) is connected with the gas flowmeter (32);
the injection system is connected with the input end of the stratum simulation system; the stratum simulation system output end is connected with the metering system input end;
a testing method realized by a testing device for improving the gas injection quantity precision of a low permeability reservoir core comprises the following steps:
s1: preparing a core for testing and fluid;
s2: establishing a gas-driven fluid model, and controlling an injection system to convey oil gas quantity to a stratum simulation system according to parameters obtained by the model;
s3: the pressure controller (9) sets a pressure value higher than the highest displacement pressure, and gas is injected into the rock core at a constant speed;
s4: every 0.05 times of pore volume change, record injection time, pump reading, ambient temperature and pressure, displacement pressure, back pressure, ring pressure, gas and oil;
s5: drawing a relation graph of pore volume relative to injection time value, and judging the metering accuracy of the gas injection amount by observing the change rate of the pore volume;
step S1 comprises the following sub-steps:
s11: washing oil, drying and testing porosity and air permeability of the rock core;
s12: ordering the cores according to the Brad rule, and loading the cores into a core holder (12) for sealing;
s13: preparing stratum water compatible with stratum mineralization degree;
s14: sampling the water injected into the target block, filtering and measuring the water quality;
s15: degassing oil in a high-temperature high-pressure kettle, and sealing and filtering;
s16: preparing stratum fluid according to GB/T26981-2011 'analysis method of physical Properties of oil and gas reservoir fluid', and measuring physical properties of crude oil;
in step S12, the sealing is performed with high-pressure nitrogen gas.
2. A method for improving the accuracy of the gas injection amount of a low-permeability reservoir core, which adopts the device for improving the accuracy of the gas injection amount of the low-permeability reservoir core according to claim 1, and is characterized by comprising the following steps:
s1: preparing a core for testing and fluid;
s11: washing oil, drying and testing porosity and air permeability of the rock core;
s12: ordering the cores according to the Brad rule, and loading the cores into a core holder (12) for sealing; sealing with high-pressure nitrogen in step S12;
s13: preparing stratum water compatible with stratum mineralization degree;
s14: sampling the water injected into the target block, filtering and measuring the water quality;
s15: degassing oil in a high-temperature high-pressure kettle, and sealing and filtering;
s16: preparing stratum fluid according to GB/T26981-2011 'analysis method of physical Properties of oil and gas reservoir fluid', and measuring physical properties of crude oil;
s2: establishing a gas-driven fluid model, and controlling an injection system to convey oil gas quantity to a stratum simulation system according to parameters obtained by the model;
s3: the pressure controller (9) sets a pressure value higher than the highest displacement pressure, and gas is injected into the rock core at a constant speed;
s4: every 0.05 times of pore volume change, record injection time, pump reading, ambient temperature and pressure, displacement pressure, back pressure, ring pressure, gas and oil;
s5: and drawing a relation graph of the pore volume relative to the injection time value, and judging the metering accuracy of the gas injection quantity by observing the change rate of the pore volume.
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